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Home My WebLink About181-173MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-11 KUPARUK RIV UNIT 1A-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 1A-11 50-029-20685-00-00 181-173-0 W SPT 5999 1811730 1500 2190 2190 2190 2190 40 40 40 40 INITAL P Bob Noble 8/25/2024 Post Rig Workover 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1A-11 Inspection Date: Tubing OA Packer Depth 660 2890 2800 2800IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240827112246 BBL Pumped:2 BBL Returned:1.9 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 99 9 9 9 9 9 99 9 9 9 7HVWZDVGXHZHOOZDV6,DIWHU IDLOLQJGLDJQRVWLFVLQ-XO\-5HJJ James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 12:47:12 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9732'feet None feet true vertical 6703' feet 9224', 9346'feet Effective Depth measured 9221'feet 8718', 8990'feet true vertical 6344'feet 5999', 6180'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 L-80 8693' 9038' 5983' 6213' Packers and SSSV (type, measured and true vertical depth)8718' 8990' 5999' 6180' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 324-340/324-249 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: Blue Pack Max Packer: Blue Pack Max SSSV: None James Ohlinger james.j.ohlinger@conocophillips.com (907) 267-1102Staff RWO/CTD Engineer 8878-8918', 8930-8938', 9082-9095', 9108-9150' 6104-6131', 6139-6144', 6245-6254', 6263-6294' 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 114' 1593 750N/A Well Shut-In 2205 measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 181-173 50-029-20685-00-00 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: ADL0025647 Kuparuk River Field/ Kuparuk Oil Pool KRU 1A-11 Plugs Junk measured Length Production 1938' 9682' Casing 1795' 6690' 1966' 9713' 2915' 114'Conductor Surface Tie-Back 16" 10-3/4" 80' 2947' 2425' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E= James.J.Ohlinger@cop.com Reason: I am the author of this document Location: Date: 2024.08.21 15:07:26-08'00' Foxit PDF Editor Version: 13.0.0 James J. Ohlinger By Grace Christianson at 3:19 pm, Aug 21, 2024 Page 1/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/1/2024 22:00 6/1/2024 23:00 1.00 MIRU, MOVE MOB P PJSM w/ rig crew on moving rig. Warm up moving system. Pull sub off of well. 6/1/2024 23:00 6/2/2024 00:00 1.00 MIRU, MOVE MOB P P/U rig mats 6/2/2024 00:00 6/2/2024 00:45 0.75 MIRU, MOVE MOB P P/U berming. Clean up pad and area around cellar. 6/2/2024 00:45 6/2/2024 05:00 4.25 MIRU, MOVE MOB P Move rig from 2T pad to 2B pad 6/2/2024 05:00 6/2/2024 06:00 1.00 MIRU, MOVE MOB P Hold for field change out. 6/2/2024 06:00 6/2/2024 16:00 10.00 MIRU, MOVE MOB P Move rig from 2B pad to 1A pad. 6/2/2024 16:00 6/3/2024 00:00 8.00 MIRU, MOVE MOB P Spread Herculite. Lay rig mats. Crew C/O. Berm in rig. Stage Support Equipment (Welding Shop, High Line trailer, Mud Shack, Smoke Shack, Parts van). 6/21/2024 12:00 6/21/2024 23:30 11.50 MIRU, WELCTL RURD P Spot on 1A-11. Safe out rig, Work acceptance check list. Set cuttings box. Start taking on fluid. Cameron opened up SSV. Take on 9.7 PPG brine. Build 40 Bbls deep clean pill. R/U circ manifold. KDTH R/U tiger tank & hard line. Take initial pressures T/I/O = 750/1775/80. Take initial RKB's. 0.0 0.0 6/21/2024 23:30 6/22/2024 00:00 0.50 MIRU, WELCTL PRTS P Flood lines. PT circ manifold & TT line T/ 2500 PSI. 0.0 0.0 6/22/2024 00:00 6/22/2024 03:30 3.50 MIRU, WELCTL KLWL P Bleed free gas off IA from 1700 PSI to 380 PSI. Kill well pumping downTBG @ 3-4 BPM. Pump 32 Bbls deep clean pill followed by 9.7 PPG brine. Pump total of 490 Bbls. Clean 9.7 PPG returns to surface. 0.0 0.0 6/22/2024 03:30 6/22/2024 04:30 1.00 MIRU, WELCTL OWFF P OWFF - no flow at tank. B/D TBG & IA lines. OWFF 30 Min no flow. 0.0 0.0 6/22/2024 04:30 6/22/2024 04:30 MIRU, WELCTL RURD P Pull tree cap. Set HP BPV. 0.0 0.0 6/22/2024 04:30 6/22/2024 05:00 0.50 MIRU, WHDBOP PRTS P PT BPV T/ 1000 PSI from below for 10 Min. 0.0 0.0 6/22/2024 05:00 6/22/2024 06:30 1.50 MIRU, WHDBOP RURD P Blow down IA line and circulating line. Blow down tubing land blooie line. R/D circ equipment and squeeze manifold 0.0 0.0 6/22/2024 06:30 6/22/2024 08:30 2.00 MIRU, WHDBOP NUND P PJSM, on nipple down. Nipple down tree and adapter, lay down. M/U DSA. Install test dart 0.0 0.0 6/22/2024 08:30 6/22/2024 13:00 4.50 MIRU, WHDBOP NUND P PJSM. Nipple up BOPE, Remove stack from stand. Install on DSA, Torque all bolts. Hook up to Koomy hoses. Get RKB's 0.0 0.0 6/22/2024 13:00 6/22/2024 17:00 4.00 MIRU, WHDBOP NUND P Open up upper doors. Install 2 7/8" X 5 1/2" VBR's. Open lower doors on dbl gate. Install blind rams. 0.0 0.0 6/22/2024 17:00 6/22/2024 21:00 4.00 MIRU, WHDBOP NUND P Charge up Koomy, Funcyion test BOPE. Reconfigure new trip tank hose. 0.0 0.0 6/22/2024 21:00 6/22/2024 22:30 1.50 MIRU, WHDBOP RURD P Install test joint. Flood BOPE w/ fresh water. Shell test. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 2/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/22/2024 22:30 6/23/2024 00:00 1.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, w/ 3 1/2" test joints. Choke valves #4, #11, #12. Upper top drive well control valves. Test 3 1/2" IF FOSV. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test inner 2 1/6" gate auxiliary valves below LPR. Test gas detectors, Witness waived by AOGCC rep Sully Sullivan. 0.0 0.0 6/23/2024 00:00 6/23/2024 10:30 10.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested UVBR's, LVBRs w/ 3 1/2" test joints. Test blinds rams. Choke valves #1 to #3, #5-#10, #13. Lower top drive well control valves. Test 3 1/2" IF IBOP. Test 3 ½ EUE FOSV. Test manual and HCR kill valves & manual and HCR choke valves. Test outer 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Test PVT and flow show. Witness waived by AOGCC rep Sully Sullivan. 0.0 0.0 6/23/2024 10:30 6/23/2024 11:00 0.50 MIRU, WHDBOP RURD P Blow down rig lines, Drain stack. Hang T -Bar, Rig down test equipment 0.0 0.0 6/23/2024 11:00 6/23/2024 12:00 1.00 MIRU, WHDBOP MPSP P Pull test dart. Pull BPV. Fluid level good Swap out elevators, P/U 3 1/2" landing joint 0.0 0.0 6/23/2024 12:00 6/23/2024 13:00 1.00 COMPZN, RPCOMP THGR P M/U landing joint set down 10K. BOLDS. Pull hanger. Worked cut @ 148K 8 times. Staged pumps up 1 Bbls at a time T/ 4 BPM. Pipe free. Pull hanger T/ RF. Pull F/ 8777' T/ 8744'. PUW dragging 125K 8,777.0 8,744.0 6/23/2024 13:00 6/23/2024 14:42 1.70 COMPZN, RPCOMP CIRC P Circulate Bottoms up 3 BPM @290 PSI, 250 BBls. No gas or fluid loss 8,744.0 8,744.0 6/23/2024 14:42 6/23/2024 15:00 0.30 COMPZN, RPCOMP OWFF P Monitor well for flow 8,744.0 8,744.0 6/23/2024 15:00 6/23/2024 16:00 1.00 COMPZN, RPCOMP PULD P Lay down landing join t, Lay down hanger. M/U control line to spooler 8,744.0 8,744.0 6/23/2024 16:00 6/23/2024 20:30 4.50 COMPZN, RPCOMP PULD P Lay down 3 1/2" completion F/ 8744' T/ 7602'. Moving SSSV F/ 1905' T/ 730', PUW=105K, SOW=56K @ 7602'. 22 SS bands recovered. Secure control line above collar on joint #38 w/ 6 new SS bands. RIH w/ joint # 37 T/ 7632'. 8,744.0 7,632.0 6/23/2024 20:30 6/23/2024 21:30 1.00 COMPZN, RPCOMP BHAH P Mobiilize & M/U BHA #1. 6" sting mill on top of joint 37 7,632.0 7,632.0 6/23/2024 21:30 6/23/2024 22:00 0.50 COMPZN, RPCOMP SVRG P Service rig grease TD. 7,632.0 7,632.0 6/23/2024 22:00 6/24/2024 00:00 2.00 COMPZN, RPCOMP PULD P PUDP to drift 7" w/ BHA #1 T/ 832', SOW=55-62K. 7,632.0 8,431.0 6/24/2024 00:00 6/24/2024 00:30 0.50 COMPZN, RPCOMP SFTY P Run TD up through derrick. Link out elevators. Inspect derrick for clearance. Set COM. 8,431.0 8,431.0 6/24/2024 00:30 6/24/2024 03:00 2.50 COMPZN, RPCOMP TRIP P POOH racking back DP F/ 8431' T/ 7632', PUW-125-130K. 8,431.0 7,632.0 6/24/2024 03:00 6/24/2024 03:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #1 6" sting mill. 7,632.0 7,632.0 6/24/2024 03:30 6/24/2024 03:45 0.25 COMPZN, RPCOMP RURD P R/U tubing handling equipment. 7,632.0 7,632.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 3/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/24/2024 03:45 6/24/2024 04:00 0.25 COMPZN, RPCOMP PULL P L/D 3 1/2" completion F/ 7632' T/ 7602', PUW=105K. Connect control line to spooler. Recovered 6 SS bands. Line severed below bands. No control line. 7,632.0 7,602.0 6/24/2024 04:00 6/24/2024 05:00 1.00 COMPZN, RPCOMP PULL P Cont L/D 3 1/2" completion dPulled heavy from 7632 125K. Up to 150K @ 7528'. Consult town, decision made to RIH on original completion string set down on cut. R/U E-line. Make Chem cut above SSSV to expose SS control line to be fished. 7,602.0 7,528.0 6/24/2024 05:00 6/24/2024 08:00 3.00 COMPZN, RPCOMP RURD P Load completion back into shed, 39 Jts, C/O lower dyes on tubing tongs . Prep floor to run pipe 7,528.0 7,528.0 6/24/2024 08:00 6/24/2024 10:00 2.00 COMPZN, RPCOMP PULD P Run completion back to cut @ 8777, 39 original Jts one Jt EUE Rabbit 2.87 on the fly. PUW=125, SOW-62K on bottom. Install 3 1/2" FOSV 7,528.0 8,777.0 6/24/2024 10:00 6/24/2024 13:00 3.00 COMPZN, RPCOMP WAIT P E-Line in route. Had to make up chem cutter in Deadhorse 8,777.0 8,777.0 6/24/2024 13:00 6/24/2024 14:00 1.00 COMPZN, RPCOMP ELNE P E-Line on location. PJSM. MIRU Pollard E-Line. Pump 30 BBls 9.7PPG warm water from pits to warm up cut interval. 3 BBL/Min @ 330 PSI 0.0 0.0 6/24/2024 14:00 6/24/2024 15:00 1.00 COMPZN, RPCOMP ELNE P RIH w/Eline. Correlate -4' correction. Cut @ 1891'. ~16' above SSSV. Good indication of fire. Relax tool for 15 min. 0.0 0.0 6/24/2024 15:00 6/24/2024 16:00 1.00 COMPZN, RPCOMP ELNE P POOH with E-Line, Lay down EL tools, Get E-line sheave off blocks 0.0 0.0 6/24/2024 16:00 6/24/2024 17:00 1.00 COMPZN, RPCOMP PULD P Latch up to 3 1/2 tubing, PUW=52k. Made cut. POOH with 3 1/2 completion F /1891 T surface. Checking for control line. 1,891.0 1,129.0 6/24/2024 17:00 6/24/2024 19:00 2.00 COMPZN, RPCOMP OTHR P RWO rig appreciation event 1,129.0 1,129.0 6/24/2024 19:00 6/24/2024 21:30 2.50 COMPZN, RPCOMP PULD P Continue out of well, F /1129 to surface, PUW=54K, Pulled 59 and 1/2 joint from well. No control line recovered. 1/2 joint out of hole 14.78' long 1,129.0 0.0 6/24/2024 21:30 6/24/2024 22:30 1.00 COMPZN, RPCOMP BHAH P Prep for DP ops, Lay down Eckel. P/U Spinners and rig tongs. M/U BHA #2 Crank shaft spear, Bumper sub, and 4.75 fishing jar 0.0 33.6 6/24/2024 22:30 6/25/2024 00:00 1.50 COMPZN, RPCOMP TRIP P RIH BHA #2, Set down @ 135'. Off Bales. POOH inspect BHA;. No visisable marks on disk. No control line. 33.6 135.0 6/25/2024 00:00 6/25/2024 00:30 0.50 COMPZN, RPCOMP TRIP P RIH T/ 135'. Took weight pipe out of elevators. K/U Rotate a couple turns. Pushed down T/ 140'. 0.0 140.0 6/25/2024 00:30 6/25/2024 01:00 0.50 COMPZN, RPCOMP SVRG P POOH, no over pull. Trouble getting broke out of top of stand. Service rig inspect grabber block on TD. 140.0 122.0 6/25/2024 01:00 6/25/2024 01:30 0.50 COMPZN, RPCOMP TRIP P POOH in inspect crank shaft spear. No control one. 122.0 0.0 6/25/2024 01:30 6/25/2024 03:30 2.00 COMPZN, RPCOMP TRIP P RIH w/ BHA #2. Push through spot @ 135' & Rot & push through spot F/ 672'. Mobilize 776 lube to pits and begin to lube up system. T/896', No SOW 0.0 896.0 6/25/2024 03:30 6/25/2024 04:00 0.50 COMPZN, RPCOMP CIRC P Pump 1% 776 lube 9.7 PPG brine around. 896.0 896.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 4/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/25/2024 04:00 6/25/2024 07:30 3.50 COMPZN, RPCOMP PULD P PUDP w/ BHA #2 Pump @ 2 BPM, 131 PSI. Rot 10 RPM, 3K Tq SOW=40K. F/ 896' T/ 1174'. Pump in hole w/ no rotation F/ 1174' T/ 1885', Set down 10K. SOW=47K 896.0 1,885.0 6/25/2024 07:30 6/25/2024 08:00 0.50 COMPZN, RPCOMP FISH P P/U 5' ROT @ 5 RPM, down to 1885'. Tq increase T/ 3.6k on bottom. Kill rotation. P/U no over pull. 1,885.0 1,885.0 6/25/2024 08:00 6/25/2024 09:00 1.00 COMPZN, RPCOMP TRIP P POOH racking back F/ 1885' T/ 65', PUW=71K. 1,885.0 65.0 6/25/2024 09:00 6/25/2024 11:30 2.50 COMPZN, RPCOMP BHAH P Pull BHA T/ RF. Control line recovered & 6 SS bands. Cut control line off of spear. Total weight of control line ~60# =577'. 65.0 0.0 6/25/2024 11:30 6/25/2024 12:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 6/25/2024 12:00 6/25/2024 12:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #3 crank shaft spear without jars & bumper sub T/ 13' 0.0 13.0 6/25/2024 12:30 6/25/2024 13:30 1.00 COMPZN, RPCOMP TRIP P RIH w/ BHA #3 T/ 1885', PUW=69K, SOW=49K. 13.0 1,885.0 6/25/2024 13:30 6/25/2024 14:30 1.00 COMPZN, RPCOMP FISH P P/U 5' ROT @ 5 RPM, down to 1885'. Tq increase T/ 3.3K on bottom. Repeat got down inside tubing T/ 1888' Kill rotation. P/U no over pull. 1,885.0 1,888.0 6/25/2024 14:30 6/25/2024 15:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 1888' T/ 33'. PUW=69K. 1,888.0 33.0 6/25/2024 15:30 6/25/2024 16:15 0.75 COMPZN, RPCOMP BHAH P Pull BHA above floor. Control line recovered & 2 SS bands. Cut control line off of spear. Total weight of control line ~15# = 144'. 33.0 0.0 6/25/2024 16:15 6/25/2024 16:45 0.50 COMPZN, RPCOMP BHAH P MU BHA #4 crank shaft spear without jars & bumper sub T/ 13'. 0.0 13.0 6/25/2024 16:45 6/25/2024 18:00 1.25 COMPZN, RPCOMP TRIP P TIH w/ BHA and attempt to recover remaining control line. 13.0 1,888.0 6/25/2024 18:00 6/25/2024 18:45 0.75 COMPZN, RPCOMP TRIP P TOOH w/ crank shaft spear. 1,888.0 13.0 6/25/2024 18:45 6/25/2024 19:15 0.50 COMPZN, RPCOMP BHAH P L/D BHA #4 (crank shaft spear). Clean. No control line recovered. 13.0 0.0 6/25/2024 19:15 6/25/2024 20:00 0.75 COMPZN, RPCOMP BHAH P MU BHA #5 (RCJB w/ 20' washpipe extension). 0.0 28.0 6/25/2024 20:00 6/25/2024 23:30 3.50 COMPZN, RPCOMP TRIP P TIH and attempt to drift BHA #5 through tight spots (dummy SSSV drift). Tag at 121'. PU. Obtain paramters. Rotate @ 10 RPM. Pump down @ 2 BPM and 113 psi, circulating from Pit #4 (1% Lube 776). Torque @ avg of 2K Ft-lbs. Slowly work down through tight spots. Sticky at approx. 700' tight spot. Cleaned up below. Limited torque to max of 4K to mitigate washpipe risks. PUW = 60K. SOW = 40K. Cont. TIH to top of tubing stub @ 1,888'. Tag top of stub @ 1,887'. Set 5K down. 28.0 1,887.0 6/25/2024 23:30 6/26/2024 00:00 0.50 COMPZN, RPCOMP WASH P PU. Screw in TD. Obtain parameters. PUW = 65K. SOW = 45K. Pump Rate 7.5 BPM @ 1,537 psi. 10 RPM. Free Torque = 1.5K. TIH and attempt to swallow tubing stub. Set 5K down. Made various adjustments to pump rates and RPM's to swallow stub. Saw minimal torque or pressure indicators. Repeatedly tagged at 1,887'. Cont. to make attempts to swallow stub. 1,887.0 1,887.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 5/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/26/2024 00:00 6/26/2024 00:30 0.50 COMPZN, RPCOMP WASH P Cont. attempting to swallow tubing stub. PU to 1,881'. Obtain parameters. 45 RPM. Free Torque = 1.8K. Pump rate @ 7.5 BPM / 1434 psi. TIH to 1,887'. Set 5K down. Torque 2.2K. Set 10K down. Saw brief 4K torque spike. PU. Made additional attempts to swallow stub. Unable to get over stub. Acting like we are spinning on something. Minimal torque response. 1,887.0 1,887.0 6/26/2024 00:30 6/26/2024 01:30 1.00 COMPZN, RPCOMP CIRC P Pump 20 bbl hi-vis pill. Circ. pill out with 1% Lube 776 from Pit #4. 1,887.0 1,887.0 6/26/2024 01:30 6/26/2024 02:45 1.25 COMPZN, RPCOMP TRIP P TOOH w/ BHA #5 (RCJB + 20' washpipe). Inspect BHA. Found washpipe backed off or popped off connection on bottom of RCJB. Fish Details LIH (Bottom to Top): 5 3/4" OD x 5" ID x 2.15' long Cut Lip Shoe + 5 3/4" OD x 5" ID x 17.37' Wash Pipe + 5 3/4" OD x 5" ID x 2.01' XO Bushing. Total Length LIH = 21.53'. No signficant thread damage on bottom of RCJB. Recovered pieces of broken RCJB basket body and retainer ring. 1,887.0 28.0 6/26/2024 02:45 6/26/2024 04:15 1.50 COMPZN, RPCOMP BHAH P L/D BHA #5. Discuss BHA options with Baker to fish wash pipe and RCJB debris. 28.0 0.0 6/26/2024 04:15 6/26/2024 07:30 3.25 COMPZN, RPCOMP WAIT T Wait on Baker Fishing tools to arrive from Deadhorse (Taper Tap, ITCO Spear, RCJB). While waiting on tools flood lines and PT hardline out to tanks. 0.0 0.0 6/26/2024 07:30 6/26/2024 08:00 0.50 COMPZN, RPCOMP RURD P Movilize BHA #6 T/ RF. Discuss options with Baker fishing. 0.0 0.0 6/26/2024 08:00 6/26/2024 08:30 0.50 COMPZN, RPCOMP SFTY P PJSM w/ Baker & rig crew on M/U BHA and fish washpipe. 0.0 0.0 6/26/2024 08:30 6/26/2024 09:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #6 taper tap, 1 JT DP, jars & bumper sub T/ 56' 0.0 56.0 6/26/2024 09:30 6/26/2024 10:45 1.25 COMPZN, RPCOMP TRIP P RIH F/ 56'. Lost string weight @ 132'. K/U push through bad spot. RIH T/ 1814', PUW=68K, SOW=50K. 56.0 1,814.0 6/26/2024 10:45 6/26/2024 11:15 0.50 COMPZN, RPCOMP FISH P K/U RIH set down on fish top @ 1866'. Set 20K down. P/U. Repeate 3 times. PUW-69K. 1,814.0 1,866.0 6/26/2024 11:15 6/26/2024 12:45 1.50 COMPZN, RPCOMP TRIP P POOH F/ 1866' T/ 56'. PUW=69K.. 1,866.0 56.0 6/26/2024 12:45 6/26/2024 13:30 0.75 COMPZN, RPCOMP BHAH P L/D BHA #6. No fish. Metal and brass wickers in taper tap. 56.0 0.0 6/26/2024 13:30 6/26/2024 14:00 0.50 COMPZN, RPCOMP ELNE P R/U YJOC E-line w/ 40 arm caliper & CCL. 0.0 0.0 6/26/2024 14:00 6/26/2024 15:00 1.00 COMPZN, RPCOMP ELOG P RIH T/ 1400'. Log to surface. 0.0 0.0 6/26/2024 15:00 6/26/2024 16:00 1.00 COMPZN, RPCOMP ELNE P L/D 40 arm caliper. M/U Baker 3 3/8" IBP run on YJOC. 0.0 0.0 6/26/2024 16:00 6/26/2024 18:45 2.75 COMPZN, RPCOMP ELNE P RIH w/ 3 3/8" IBP. Set IBP @ 1,226' (COE). Took approx. 64 minutes to inflate and shear off. Set down on IBP to confirm good set. Top of IBP @ 1,220'. Bottom of IBP @ 1230.5'. POOH. Standback E-line. 0.0 0.0 6/26/2024 18:45 6/26/2024 19:00 0.25 COMPZN, RPCOMP RURD P RU pressure testing equipment to PT IBP through kill line w/ sensator. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 6/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/26/2024 19:00 6/26/2024 20:00 1.00 COMPZN, RPCOMP PRTS P Close blinds. PT IBP to 1,000 psi for 10 -min. Took 11 strokes to pressure up. Charted. Bleed off. Open blinds. Release E-line after a good test. 0.0 0.0 6/26/2024 20:00 6/26/2024 20:30 0.50 COMPZN, RPCOMP MPSP P Set test plug (yellow for old tubing head). 0.0 0.0 6/26/2024 20:30 6/26/2024 21:30 1.00 COMPZN, RPCOMP BOPE P C/O LPR's to 7" Fixed. Open OA to tiger to bleed off any potential gas. 0.0 0.0 6/26/2024 21:30 6/26/2024 22:30 1.00 COMPZN, RPCOMP RURD P PU 7" Donut TJ and CPAI XO# 090 (7" BTC x 3 1/2" IF). Install TJ across stack w/ 3 1/2" IF Floor valve. Close LPR against TJ. Install hose and sensator at test spool. 0.0 0.0 6/26/2024 22:30 6/27/2024 00:00 1.50 COMPZN, RPCOMP BOPE P PT 7" rams to 250/2500 psi for 5-min. Found 7" x 3 1/2" IF XO leaking. Clean up, tighten, and re-test. XO holding. 3 1/2" IF Floor Valve holding. Troubleshoot CM valves for leak. Purge air. Re-test. Charted. Passed. Bleed off. 0.0 0.0 6/27/2024 00:00 6/27/2024 01:00 1.00 COMPZN, RPCOMP RURD P R/D pressure testing equipment. L/D 7" donut test joint. Drain stack. Pull test plug. 0.0 0.0 6/27/2024 01:00 6/27/2024 01:30 0.50 COMPZN, RPCOMP OWFF P OWFF. Open up IA and OA for 30-min to confirm no flow (0 psi and no gas). 0.0 0.0 6/27/2024 01:30 6/27/2024 03:00 1.50 COMPZN, RPCOMP NUND P ND BOP. 0.0 0.0 6/27/2024 03:00 6/27/2024 08:30 5.50 COMPZN, RPCOMP CUTP P M/U Cameron tensioning tool and plate to tubing head. BOLDS. Allow casing to grow. Total growth = 29.5". Initial Compression Force= 180K after first growth cycle of 4". 30 Min wait period. R/D Cameron tensioning tool. 0.0 0.0 6/27/2024 08:30 6/27/2024 09:00 0.50 COMPZN, RPCOMP CUTP P Remove old Tubing Head. . 0.0 0.0 6/27/2024 09:00 6/27/2024 12:00 3.00 COMPZN, RPCOMP CUTP P MU BHA #7 (7" casing spear). Run on 1 Joint of DP. Engage 7" casing. Pull 50K to stretch casing. Total stretch = 7". Set 7" Slips. L/D spear. Cut 7" stub with Wachs. Install pack-off. 0.0 0.0 6/27/2024 12:00 6/27/2024 13:45 1.75 COMPZN, RPCOMP NUND P N/U new Tubing head. Install secondary IA valve. 0.0 0.0 6/27/2024 13:45 6/27/2024 14:15 0.50 COMPZN, RPCOMP PRTS P PT pack off T/ 3000 PSI for 15 Min. Install test plug. 0.0 0.0 6/27/2024 14:15 6/27/2024 17:45 3.50 COMPZN, RPCOMP NUND P N/U DSA & BOP. Install flow nipple. R/U trip hose. 0.0 0.0 6/27/2024 17:45 6/27/2024 18:45 1.00 COMPZN, RPCOMP PRTS P Perform BOP shell test and PT breaks to 250/2500 psi. Crew C/O. 0.0 0.0 6/27/2024 18:45 6/27/2024 20:00 1.25 COMPZN, RPCOMP RURD P R/D PT equipment. Drain Stack. Pull Test Plug. Set Wear Ring. 0.0 0.0 6/27/2024 20:00 6/27/2024 20:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #8 (RBP Drift). 0.0 19.0 6/27/2024 20:30 6/27/2024 21:30 1.00 COMPZN, RPCOMP TRIP P TIH w/ RBP. Drift clean through tight spots @ 121', 700', and 1,100'. Cont. TIH to 1,170' (50' above top of IBP). 19.0 1,170.0 6/27/2024 21:30 6/27/2024 22:15 0.75 COMPZN, RPCOMP TRIP P TOOH w/ BHA #8 (RBP Drift) F/ 1,170'. 1,170.0 19.0 6/27/2024 22:15 6/27/2024 22:45 0.50 COMPZN, RPCOMP BHAH P L/D BHA #8 (RBP Drift). 19.0 0.0 6/27/2024 22:45 6/27/2024 23:15 0.50 COMPZN, RPCOMP BHAH P M/U BHA #9 (IBP retrieving head). 0.0 6.0 6/27/2024 23:15 6/28/2024 00:00 0.75 COMPZN, RPCOMP TRIP P TIH w/ BHA #9 (IBP retrieving head) to just above IBP. 6.0 1,220.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 7/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/28/2024 00:00 6/28/2024 00:45 0.75 COMPZN, RPCOMP MPSP P PU = 50K. SO = 48K. Set 10K down on top of IBP @ 1,229' to equalize. PU 6K to release and deflate IBP. Wait 30-min for element to relax. 1,220.0 1,220.0 6/28/2024 00:45 6/28/2024 01:45 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #9 + IBP F/ 1,220'. 1,220.0 6.0 6/28/2024 01:45 6/28/2024 02:15 0.50 COMPZN, RPCOMP BHAH P L/D BHA #9 w/ IBP plug. 6.0 0.0 6/28/2024 02:15 6/28/2024 03:00 0.75 COMPZN, RPCOMP BHAH P MU BHA #10 (ITCO Spear). While MU ITCO spear Baker rep noticed stop sub on BHA would not fully makeup. Identified a 3/8" gap. Made decision to call out a new ITCO spear assembly from Deadhorse and not run a suspect tool in the well. 0.0 0.0 6/28/2024 03:00 6/28/2024 05:00 2.00 COMPZN, RPCOMP WAIT P Wait on new ITCO spear from Deadhorse. 0.0 0.0 6/28/2024 05:00 6/28/2024 06:15 1.25 COMPZN, RPCOMP BHAH P MU BHA #10 Spear W/ 4.555" grapple, joint of DP, jars & bumper sub T/ 46' 0.0 46.0 6/28/2024 06:15 6/28/2024 07:15 1.00 COMPZN, RPCOMP PULD P PUDP F/ 46' T/ 707', SOW=46K. 46.0 707.0 6/28/2024 07:15 6/28/2024 08:15 1.00 COMPZN, RPCOMP TRIP P TIH w/ Spear F/ 707' T/1816', PUW=60K, SOW=56K. 707.0 1,816.0 6/28/2024 08:15 6/28/2024 08:45 0.50 COMPZN, RPCOMP FISH P TIH to engage fish tagged top @ 1,866'. Swallowed T/ 1869'. Indication entered fish top. Set down 25K P/U and repeat. 1,816.0 1,819.0 6/28/2024 08:45 6/28/2024 09:45 1.00 COMPZN, RPCOMP TRIP P POOH F/ 1819' T/ 46', PUW=60K. 793' - 703' 5K drag. 1,819.0 46.0 6/28/2024 09:45 6/28/2024 10:30 0.75 COMPZN, RPCOMP BHAH P L/D BHA #10. Fish on. Upper two connections were swelled due to being forced through corkscrewed casing. Cut lip showed damage from tubing stub. 46.0 0.0 6/28/2024 10:30 6/28/2024 11:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 6/28/2024 11:00 6/28/2024 12:00 1.00 COMPZN, RPCOMP RURD P Mobilize BHA #11 to RF. 0.0 0.0 6/28/2024 12:00 6/28/2024 12:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #11 tandem 6 1/8" string mill w/ flex joint in between T/ 43'. SOW=35K. 0.0 43.0 6/28/2024 12:30 6/28/2024 13:00 0.50 COMPZN, RPCOMP TRIP P RIH T/ 118' tagged up w/ tandem mills. Work T/ 122' w/ 5K drag. Unable to pass 122' w/ lower mill. POOH T/ 43' 43.0 43.0 6/28/2024 13:00 6/28/2024 13:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #11. 43.0 0.0 6/28/2024 13:30 6/28/2024 14:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #12 tandem 5 7/8" & 6" string mill w/ flex joint in between T/ 43'. SOW=35K. 0.0 43.0 6/28/2024 14:00 6/28/2024 14:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Service tongs. Grease draw works. 43.0 43.0 6/28/2024 14:30 6/28/2024 15:00 0.50 COMPZN, RPCOMP TRIP P RIH T/123' tagged up w/ tandem mills. Unable to pass 123' w/ lower mill. POOH T/ 43'. 43.0 43.0 6/28/2024 15:00 6/28/2024 15:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #12. 43.0 0.0 6/28/2024 15:30 6/28/2024 16:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 6/28/2024 16:00 6/28/2024 16:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #13 RPB T/ 19' 0.0 19.0 6/28/2024 16:30 6/28/2024 17:15 0.75 COMPZN, RPCOMP TRIP P RIH T/ 1230'. PUW=50, SOW=49K' 19.0 1,230.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 8/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/28/2024 17:15 6/28/2024 17:30 0.25 COMPZN, RPCOMP PACK P Set RBP @ 1230 COE. Set 25K down. Pull 20K over 3 times. Release from IBP. 1,230.0 1,230.0 6/28/2024 17:30 6/28/2024 18:15 0.75 COMPZN, RPCOMP TRIP P POOH F/ 1230'. 1,230.0 19.0 6/28/2024 18:15 6/28/2024 18:45 0.50 COMPZN, RPCOMP BHAH P L/D BHA #13 (RBP setting tools). 19.0 0.0 6/28/2024 18:45 6/28/2024 19:00 0.25 COMPZN, RPCOMP RURD P RU Pressure testing equipment. 0.0 0.0 6/28/2024 19:00 6/28/2024 19:30 0.50 COMPZN, RPCOMP PRTS P Close Blinds. PT through kill line, with sensator on test spool. PT RBP to 2,500 psi for 10-min. Chart. 0.0 0.0 6/28/2024 19:30 6/28/2024 22:00 2.50 COMPZN, RPCOMP TRIP P TIH w/ muleshoe on DP to approx. 100' above top of RBP (RBP set @ 1,230' CEO RKB). Top of RBP @ approx. 1,225'. Use charge pump to estimate circ rate for 2X tubing volume to cuttings tank. Possum belly gate broke. Repair. Restart charge pump circ test. Determined charge pump flow rate through sand hopper hose is approx. 0.5 BPM (bucket test). 0.0 1,141.0 6/28/2024 22:00 6/29/2024 00:00 2.00 COMPZN, RPCOMP OTHR P Dump 25 bags (65' in 7" 26# casing) of sand on top of RBP. Circ 2X DP volume (14 bbls) after dumping last bag. Wait for 30-min to sand to settle in casing. Dry tag TOS. 1,141.0 1,141.0 6/29/2024 00:00 6/29/2024 05:30 5.50 COMPZN, RPCOMP OTHR P Finish dumping 65' of sand on top of RBP. Run charge pump for 10-min to flush DP of sand. Wait 30-min for sand to settle. Dry tag TOS @ 1,164'. LRS heat up truck of seawater T/ 140*. 1,141.0 1,141.0 6/29/2024 05:30 6/29/2024 06:30 1.00 COMPZN, RPCOMP TRIP P TOOH standing back DP. 1,141.0 0.0 6/29/2024 06:30 6/29/2024 07:00 0.50 COMPZN, RPCOMP OWFF P Suck out stack, B/D surface lines. 0.0 0.0 6/29/2024 07:00 6/29/2024 07:30 0.50 COMPZN, RPCOMP RURD P Pull wear ring. OWFF for 30-min 0.0 0.0 6/29/2024 07:30 6/29/2024 08:15 0.75 COMPZN, RPCOMP NUND P ND BOP. 0.0 0.0 6/29/2024 08:15 6/29/2024 08:45 0.50 COMPZN, RPCOMP NUND P ND Tubing Head. BOLDS on CSG head. 0.0 0.0 6/29/2024 08:45 6/29/2024 09:00 0.25 COMPZN, RPCOMP BHAH P M/U BHA #14 7" spear. 0.0 1.0 6/29/2024 09:00 6/29/2024 09:30 0.50 COMPZN, RPCOMP CUTP P Pull tension in 7" T/ 260K. Remove slips & pack off. Decision made T/ set 7" back down/ Release spear. 0.0 0.0 6/29/2024 09:30 6/29/2024 09:45 0.25 COMPZN, RPCOMP BHAH P L/D BHA #14 0.0 0.0 6/29/2024 09:45 6/29/2024 11:00 1.25 COMPZN, RPCOMP NUND P N/U 11"3 K x 11" 5K DSA & BOP. Remove reducer bushing from TBG head for redress. 0.0 0.0 6/29/2024 11:00 6/29/2024 11:30 0.50 COMPZN, RPCOMP PRTS P PT BOP flange T/ 2500 PSI through external ports. 0.0 0.0 6/29/2024 11:30 6/29/2024 12:30 1.00 COMPZN, RPCOMP NUND P Align stack. Install flow nipple & trip tank hose 0.0 0.0 6/29/2024 12:30 6/29/2024 13:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #15 Multi String cutter T/ 34'. 0.0 34.0 6/29/2024 13:00 6/29/2024 14:30 1.50 COMPZN, RPCOMP TRIP P RIH T/ 1058'' PUW=49K, SOW=48K. 34.0 458.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 9/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/29/2024 14:30 6/29/2024 15:00 0.50 COMPZN, RPCOMP CUTP P Wash in hole @ 2 BPM, 190 PSI. Locate collar @ 1126'. Shut off pumps. P/U. RIH T/ 1131'. Cut 7" Rot @ 60 RPM, .9K Free Tq. Pump @ 4.5 BPM 800 PSI. Saw PSI drop to 680 PSI. TQ 2.3K. Arctic pack observed at surface. Close in annular to divert returns to 400 Bbls Open top tank. 1,058.0 1,131.0 6/29/2024 15:00 6/29/2024 20:00 5.00 COMPZN, RPCOMP CIRC P Circ remaining 65 Bbls 9.7# NaCl followed by hi-vis brine, followed by 110 Bbls 140* seawater @ 2 BPM, 300 PSI, taking returns to open top tank. Returns started to clean up. OWFF. Open annular. Circ 10 Bbls arctic pack off top of well started to clean up. Shut down wait 20 min & repeat. 1,131.0 1,131.0 6/29/2024 20:00 6/29/2024 20:30 0.50 COMPZN, RPCOMP OWFF P OWFF for 30-min. 1,131.0 1,131.0 6/29/2024 20:30 6/29/2024 21:30 1.00 COMPZN, RPCOMP TRIP P TOOH W/ BHA #15 (MSC). Clean and clear floor. 1,131.0 34.0 6/29/2024 21:30 6/29/2024 22:00 0.50 COMPZN, RPCOMP BHAH P L/D Baker MSC. Inspect blades to ensure good for follow up cuts if needed. 34.0 0.0 6/29/2024 22:00 6/29/2024 22:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #16 (7" Spear w/ Pack-Off). 0.0 41.0 6/29/2024 22:30 6/29/2024 23:00 0.50 COMPZN, RPCOMP PULL P Engage 7" spear in casing. PU approx. 8' to space out 7" casing across LPR. PUW to get moving = 60K. 41.0 1,123.0 6/29/2024 23:00 6/30/2024 00:00 1.00 COMPZN, RPCOMP CIRC P Circ. 100 bbls SW @ 2 BPM, Pumping down the 7" casing, taking OA returns to cuttings tank through flow line. Methane gas alarm. 20 PPM in shaker room. SD Pumps. Close 7" LPR. Line up to cuttings tanks. Bring pumps back online. 2 BPM @ 54 psi. Circulate arctic pack out OA to cuttings tank. 1,123.0 1,123.0 6/30/2024 00:00 6/30/2024 00:30 0.50 COMPZN, RPCOMP OWFF P 7" and OA @ 0psi. Open LPR. OWFF for 30-min. RU GBR 7" pipe handling equipment. 1,123.0 1,123.0 6/30/2024 00:30 6/30/2024 01:00 0.50 COMPZN, RPCOMP PULL P Pull 7" casing to rig floor @ 63K. 1,123.0 1,097.0 6/30/2024 01:00 6/30/2024 01:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #16 (7" spear w/ pack-off). 1,097.0 1,097.0 6/30/2024 01:30 6/30/2024 04:00 2.50 COMPZN, RPCOMP PULL P Pull 7" casing from 1,097' to surface. Cut Joint Length = 5.63'. (Flared T/ 7.5") Total Joints Pulled = 27 Full + 1 Partial. Recovered 6 of 11 stand off band centralizers. Could be 5 LIH. 1,097.0 0.0 6/30/2024 04:00 6/30/2024 04:45 0.75 COMPZN, RPCOMP RURD P RD GBR. Load Baker tools in shed for upcoming run. Kick out last of 7" Joints. Load Test Joints. 0.0 0.0 6/30/2024 04:45 6/30/2024 06:00 1.25 COMPZN, RPCOMP WWWH P Jet BOP stack. Mobilize test joints & test plug to RF. Crew change out. 0.0 0.0 6/30/2024 06:00 6/30/2024 06:30 0.50 COMPZN, RPCOMP MPSP P Set 11" test plug. 0.0 0.0 6/30/2024 06:30 6/30/2024 07:30 1.00 COMPZN, RPCOMP RURD P R/U testing equipment. Grease choke & manuals. Fill BOP w/ fresh water. 0.0 0.0 6/30/2024 07:30 6/30/2024 10:30 3.00 COMPZN, RPCOMP BOPE P Function test BOPE. Perform after usage BOPE test. Test BOP breaks, annular (3 1/2" and 7" Donut Test Joints), manual choke and kill. CMV # 5 & #6, Super choke. Witness waived by Josh Hunt. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 10/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/30/2024 10:30 6/30/2024 11:00 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. Suck out stack. 0.0 0.0 6/30/2024 11:00 6/30/2024 11:30 0.50 COMPZN, RPCOMP MPSP P Pull test plug. Set wear bushing. 0.0 0.0 6/30/2024 11:30 6/30/2024 13:30 2.00 COMPZN, RPCOMP RURD P Mobilize BHA # 17 to RF. 0.0 0.0 6/30/2024 13:30 6/30/2024 15:30 2.00 COMPZN, RPCOMP BHAH P M/U BHA #17 Drift run, 8.5" junk mill & tandem 8.5" sting mills, jars, bumper sub T/ 144', 0.0 144.0 6/30/2024 15:30 6/30/2024 16:15 0.75 COMPZN, RPCOMP TRIP P RIH w/ drift BHA tag stump @ 1130' w/ 10K', PUW=55K, SOW=53K. 144.0 1,130.0 6/30/2024 16:15 6/30/2024 16:45 0.50 COMPZN, RPCOMP DISP P Displace well w/ vis seawater @ 3 BPM, 72 PSI. Rot @ 25 RPM, .7K free torque. ROT=52K. Overboarding seawater. 1,130.0 1,130.0 6/30/2024 16:45 6/30/2024 17:00 0.25 COMPZN, RPCOMP MILL P Polish to of stub for 3 Min. Pump @ 6 BPM, 121 PSI. Rot @ 45 RPM, 1K free torque. ROT=52K. 2-3K WOB. Tq=1.4K. 1,130.0 1,130.0 6/30/2024 17:00 6/30/2024 17:15 0.25 COMPZN, RPCOMP CIRC P Circ STS @ 9 BPM, 280 PSI.. Recip pipe. 1,130.0 1,130.0 6/30/2024 17:15 6/30/2024 18:30 1.25 COMPZN, RPCOMP TRIP P POOH F/ 1130' T/ 144', PUW=53K. Crew C/O. 1,130.0 144.0 6/30/2024 18:30 6/30/2024 20:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA #17 (8 1/2" junk mill + tandem 8 1/2" string mills). 144.0 0.0 6/30/2024 20:00 6/30/2024 21:00 1.00 COMPZN, RPCOMP BHAH P Load Baker tools to rig floor. MU BHA #18 (7" dress off shoe w/ 4.42' total swallow). 0.0 125.0 6/30/2024 21:00 6/30/2024 21:45 0.75 COMPZN, RPCOMP TRIP P TIH to above 7" stub (stub @ 1,130'). TIH and No-Go out @ 1,134.4' (Fully swallowed w/ dress off shoe). 125.0 1,134.4 6/30/2024 21:45 6/30/2024 22:15 0.50 COMPZN, RPCOMP MILL P Obtain parameters. PUW = 52K. SOW = 51K. Pump Rate = 4 BPM @ 88 psi. Rotary = 60 RPM. FT = 1.1K. TIH and dress off 7" casing stub. Set 7K down. Let mill off to 5K. Repeat. TIH Dress off stub from 1,130' to 1,131' (dressed off 1" total). Swallow stub to ensure backside is clear. 1,134.4 1,134.4 6/30/2024 22:15 6/30/2024 22:45 0.50 COMPZN, RPCOMP CIRC P After dress off. Pump 20 bbl hi-vis pill. Chase out with 110 bbls of 8.6# SW @ 8 BPM @ 200 psi. Pump STS and still seeing some scale debris coming back. Cont pumping until cleans up. Pump total of 268 BBLS SW. 1,134.4 1,134.4 6/30/2024 22:45 6/30/2024 23:15 0.50 COMPZN, RPCOMP OWFF P OWFF. 1,134.4 1,134.4 6/30/2024 23:15 7/1/2024 00:00 0.75 COMPZN, RPCOMP TRIP P TOOH w/ BHA #18 (7" dress off shoe). 1,134.4 125.0 7/1/2024 00:00 7/1/2024 00:45 0.75 COMPZN, RPCOMP BHAH P Stand back collars. L/D BHA #18 (7" dress off shoe). 125.0 0.0 7/1/2024 00:45 7/1/2024 01:45 1.00 COMPZN, RPCOMP RURD P RU GBR 7" handling equipment. Pull Wear Ring. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 11/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/1/2024 01:45 7/1/2024 05:00 3.25 COMPZN, RPCOMP PUTB P Verify 7" Temp Tieback Tally and Jewelry. PJSM. Run 7" HYD563 temp tieback to just above 7" stub (stub @ 1,130'). Obtain parameters. PUW = 60K. SOW = 57K. Pump Rate = 1 BPM @ 55 psi. TIH and latch 7" casing stub. Set down 15K at 1,133'. No pressure indicator. PU. Rotate @ 5 RPM. F.T. = 1.1K. TIH and see press. indicator @ 1,134'. SD pumps. Open bleeder. Swallow 7" stub to No-Go depth of 1,135.5'. Set 25K down. Pull 50K tension (115K total) to confirm good latch. Repeat. Slack off to 80K total (15K tension in 7"). Pressure up to 500 psi. Holding. Bleed off. Release GBR. 0.0 1,135.5 7/1/2024 05:00 7/1/2024 05:45 0.75 COMPZN, RPCOMP RURD P RU PT equipment w/ sensator on 7" casing. 1,135.5 1,135.5 7/1/2024 05:45 7/1/2024 06:00 0.25 COMPZN, RPCOMP PRTS P PT 7" Temp Tieback to 2,500 psi for 10- min. Charted. Bleed off. 1,135.5 1,135.5 7/1/2024 06:00 7/1/2024 06:15 0.25 COMPZN, RPCOMP RURD P RD PT equipment. RD GBR equipment. 1,135.5 1,135.5 7/1/2024 06:15 7/1/2024 06:45 0.50 COMPZN, RPCOMP OWFF P OWFF. Drain Stack. 1,135.5 1,135.5 7/1/2024 06:45 7/1/2024 07:30 0.75 COMPZN, RPCOMP NUND P Split BOP and lift stack. 1,135.5 1,135.5 7/1/2024 07:30 7/1/2024 11:00 3.50 COMPZN, RPCOMP CUTP P Set emergency slips w/ 50 tension over string weight. Cut 7" w/ Whacks saw. Pull cut joint. Rack back BOP. Install pack off. 1,135.5 0.0 7/1/2024 11:00 7/1/2024 12:30 1.50 COMPZN, RPCOMP NUND P N/U new tubing head. 0.0 0.0 7/1/2024 12:30 7/1/2024 13:00 0.50 COMPZN, RPCOMP PRTS P PT pack off T/ 3000 PSI for 15 Min. 0.0 0.0 7/1/2024 13:00 7/1/2024 15:00 2.00 COMPZN, RPCOMP NUND P Set test plug. N/U DSA & BOP. Install flow nipple & trip tank hose. 0.0 0.0 7/1/2024 15:00 7/1/2024 15:30 0.50 COMPZN, RPCOMP RURD P R/U testing equipment. Fill stack w/ fresh water. 0.0 0.0 7/1/2024 15:30 7/1/2024 16:30 1.00 COMPZN, RPCOMP PRTS P PT stack breaks 250/2500 PSI. 0.0 0.0 7/1/2024 16:30 7/1/2024 17:00 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 0.0 0.0 7/1/2024 17:00 7/1/2024 17:30 0.50 COMPZN, RPCOMP RURD P Pull test plug. Install wear bushing. 0.0 0.0 7/1/2024 17:30 7/1/2024 18:30 1.00 COMPZN, RPCOMP RURD P Mobilize BHA #19 to RF. Crew change out. 0.0 0.0 7/1/2024 18:30 7/1/2024 19:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #19 RCJB T/ 44' 0.0 44.0 7/1/2024 19:00 7/1/2024 20:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ 44' T/ 1154', PUW=49K, SOW=48K 44.0 1,154.0 7/1/2024 20:00 7/1/2024 20:30 0.50 COMPZN, RPCOMP WASH P K/U. Dry tag sand top @ 1166'. Wash & ream F/ 1154' T/ 1176'. Pump @ 10 BPM, 1565 PSI. Rot @ 25 RPM, Free Tq = .7K. ROT=48K. 1,154.0 1,176.0 7/1/2024 20:30 7/1/2024 21:00 0.50 COMPZN, RPCOMP CIRC P Circ sand OOH @ 10 BPM, 1565 PSI. Sand at shakers. 1,176.0 1,176.0 7/1/2024 21:00 7/1/2024 21:45 0.75 COMPZN, RPCOMP TRIP P POOH F/ 1176' T/ 44', PUW=49K. 1,176.0 44.0 7/1/2024 21:45 7/1/2024 22:15 0.50 COMPZN, RPCOMP BHAH P L/D BHA #19. Nothing in baskets. 44.0 0.0 7/1/2024 22:15 7/1/2024 22:30 0.25 COMPZN, RPCOMP BHAH P M/U BHA #20 RBP retrieval head T/ 42' 0.0 42.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 12/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/1/2024 22:30 7/1/2024 23:15 0.75 COMPZN, RPCOMP TRIP P RIH T/ 1154', PUW=49K, SOW=48K. 42.0 1,154.0 7/1/2024 23:15 7/1/2024 23:30 0.25 COMPZN, RPCOMP WASH P K/U; Dry tag sand top @ 1,180'. Wash in hole @ 6 BPM and 175 psi down to plug @ 1,225'. Set xK down (top of RBP). 1,154.0 1,225.0 7/1/2024 23:30 7/2/2024 00:00 0.50 COMPZN, RPCOMP CIRC P Pump 30 bbl hi-vis sweep. Circ well over to 9.7# Brine (KWF). 1,225.0 1,225.0 7/2/2024 00:00 7/2/2024 01:30 1.50 COMPZN, RPCOMP CIRC P Circ well over to 9.7# brine. 5 BPM @ 193 psi. 1,225.0 1,225.0 7/2/2024 01:30 7/2/2024 01:45 0.25 COMPZN, RPCOMP MPSP P Latch, equalize, and release RBP. 1,225.0 1,225.0 7/2/2024 01:45 7/2/2024 02:15 0.50 COMPZN, RPCOMP OWFF P OWFF for 30-min. 1,225.0 1,225.0 7/2/2024 02:15 7/2/2024 03:00 0.75 COMPZN, RPCOMP TRIP P TOOH w/ BHA #20 (Retreiving head + RBP) 1,225.0 42.0 7/2/2024 03:00 7/2/2024 03:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #20. 42.0 0.0 7/2/2024 03:30 7/2/2024 04:00 0.50 COMPZN, RPCOMP BHAH P MU BHA #21 (RCJB w/ 30' washpipe). 0.0 68.0 7/2/2024 04:00 7/2/2024 05:00 1.00 COMPZN, RPCOMP TRIP P TIH to 1,876' (tubing stub @ 1,888'). 68.0 1,876.0 7/2/2024 05:00 7/2/2024 06:45 1.75 COMPZN, RPCOMP WASH P Obtain parameters. PUW = 59K. SOW = 55K. Pump rate = 6 BPM at 990 psi. TIH w/ pumps on and see 2K WT bobble @ 1,884.4'. PUH. Bring on Rotary = 25 RPM. F.T. = 1K ft-lbs. Increase pump rate to 8 BPM @ 1,600 psi. Wash over stub. See bobble again at 1,884.4' (likely top of stub). Cont. TIH washing backside of stub to 1,901' (approx. 17' swallow w/ washpipe). Clean rotating torque at 1,901'. Likely rotating on top of SSSV. Repeat wash down. Build and pump 25 bbl hi-vis pill. 1,901.0 1,901.0 7/2/2024 06:45 7/2/2024 07:00 0.25 COMPZN, RPCOMP CIRC P PUH off top of stub. Circ. STS to clear hi-vis pill. 1,901.0 1,822.0 7/2/2024 07:00 7/2/2024 07:15 0.25 COMPZN, RPCOMP OWFF P OWFF 1,822.0 1,822.0 7/2/2024 07:15 7/2/2024 08:15 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #21. 1,822.0 68.0 7/2/2024 08:15 7/2/2024 08:45 0.50 COMPZN, RPCOMP BHAH P L/D same. Inspect junk baskets for debris. Recovered pieces of finger cage, SS band, small piece of control line, and small chunk of tubing. 68.0 0.0 7/2/2024 08:45 7/2/2024 09:15 0.50 COMPZN, RPCOMP BHAH P MU RCJB Run #2 0.0 68.0 7/2/2024 09:15 7/2/2024 10:00 0.75 COMPZN, RPCOMP TRIP P TIH to 1,876' (tubing stub @ 1,888'). 68.0 1,876.0 7/2/2024 10:00 7/2/2024 10:15 0.25 COMPZN, RPCOMP WASH P Obtain parameters. Wash backside of tubing stub to top of SSSV @ 1,901. Wash over stub repeatedly to clean debris from backside. 1,876.0 1,901.0 7/2/2024 10:15 7/2/2024 11:15 1.00 COMPZN, RPCOMP CIRC P Pump 30 bbls hi-vis pill. Circ 9.7# brine STS until clean. 1,901.0 1,876.0 7/2/2024 11:15 7/2/2024 11:45 0.50 COMPZN, RPCOMP TRIP P TOOH w/ RCJB Run #2 1,876.0 68.0 7/2/2024 11:45 7/2/2024 12:00 0.25 COMPZN, RPCOMP BHAH P L/D same. Inspect junk baskets for debris. Recoverd chunk of tubing (chem cut) and piece of control line. 68.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 13/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/2/2024 12:00 7/2/2024 12:30 0.50 COMPZN, RPCOMP BHAH P MU RCJB Run #3 0.0 68.0 7/2/2024 12:30 7/2/2024 13:15 0.75 COMPZN, RPCOMP TRIP P TIH to 1,876' (tubing stub @ 1,888'). 68.0 1,876.0 7/2/2024 13:15 7/2/2024 13:45 0.50 COMPZN, RPCOMP WASH P Obtain parameters. Wash backside of tubing stub to top of SSSV @ 1,901. Wash over stub repeatedly to clean debris from backside. 1,876.0 1,901.0 7/2/2024 13:45 7/2/2024 14:15 0.50 COMPZN, RPCOMP CIRC P Pump 30 bbls hi-vis pill. Circ 9.7# brine STS until clean. 1,901.0 1,876.0 7/2/2024 14:15 7/2/2024 14:45 0.50 COMPZN, RPCOMP TRIP P TOOH w/ RCJB Run #3 1,876.0 68.0 7/2/2024 14:45 7/2/2024 15:00 0.25 COMPZN, RPCOMP BHAH P L/D same. Inspect junk baskets. Clean. 68.0 0.0 7/2/2024 15:00 7/2/2024 15:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #22 (3 1/2" dress off shoe). 0.0 69.0 7/2/2024 15:30 7/2/2024 16:30 1.00 COMPZN, RPCOMP TRIP P TIH w/ dress off shoe to just above tubing stub (stub @ 1,884'.) 69.0 1,830.0 7/2/2024 16:30 7/2/2024 17:00 0.50 COMPZN, RPCOMP MILL P Obtain parameters. PUW = 59K. SOW = 55K. Pump rate = 5 BPM at 644 psi. Rotary = 40 RPM. F.T. = 1K. TIH and dress off stub @ 1,884'. Swallow to collar above SSSV @ 1,898'. PUH. Clean drift over stub with no rotation. 1,830.0 1,898.0 7/2/2024 17:00 7/2/2024 17:15 0.25 COMPZN, RPCOMP CIRC P Pump hi-vis pill. Circ STS. 1,898.0 1,882.0 7/2/2024 17:15 7/2/2024 17:30 0.25 COMPZN, RPCOMP OWFF P OWFF 1,882.0 1,882.0 7/2/2024 17:30 7/2/2024 18:30 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #22 // Pu Wt 64K // 1,882.0 69.0 7/2/2024 18:30 7/2/2024 19:00 0.50 COMPZN, RPCOMP BHAH P Lay down BHA, inspect for metal, found 7" long by 2.5" wide metal 69.0 0.0 7/2/2024 19:00 7/2/2024 19:30 0.50 COMPZN, RPCOMP BHAH P Make up BHA # 22 Run 2 BHA Dress off BHA 0.0 69.0 7/2/2024 19:30 7/2/2024 20:00 0.50 COMPZN, RPCOMP TRIP P TIH with dress off BHA T/ 1881' 69.0 1,881.0 7/2/2024 20:00 7/2/2024 20:15 0.25 COMPZN, RPCOMP WASH P Wash over fish T/ 1898' w/o rotation stack on tubing collar, rotate to confirm no forward progress, 18' of fish neck available for fishing, Up Wt 59K Dn Wt 55K, pick up off fish clean no over pull 1,881.0 1,898.0 7/2/2024 20:15 7/2/2024 20:30 0.25 COMPZN, RPCOMP CIRC P Circulate B/U, OWFF no flow 1,898.0 1,881.0 7/2/2024 20:30 7/2/2024 21:30 1.00 COMPZN, RPCOMP TRIP P TOOH to lay down dress off BHA # 22 Run 2 1,881.0 69.0 7/2/2024 21:30 7/2/2024 22:00 0.50 COMPZN, RPCOMP BHAH P Lay down BHA and inspect 69.0 0.0 7/2/2024 22:00 7/2/2024 22:45 0.75 COMPZN, RPCOMP BHAH P Pick up BHA# 23 Overshot fishing BHA 0.0 162.0 7/2/2024 22:45 7/2/2024 23:45 1.00 COMPZN, RPCOMP TRIP P TIH above fish 1881' // Up wt 60K Dn Wt 58K // Pump 3 bpm @ 120psi 162.0 1,881.0 7/2/2024 23:45 7/3/2024 00:00 0.25 COMPZN, RPCOMP FISH P Wash over fish T/1889' // Pump pressure increase @ 1884' to 165psi // 5' Swallow on overshot 1,881.0 1,889.0 7/3/2024 00:00 7/3/2024 01:00 1.00 COMPZN, RPCOMP FISH P Pick up to 100K bleed off jars // Straight pull T/ 118K fish moving // OWFF no flow 1,889.0 8,777.0 7/3/2024 01:00 7/3/2024 02:00 1.00 COMPZN, RPCOMP TRIP P TOOH pulling 3.5" tubing fish to surface 8,777.0 5,133.0 7/3/2024 02:00 7/3/2024 03:00 1.00 COMPZN, RPCOMP BHAH P Stand back collars // lay down overshot BHA # 23 and inspect 5,133.0 4,968.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 14/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/3/2024 03:00 7/3/2024 04:00 1.00 COMPZN, RPCOMP RURD P Rig up to pull 3.5" completion tubing 4,968.0 4,968.0 7/3/2024 04:00 7/3/2024 11:00 7.00 COMPZN, RPCOMP PULL P Pull 3.5" completion // Lay down SSSV and 1 GLM. GLM has heavy corrosion/pitting. RCT Cut was clean. No flare. 4,968.0 0.0 7/3/2024 11:00 7/3/2024 11:30 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor for E-line operations 0.0 0.0 7/3/2024 11:30 7/3/2024 12:30 1.00 COMPZN, RPCOMP ELNE P RU E-line for CBL/CCL. MU CBL toolstring. Zero depth at rig floor. 0.0 0.0 7/3/2024 12:30 7/3/2024 15:30 3.00 COMPZN, RPCOMP ELOG P RIH w/ E-line + CBL to 3,032'. Log CBL from 3,032' to surface @ 30 Ft/Min. Email log files to HES Rep in Town for processing. Est. TOC @ 2,204'. 0.0 0.0 7/3/2024 15:30 7/3/2024 16:45 1.25 COMPZN, RPCOMP ELNE P L/D CBL toolstring. RD E-line. 0.0 0.0 7/3/2024 16:45 7/3/2024 18:00 1.25 COMPZN, RPCOMP BHAH P MU BHA #24 (RBP) 0.0 15.0 7/3/2024 18:00 7/3/2024 19:45 1.75 COMPZN, RPCOMP TRIP P TIH and set RBP @ 2,220' (COE). // TIH @ 80'/min 15.0 2,160.0 7/3/2024 19:45 7/3/2024 22:00 2.25 COMPZN, RPCOMP TRIP P G-plug hung up , log shows casing deformation in area // TOOH for drift/dress off run // Found some wear on G-plug from tight spots 2,160.0 0.0 7/3/2024 22:00 7/3/2024 23:30 1.50 COMPZN, RPCOMP BHAH P Pick up clean out BHA w/ 3.5" dress off 0.0 180.0 7/3/2024 23:30 7/4/2024 00:00 0.50 COMPZN, RPCOMP TRIP P TIH w/ clean out BHA 180.0 1,000.0 7/4/2024 00:00 7/4/2024 01:00 1.00 COMPZN, RPCOMP TRIP P Continue in hole with 6-1/8" drift BHA w/ 3.5" dress off // Set down 1390' work through continue in hole 1,000.0 2,671.0 7/4/2024 01:00 7/4/2024 07:15 6.25 COMPZN, RPCOMP WAIT P Strap and tally drill pipe (aditional 229 Joints of DP) to get to tubing stub @ 8,777'. Sent damaged G-Plug to Deadrhose. Truck will pickup new G- plug and haul back to location. 2,671.0 2,671.0 7/4/2024 07:15 7/4/2024 15:15 8.00 COMPZN, RPCOMP TRIP P Cont. TIH from 2,671' to 6,037'. PUW = 109K. SOW = 85K. Cont. TIH to tag @ 8,161'. Set 10K down. PUW = 155K. PUH to 8,135'. Acting like we had junk around the tools or tight spot in 7" casing. Sticky. Bring pumps on @ 5 BPM and 1600 psi. TBIH to 8,154'. Set down again. PUH to 8144'. Correct depth to 8,182' (Joint #259). Bring on rotary @ 40 RPM. F.T. = 4.2K. TBIH. Rotating Wt = 110K. Torque spiked to 6K at 8,206'. Relieve Torque. PUH. PUW = 150K. Broke Free. PUW after free = 130K. Repeat. Torque spiked at same 8,206' depth. Relieve Torque. PUW = 165K. Came free. Repeat. Same result. Max overpull during attempts was approx. 50K. PUH and set in slips. Call Town to discuss. Decision made to TOOH and progress subsidence repair. 2,671.0 8,206.0 7/4/2024 15:15 7/4/2024 17:15 2.00 COMPZN, RPCOMP SLPC P Slip and Cut Drill Line. Pump 30 bbl 9.7# hi-vis pill. Circ. 9.7# brine STS chasing hi-vis pill out of the hole. 8,206.0 8,148.0 7/4/2024 17:15 7/4/2024 18:45 1.50 COMPZN, RPCOMP TRIP P TOOH standing back DP F/ 8200' to 180'. 8,148.0 7,400.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 15/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/4/2024 18:45 7/4/2024 19:30 0.75 COMPZN, RPCOMP OTHR P Working Stuck pipe @ 7400' // Work pipe 20K over up and set down 20K // Torque 6800 ft lbs broke free Circulate 5 bpm BU 7,400.0 7,400.0 7/4/2024 19:30 7/5/2024 00:00 4.50 COMPZN, RPCOMP TRIP P TOOH standing back DP F/ 7400' to 180'. Circulate sweep at 2200 7,400.0 180.0 7/5/2024 00:00 7/5/2024 01:30 1.50 COMPZN, RPCOMP BHAH P L/D BHA #25 (RCJB + 6 1/8" drift + wash pipe + 3 1/2" dress off shoe). Recoverd 1 SS band and pieces of RCJB fingers. Scarring on OD of 3 1/2" dress off shoe. Likely was getting hung up by junk at dress off shoe. 180.0 0.0 7/5/2024 01:30 7/5/2024 02:15 0.75 COMPZN, RPCOMP BHAH P MU BHA #26 (RBP) 0.0 13.0 7/5/2024 02:15 7/5/2024 03:45 1.50 COMPZN, RPCOMP TRIP P TIH and place RBP (COE) @ 2,220'. 13.0 2,220.0 7/5/2024 03:45 7/5/2024 04:45 1.00 COMPZN, RPCOMP MPSP P Set RBP @ 2,223 (COE). Top of RBP @ 2,219'. 2,220.0 2,223.0 7/5/2024 04:45 7/5/2024 06:30 1.75 COMPZN, RPCOMP PRTS P Circulate SxS ensure air out of system. PRTS plug 2500psi 10 min. Found leaking gland nut. Tighten and re-test. PT RBP to 2,000 psi for 30-min. Charted. Good Test. Bleed off. 2,223.0 2,046.0 7/5/2024 06:30 7/5/2024 16:45 10.25 COMPZN, RPCOMP OTHR P RU sand hopper and circ hose. Dump 65 bags of sand on top of RBP. One last bag, let charge pump run for 30-min to clear DP volume. Wait 30-min for sand to settle. TIH and lightly tag top of sand @ 2,160'. 2,046.0 2,046.0 7/5/2024 16:45 7/5/2024 17:45 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #26 (RBP setting tool). 2,046.0 13.0 7/5/2024 17:45 7/5/2024 18:15 0.50 COMPZN, RPCOMP BHAH P L/D BHA #26. 13.0 0.0 7/5/2024 18:15 7/5/2024 18:45 0.50 COMPZN, RPCOMP WWWH P Pull Wear Ring. Jet/Wash stack. 0.0 0.0 7/5/2024 18:45 7/5/2024 20:00 1.25 COMPZN, RPCOMP RURD P Ensure IA and OA are at 0 psi. Drain stack. Pull Wear Ring. Set test plug. Shell test to 250/2500 psi. Load 3 1/2" test joint and 7" donut TJ. 0.0 0.0 7/5/2024 20:00 7/6/2024 00:00 4.00 COMPZN, RPCOMP BOPE P Perform bi-weekly BOP test to 250/2500 psi. Utilize ported 3 1/2" IF and 7" donut TJs. Tested BOPE at 250/2500 PSI for 5 Min each, Tested UVBR's, LPRs w/ 7" test joints. Test blinds rams. Choke valves #1 to #3, #5-#10, #13. Lower top drive well control valves. Test 3 1/2" IF IBOP. Test 3 ½ EUE FOSV. Test manual and HCR kill valves & manual and HCR choke valves. Test outer 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Test PVT and flow show. Witnessed by AOGCC Kam StJohn . 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 16/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/6/2024 00:00 7/6/2024 02:00 2.00 COMPZN, RPCOMP BOPE P Perform bi-weekly BOP test to 250/2500 psi. Utilize ported 3 1/2" IF and 7" donut TJs. Tested BOPE at 250/2500 PSI for 5 Min each, Tested UVBR's, LPRs w/ 7" test joints. Test blinds rams. Choke valves #1 to #3, #5-#10, #13. Lower top drive well control valves. Test 3 1/2" IF IBOP. Test 3 ½ EUE FOSV. Test manual and HCR kill valves & manual and HCR choke valves. Test outer 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Test PVT and flow show. Witnessed by AOGCC Kam StJohn . 0.0 0.0 7/6/2024 02:00 7/6/2024 03:00 1.00 COMPZN, RPCOMP RURD P Rig down test equipment from BOP test // Kick out test jts // Put hoses away from test pump. Pull test plug. Set Wear Ring. 0.0 0.0 7/6/2024 03:00 7/6/2024 04:00 1.00 COMPZN, RPCOMP RURD P RU PT equipment. Flood stack. Purge air. Close blinds. 0.0 0.0 7/6/2024 04:00 7/6/2024 05:00 1.00 COMPZN, RPCOMP PRTS P PT RBP to 3,000 psi for 15-min. Chart. Bleed off. Open blinds. 0.0 0.0 7/6/2024 05:00 7/6/2024 06:15 1.25 COMPZN, RPCOMP RURD P Rig down test equipment. PT outside hardline to tanks to 2,500 psi. Bleed OA to tanks before making cut. 0.0 0.0 7/6/2024 06:15 7/6/2024 06:30 0.25 COMPZN, RPCOMP BHAH P PJSM. Pick up BHA# 27 (MSC) 0.0 35.0 7/6/2024 06:30 7/6/2024 08:15 1.75 COMPZN, RPCOMP TRIP P TIH w/ MSC. Locate collars @ 1,946' and 1,986'. Collars found 7' shallow compared to E-line CBL. Ensure OA is bled off and Shut-In for monitoring. PUW = 59K. SOW = 55K. 35.0 1,953.0 7/6/2024 08:15 7/6/2024 08:30 0.25 COMPZN, RPCOMP CPBO P Space out for cut @ 1,956' (10' into Full Joint). Obtain parameters. Pump 5 bbls/min @ 982 psi. Rot @ 65 rpm @ 1.2Kft/lb. Perform 7" csg cut. Avg Torque = 1.9K. Start cut @ 8:18. See torque fell off @ 8:21 (3-minutes to cut). OA pressure indicator = 100 psi. PU. Space out. Close UPR. 1,956.0 1,956.0 7/6/2024 08:30 7/6/2024 10:15 1.75 COMPZN, RPCOMP DISP P Displace arcticpack out of OA and load with 8.6# Seawater @ 3 BPM @ 348 psi. Pump 67 bbls 9.7# out of Pit #2. Pump 30 bbls heated deepclean in 8.6# seawater. Chase w/ 125 bbls 140° 8.6# seawater to flush OA. SD Pumps. Line up to pump down 7" x 3 1/2" annulus taking returns out OA to tanks. Pump hot seawater at 8 BPM / 780 psi down annulus taking OA returns. Swap to cuttings tank with 350 bbls in open top. Slow rate to 6 BPM. Measure 8.5# returns. SD Pumps. 1,956.0 1,942.0 7/6/2024 10:15 7/6/2024 11:15 1.00 COMPZN, RPCOMP OWFF P Bleed off. Blowdown lines. With DP + IA + OA reading 0 psi. Open UPR. OWFF. Suck 9.7# out of trip tank. Fill w/ 8.6# Seawater. 1,942.0 1,942.0 7/6/2024 11:15 7/6/2024 12:15 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA#27. 1,942.0 35.0 7/6/2024 12:15 7/6/2024 13:45 1.50 COMPZN, RPCOMP BHAH P L/D BHA #27. Cutters in good condition. Build stands w/ 24 Joints in Pipe shed. 35.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 17/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/6/2024 13:45 7/6/2024 15:15 1.50 COMPZN, RPCOMP OWFF P OWFF. Drain Stack. Pull Wear Ring. OA pressure reading 0 psi on 300 psi gauge, but still has slight flow. Clean fluid. Acting like small gas bubbles from arctic pack sump migrating uphole slowly. 0.0 0.0 7/6/2024 15:15 7/6/2024 15:45 0.50 COMPZN, RPCOMP CIRC P Line up to pump down 7" casing taking OA returns to cuttings tanks. Close blind rams. Pump 25 bbls Seawater @ 1 BPM / 60 psi. SD Pumps. Bleed off. Open blinds. 0.0 0.0 7/6/2024 15:45 7/6/2024 16:00 0.25 COMPZN, RPCOMP OWFF P Suck out and drain stack. Blowdown line to cuttings tank. OWFF. OA still has slight flow. 0.0 0.0 7/6/2024 16:00 7/6/2024 16:30 0.50 COMPZN, RPCOMP OWFF P SI OA. Monitor OA pressure buildup for 30-min. Allow arctic pack sump gas to migrate up OA. OA pressure after 30- min shut in = 1 psi. 0.0 0.0 7/6/2024 16:30 7/6/2024 17:00 0.50 COMPZN, RPCOMP CIRC P Line up to pump down 7" casing taking OA returns to cuttings tanks. Close blind rams. Pump 25 bbls Seawater @ 1 BPM / 60 psi. SD Pumps. Bleed off. Open blinds. 0.0 0.0 7/6/2024 17:00 7/6/2024 17:45 0.75 COMPZN, RPCOMP OWFF P Suck out and drain stack. Blowdown line to cuttings tank. OWFF. Monitor OA for flow. 0.0 0.0 7/6/2024 17:45 7/6/2024 20:45 3.00 COMPZN, RPCOMP NUND P Nipple down BOPs // Remove tubing head // Remove packoffs // Spear casing // Pick up 90K (50K tension at temp patch) // Remove slips from 7" casing head. Build stands of DP w/ remaining DP in Pipe Shed. 0.0 0.0 7/6/2024 20:45 7/6/2024 22:15 1.50 COMPZN, RPCOMP NUND P NU 11" ported DSA (w/ ported ring gaskets). NU BOPs to 11" DSA. 0.0 0.0 7/6/2024 22:15 7/6/2024 22:45 0.50 COMPZN, RPCOMP PRTS P Test BOP Breaks and 11" DSA breaks to 2,500 psi. RU GBR. 0.0 0.0 7/6/2024 22:45 7/7/2024 00:00 1.25 COMPZN, RPCOMP PULL P Pull 7" casing ro rig floor. L/D Joints #1- 27 to be re-used for Tieback run. Save temp tie back casing patch. Sent old 7" casing below casing patch to lay down area. 1,956.0 7/7/2024 00:00 7/7/2024 03:30 3.50 COMPZN, RPCOMP PULL P Continue pulling 7" casing // Jt 16 in tally of new pipe bent kicked out // 1985 7" pipe extrememly bent // Cut Jt from 1956' = 10.65' // 10 centralizers recovered ( 16 total recovered from original completion ) 1,956.0 0.0 7/7/2024 03:30 7/7/2024 04:00 0.50 COMPZN, RPCOMP CLEN P Clean up floor // Rig down GBR casing equipment 0.0 0.0 7/7/2024 04:00 7/7/2024 06:45 2.75 COMPZN, RPCOMP BHAH P Prep handling equipment for 3 1/2" DP. PU/MU BHA #29 (Casing Patch Drift + Dress Off). Crew C/O. 0.0 147.0 7/7/2024 06:45 7/7/2024 08:00 1.25 COMPZN, RPCOMP TRIP P TIH w/ BHA #29. Obtain parameters. PUW = 65K. SOW = 62K. Pumps @ 5 BPM and 300 psi. Rotary 7 RPM. Free Torque = 1.4 K. TIH and swallow stub to 1,960' (dress off shoe has 4.42' swallow. Top of 7" stub @ approx. 1,956'. 147.0 1,956.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 18/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/7/2024 08:00 7/7/2024 08:45 0.75 COMPZN, RPCOMP MILL P PUH. Obtain parameters for dress off. PUW = 65K. SOW = 62K. See arctic pack gas coming back. Slow rate to 1 BPM. Circ. out gas bubble. Saw arctic pack in returns. Cleaned up. Increase rate back up to 6 BPM @ 406 psi. Rotary = 45 RPM. F.T. 1.5K. TIH. See pressure indicator @ 1,958' to 424 psi. See Torque Increase @ 1,962' to 2.1K. Dress off from approx. 1,956' to 1,958'. PUH. SD rotary. Slide over 7" stub and confirm top left @ 1,958. (set 4K down @ 1,963'). 1,963.0 1,950.0 7/7/2024 08:45 7/7/2024 09:30 0.75 COMPZN, RPCOMP CIRC P Pump 30BBL hi-vis sweep. Circ STS @ 10 BPM @ 1,050 psi. Kick dirty fluids outside when sweep came back. Circ until clean. SD Pumps. 1,950.0 1,950.0 7/7/2024 09:30 7/7/2024 09:45 0.25 COMPZN, RPCOMP OWFF P OWFF. 1,950.0 1,950.0 7/7/2024 09:45 7/7/2024 10:45 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #29 (dress off shoe) 1,950.0 147.0 7/7/2024 10:45 7/7/2024 13:00 2.25 COMPZN, RPCOMP BHAH P L/D BHA #29. Pull Wear Ring. 147.0 0.0 7/7/2024 13:00 7/7/2024 14:30 1.50 COMPZN, RPCOMP RURD P RU GBR 7" handling equipment and torque turn. Break out 20' pup from 7" cut joint. 0.0 0.0 7/7/2024 14:30 7/7/2024 18:00 3.50 COMPZN, RPCOMP PUTB P Verify 7" Tally and jewelry run order. PJSM. Run 7" Tieback as per tally to just above 7" stub (stub @ 1,958'). Replaced Joint #7 w/ Spare Joint 'A' @ 39.95'. Used Spare Joint 'E' to replace damaged Joint #16 that was bent during temp tieback run. MU Joint #49 and space out pup (3.67'). MU 3 1/2" IF x 7" HYD563 XO. Screw in TD. 0.0 1,965.0 7/7/2024 18:00 7/7/2024 19:30 1.50 COMPZN, RPCOMP CIRC P RU head pin and PT equipment. Circulate B/U get base line numbers 1 bpm @ 57 psi 3 bpm @ 57 psi 5 bpm @ 57 psi // Circulate SxS arctic pack in returns take to cuttings tank // OWFF 15min small ammount of flow, Circulate B/U returns clean 1,965.0 1,965.0 7/7/2024 19:30 7/7/2024 20:30 1.00 COMPZN, RPCOMP PRTS P Obtain parameters. PUW = 79K. SOW = 74K. Pump Rate = 1 BPM @ 57 psi. TIH and swallow 7" stub @ 1,958'. See pressure indicator @ 1,963'. SD pumps. Open bleeder. TIH and fully locate @ 1,966'. Set 25K down. PU 50K tension (130K total) to confirm latch. PT 7" casing and casing patch to 2,500 psi for 30-min. Good pressure test 1,965.0 1,965.0 7/7/2024 20:30 7/7/2024 21:15 0.75 COMPZN, RPCOMP CIRC P RD PT equipment. Screw in TD. Pull 7" casing to neutral (80K). Pressure up 7" casing to 3400psi to shear open ES Cementer. Circ 8.6# Seawater STS. 3 bpm @ 57 psi 1,965.0 1,965.0 7/7/2024 21:15 7/7/2024 22:15 1.00 COMPZN, RPCOMP OWFF P MT stack to well head OWFF for 30- min. // Slight flow @ OA // Circulate B/U , MT stack to well head, OWFF no flow // 1,965.0 1,965.0 7/7/2024 22:15 7/8/2024 00:00 1.75 COMPZN, RPCOMP NUND P ND BOP's. Pull 50K tension. Set 7" emergency slips. NU BOPs. test flange 3000psi 1,965.0 1,965.0 7/8/2024 00:00 7/8/2024 02:30 2.50 COMPZN, RPCOMP WAIT T HES didn't bring cement head with them, wait for delivery from Deadhorse 1,965.0 1,965.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 19/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/8/2024 02:30 7/8/2024 03:45 1.25 COMPZN, RPCOMP RURD P Rig up cement equipment and pressure test lines // PT lines 4000 psi // 1,965.0 1,965.0 7/8/2024 03:45 7/8/2024 04:15 0.50 COMPZN, RPCOMP CIRC P Circulate 120 bbls 140° water to warm // 5 bbls/min @ 265 psi taking returns past casing slips up stack down flow line 1,965.0 1,965.0 7/8/2024 04:15 7/8/2024 06:15 2.00 COMPZN, RPCOMP CMNT P Pump cement job as per Halliburton pump schedule. Cement Wet @ 04:27AM. Displace closing plug w/ rig pumps @ 3.5 BPM and 640 psi. Slow rate to 2 BPM @ 726 psi to bump closing plug. Final Circ. Pressure = 726 psi (@ 2 BPM). Bump closing plug. Shift cementer closed @ 1,900 psi. Hold 2,500 psi for 5-min. Bleed off to ensure cementer is closed and holding. Cement in place @ 06:00AM. o 10 bbls 80 deg F Fresh Water (w/ red dye) o 173 bbls of 15.3# Cement o Drop Closing Plug o 10 bbls Fresh Water Spacer o SD HES Pump. Turn over to Rig Pumps o Pump 65 BBLS 8.6# Seawater to displace closing plug 1,965.0 1,965.0 7/8/2024 06:15 7/8/2024 13:00 6.75 COMPZN, RPCOMP RURD P Bleed off. RD cement head. Washup HES cementers. Close bag. Open LPR. Vac truck suck 70 bbls cement out of cuttings tank. Pump down kill taking returns to cuttings tank. Wash cement from stack. Blowdown. Drain stack. Open up LPR. Clean cement out of BOP and test spool. Install VBR's in LPR. Flush cuttings tank w/ 100 bbls FW. Unload spare 7" casing and centralizer from pipe shed for restock. 1,965.0 1,965.0 7/8/2024 13:00 7/8/2024 14:30 1.50 COMPZN, RPCOMP WOC P WOC until +/- 100 psi compressive strength 1,965.0 1,965.0 7/8/2024 14:30 7/9/2024 00:00 9.50 COMPZN, RPCOMP NUND P ND BOP and 11" ported DSA. Rough cut 7". L/D and break out 4' pup from cut joint. RD GBR. Finish cut 7". Install pack-off. NU Tubing Head Adapter. PT pack-off. PT hanger void to 3,000 psi for 15-min. Measure new RKB to ULDS. NU BOPs. Install riser. Hook up trip tank hose. Install mouse hole. 1,965.0 0.0 7/9/2024 00:00 7/9/2024 01:00 1.00 COMPZN, RPCOMP BOPE P Set 7" test plug. PT BOP breaks to 2,500 psi. Pull test plug. 0.0 0.0 7/9/2024 01:00 7/9/2024 05:00 4.00 COMPZN, RPCOMP WAIT T Wait on test plug to be re-built // Unable to get test plug, install hanger with TWC // Test breaks 250/2500 0.0 0.0 7/9/2024 05:00 7/9/2024 06:00 1.00 COMPZN, RPCOMP RURD P RU 3 1/2' pipe handling equipment. Set Wear Ring. 0.0 0.0 7/9/2024 06:00 7/9/2024 07:30 1.50 COMPZN, RPCOMP BHAH P MU BHA #30 (Cement Mill out) 0.0 110.0 7/9/2024 07:30 7/9/2024 09:30 2.00 COMPZN, RPCOMP OTHR T Wear ring lock downs torqued in too far unable to pass through with BHA // Egged wear ring replaced with new 110.0 110.0 7/9/2024 09:30 7/9/2024 11:30 2.00 COMPZN, RPCOMP TRIP P TIH w/ BHA #30 to approx. 1900'. 110.0 1,900.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 20/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/9/2024 11:30 7/9/2024 15:30 4.00 COMPZN, RPCOMP MILL P Dry tag cement @ 1912' // Get free spin parameters // Pump 5 bpm @ 310 psi Rot 47 rpm @ 1681 ft/lbs Mill cement sleeve and plug T/ 1949' drop through cementer Continue in hole to top of sand @ 2,160' Dry drill on sand T/ 2,175' 1,900.0 2,165.0 7/9/2024 15:30 7/9/2024 17:30 2.00 COMPZN, RPCOMP TRIP P Pump sweep // OWFF // TOOH for venturi run 2,165.0 135.0 7/9/2024 17:30 7/9/2024 18:00 0.50 COMPZN, RPCOMP BHAH P Rack back drill collars, Lay down intensifier. Clean rig floor 135.0 35.0 7/9/2024 18:00 7/9/2024 19:00 1.00 COMPZN, RPCOMP BHAH P Lay down BHA #30, Jars, Bumper sub, and 6 1/8" mill 35.0 0.0 7/9/2024 19:00 7/9/2024 19:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #31, RCJB 0.0 44.5 7/9/2024 19:30 7/9/2024 21:00 1.50 COMPZN, RPCOMP TRIP P Trip in hole F//44' to top of sand @ 2170. 44.5 2,170.0 7/9/2024 21:00 7/9/2024 21:30 0.50 COMPZN, RPCOMP CIRC P PUH, PUW=64K, .Fluid vis to high @140K, to get optimal rate for basket. Circ 2X BU to thin down fluid. 2,170.0 2,171.0 7/9/2024 21:30 7/9/2024 22:00 0.50 COMPZN, RPCOMP OTHR P Wash down from 2170 to 2180' 9 BPM @ 1460 PSI. PUH 3" Circ BU 1.5X. Getting gel lumps in returns with small amount of rubber 2,171.0 2,180.0 7/9/2024 22:00 7/9/2024 23:00 1.00 COMPZN, RPCOMP TRIP P Trip out of hole F / 2177. PUW=64K 2,180.0 44.0 7/9/2024 23:00 7/9/2024 23:30 0.50 COMPZN, RPCOMP BHAH P Clean RCJB and rig floor. Some aliminum pieces and cement 44.0 0.0 7/9/2024 23:30 7/10/2024 00:00 0.50 COMPZN, RPCOMP TRIP P Trip in hole with RCJB second run 0.0 730.0 7/10/2024 00:00 7/10/2024 00:30 0.50 COMPZN, RPCOMP TRIP P Continue in well, RCJB run # 2. Dry tag @ 2183', RIW=55K 730.0 2,183.0 7/10/2024 00:30 7/10/2024 01:30 1.00 COMPZN, RPCOMP CIRC P Estabish circulation @ 9 BPM @ 1530PSI while diluting vised up seawater.Circ BU X2. Still getting gel clumps from wellbore 2,183.0 2,183.0 7/10/2024 01:30 7/10/2024 02:00 0.50 COMPZN, RPCOMP OTHR P Wash down to 2193 @ 9 BPM 600 PSI. 25 RPM 1.4K free torque. Recip 2175 to 2193 3X. Circ BU X1.2 2,183.0 2,193.0 7/10/2024 02:00 7/10/2024 03:00 1.00 COMPZN, RPCOMP TRIP P Trip out of hole W/RCJB, PUW=65K 2,193.0 0.0 7/10/2024 03:00 7/10/2024 03:30 0.50 COMPZN, RPCOMP BHAH P Clean RCJB small amount of aluminum and brass. Clean rig floor. Plan to RIH taking bigger bite of sand 0.0 0.0 7/10/2024 03:30 7/10/2024 04:30 1.00 COMPZN, RPCOMP TRIP P RIH RCJB run # 3 0.0 2,200.0 7/10/2024 04:30 7/10/2024 05:00 0.50 COMPZN, RPCOMP CIRC P Clean out sand to 2210' 2,200.0 2,210.0 7/10/2024 05:00 7/10/2024 07:00 2.00 COMPZN, RPCOMP TRIP P TOOH inspect RCJB 2,210.0 0.0 7/10/2024 07:00 7/10/2024 07:30 0.50 COMPZN, RPCOMP BHAH P Pick up BHA for RBP retrieval 0.0 12.0 7/10/2024 07:30 7/10/2024 09:00 1.50 COMPZN, RPCOMP TRIP P TIH to 2140 12.0 2,140.0 7/10/2024 09:00 7/10/2024 11:45 2.75 COMPZN, RPCOMP DISP P Displace well to 9.7# NaCl 2,140.0 2,140.0 7/10/2024 11:45 7/10/2024 13:15 1.50 COMPZN, RPCOMP TRIP P TOOH lay down RBP 2,140.0 0.0 7/10/2024 13:15 7/10/2024 13:45 0.50 COMPZN, RPCOMP CLEN P Clean rig floor prep for testing casing 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 21/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/10/2024 13:45 7/10/2024 15:45 2.00 COMPZN, RPCOMP PRTS P Pressure test casing 3500 psi 30 min // Pressure up on 7" 3500 psi rapid pressure loss with 0 psi on OA // Pump 10 bbls into well // Isolate pumps ensure pumps holding pumps holding good // Attempt to pt 7" unable to build past 550 psi pump 8 bbls into well // Bleed off pressure .5 bbls returned 0.0 0.0 7/10/2024 15:45 7/10/2024 16:00 0.25 COMPZN, RPCOMP SIPB T Well started flowing // took 2.5 BBl gain // Open to trip tank to monitor // Flow increasing. 13 BBl total // Close Blinds and monitor pressure // 15 min 140 psi 0.0 0.0 7/10/2024 16:00 7/10/2024 19:00 3.00 COMPZN, RPCOMP OWFF T Monitor and record pressures from choke every 10 minutes 0.0 0.0 7/10/2024 19:00 7/10/2024 22:30 3.50 COMPZN, RPCOMP OTHR T Well stabilized 1800 to 1900 @ 220 PSI tubing, O on annulas and conductor. Bleed off in step wise monor to zero WHP. Monitor for 30 Min. OPen blinds. Fill hole 13.6 BBls.to fill. Gas continue to break out. Took 3 BBl gain in trip tank with well at rolling boil. Shut in well. Prepare to perform Injectivity test 0.0 0.0 7/10/2024 22:30 7/10/2024 23:00 0.50 COMPZN, RPCOMP OTHR T Bullhead down well. 3 BPM @ 1500 PSI. Unable to get more rate below 1500 PSI. Pump 50 BBls 0.0 0.0 7/10/2024 23:00 7/11/2024 00:00 1.00 COMPZN, RPCOMP OWFF T Monitor well, 550 PSI @ 2300. 337 PSI @ 2400 0.0 0.0 7/11/2024 00:00 7/11/2024 03:30 3.50 COMPZN, RPCOMP OWFF T Bleed well off in steps from 320 PSI to 160 PSI. Monitor 30 Mim. Increase to 190. Bleed 190 to 95 PSI. Monitor 30 Min. Increaase to 130 PSI. Bleed down to 0 PSI. Observe 30 Min. A 20 min. presure up to 42 PSI. Bleed to zero. Observe well. Still zero after 30 minutes 0.0 0.0 7/11/2024 03:30 7/11/2024 04:00 0.50 COMPZN, RPCOMP OWFF T Well at no flow. Open blind rams. Hole full. Gas still rolling at surface. Calmer then earlier. Annulus and conductor pressure unchanged all tour. 0.0 0.0 7/11/2024 04:00 7/11/2024 05:30 1.50 COMPZN, RPCOMP OTHR T P/U Joint and wear ring pulling tool. Pull wear ring. Set hanger. Run in LDS's. Set BPV 0.0 0.0 7/11/2024 05:30 7/11/2024 06:30 1.00 COMPZN, RPCOMP BOPE T Test Blind Rams 250 low 2500 PSI high with chart 0.0 0.0 7/11/2024 06:30 7/11/2024 07:30 1.00 COMPZN, RPCOMP MPSP T Pull hanger and TWC install wear ring in stack 0.0 0.0 7/11/2024 07:30 7/11/2024 07:45 0.25 COMPZN, RPCOMP BHAH T Pick up test packer BHA 0.0 16.0 7/11/2024 07:45 7/11/2024 11:00 3.25 COMPZN, RPCOMP TRIP T TIH with test packer T/ 4000' to test casing to locate hole 16.0 3,990.0 7/11/2024 11:00 7/11/2024 12:00 1.00 COMPZN, RPCOMP CIRC T Circulate SxS ensure air out of system and well clean to 4000' 3,990.0 3,990.0 7/11/2024 12:00 7/11/2024 13:00 1.00 COMPZN, RPCOMP PRTS T Set test packer 3990' COE // Up wt 80K Dn wt 70K // Pressure test 2000psi under test packer // Test below packer fail inject 3 bbls/min @ 1000 psi // Test 4000' to surface good test 3,990.0 3,990.0 7/11/2024 13:00 7/11/2024 14:45 1.75 COMPZN, RPCOMP TRIP T TIH T/ 6000' 3,990.0 6,000.0 7/11/2024 14:45 7/11/2024 15:30 0.75 COMPZN, RPCOMP PRTS T Set packer 6000' // Test casing below 6000' unable to pressure up pump away 4 bbls @ 3 bbls/min // Test casing above 6000' 2000 psi good test 6,000.0 6,000.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 22/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/11/2024 15:30 7/11/2024 16:15 0.75 COMPZN, RPCOMP PRTS T Set Test packer 6000' // Up Wt 115K Dn Wt 83K // Pressure test casing under packer 2000 psi 6,000.0 6,000.0 7/11/2024 16:15 7/11/2024 18:30 2.25 COMPZN, RPCOMP TRIP T TIH T/ 8000' 6,000.0 8,000.0 7/11/2024 18:30 7/11/2024 19:00 0.50 COMPZN, RPCOMP PRTS T Set test packer @ 8012'. Attempt to test below packer to 2000 PSI - FAIL. 1500 PSI @ 3 BPM injection. zline up to pump down annulus. Pressure up to 2000PSI / 5 min. Good test. Bleed off annulus. Open UPR's. Release test packer. 8,000.0 8,012.0 7/11/2024 19:00 7/11/2024 20:00 1.00 COMPZN, RPCOMP OTHR T Weigh up fluid to 9.8 PPG in pits. Monitor well on trip tank Continue to circulate well @ 3 BPM @ 735 PSI 8,012.0 8,012.0 7/11/2024 20:00 7/11/2024 23:30 3.50 COMPZN, RPCOMP DISP T Continue to circulate well @ 4 BPM @ 715 PSI. Weighing up to 9.8 PPG in and out 8,012.0 8,012.0 7/11/2024 23:30 7/12/2024 00:00 0.50 COMPZN, RPCOMP OWFF T Shut down pump. Observe well for flow 30 minutes. Pass 8,012.0 8,012.0 7/12/2024 00:00 7/12/2024 05:30 5.50 COMPZN, RPCOMP TRIP T Trip out of well after getting 9.8 PPG fluid around, PUW=135K // Slow trip speed minimize swabbing 8,012.0 15.0 7/12/2024 05:30 7/12/2024 06:00 0.50 COMPZN, RPCOMP BHAH T Lay down Test packer BHA 15.0 0.0 7/12/2024 06:00 7/12/2024 06:30 0.50 COMPZN, RPCOMP SVRG P Service rig // adjust breaks on drawworks // service TD 0.0 0.0 7/12/2024 06:30 7/12/2024 08:00 1.50 COMPZN, RPCOMP BHAH P Pick up clean out BHA // Junk mill, boot baskets, srtring mills, and magnets 0.0 150.0 7/12/2024 08:00 7/12/2024 13:30 5.50 COMPZN, RPCOMP TRIP P TIH with clean out BHA // Tag @ 8219' 150.0 8,219.0 7/12/2024 13:30 7/12/2024 18:00 4.50 COMPZN, RPCOMP REAM P Clean out well T/ 8760 // Up wt 135K Dn wt 95K // Pump 5 bpm @ 1360 psi // Rot 65 rpm @ 7-8K torque // Add .75% to system free torque 4.5K Working tight spots F/ 8200' to 8219' // Overpulls T 200K // 8,219.0 8,760.0 7/12/2024 18:00 7/12/2024 19:30 1.50 COMPZN, RPCOMP CIRC P Pump Hi Vis sweep S X S. 5 BPM @ 8,760.0 8,755.0 7/12/2024 19:30 7/12/2024 20:00 0.50 COMPZN, RPCOMP OWFF P Perform 30 Min flow check 8,755.0 8,755.0 7/12/2024 20:00 7/12/2024 20:30 0.50 COMPZN, RPCOMP OTHR P Blow down top drive 8,755.0 8,755.0 7/12/2024 20:30 7/13/2024 00:00 3.50 COMPZN, RPCOMP TRIP P Trip out of well, PUW=135K, Lay down top joint stand 78, Bent. Continue out of hole to 2815' Midnight 8,755.0 2,815.0 7/13/2024 00:00 7/13/2024 01:00 1.00 COMPZN, RPCOMP TRIP P Continue tripping out of well 2,815.0 297.0 7/13/2024 01:00 7/13/2024 02:30 1.50 COMPZN, RPCOMP BHAH P At BHA, Lay down magnets and mill 297.0 0.0 7/13/2024 02:30 7/13/2024 03:30 1.00 COMPZN, RPCOMP BOPE P Drain stack, Perform weekly BOPE function test, Bring fishing tools to rig floor 0.0 0.0 7/13/2024 03:30 7/13/2024 04:30 1.00 COMPZN, RPCOMP BHAH P P/U BHA 36, Overshot, Bumpersub, and fishing Jars, Drill collar, intensifier 0.0 125.0 7/13/2024 04:30 7/13/2024 07:15 2.75 COMPZN, RPCOMP TRIP P Trip in well, BHA #36 125.0 5,200.0 7/13/2024 07:15 7/13/2024 09:30 2.25 COMPZN, RPCOMP SLPC P Cut and slip drill line 5,200.0 5,200.0 7/13/2024 09:30 7/13/2024 11:00 1.50 COMPZN, RPCOMP BHAH P P/U BHA 36, Overshot, Bumpersub, and fishing Jars, Drill collar, intensifier 5,200.0 8,700.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 23/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/13/2024 11:00 7/13/2024 12:00 1.00 COMPZN, RPCOMP FISH P Kelly up to pipe // Bring on pumps get perameters // Up wt 135K Dn wt 106K // Pump 3 bpm @ 507psi // Over shot top @ 8761' pressure increase to 900 psi // Full swallow T/ 8776.7' set down 10K Pick up 150K fish on // Jart 4 times 200K straight pull 225K no movement // Straight pull 250K pull fish free 8,700.0 8,770.0 7/13/2024 12:00 7/13/2024 14:00 2.00 COMPZN, RPCOMP CIRC P Circulate well SxS take bottoms up outside // Looked to get 4 seals back likely from plug // Work pipe ensure fish free // 5 bpm @ 550 psi // Flow check well 30min 8,770.0 8,770.0 7/13/2024 14:00 7/13/2024 15:00 1.00 COMPZN, RPCOMP SVRG P Inspect derrick after jarring // Fix bolt in TD track 8,770.0 8,770.0 7/13/2024 15:00 7/13/2024 20:00 5.00 COMPZN, RPCOMP TRIP P Trip out of well, PUW=60K 8,770.0 1,780.0 7/13/2024 20:00 7/13/2024 20:30 0.50 COMPZN, RPCOMP RGRP P Fill trip tank, Repair safety cable on grabber box retaining bolt 1,780.0 1,780.0 7/13/2024 20:30 7/13/2024 21:30 1.00 COMPZN, RPCOMP TRIP P Continue out of well, PUW=50K 1,780.0 131.0 7/13/2024 21:30 7/13/2024 22:30 1.00 COMPZN, RPCOMP BHAH P Lay down BHA # 36, Recover 22.07' cut joint, 4.06' pup, 10.0' seal assembly 131.0 0.0 7/13/2024 22:30 7/14/2024 00:00 1.50 COMPZN, RPCOMP BHAH P M/U BHA 37 to spear and retrive packer @ 8787 0.0 131.0 7/14/2024 00:00 7/14/2024 03:36 3.60 COMPZN, RPCOMP TRIP P Trip in hole BHA # 37 to spear packer @ 8787, KU stand 94. 3 BPM @ 715PSI, PUW=135K, SOW=105K 131.0 8,787.0 7/14/2024 03:36 7/14/2024 05:00 1.40 COMPZN, RPCOMP JAR P Pressure up @ 8787. Fully buried @ 8794, PU to 200K jars fire, Set down to 80k. Start jarring @ 225K with straight pulls. Jar 25 cycle 8,787.0 8,787.0 7/14/2024 05:00 7/14/2024 05:18 0.30 COMPZN, RPCOMP SVRG P Perform derrick inspection 8,787.0 8,787.0 7/14/2024 05:18 7/14/2024 05:48 0.50 COMPZN, RPCOMP SVRG P Lock in clutch bolts due to low clutch slipping 8,787.0 8,787.0 7/14/2024 05:48 7/14/2024 06:45 0.95 COMPZN, RPCOMP JAR P Continue jarring on packer // Total hits on packer 34, packer free 8,787.0 8,787.0 7/14/2024 06:45 7/14/2024 08:45 2.00 COMPZN, RPCOMP CIRC P Circulate SxS // pump through gas buster for any gas bubble coming to surface // Dump dirty mud to cuttings box ~ 10 bbls // shut down check for flow 8,787.0 8,787.0 7/14/2024 08:45 7/14/2024 15:00 6.25 COMPZN, RPCOMP TRIP P TOOH with packer, slight overpulls @ collars through 8100' // Continue out of hole 70'-90' per min not to swab well 8,787.0 38.0 7/14/2024 15:00 7/14/2024 15:30 0.50 COMPZN, RPCOMP BHAH P Lay down fish and spear BHA // Length of fish = 37.88' (8824.89' TOF left in hole) 38.0 0.0 7/14/2024 15:30 7/14/2024 20:30 5.00 COMPZN, RPCOMP TRIP P Pick up BHA# 38 test packer ( 15.18' OAL 9.62' COE ), TIH T/8800' COE 0.0 8,722.0 7/14/2024 20:30 7/14/2024 21:00 0.50 COMPZN, RPCOMP MPSP P KU @ 8722, Continue in to 8800', COE=8800' 8,722.0 8,800.0 7/14/2024 21:00 7/14/2024 21:30 0.50 COMPZN, RPCOMP MPSP P R/U test equipment 8,800.0 8,800.0 7/14/2024 21:30 7/14/2024 22:12 0.70 COMPZN, RPCOMP PRTS P PT 7" casing 3000PSI / 30 min. Good test. R/D test equipment, Release test packer 8,800.0 8,800.0 7/14/2024 22:12 7/14/2024 22:30 0.30 COMPZN, RPCOMP MPSP P Release test packer 8,800.0 8,800.0 7/14/2024 22:30 7/15/2024 00:00 1.50 COMPZN, RPCOMP TRIP P Fill trip tank, Trip out of well, PUW=135K 8,800.0 5,575.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 24/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/15/2024 00:00 7/15/2024 02:00 2.00 COMPZN, RPCOMP TRIP P Continue out of well with test packer 5,575.0 15.0 7/15/2024 02:00 7/15/2024 02:30 0.50 COMPZN, RPCOMP BHAH P Clean / Organize rig floor 15.0 15.0 7/15/2024 02:30 7/15/2024 03:00 0.50 COMPZN, RPCOMP BHAH P Lay down pup joint and test packer. BHA 38 15.0 0.0 7/15/2024 03:00 7/15/2024 04:00 1.00 COMPZN, RPCOMP BHAH P Make up fishing BHA 39 to retrieve seals. 0.0 131.0 7/15/2024 04:00 7/15/2024 08:45 4.75 COMPZN, RPCOMP TRIP P Trip in BHA #39 T/ 8740' 131.0 8,740.0 7/15/2024 08:45 7/15/2024 10:45 2.00 COMPZN, RPCOMP SLPC P Slip and cut drill line 8,740.0 8,740.0 7/15/2024 10:45 7/15/2024 11:45 1.00 COMPZN, RPCOMP FISH P Pump 5 bpm @ 842 psi // Overshot top of fish @ 8825' Fully locate 8830' // Pump pressure after fish engaged 5 bpm @ 1290 psi 8,740.0 8,825.0 7/15/2024 11:45 7/15/2024 13:30 1.75 COMPZN, RPCOMP CIRC P Circulate B/U @ 5 bpm @ 1350 psi // Flow check well some bubbles in stack // Circulate 1500 more strokes // OWFF well dead 8,825.0 8,825.0 7/15/2024 13:30 7/15/2024 19:00 5.50 COMPZN, RPCOMP TRIP P POOH to lay down fish 8,825.0 1,500.0 7/15/2024 19:00 7/15/2024 19:30 0.50 COMPZN, RPCOMP SVRG P Service tong line on break out 1,500.0 1,500.0 7/15/2024 19:30 7/15/2024 21:00 1.50 COMPZN, RPCOMP TRIP P Continue out of hole with fish 1,500.0 110.0 7/15/2024 21:00 7/15/2024 23:00 2.00 COMPZN, RPCOMP BHAH P Lay down fish // Blast joints // total fish recovered 125.02' // New top of fish 8950' 110.0 0.0 7/15/2024 23:00 7/16/2024 00:00 1.00 COMPZN, RPCOMP BHAH P Re-bait grapple in BHA // Pick up and run in hole 0.0 0.0 7/16/2024 00:00 7/16/2024 00:30 0.50 COMPZN, RPCOMP BHAH P P/U Overshot, bumper sub, Jar. and Intensifier 0.0 131.0 7/16/2024 00:30 7/16/2024 03:30 3.00 COMPZN, RPCOMP TRIP P Trip in well, BHA 40 to retrieve lower seal assembly 131.0 8,890.0 7/16/2024 03:30 7/16/2024 04:30 1.00 COMPZN, RPCOMP FISH P KU, PUW=130K, SOW=100K, 4 BPM @ 630 PSI, Rot 25 RPM, 2200 Tq. Wash down to 8950 see pressure increase to 850PSI. Swallow down to 8954, Pull up see 5-7K over for 3" 8,890.0 8,954.0 7/16/2024 04:30 7/16/2024 06:30 2.00 COMPZN, RPCOMP CIRC P Circ BU 4 BPM @ 815 PSI, OWFF Gas breaking out in flow nipple 8,954.0 8,954.0 7/16/2024 06:30 7/16/2024 09:30 3.00 COMPZN, RPCOMP CIRC P Line up to gas buster. Go back to circulate. Get out MW floating 9.6 heavy to 9.7 heavy. Add salt to keep 9.8PPG going in. Circ until 9.8 in and out 8,954.0 8,954.0 7/16/2024 09:30 7/16/2024 10:00 0.50 COMPZN, RPCOMP OWFF P Observe for flow. Well took .6 BBl/30 min 8,954.0 8,954.0 7/16/2024 10:00 7/16/2024 15:30 5.50 COMPZN, RPCOMP TRIP P Trip out of well, 70 FPM per BOT rep 8,954.0 130.0 7/16/2024 15:30 7/16/2024 17:30 2.00 COMPZN, RPCOMP BHAH P At surface, Looks like catcher is up in basket. Break off cut lip guide and pull grapple. Catcher stuck in top sub. Unable to recover from top sub. 130.0 0.0 7/16/2024 17:30 7/16/2024 18:30 1.00 COMPZN, RPCOMP WAIT P Mobilize new top sub from Deadhorse. Mobilize BHA #41 T/ RF. Crew change out. 0.0 0.0 7/16/2024 18:30 7/16/2024 19:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #41 Overshot T/ 131'. 0.0 131.0 7/16/2024 19:30 7/16/2024 22:30 3.00 COMPZN, RPCOMP TRIP P RIH F/ 131' T/ 8937', PUW=135K, SOW=105K. 131.0 8,937.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 25/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/16/2024 22:30 7/16/2024 23:15 0.75 COMPZN, RPCOMP FISH P K/U pump @ 4 BPM, 860 PSI. Rot @ 25 RPM, Free Tq=4.2K, Rot @ 40 RPM. Free Tq=5.5K. Kill rotary. Wash down tag w/ 15K down @ 8951'. No PSI increase. P/U 15K over. Rot down over stump multiple times T/ 8954'. Tq= 4-7K. No PSI increase. No over pull. Decision made to pull and look at tool string. 8,937.0 8,954.0 7/16/2024 23:15 7/17/2024 00:00 0.75 COMPZN, RPCOMP CIRC P Circ @ 4 BPM, 860 PSI. Slight gas cut brine, light weight 9.7 PPG brine until 9.8 PPG brine returns at surface. 8,954.0 8,954.0 7/17/2024 00:00 7/17/2024 00:30 0.50 COMPZN, RPCOMP OWFF P OWFF - no flow 8,954.0 8,954.0 7/17/2024 00:30 7/17/2024 01:00 0.50 COMPZN, RPCOMP TRIP P L/D working single. B/D TD. POOH F/ 8954' T/ 8793'. PUW=135K. 8,954.0 8,793.0 7/17/2024 01:00 7/17/2024 01:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Service hook load sensor on TD. 8,793.0 8,793.0 7/17/2024 01:30 7/17/2024 05:00 3.50 COMPZN, RPCOMP TRIP P POOH F/ 8793' T/ 3075'. PUW=135K. 8,793.0 3,075.0 7/17/2024 05:00 7/17/2024 05:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Drive shaft rotary table. 3,075.0 3,075.0 7/17/2024 05:30 7/17/2024 06:00 0.50 COMPZN, RPCOMP OWFF P OWFF 30 Min. PASS 3,075.0 3,075.0 7/17/2024 06:00 7/17/2024 08:30 2.50 COMPZN, RPCOMP TRIP P POOH F/ 3075' T/ 131', PUW=65K. 3,075.0 131.0 7/17/2024 08:30 7/17/2024 10:30 2.00 COMPZN, RPCOMP BHAH P Lay down BHA # 41, No fish, Cut lip guide distorted and cracked. Mill control show severe wear, Grapple had single wicker. No marks on top sub like we were bottoming out. Modify cut lip to decrease depth to grapple 131.0 0.0 7/17/2024 10:30 7/17/2024 11:00 0.50 COMPZN, RPCOMP BHAH P Make up BHA # 42 T/ 130' 0.0 130.0 7/17/2024 11:00 7/17/2024 15:00 4.00 COMPZN, RPCOMP TRIP P RIH F/ 130' T/ 8936', PUW=139K, SOW=101K. 130.0 8,936.0 7/17/2024 15:00 7/17/2024 15:45 0.75 COMPZN, RPCOMP FISH P KU Stand 95, PUW=139, SOW=101K, Pumps on 4 BPM @ 830 PSI. Stack out m@ 8950 with no PSI Increase. P/U and cycle. set back down. Rotate 15 RPM @ 3.9K Torque. Work down to 8954. See pressure increase @ 8951. PUH with 4K friction bite. Lose pressure. Set back down gain pressure. Spud multiple times work to get latch. Never more then friction bites with pressure loss. 8,936.0 8,954.0 7/17/2024 15:45 7/17/2024 18:45 3.00 COMPZN, RPCOMP CIRC P P/U circ well until consistent 9.8+ PPG fluid in and out. 8,954.0 8,934.0 7/17/2024 18:45 7/17/2024 19:15 0.50 COMPZN, RPCOMP OWFF P OWFF - no flow. 8,934.0 8,934.0 7/17/2024 19:15 7/17/2024 23:30 4.25 COMPZN, RPCOMP TRIP P POOH F/ 8934' T/ 130', PUW=139K. 8,934.0 130.0 7/17/2024 23:30 7/18/2024 00:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA F/ 130' T/ surface - No fish. 130.0 7/18/2024 00:00 7/18/2024 00:30 0.50 COMPZN, RPCOMP BHAH P Break down and inspect overshot. Cut lip guide belled out and cracked, heave wear pattern on bottom and inside of cut lip. Tapered plane control showed heave wear, bevel was rounded to 4 5/16" ID. Grapple showed minimal friction damage one side of it possibly from RBP. 0.0 0.0 7/18/2024 00:30 7/18/2024 01:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 26/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/18/2024 01:00 7/18/2024 01:30 0.50 COMPZN, RPCOMP SVRG P Service rig, grease crown, TD, draw works. 0.0 0.0 7/18/2024 01:30 7/18/2024 02:00 0.50 COMPZN, RPCOMP RURD P Mobilize BHA #43 to RF & pipe shed. 0.0 0.0 7/18/2024 02:00 7/18/2024 03:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #43 crown shoe, joint of wash pipe, RCJB T/ 183'. SOW=42K. 0.0 183.0 7/18/2024 03:00 7/18/2024 06:30 3.50 COMPZN, RPCOMP TRIP P RIH F/ 183' T/ 8813', PUW=140K, SOW=100K. 183.0 8,813.0 7/18/2024 06:30 7/18/2024 08:30 2.00 COMPZN, RPCOMP SLPC P Cut & slip 62' of drill line. 8,813.0 8,813.0 7/18/2024 08:30 7/18/2024 08:42 0.20 COMPZN, RPCOMP TRIP P Trip in to 8923, RIW=105K 8,813.0 8,923.0 7/18/2024 08:42 7/18/2024 11:00 2.30 COMPZN, RPCOMP CIRC P PJSM to displace to viscosified 9.8 PPG fluid. Line up to open top tan. Online 3 BPM @ 641 PSI 8,923.0 8,923.0 7/18/2024 11:00 7/18/2024 14:45 3.75 COMPZN, RPCOMP MILL P Obtain parameters, PUW=140K, RIW=100K, 4 BPM @ 896 PSI, 62 RPM, Free torque 4.7K. Set torque limit @ 6K. Start light 1 to 3K WOB, Set torque limit @ 6K. Start light 1 to 3K WOB, Saw weight bobble @ 8950.23'. Start working @ 8953.1' 8,923.0 8,953.6 7/18/2024 14:45 7/18/2024 15:45 1.00 COMPZN, RPCOMP RGRP P Pull off bottom. Hydraulic leak on top drive pipe handler. Loose hose. Adjust service loop 8,950.0 8,953.6 7/18/2024 15:45 7/18/2024 21:15 5.50 COMPZN, RPCOMP MILL P Obtain parameters, PUW=140K, RIW=100K, 4 BPM @ 896 PSI, 62 RPM, Free torque 4.7K. Set torque limit @ 6K. Start light 1 to 3K WOB, Set torque limit @ 7K.. Work WOB up T/ 5- 15K. 5-7 Tq. Dry drill for 15 min. Followed by milling with pumps on for 15 Min. Dry tag @ 8955.55'. Consult w/ town, decision made to pull and inspect due to long duration of milling time w/ limited footage. 8,953.6 8,955.6 7/18/2024 21:15 7/18/2024 22:00 0.75 COMPZN, RPCOMP CIRC P Circ BU @ 5.5 BPM, 1395 PSI. 8,955.6 8,955.6 7/18/2024 22:00 7/18/2024 22:30 0.50 COMPZN, RPCOMP OWFF P OWFF - no flow. B/D TD. 8,955.6 8,955.6 7/18/2024 22:30 7/19/2024 00:00 1.50 COMPZN, RPCOMP TRIP P POOH F/ 8955' T/ 6026', PUW=140K. 8,955.6 7/19/2024 00:00 7/19/2024 02:00 2.00 COMPZN, RPCOMP TRIP P POOH F/ 6026' T/ 183', PUW=115K. 6,026.0 183.0 7/19/2024 02:00 7/19/2024 05:30 3.50 COMPZN, RPCOMP BHAH P L/D & inspect BHA #43. Very minimal metal shavings on magnets. Crown shoe worn down to nub .24' shorter. Recovered 2.1' wadded up piece of rotten tubing & 2.2' of equalizing valve out of shoe. Recovered RBP & 2' additional piece of rotten tubing out of wash pipe. 183.0 0.0 7/19/2024 05:30 7/19/2024 08:00 2.50 COMPZN, RPCOMP BHAH P Clean and organize rig floor. Clean items retrieved from well. Formulate plan forward. P/U BHA # 44 with 6" crown shoe, Wash Pipe, finger catchers, and junk barrel extension 0.0 183.6 7/19/2024 08:00 7/19/2024 11:30 3.50 COMPZN, RPCOMP TRIP P Trip in well. BHA #44 183.6 8,900.0 7/19/2024 11:30 7/19/2024 12:30 1.00 COMPZN, RPCOMP TRIP P KU on stand 95, PUW=135K. 115K rotating, SOW=100K. 8,900.0 8,900.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 27/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/19/2024 12:30 7/19/2024 18:00 5.50 COMPZN, RPCOMP MILL P Initial tag 8955.71 Dry 5.5 BPM @ 1440 PSI 46 RPM @ 5K torque. WOB 3-13K, On bottom Tq 6.3-7.5K. Mill T/ packer top@ 8968.21'. Ream up off top and back down to packer top several times. 8,955.7 8,968.2 7/19/2024 18:00 7/19/2024 19:00 1.00 COMPZN, RPCOMP CIRC P P/U above fish top T/ 8923'. Circ BU @ 5.5 BPM, 1480 PSI. 8,968.2 8,923.0 7/19/2024 19:00 7/19/2024 19:30 0.50 COMPZN, RPCOMP OWFF P OWFF - no flow. B/D TD. 8,923.0 8,923.0 7/19/2024 19:30 7/19/2024 23:00 3.50 COMPZN, RPCOMP TRIP P POOH F/ 8923' T/ 183'. PUW=145K. 8,923.0 183.0 7/19/2024 23:00 7/20/2024 00:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA #44, minimal metal shavings on magnets. Large pieces of rotten,3 1/2" tubing in RCJB. Heavy wear on crown shoe. 183.0 0.0 7/20/2024 00:00 7/20/2024 00:30 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 7/20/2024 00:30 7/20/2024 01:30 1.00 COMPZN, RPCOMP WWWH P Jet BOP stack. Suck out stack. 0.0 0.0 7/20/2024 01:30 7/20/2024 02:00 0.50 COMPZN, RPCOMP MPSP P Pull wear bushing. Set test plug. 0.0 0.0 7/20/2024 02:00 7/20/2024 03:00 1.00 COMPZN, RPCOMP RURD P R/U testing equipment. Grease manuals & HCR's. Fill BOPE w/ fresh water. 0.0 0.0 7/20/2024 03:00 7/20/2024 03:30 0.50 COMPZN, RPCOMP SFTY P Crew change out. Shell test. 0.0 0.0 7/20/2024 03:30 7/20/2024 04:00 0.50 COMPZN, RPCOMP RURD P Purge air out of BOPE. 0.0 7/20/2024 04:00 7/20/2024 10:30 6.50 COMPZN, RPCOMP BOPE P Bi-weekly BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's, w/ 3 1/2" test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3100 PSI, after closure=1750 PSI, 200 PSI attained =19 sec, full recovery attained = 99 sec. UVBR's= 5 sec, Annular= 16 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2000 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Adam Earl. No Failures during test 0.0 0.0 7/20/2024 10:30 7/20/2024 11:00 0.50 COMPZN, RPCOMP WWSP P Pull test plug, Install wear ring 0.0 0.0 7/20/2024 11:00 7/20/2024 11:30 0.50 COMPZN, RPCOMP SVRG P Service / Inspect top drive.Service draw works 0.0 0.0 7/20/2024 11:30 7/20/2024 12:00 0.50 COMPZN, RPCOMP BHAH P Clean rig floor / Reconfigure overshot 0.0 0.0 7/20/2024 12:00 7/20/2024 13:00 1.00 COMPZN, RPCOMP BHAH P Put BHA in order, P/U BHA #45 5 3/4" Overshot with cut lip guide w. 4.5" spiral grapple, 2 extensions, top sub, LBS, 4 3/4" jar, Drill collars, and intensifier 0.0 134.7 7/20/2024 13:00 7/20/2024 17:30 4.50 COMPZN, RPCOMP TRIP P RIH w/ BHA #45 T/ 8940', PUW135K,, SOW=96K. 134.7 8,940.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 28/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/20/2024 17:30 7/20/2024 18:15 0.75 COMPZN, RPCOMP FISH P Obtain parameters pump @ 3 BPM, 520 PSI. Rot @ 15 RPM, 4K Free Tq. Wash @ ream over fish top. Saw PSI increase T/ 715 PSI @ 8955'. Swallow T/ 8957' set down 15K. P/U T/ 180K bleed jars. Straight pull T/ 200K. Hold tension for 5 Min. Pipe free. P/U 140K. RIH saw PSI increase @ 8951' indicating seals are on. P/U T/ 8940'. 8,940.0 8,940.0 7/20/2024 18:15 7/20/2024 19:00 0.75 COMPZN, RPCOMP CIRC P Circ BU @ 5.5 BPM, 1000 PSI. 8,940.0 8,940.0 7/20/2024 19:00 7/20/2024 19:30 0.50 COMPZN, RPCOMP OWFF P OWFF - no flow. L/D single. B/D TD. 8,940.0 8,940.0 7/20/2024 19:30 7/21/2024 00:00 4.50 COMPZN, RPCOMP TRIP P POOH F/ 8940' T/ 1616', PUW=145K. 8,940.0 1,616.0 7/21/2024 00:00 7/21/2024 00:45 0.75 COMPZN, RPCOMP TRIP P POOH F/ 1616' T/ 135', PUW=60K. 1,616.0 135.0 7/21/2024 00:45 7/21/2024 01:30 0.75 COMPZN, RPCOMP BHAH P L/D BHA #45 - No fish. Inspect grapple, wear signs on stop ring & control. Slight wear on grapple. Downsize grapple F/ 4.5" T/ 4.375" 135.0 0.0 7/21/2024 01:30 7/21/2024 02:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #46 Overshot w/ 4.375" spiral grapple T/ 135'. 0.0 135.0 7/21/2024 02:00 7/21/2024 03:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ 135' T/ 1616' SOW=55K. 135.0 1,616.0 7/21/2024 03:00 7/21/2024 03:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Inspect draw works. 1,616.0 1,616.0 7/21/2024 03:30 7/21/2024 06:30 3.00 COMPZN, RPCOMP TRIP P RIH F/ 1616' T/ 8940. 1,616.0 8,940.0 7/21/2024 06:30 7/21/2024 07:30 1.00 COMPZN, RPCOMP FISH P 8940', P/U Single, Kelly Up.PUW=150K, RIW=60K Pump online 3 BPM @515 PSI. RIH, See pressure increase @ 8951. Continue in to hard tag 8957. Set down 25K. Final pressure increase 930 PSI. PUH @ 8952 see pressure drop off. No over pull. Repeat. Pressures the same. looks like seals stroking into PBR 8,940.0 8,957.0 7/21/2024 07:30 7/21/2024 13:00 5.50 COMPZN, RPCOMP TRIP P Lay down singe, Trip out, PUW=150K, Trip out 70 FPM 8,957.0 135.0 7/21/2024 13:00 7/21/2024 14:30 1.50 COMPZN, RPCOMP BHAH P Stand back collars, Lay down LBS. Seals assembly in overshot. Unable to remove assemble from overshot. Break off overshot bowl. Lay down seal assembly. Seal 6.5', Pup 9.51, Ava nipple 2.85, Ava on top of nipple 1.15. OAL=20.01'. Isolation sleeve in AVA nipple 135.0 0.0 7/21/2024 14:30 7/21/2024 15:00 0.50 COMPZN, RPCOMP BHAH P Clean rig floor, Prep to pick up BHA #47 0.0 0.0 7/21/2024 15:00 7/21/2024 16:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #47, 6.125 packer mill, Boot basket X2, LBS, Jar, 1 stand collars, Intensifier, Magnets X2 T/ 161' 0.0 161.7 7/21/2024 16:00 7/21/2024 20:00 4.00 COMPZN, RPCOMP TRIP P RIH F/ 161' T/ 8840', PUW=150K, SOW=95K. 161.7 8,840.0 7/21/2024 20:00 7/21/2024 21:30 1.50 COMPZN, RPCOMP SLPC P Slip & cut 66' of drill line, Calibrate block height. Set COM. Calibrate hook load. 8,840.0 8,840.0 7/21/2024 21:30 7/21/2024 22:15 0.75 COMPZN, RPCOMP REAM P RIH took 15K string weight @ 8858'. Wash & ream through tight spot. F/ 8855' T/ 8858'. Pump @ 5 BPM, 940 PSI. Rot @ 80 RPM, 4.7K Free Tq. ROT=118K. Ream down T/ 8874'. Back up T/ 8850' & back down, Tq=7K. 8,840.0 8,874.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 29/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/21/2024 22:15 7/21/2024 22:30 0.25 COMPZN, RPCOMP TRIP P RIH F/ 8874' T/ 8964', PUW=150K, SOW=95K. 8,874.0 8,964.0 7/21/2024 22:30 7/22/2024 00:00 1.50 COMPZN, RPCOMP MILL P K/U obtain parameters. Pump @ 3-4.5 BPM, 500-770 PSI. Rot @ 70 RPM, 4.7K Free Tq. ROT=118K. Tag packer top @ 8968'. Mill F/ 8968 T/ 8969', WOB=5-10K, Tq=6-8.4K. 8,964.0 8,969.0 7/22/2024 00:00 7/22/2024 03:00 3.00 COMPZN, RPCOMP MILL P Cont milling packer F/ 8969' T/ 8971'. Packer moving down hole. Pump @ 2- 4.5 BPM, 330-770 PSI. Rot @ 70 RPM, 4.7K Free Tq. ROT=118K. WOB=5- 15K, Tq=6-8.4K. Push packer T/ 8997'. P/U space out T/ 8964'. 8,969.0 8,964.0 7/22/2024 03:00 7/22/2024 04:00 1.00 COMPZN, RPCOMP CIRC P Circ packer gas out starting @ 2.BPM, 330 PSI. staging up @ 3 BPM, 520 PSI, @ 4 BPM, 706 PSI. @ 5 BPM, 950 PSI. 8,964.0 8,964.0 7/22/2024 04:00 7/22/2024 04:30 0.50 COMPZN, RPCOMP REAM P Wash & ream in hole Circ @ 2 BPM, 330 PSI, Rot 70 RPM, 4.7K Tq. Pushing packer T/ 9018' torque up. took weight. Stop ROT. Set down 25K @ 9018' P/U, set down 30K @ 9018'. L/D 2 singles T/ 8964''. 8,964.0 8,964.0 7/22/2024 04:30 7/22/2024 05:00 0.50 COMPZN, RPCOMP OWFF P OWFF, B/D TD. 8,964.0 8,964.0 7/22/2024 05:00 7/22/2024 05:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease TD, blocks & crown. 8,964.0 8,964.0 7/22/2024 05:30 7/22/2024 10:30 5.00 COMPZN, RPCOMP TRIP P POOH F/ 8964' T/ 161 8,964.0 161.0 7/22/2024 10:30 7/22/2024 11:00 0.50 COMPZN, RPCOMP BHAH P At BHA, Lay down Packer Milling BHA #47, Clean boot baskets and magnets 161.0 0.0 7/22/2024 11:00 7/22/2024 13:30 2.50 COMPZN, RPCOMP BHAH P Clean and clear rig floor, Send out BHA #47 Get BHA # 48 in order. P/U Spear, bumper sub, Jars, Stand of collars, PU Intensifier 0.0 131.0 7/22/2024 13:30 7/22/2024 16:00 2.50 COMPZN, RPCOMP TRIP P Trip in well, 131' to 8937, PUW=150K. SOW=98K 131.0 8,937.0 7/22/2024 16:00 7/22/2024 17:00 1.00 COMPZN, RPCOMP FISH P P/U Single, attempt to stab packer @ 9018', Wash down to 9190, Pick up 9 singles, Pumping 3 BPM @ 578PSI. Pushing fish down, Set down 30K on bottom with 8,937.0 9,190.0 7/22/2024 17:00 7/22/2024 18:00 1.00 COMPZN, RPCOMP CIRC P Circ BU, 4 BPM @ 936 PSI 9,190.0 9,119.0 7/22/2024 18:00 7/22/2024 19:00 1.00 COMPZN, RPCOMP OWFF P OWFF, Service top drive. C/O Lube oil filter 9,119.0 9,119.0 7/22/2024 19:00 7/22/2024 20:00 1.00 COMPZN, RPCOMP TRIP P Trip out of well, 9120 to 8720, Limited to 70 FPM 9,119.0 8,720.0 7/22/2024 20:00 7/22/2024 23:00 3.00 COMPZN, RPCOMP CIRC P 8720, Trip sheet showing gain, swabbing. KU to stand 93, Circulate BU. Getting gassy returns with sand. 3 BBLs/min. Pump 20 BBl 57K LSRV. STS 8,720.0 8,720.0 7/22/2024 23:00 7/22/2024 23:30 0.50 COMPZN, RPCOMP OWFF P OWFF- no flow. POOH F/ 8720 T? 8561'. Small gain in T/ 8868'. 8,720.0 8,720.0 7/22/2024 23:30 7/23/2024 00:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 8720 T/ 8568'. Small gain in TT. Well continued swabbing. 8,720.0 8,658.0 7/23/2024 00:00 7/23/2024 11:45 11.75 COMPZN, RPCOMP PMPO P Pump OOH @ 40' FPM @1.5 BPM F/ 8658' T/ 8287'. Good hole fill. Pump OOH @ 70 FPM @ 2 BPM F/ 8267; T/ 131' 8,658.0 131.0 7/23/2024 11:45 7/23/2024 13:00 1.25 COMPZN, RPCOMP BHAH P L/D BHA #48 & fish. OAL PBR T/ WLEG 31.80'. 131.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 30/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/23/2024 13:00 7/23/2024 13:30 0.50 COMPZN, RPCOMP CLEN P CLean & clear RF. 0.0 0.0 7/23/2024 13:30 7/23/2024 14:15 0.75 COMPZN, RPCOMP BHAH P M/U BHA #49,Clean out Assy - mule shoe, tandem 6 1/8" sting mills, magnets, jars & bumper sub, stand DC's & intensifier T/ 167'. 0.0 167.0 7/23/2024 14:15 7/23/2024 16:00 1.75 COMPZN, RPCOMP TRIP P RIH F/ 167' T/ 4341', SOW=75K. 167.0 4,341.0 7/23/2024 16:00 7/23/2024 17:00 1.00 COMPZN, RPCOMP SVRG P Service rig. Work on foot throttle. 4,341.0 4,341.0 7/23/2024 17:00 7/23/2024 19:00 2.00 COMPZN, RPCOMP TRIP P RIH F/ 4341' T/ 8650' obtain parameters. PUWT:140 SOWT:95 ROTWT: 115K @ 3.8K TQ 4,341.0 8,650.0 7/23/2024 19:00 7/23/2024 22:30 3.50 COMPZN, RPCOMP REAM P Wash and Ream F/8650' to 9016'. Pump around high vis sweeps @ 8879'. Encountered torque spike @ 9016' to 7600 FT/LBS 944 PSI @ 5 BBL/ Min 5.8K TQ @ 60 RPM 115K ROTWT 8,650.0 9,016.0 7/23/2024 22:30 7/24/2024 00:00 1.50 COMPZN, RPCOMP CIRC P Work tight spot F/ 9016'- 9050' using 60 RPM working tight spot w/60 RPM @ 7.5K to 8.5K TQ with out success. Reduce rotary to 15 RPM @ 4K-5K TQ, and work first mill past tight spot. Increase rotary and use upper mill to work through tight spot w/ 60 RPM until TQ reduced to 6K. Turn off rotary and drift through two times. 9,016.0 9,050.0 7/24/2024 00:00 7/24/2024 01:00 1.00 COMPZN, RPCOMP REAM P Wash and Ream F/9030' to 9175'. 946 PSI @ 5 BBL/ Min 5.8K TQ @ 60 RPM 115K ROTWT 9,050.0 9,175.0 7/24/2024 01:00 7/24/2024 03:00 2.00 COMPZN, RPCOMP CIRC P Circulate around 2 15 BBL hi vis sweeps. Circulate hole clean @ 960 PS @ 5 BBL/ Min. P/U T/ 9156' 9,175.0 9,156.0 7/24/2024 03:00 7/24/2024 03:30 0.50 COMPZN, RPCOMP OTHR P L/D signal. Blow down top drive, choke, and kill lines. Prepare pipe shed to lay down pipe. 9,156.0 9,156.0 7/24/2024 03:30 7/24/2024 04:00 0.50 COMPZN, RPCOMP SVRG P Service top drive, and rig floor equipment. 9,156.0 7/24/2024 04:00 7/24/2024 05:00 1.00 COMPZN, RPCOMP RGRP T Change out gear oil in TD. 9,155.0 9,156.0 7/24/2024 05:00 7/24/2024 08:30 3.50 COMPZN, RPCOMP PULD P POOH L/D DP F/ 9156' T/ 6257;. PUW=145 9,156.0 6,257.0 7/24/2024 08:30 7/24/2024 09:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Replace tong pull back line. 6,257.0 6,257.0 7/24/2024 09:00 7/24/2024 09:30 0.50 COMPZN, RPCOMP RGRP T Cont replacing tong pull back line. 6,257.0 6,257.0 7/24/2024 09:30 7/24/2024 15:00 5.50 COMPZN, RPCOMP PULD P LDDP F/ 6257' T/ 167'. PUW=125K. 6,257.0 167.0 7/24/2024 15:00 7/24/2024 16:30 1.50 COMPZN, RPCOMP BHAH P L//D BHA #49. 167.0 0.0 7/24/2024 16:30 7/24/2024 17:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. Send all Baker tools out. 0.0 0.0 7/24/2024 17:00 7/24/2024 17:30 0.50 COMPZN, RPCOMP SFTY P PJSM w/ SLB E-line & rig crew on R/U and run caliper. 0.0 0.0 7/24/2024 17:30 7/24/2024 19:00 1.50 COMPZN, RPCOMP ELNE P R/U SLB E-line, and pick up tools. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 31/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/24/2024 19:00 7/24/2024 20:30 1.50 COMPZN, RPCOMP ELOG P RIH F/ surface to 9175. P/U to 9165 to put tools/ line intension. Turn on logging tools. 0.0 9,165.0 7/24/2024 20:30 7/24/2024 21:30 1.00 COMPZN, RPCOMP ELOG P Log F/ 9165' to 8587' 9,165.0 8,587.0 7/24/2024 21:30 7/24/2024 23:00 1.50 COMPZN, RPCOMP ELOG P Turn off tools, and POOH to surface. Contact town, discuss logs, and packer placement, and tally. 8,587.0 0.0 7/24/2024 23:00 7/25/2024 00:00 1.00 COMPZN, RPCOMP ELNE P Break down Logging tools, and rig down Eline. 0.0 0.0 7/25/2024 00:00 7/25/2024 01:30 1.50 COMPZN, RPCOMP OTHR P Pull wear ring, R/D pipe spinners, R/U GBR casing equipment on the rig floor. 0.0 0.0 7/25/2024 01:30 7/25/2024 12:00 10.50 COMPZN, RPCOMP PUTB P P/U and RIH W/ 3.5" 9.3# HYD 563 tubing F/ surface T/ 9038' WLEG ORKB. Hyd 563 torque turned T/ 2900 Ft/lbs. Best O life 2000 arctic grade dope used. PUWT: 99K SOWT: 70K 0.0 9,038.0 7/25/2024 12:00 7/25/2024 13:00 1.00 COMPZN, RPCOMP RURD P R/U circ hose T/ TBG. 9,038.0 9,038.0 7/25/2024 13:00 7/25/2024 14:30 1.50 COMPZN, RPCOMP PACK P Pressure up & set tandem Bluepack Max packers staging pumps in 500 PSI increments & holding for 1 min T/ 3600 PSI. Seals sheared from PBR, lost string weight. After shear pressure fell T/ 3350 PSI. Over 30 Min pressure fell T/ 3000 PSI. Pressure back up T/ 3600 PSI, held for 20 minutes fell T/ 3500 PSI. Pressure back up T/ 3620 PSI & hold for additional 10 minutes pressure fell T/ 3600 PSI. This meets SLB criteria for packer set 30 Min @ 3500 PSI. 9,038.0 9,037.0 7/25/2024 14:30 7/25/2024 15:45 1.25 COMPZN, RPCOMP HOSO P Pull seals out T/ 8670'. Pump @ 2 BPM, 285 PSI. RIH locate top of PBR @ 8678' pump pressure increase T/ 450 PSI. Bleed off pump. RIH fully locate @ 8699' w/ 5K string weigh. P/U 6' mark pipe. Space out. L/D joints #285, # 284, #283. M/U space out pups 9.69', 9.73', 8.08', M/U joint # 283. PUW=100K, SOW=69K. 8,700.0 8,660.0 7/25/2024 15:45 7/25/2024 16:30 0.75 COMPZN, RPCOMP PULD P P/U landing joint. R/U circ equipment on top. M/U landing joint to hanger. M/U hanger to string. 8,660.0 8,660.0 7/25/2024 16:30 7/25/2024 18:30 2.00 COMPZN, RPCOMP CRIH P Reverse circ 240 Bbls 9.8 PPG Ci brine down IA. Followed by 10 Bbls neat 9.8 PPG Brine out of pits @ 3 BPM, 220 PSI. 8,660.0 8,660.0 7/25/2024 18:30 7/25/2024 19:00 0.50 COMPZN, RPCOMP OTHR P Blow down lines, Empty trip tank. Drain stack. 8,660.0 8,660.0 7/25/2024 19:00 7/25/2024 20:00 1.00 COMPZN, RPCOMP THGR P Land hanger, verify hanger on seat. RILDS. 8,692.0 0.0 7/25/2024 20:00 7/25/2024 21:00 1.00 COMPZN, RPCOMP SEQP P R/U lines on tubing, and IA, and circulating manifold. Flood lines and pressure test surface lines. 0.0 0.0 7/25/2024 21:00 7/25/2024 22:30 1.50 COMPZN, RPCOMP PRTS P Line up and pressure test tubing to 3500 PSI for 30 min: GOOD. Bleed tubing to 2000 PSI, and trap pressure in tubing. Line up on IA and pressure test IA to 3000 PSI for 30 MIN: GOOD. Line up on tubing, and bleed tubing pressure, observe SOV shear out at 2000 PSI differential, bleed IA. Line up to and reverse circulate at 2 BPM @ 225 PSI. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Page 32/32 1A-11 Report Printed: 8/15/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/25/2024 22:30 7/25/2024 23:30 1.00 COMPZN, RPCOMP MPSP P Rig down tubing line, and pull landing joint. Drain fluid from stack. Dry rod in BPV. 0.0 0.0 7/25/2024 23:30 7/26/2024 00:00 0.50 COMPZN, RPCOMP MPSP P Line up and test BPV from bellow to 1000 PSI for 10 min: GOOD test. 0.0 0.0 7/26/2024 00:00 7/26/2024 01:00 1.00 COMPZN, WHDBOP RURD P Blow down, and rig down test lines. 0.0 0.0 7/26/2024 01:00 7/26/2024 09:00 8.00 COMPZN, WHDBOP OTHR P N/D bell nipple, and flow box to perform between wells maintenance of the annular. R/D hole fill line, and actuator hoses. Open ram doors, clean and inspect for between wells maintenance. Clean pits. Remove pad eye in the derrick. 0.0 0.0 7/26/2024 09:00 7/26/2024 10:00 1.00 COMPZN, WHDBOP NUND P N/D BOP 0.0 0.0 7/26/2024 10:00 7/26/2024 11:45 1.75 COMPZN, WHDBOP NUND P Set tree test dart. N/U adaptor spool & tree. 0.0 0.0 7/26/2024 11:45 7/26/2024 12:15 0.50 COMPZN, WHDBOP PRTS P PT hanger void T/ 5000 PSI for 15 Min. 0.0 0.0 7/26/2024 12:15 7/26/2024 14:30 2.25 COMPZN, WHDBOP RURD P N/U companion flange off of production valve. R/U circ equipment & LRS for tree test & freeze protect. 0.0 0.0 7/26/2024 14:30 7/26/2024 15:30 1.00 COMPZN, WHDBOP PRTS P PT tree T/ 5000 PSI for 10 Min. 0.0 0.0 7/26/2024 15:30 7/26/2024 16:00 0.50 COMPZN, WHDBOP MPSP P Pull test dart & BPV 0.0 0.0 7/26/2024 16:00 7/26/2024 18:00 2.00 COMPZN, WHDBOP FRZP P LRS freeze protect w/ 81 Bbls diesel down IA. ICP=700. FCP=1000. U-tube well for 1 Hr. 0.0 0.0 7/26/2024 18:00 7/26/2024 19:30 1.50 DEMOB, MOVE RURD P R/D circulating lines, and remove other equipment from cellar. Empty remaining fluid in pits. Move equipment from around rig, and prepare to move rig. 0.0 7/26/2024 19:30 7/26/2024 21:00 1.50 DEMOB, MOVE MOB P Pull rig of off of 1A-11. Release rig @ 2100 hrs. Final pressures Tubing 45 PSI, 300 PSI IA Rig released @ 21:00 Hrs Rig: NORDIC 3 RIG RELEASE DATE 7/26/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,221.0 1A-11 8/4/2024 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Replace SOV w/ DMY. Pull B&R/RHC. Tag 1A-11 8/4/2024 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 33.0 80.0 80.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 31.6 2,946.7 2,425.0 45.50 K-55 BUTT Tie-Back String 7 6.28 27.8 1,966.0 1,794.9 26.00 L-80 HYD 563 Production 7 6.28 1,963.0 9,712.6 6,689.8 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.1 Set Depth 8,692.9 String Max No 3 1/2 Set Depth 5,982.8 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.1 26.1 0.00 Hanger 7.010 Cameron 7 1/16" x 3 1/2" Gen 4 TBG Hanger (EUE top thread) Camero n Gen 4 2.950 8,591.3 5,918.3 51.09 Mandrel GAS LIFT 5.927 3.5" x 1.5" SLB MMG, GLM SLB MMG 2.920 8,650.7 5,955.8 50.49 Nipple - X 4.290 3.5" HES 2.813" X-Nipple HES X Nipple 2.813 8,669.8 5,968.0 50.30 Locator 4.500 Baker Locator Baker Locator 2.960 8,671.2 5,968.9 50.29 Seal Assembly 3.980 Baker 80-40, BG22 Seal Assembly (21.71' seals) (6.63' from fully located) Baker 80-40 Seal Assembl y 2.990 Top (ftKB) 8,677.8 Set Depth 9,038.2 String Max No 3 1/2 Set Depth 6,213.4 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,677.8 5,973.2 50.22 PBR 5.880 Baker 80-40 PBR (22.01' PBR) Baker 80-40 PBR 4.000 8,717.8 5,998.8 49.82 Packer 6.280 3-1/2" x 7" BluePack Max RH Vam Top B x P SLB Bluepac k Max RH 2.894 8,990.1 6,180.0 46.62 Packer 6.280 3-1/2" x 7" BluePack Max RH Vam Top B x P SLB Bluepac k Max RH 2.894 9,016.2 6,198.0 46.02 Nipple - X 4.290 3.5" x 2.813" X-Nipple HES X Nipple 2.813 9,037.7 6,213.0 45.37 Wireline Guide 4.290 3.5" Wire Line Entry Guide HES WLEG 2.998 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) 27.8 27.8 0.00 EMERGENCY SLIPS 11" x 7" Emergency Slips 7/8/2024 7.000 9,224.0 6,346.1 44.88 FISH E-Line Tool 18.5' long 10/31/1982 9,346.0 6,432.9 44.73 FISH VANN GUN 278' long 12/2/1981 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,591.3 5,918.3 51.09 1 GAS LIFT DMY RK 1 1/2 0.0 8/3/2024 SLB MMG 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,950.3 1,783.9 45.38 Collar - Stage 8.255 CMTR,TYPE H ES-II, HYD 563 L- 80 (S/N#: B5031046-01) Halliburto n HES II CMTR 6.267 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,878.0 8,918.0 6,104.0 6,130.9 C-4, C-3, C-2, C- 1, 1A-11 12/21/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph 8,930.0 8,938.0 6,139.0 6,144.4 UNIT B, 1A-11 12/21/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph 9,082.0 9,095.0 6,244.5 6,253.9 A-5, 1A-11 12/21/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph 9,108.0 9,150.0 6,263.3 6,293.6 A-4, 1A-11 12/21/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 27.8 1,966.0 27.8 1,794.9 Production String 1 Cement 173 bbls of 15.3# cement to surface 7/8/2024 1A-11, 8/15/2024 9:12:58 AM Vertical schematic (actual) Production; 1,963.0-9,712.6 FISH; 9,346.0 FISH; 9,224.0 IPERF; 9,108.0-9,150.0 IPERF; 9,082.0-9,095.0 Nipple - X; 9,016.2 Packer; 8,990.1 IPERF; 8,930.0-8,938.0 IPERF; 8,878.0-8,918.0 Packer; 8,717.8 Seal Assembly; 8,671.2 Nipple - X; 8,650.7 Mandrel GAS LIFT; 8,591.3 SURFACE; 31.6-2,946.7 Tie-Back String; 27.7-1,966.0 Production String 1 Cement; 27.8 ftKB CONDUCTOR; 33.0-80.0 EMERGENCY SLIPS; 27.8 Hanger; 26.1 KUP INJ KB-Grd (ft) 39.01 RR Date 12/22/198 1 Other Elev 1A-11 ... TD Act Btm (ftKB) 9,732.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292068500 Wellbore Status INJ Max Angle & MD Incl (°) 57.00 MD (ftKB) 7,900.00 WELLNAME WELLBORE1A-11 Annotation Last WO: End Date 7/26/2024 H2S (ppm) DateComment SSSV: TRDP C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-07-24_20292_KRU_1A-11_CaliperCasingSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20292 KRU 1A-11 50-029-20685-00 Caliper Casing Survey 24-Jul-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 181-173 T39309 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.29 13:58:10 -08'00' Originated: Delivered to:9-Jul-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-11 50-029-20685-00 909447215 Kuparuk River Radial Bond Record Field & Processed 3-Jul-24 0 1 2 1B-04 50-029-20595-00 909359143 Kuparuk River Plug Setting Record Field- Final 5-Jun-24 0 1 3 1C-24 50-029-23063-00 n/a Kuparuk River Plug Setting Record Field- Final 6-May-24 0 1 4 1C-157 50-029-23754-00 909345851 Kuparuk River Water Flow Record Field & Processed 25-May-24 0 1 5 1D-135 50-029-22816-00 n/a Kuparuk River Plug Setting Record Field- Final 25-May-24 0 1 6 1D-145 50-029-23526-00 909335380 Kuparuk River Jewelry Record Field- Final 14-May-24 0 1 7 1E-08A 50-029-20496-01 909539034 Kuparuk River Plug Setting Record Field- Final 1-Jun-24 0 1 8 1F-03A 50-029-20853-01 909382731 Kuparuk River Leak Detect Log Field- Final 18-Jun-24 0 1 9 1F-03A 50-029-20853-01 909424095 Kuparuk River Multi Finger Caliper Field & Processed 2-Jul-24 0 1 10 1G-04 50-029-20835-00 909359162 Kuparuk River Patch Setting Record Field- Final 11-Jun-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39146 T39147 T39148 T39149 T39150 T38151 T39152 T39153 T39153 T39154 181-173 181-065 201-248 223-038 197-184 214-138 210-181 196-096 182-161 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:03:51 -08'00' 1A-11 50-029-20685-00 909447215 Kuparuk River Radial Bond Record Field & Processed 3-Jul-24 0 1 T39146 181-173 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 1A-11 JBR 08/15/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Used 3-1/2" & 7" TJ Shaker LEL alarm failed replaced and passed. 11 Accumulator bottles at 1000 psi precharge avg. BOP Misc.: 2 each 2 1/16” 5K gate valves on test spool located on BOP stack below the lower rams. Choke Misc.: 3” Demco valve located on the downstream of the manifold Test Results TEST DATA Rig Rep:Hansen/BezoldOperator:ConocoPhillips Alaska, Inc.Operator Rep:Wiese/Erdman Rig Owner/Rig No.:Nordic 3 PTD#:1811730 DATE:7/6/2024 Type Operation:WRKOV Annular: 250/2500Type Test:BIWKLY Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopKPS240706140839 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6 MASP: 2300 Sundry No: 324-249 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 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 1 PCH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 2 7/8" X 5 1/2 P #2 Rams 1 Blinds P #3 Rams 1 7" Fixed P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"P Kill Line Valves 1 3-1/8"P Check Valve 0 NA BOP Misc 2 2 1/16” 5K ga P System Pressure P3100 Pressure After Closure P1525 200 PSI Attained P24 Full Pressure Attained P137 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 2000 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P FPMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P17 #1 Rams P5 #2 Rams P5 #3 Rams P5 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9999 9 9 FP Shaker LEL alarm failed CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Al Hansen To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Cc:Company Man, Nordic 3; greg.s.hobbs@conocophillips.com Subject:KUP 1A-11 AOGCC 6-30-24 Date:Monday, July 1, 2024 10:29:36 AM Attachments:KUP 1A-11 AOGCC 6-30-24.xlsx Al Hansen Rig Manager Rig 3 907-670-6143 Office 907-670-6144 Rig Doghouse 907-440-6928 Cell This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. .XSDUXN5LYHU8QLW$ 37' %23(7HVWUHSRUWIROORZLQJ QRWLILFDWLRQRIXVHRQ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m itt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:3 DATE: 6/30/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #11811730 Sundry #324249 Operation: Drilling: Workover: xxx Explor.: Test: Initial: Weekly: Bi-Weekly: Other: xxx Rams:N/A Annular:250/2500 Valves:250/2500 MASP:2300 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1NA Permit On Location P Hazard Sec.P Lower Kelly 1NA Standing Order Posted P Misc.NA Ball Type 1NA Test Fluid Water Inside BOP 1NA FSV Misc 1NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 13 5/8"P Pit Level Indicators NA NA #1 Rams 1 2 7/8" X 5 1/2"NA Flow Indicator NA NA #2 Rams 1 Blinds NA Meth Gas Detector NA NA #3 Rams 0 7" Fixed NA H2S Gas Detector NA NA #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"NA System Pressure (psi)NA Kill Line Valves 1 3 1/8"P Pressure After Closure (psi)NA Check Valve 0NA200 psi Attained (sec)NA BOP Misc 2 2 1/16" 5000 NA Full Pressure Attained (sec)NA Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4@2100 P No. Valves 3P ACC Misc 0NA Manual Chokes 1NA Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 1NA Annular Preventer 18 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:3.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 5-30-24/06:22 Waived By Test Start Date/Time:5/30/2024 7:30 (date) (time)Witness Test Finish Date/Time:5/30/2024 10:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Josh Hunt Nordic Post BOPE usage test. Tested annular with 3 1/2" & 7 " test joints, Choke valves #3,#5 & #6 Manual choke & kill, Hydraulic choke. Performed weekly function test on BOPE Hansen/Twedt CPAI Barr/Wiese KRU 1A-11 Test Pressure (psi): gmanager.rig3@nordic-calista.co c3.Companyman@conocophillips Form 10-424 (Revised 08/2022) 2024-0630_BOP_Nordic3_test-after-use_KRU_1A-11 9 9 9 9 9 97HVWQRWUHT G 9 9 9 9 9 9 9 9 9 9 9 MEU MEU 9 Post BOPE usage test. Tested annular with 3 1/2" & 7 " test joints, Choke valves #3,#5 & #6 Manual choke & kill, Hydraulic choke. 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:Klem, Adam To:DOA AOGCC Prudhoe Bay; Loepp, Victoria T (OGC) Cc:Company Man, Nordic 3; Coberly, Jonathan; Nezaticky, Peter Subject:Notification of BOP use on Nordic 3 on 6/29/2024 Date:Sunday, June 30, 2024 9:33:28 AM Attachments:1A-11 BOPE Letter 6.29.24.doc Victoria and to whom it may concern, Please see attached document in response to Bulletin 10-003 in order to document the use of BOP equipment on 1A-11 Please let me know if you have any questions. Thanks. Good day. Adam Klem Staff RWO/CTD Engineer ConocoPhillips Alaska 700 G St ATO 1478 Anchorage, AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com .58$ 37' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Mar 25, 2022 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up on BOPE usage on Nordic 3 with a written report. Time of BOPE Use: 6/29/2024 at 15:02 hours Well Location: 1A-11 API Number: 50-029-2920685-00-00 PTD Number: 181-173 Rig Name: Nordic 3 Operator Contact: Adam Klem. (o) 907-263-4529. (c) 970-317-0300. Adam.klem@conocophillips.com Operations Summary: We had previously attempted to pull the completion from a pre rig cut at 8,770’ MD. The SSSA hung up at a suspected casing restriction at ~670’ MD. We cut the tubing ~17’ above the SSSV, and dropped the completion back onto the pre rig cut. We then attempted several options to retrieve control line and grow and stretch casing. After several failed drifts, we decided the best course of action was to cut the 7” casing above the top of the remaining completion and then patch in new un damaged 7” casing. We set an RBP at 1,230’ MD and pressure tested it. We then cut the 7” at 1,131’ MD. At the point of the cut we had ~9.7ppg brine inside the 7”. Once the cut was performed, we observed arctic pack U-tubing up the backside. We closed annular to control the flow. We then circulated the arctic pack & gas out of well. Then we performed a no flow check and then opened up well. We then continued circulation. We intend on testing annual & manual choke & kill when we get 7” out and can set a test plug in casing head. BOPE Used: Annular Reason for BOPE Use: The annular was closed to halt any inflow from the u-tubing of unbalanced fluids Actions To Be Taken: The BOPE will be retested when we get the 7” out of the hole and can set a test plug in the casing head. If you have any questions or require any further information, please contact me at my cell phone number above. Sincerely, Adam Klem Rig Workover Engineer CPAI Drilling and Wells MEU 9 9 9 9 9 9 9 gp p g cut the 7” at 1,131’ MD. At the point of the cut we had ~9.7ppg brine,p , p ppg inside the 7”. Once the cut was performed, we observed arctic pack U-tubing up the backside. We closed annular to control the flow. 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:Klem, Adam To:DOA AOGCC Prudhoe Bay; Loepp, Victoria T (OGC) Cc:Company Man, Nordic 3; Coberly, Jonathan; Nezaticky, Peter Subject:Notification of BOP use on Nordic 3 on 6/29/2024 Date:Sunday, June 30, 2024 9:33:28 AM Attachments:1A-11 BOPE Letter 6.29.24.doc Victoria and to whom it may concern, Please see attached document in response to Bulletin 10-003 in order to document the use of BOP equipment on 1A-11 Please let me know if you have any questions. Thanks. Good day. Adam Klem Staff RWO/CTD Engineer ConocoPhillips Alaska 700 G St ATO 1478 Anchorage, AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com .XSDUXN5LYHU8QLW$ 37' 9 1RUGLF5LJ document the use of BOP equipment on 1A-11 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Mar 25, 2022 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up on BOPE usage on Nordic 3 with a written report. Time of BOPE Use: 6/29/2024 at 15:02 hours Well Location: 1A-11 API Number: 50-029-2920685-00-00 PTD Number: 181-173 Rig Name: Nordic 3 Operator Contact: Adam Klem. (o) 907-263-4529. (c) 970-317-0300. Adam.klem@conocophillips.com Operations Summary: We had previously attempted to pull the completion from a pre rig cut at 8,770’ MD. The SSSA hung up at a suspected casing restriction at ~670’ MD. We cut the tubing ~17’ above the SSSV, and dropped the completion back onto the pre rig cut. We then attempted several options to retrieve control line and grow and stretch casing. After several failed drifts, we decided the best course of action was to cut the 7” casing above the top of the remaining completion and then patch in new un damaged 7” casing. We set an RBP at 1,230’ MD and pressure tested it. We then cut the 7” at 1,131’ MD. At the point of the cut we had ~9.7ppg brine inside the 7”. Once the cut was performed, we observed arctic pack U-tubing up the backside. We closed annular to control the flow. We then circulated the arctic pack & gas out of well. Then we performed a no flow check and then opened up well. We then continued circulation. We intend on testing annual & manual choke & kill when we get 7” out and can set a test plug in casing head. BOPE Used: Annular Reason for BOPE Use: The annular was closed to halt any inflow from the u-tubing of unbalanced fluids Actions To Be Taken: The BOPE will be retested when we get the 7” out of the hole and can set a test plug in the casing head. If you have any questions or require any further information, please contact me at my cell phone number above. Sincerely, Adam Klem Rig Workover Engineer CPAI Drilling and Wells 9 9 .XSDUXN5LYHU8QLW 9 6669 9 9 ,p observed arctic pack U-tubing up the backside ppg closed annular to control the flow g ppp testing annual & manual choke & kill when we get 7” out and can set a test plug in casing head ORIGINATED TRANSMITTAL DATE: 6/25/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4870 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4870 1A-11 50-029-20685-00 Tubing Cut Record 8-Jun-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 181-173 T39043 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.26 08:48:13 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com 0 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Pull/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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9732'9224', 9346' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 265-6312 Senior RWO/CTD Engineer KRU 1A-11 6703' 9006' 6191' 9006' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: sydney.long@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8815' MD and 6062' TVD 8985' MD and 6177' TVD 1905' MD and 1752' TVD Sydney Long STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025647 181-173 P.O. Box 100360, Anchorage, AK 99510 50-029-20685-00-00 Kuparuk River Field Kuparuk River Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst 9019' MD MD 114' 2425' 114' 2947' 6690'9713' 16" 10-3/4" 80' 2915' 8878-8918', 8930-8938', 9082- 9095', 9108-9150' 9682' 6104-6131', 6139-6144', 6244- 6254', 6263-6294' 7" Perforation Depth TVD (ft): 5/15/2025 3-1/2" Packer: Baker HB Packer Packer: Brown 2B Packer SSSV: Camco TRDP-1A-ENC Sfty Vlv Perforation Depth MD (ft): J-55 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:35 pm, Jun 11, 2024 324-340 X BOP test to 2500 psig Annular preventer to 2500 psig VTL 6/21/2024 2300 X 10-404X DSR-6/11/24SFD 6/12/2023*&:JLC 6/21/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.21 11:04:07 -08'00'06/21/24 RBDMS JSB 062624 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 25, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Sydney Long Senior Rig Workover Engineer CPAI Drilling and Wells Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Injector 1A- 11 (PTD #181-173). This well was drilled in 1981 as a Kuparuk A and C Sand injector. This well is shut in due to Tubing by IA communication with a leak in the PBR and one of the gas lift mandrels. The selectivity of the C-Sand is also compromised. It would be our objective to repair the tubing integrity and the selective across the C-Sand. 1A pad is a high-risk subsidence pad and this well has a significant estimated subsidence. The base plan would include a grow-and-stretch of the production casing – with the contingency of a full subsidence repair. If you have any questions or require any further information, please contact me at 907-265-6312. well has a significant estimated subsidence 1A-11 Kuparuk Injector Repair Selective with Subsidence Contingency PTD: 181-173 Pre-Rig Work 1. Set plug in D nipple @ 9007’ 2. SIBHP of C Sand 3. Cut tubing below blast joints at ~8965’ 4. Cut tubing above blast joints at ~8830’ 5. Set plug in tubing above cut and below packer at ~8820’ 6. Cut tubing in joint above seals at ~8770’ Rig Work MIRU 1. MIRU Nordic 3 on 1A-11. (No BPV will be set due to risk assessment done on Nordic 3) 2. Record shut-in pressures on the T & IA. If pressure is observed, bleed oƯ and complete 30- minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and conƱrm as a barrier if needed, ND tree, NU BOPE and test to 250/2500 PSI. Test annular to 250/2500 PSI. Retrieve Tubing 4. Pull BPV and MU landing joint. BOLDS. 5. Pull 3-1/2” tubing down to pre rig cut at ~8770’ a. If unable to pull tubing to surface: i. RU Eline ii. RIH and set IBP in 7” casing. PT plug to conƱrm as a barrier iii. Dump sand on plug. Set tubing down on sand. iv. Proceed to grow and stretch 6. Drift 7” casing. If successful, proceed to perform grow and stretch on 7” casing. a. If unsuccessful, proceed to full subsidence repair. Grow and Stretch Casing 7. ND BOPE. ND old tubing spool. NU BOPE. 8. Grow and stretch 7” casing as necessary. 9. Land slips, cut excess casing and install packoƯs. Install new tubing spool and terminate the 7”. MU BOPE and test Ʋange break. Selective Repair and Subsidence 1A-11 Kuparuk Producer PTD: 185-072 FullSubsidence Repair 10. Set storm packer or plug in 7” casing and PT to conƱrm as a barrier 11. ND BOPE. ND old tubing spool. NU BOPE and test Ʋange break. a. Shell test, as soon as practical 12. Grow and stretch 7” casing as necessary. 13. RU Eline and log 7” casing for OA cement from Arctic Pack job 14. Cut 7” casing above OA cement a. Circulate out Arctic Pack and diesel/slurry as needed 15. Pull 7” casing down to cut a. Make additional cuts/runs as determined necessary b. If any 3-1/2” tubing remains in the well, remove to clear wellbore for running of 7” tieback 16. PU mills and bore out 10-3/4” as necessary to obtain drift 17. Run new 7” tieback casing with overshot 18. Test casing to 2500 PSI 19. Cement OA to surface 20. Split stack, land slips, cut excess casing and install packoƯs. Install new tubing spool and terminate the 7”. MU BOPE and test Ʋange break. 21. Remove any plugs/equipment from the interior of the 7” to regain full bore access 22. Perform cleanout run if necessary Remove C-Sand Selective Completion 23. Fish tubing stub from 8770’ to seals 24. Mill/remove 3-1/2” x 7” production packer a. Close annular and circulate out packer gas. Weight up as required. 25. Fish packer down to cut at 8830’ 26. Fish blast joints down to cut at 8965’ 27. Fish tubing stub from 8965’ down to seals 28. Mill/remove 3-1/2” x 7”selective packer 29. Perform cleanout across the perforations as necessary. Run New Completion 30. MU 3-1/2” completion with seals, packers, nipples and GLMs. RIH with completion. 31. Once on depth, circulate in CI Ʋuid at opportune time. After CI is in place, set packer. 32. Pressure test tubing to 3500 PSI 33. Pressure test IA to 3000 PSI 34. Shear out SOV with pressure diƯerential 35. Install BPV. Test. 36. ND BOPE. NU tree. PT tree 37. Freeze protect. Pull BPV if necessary. 38. RDMO Selective Repair and Subsidence 1A-11 Kuparuk Producer PTD: 185-072 Post Rig 39. Pull any plugs 40. Install GLD 41. Turn over to operations General Well Information: Estimated Start Date: 6/15/2024 Current Operations: Shut In Well Type: Injector Wellhead Type: McEvoy Gen I BOP ConƱguration: Annular / Pipe Rams / Blind Rams Static BHP: 2,910 PSI at 6,099 TVD on 4/3/2023 MPSP: 2300 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut. Address any subsidence in the well by either a grow-and-stretch or by a full 7” subsidence repair, as determined necessary. Remove the full selective completion. Run new completion which blanks oƯ the C-Sands. Personnel: Workover Engineer: Sydney Long (265-6312 / Sydney.Long@conocophillips.com) Reservoir Surv. Engineer: Jennifer McLeod Production Engineer: Wesley Robertson 1A-11 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread Conductor 80 80 16 15.062 65 H-40 Welded Surface 5946 2425 10-3/4 9.95 45.5 K-55 BUTT Current Production 9712 6689 7 6.276 26 K-55 BTC Subs. Production ~2500 ~2000 7 6.276 26 L-80 BTCM Current Tubing 9019 6200 3-1/2 2.992 9.2 J-55 BTCM New Tubing 8985 6177 3-1/2 2.992 9.2 L-80 EUE PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to Surface 3-1/2" Camco MMG Gas Lift Mandrel @ TBD 3-½" X landing Nipple at 8850' RKB (2.813" min ID) Baker 3-1/2" PBR 8800' RKB (3" ID) SLB Bluepack Packer @ 8815' RKB (4" ID) 3-1/2" Locator Seal Assembly SLB Bluepack Packer @ 8,980' RKB 3-½" X landing Nipple at 8850' RKB (2.813" min ID) Surface Casing 2946' MD / 2425' TVD Production Casing 9712' MD / 6689' TVD C-Sand 8878' - 8918' MD A-Sand 8930' - 9150' MD Upper Packer 8836' MD Lower Packer 8985' MD 1A-11 Proposed RWO Completion - Subsidence Contingency COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread Conductor 80 80 16 15.062 65 H-40 Welded Surface 5946 2425 10-3/4 9.95 45.5 K-55 BUTT Current Production 9712 6689 7 6.276 26 K-55 BTC Subs. Production ~2500 ~2000 7 6.276 26 L-80 BTCM Current Tubing 9019 6200 3-1/2 2.992 9.2 J-55 BTCM New Tubing 8985 6177 3-1/2 2.992 9.2 L-80 EUE PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to Surface 3-1/2" Camco MMG Gas Lift Mandrel @ TBD Baker 3-1/2" PBR 8800' RKB (3" ID) Baker FHL Packer @ 8815' RKB (4" ID) 3-½" X landing Nipple at 8850' RKB (2.813" min ID) 3-1/2" Locator Seal Assembly REMAINING COMPLETION LEFT IN HOLE Brown 2B Packer Crossover 3.5" x 2.875" Surface Casing 2946' MD / 2425' TVD Production Casing 9712' MD / 6689' TVD C-Sand 8878' - 8918' MD A-Sand 8930' - 9150' MD Upper Packer 8836' MD Lower Packer 8985' MD Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,129.0 1A-11 4/29/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled plug w/ gauges. Set plug & catcher. 1A-11 4/13/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Upper patch depths corrected to tubing tally. Verified depths are correct. 8/26/2014 hipshkf NOTE: LDL STOP COUNTS ABOVE & BELOW CONFIRMED LEAK @ 8903' IN TBG JOINT 3/8/2009 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 33.0 80.0 80.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 31.6 2,946.7 2,425.0 45.50 K-55 BUTT PRODUCTION 7 6.28 30.3 9,712.6 6,689.8 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.0 Set Depth … 9,019.3 Set Depth … 6,200.1 String Max No… 3 1/2 Tubing Description TUBING 3.5 x 2.875 Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC-AB MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.0 26.0 0.00 HANGER 8.000 MCEVOY GEN III HANGER 3.500 1,905.4 1,751.9 43.93 SAFETY VLV 5.938 CAMCO TRDP-1A-ENC SAFETY VALVE 2.812 8,758.8 6,025.4 49.41 GAS LIFT 5.938 OTIS LBX 2.906 8,803.3 6,054.5 48.96 PBR 5.125 BAKER PBR 3.000 8,815.0 6,062.2 48.81 PACKER 6.000 BAKER HB PACKER 3.000 8,851.8 6,086.5 48.35 INJECTION 5.390 CAMCO KBUG 2.920 8,889.8 6,111.9 47.88 BLAST JTS 3.500 STEEL BLAST JOINTS (2) 2.992 8,972.0 6,167.6 46.85 NIPPLE 4.480 AVA BPL PORTED LANDING NIPPLE 2.312 8,984.9 6,176.4 46.69 SEAL ASSY 4.000 BAKER LOCATOR SEAL ASSEMBLY 3.000 8,985.4 6,176.8 46.68 PACKER 6.150 BROWN 2B PACKER 3.000 8,995.7 6,183.8 46.55 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 9,006.8 6,191.5 46.29 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 9,018.4 6,199.5 45.95 SOS 3.750 BROWN SHEAR OUT SUB. **TTL ELMD 9000' @ IPROF 7/7/1999** 2.568 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,972.0 6,167.6 46.85 SLEEVE-C AVA BPI 8/7/2003 2.313 9,001.0 6,187.5 46.47 CATCHER Set 2.28" x 68" catcher on top of plug. 4/13/2024 0.000 9,006.0 6,190.9 46.32 TUBING PLUG Set 2.25" CA 2 plug. 4/13/2024 0.000 9,224.0 6,346.1 44.88 FISH E-Line Tool 18.5' long 10/31/1982 9,346.0 6,432.9 44.73 FISH VANN GUN 278' long 12/2/1981 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,758.8 6,025.4 49.41 1 GAS LIFT OPEN 1 1/2 11/30/2017 OTIS LBX 8,851.8 6,086.5 48.35 2 INJ DMY BK 1 0.0 6/27/1989 CAMCO KBUG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,878.0 8,918.0 6,104.0 6,130.9 C-4, C-3, C-2, C- 1, 1A-11 12/21/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph 8,930.0 8,938.0 6,139.0 6,144.4 UNIT B, 1A-11 12/21/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph 9,082.0 9,095.0 6,244.5 6,253.9 A-5, 1A-11 12/21/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph 9,108.0 9,150.0 6,263.3 6,293.6 A-4, 1A-11 12/21/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph 1A-11, 4/25/2024 12:53:18 PM Vertical schematic (actual) PRODUCTION; 30.3-9,712.6 FISH; 9,346.0 FISH; 9,224.0 IPERF; 9,108.0-9,150.0 IPERF; 9,082.0-9,095.0 TUBING PLUG; 9,006.0 CATCHER; 9,001.0 PACKER; 8,985.4 SLEEVE-C; 8,972.0 IPERF; 8,930.0-8,938.0 IPERF; 8,878.0-8,918.0 INJECTION; 8,851.8 PACKER; 8,815.0 GAS LIFT; 8,758.8 SURFACE; 31.6-2,946.7 SAFETY VLV; 1,905.4 CONDUCTOR; 33.0-80.0 KUP INJ KB-Grd (ft) 39.01 RR Date 12/22/198 1 Other Elev… 1A-11 ... TD Act Btm (ftKB) 9,732.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292068500 Wellbore Status INJ Max Angle & MD Incl (°) 57.00 MD (ftKB) 7,900.00 WELLNAME WELLBORE1A-11 Annotation Last WO: End Date 10/15/1985 H2S (ppm) DateComment SSSV: TRDP 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: Pull/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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9732' 9224', 9346' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 5/15/2025 3-1/2" Packer: Baker HB Packer Packer: Brown 2B Packer SSSV: Camco TRDP-1A-ENC Sfty Vlv Perforation Depth MD (ft): J-55 2915' 8878-8918', 8930-8938', 9082- 9095', 9108-9150' 9682' 6104-6131', 6139-6144', 6244- 6254', 6263-6294' 7" Perforation Depth TVD (ft): 114' 2947' 6690'9713' 16" 10-3/4" 80' 9019' MD MD 114' 2425' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025647 181-173 P.O. Box 100360, Anchorage, AK 99510 50-029-20685-00-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8815' MD and 6062' TVD 8985' MD and 6177' TVD 1905' MD and 1752' TVD Sydney Long Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: sydney.long@conocophillips.com (907) 265-6312 Senior RWO/CTD Engineer KRU 1A-11 6703' 9006' 6191' 9006' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:16 am, Apr 26, 2024 DSR-4/29/24SFD 4/29/2024 X X VTL 5/8/2024 10-404 X 2300 BOP test to 2500 psig Annular preventer test to 2500 psig JLC 5/8/2024 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 25, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Injector 1A- 11 (PTD #181-173). This well was drilled in 1981 as a Kuparuk A and C Sand injector. This well is shut in due to Tubing by IA communication with a leak in the PBR and one of the gas lift mandrels. The selectivity of the C-Sand is also compromised. It would be our objective to repair the tubing integrity and the selective across the C-Sand. 1A pad is a high-risk subsidence pad and this well has a significant estimated subsidence. The base plan would include a grow-and-stretch of the production casing with the contingency of a full subsidence repair. If you have any questions or require any further information, please contact me at 907-265-6321. Sydney Long Senior Rig Workover Engineer CPAI Drilling and Wells 1A-11 Kuparuk Injector Repair Selective with Subsidence Contingency PTD: 181-173 Pre-Rig Work 1. Set plug in D nipple @ 9007 2. SIBHP of C Sand 3. Cut tubing below blast joints at ~8965 4. Cut tubing above blast joints at ~8830 5. Set plug in tubing above cut and below packer at ~8820 6. Cut tubing in joint above seals at ~8770 Rig Work MIRU 1. MIRU Nordic 3 on 1A-11. (No BPV will be set due to risk assessment done on Nordic 3) 2. Record shut-in pressures on the T & IA. If pressure is observed, bleed o and complete 30- minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and con rm as a barrier if needed, ND tree, NU BOPE and test to 250/2500 PSI. Test annular to 250/2500 PSI. Retrieve Tubing 4. Pull BPV and MU landing joint. BOLDS. 5. Pull 3-1/2 tubing down to pre rig cut at ~8770 a. If unable to pull tubing to surface: i. RU Eline ii. RIH and set IBP in 7 casing. PT plug to con rm as a barrier iii. Dump sand on plug. Set tubing down on sand. iv. Proceed to grow and stretch 6. Drift 7 casing. If successful, proceed to perform grow and stretch on 7 casing. a. If unsuccessful, proceed to full subsidence repair. Grow and Stretch Casing 7. ND BOPE. ND old tubing spool. NU BOPE. 8. Grow and stretch 7 casing as necessary. 9. Land slips, cut excess casing and install packo s. Install new tubing spool and terminate the 7. MU BOPE and test ange break. Selective Repair and Subsidence 1A-11 Kuparuk Producer PTD:181-173 FullSubsidenceRepair 10. Set storm packer or plug in 7 casing and PT to con rm as a barrier 11. ND BOPE. ND old tubing spool. NU BOPE and test ange break. a. Shell test, as soon as practical 12. Grow and stretch 7 casing as necessary. 13. RU Eline and log 7 casing for OA cement from Arctic Pack job 14. Cut 7 casing above OA cement a. Circulate out Arctic Pack and diesel/slurry as needed 15. Pull 7 casing down to cut a. Make additional cuts/runs as determined necessary b. If any 3-1/2 tubing remains in the well, remove to clear wellbore for running of 7 tieback 16. PU mills and bore out 10-3/4 as necessary to obtain drift 17. Run new 7 tieback casing with overshot 18. Test casing to 2500 PSI 19. Cement OA to surface 20. Split stack, land slips, cut excess casing and install packo s. Install new tubing spool and terminate the 7. MU BOPE and test ange break. 21. Remove any plugs/equipment from the interior of the 7 to regain full bore access 22. Perform cleanout run if necessary Remove C-Sand Selective Completion 23. Fish tubing stub from 8770 to seals 24. Mill/remove 3-1/2 x 7 production packer a. Close annular and circulate out packer gas. Weight up as required. 25. Fish packer down to cut at 8830 26. Fish blast joints down to cut at 8965 27. Fish tubing stub from 8965 down to seals 28. Perform cleanout across the perforations as necessary. Run New Completion 29. MU 3-1/2 completion with seals, packer, nipples and GLMs. RIH with completion. 30. Once on depth, circulate in CI uid at opportune time. After CI is in place, set packer. 31. Pressure test tubing to3500 PSI 32. Pressure test IA to 3000 PSI 33. Shear out SOV with pressure di erential 34. Install BPV. Test. 35. ND BOPE. NU tree. PT tree 36. Freeze protect. Pull BPV if necessary. 37. RDMO Well Type: Injector Wellhead Type: McEvoy Gen I BOP Con guration: Annular / Pipe Rams / Blind Rams Static BHP: 2,910 PSI at 6,099 TVD on 4/3/2023 MPSP: 2300 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2 completion to a pre-rig cut. Address any subsidence in the well by either a grow-and-stretch or by a full 7 subsidence repair, as determined necessary. Remove the selective completion across the C- Sands. Run new completion which blanks o the C-Sands and install a new production packer. Personnel: Workover Engineer: Sydney Long (265-6321 / Sydney.Long@conocophillips.com) Reservoir Surv. Engineer: Jennifer McLeod Production Engineer: Wesley Robertson Selective Repair and Subsidence 1A-11 Kuparuk Producer PTD:181-173 Post Rig 38. Pull any plugs 39. Install GLD 40. Turn over to operations General Well Information: Estimated Start Date: 6/15/2024 Current Operations: Shut In 1A-11 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread Conductor 80 80 16 15.062 65 H-40 Welded Surface 5946 2425 10-3/4 9.95 45.5 K-55 BUTT Current Production 9712 6689 7 6.276 26 K-55 BTC Current Tubing 9019 6200 3-1/2 2.992 9.2 J-55 BTCM New Tubing 8985 6177 3-1/2 2.992 9.2 L-80 HYD563 PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to Surface 3-1/2" Camco MMG Gas Lift Mandrel @ TBD Baker 3-1/2" PBR 8800' RKB (3" ID) Baker FHL Packer @ 8815' RKB (4" ID) 3-½" X landing Nipple at 8850' RKB (2.813" min ID) 3-1/2" Locator Seal Assembly REMAINING COMPLETION LEFT IN HOLE Brown 2B Packer Crossover 3.5" x 2.875" Camco D Nipple No Go Surface Casing 2946' MD / 2425' TVD Production Casing 9712' MD / 6689' TVD C-Sand 8878' - 8918' MD A-Sand 8930' - 9150' MD Upper Packer 8836' MD Lower Packer 8985' MD 1A-11 Proposed RWO Completion - Subsidence Contingency COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread Conductor 80 80 16 15.062 65 H-40 Welded Surface 5946 2425 10-3/4 9.95 45.5 K-55 BUTT Current Production 9712 6689 7 6.276 26 K-55 BTC Subs. Production ~2500 ~2000 7 6.276 26 L-80 BTCM Current Tubing 9019 6200 3-1/2 2.992 9.2 J-55 BTCM New Tubing 8985 6177 3-1/2 2.992 9.2 L-80 EUE PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to Surface 3-1/2" Camco MMG Gas Lift Mandrel @ TBD Baker 3-1/2" PBR 8800' RKB (3" ID) Baker FHL Packer @ 8815' RKB (4" ID) 3-½" X landing Nipple at 8850' RKB (2.813" min ID) 3-1/2" Locator Seal Assembly REMAINING COMPLETION LEFT IN HOLE Brown 2B Packer Crossover 3.5" x 2.875" Surface Casing 2946' MD / 2425' TVD Production Casing 9712' MD / 6689' TVD C-Sand 8878' - 8918' MD A-Sand 8930' - 9150' MD Upper Packer 8836' MD Lower Packer 8985' MD Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled plug w/ gauges. Set plug & catcher. 1A-11 4/13/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Upper patch depths corrected to tubing tally. Verified depths are correct. 8/26/2014 hipshkf NOTE: LDL STOP COUNTS ABOVE & BELOW CONFIRMED LEAK @ 8903' IN TBG JOINT 3/8/2009 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 33.0 80.0 80.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 31.6 2,946.7 2,425.0 45.50 K-55 BUTT PRODUCTION 7 6.28 30.3 9,712.6 6,689.8 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.0 Set Depth 9,019.3 Set Depth 6,200.1 String Max No 3 1/2 Tubing Description TUBING 3.5 x 2.875 Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC-AB MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.0 26.0 0.00 HANGER 8.000 MCEVOY GEN III HANGER 3.500 1,905.4 1,751.9 43.93 SAFETY VLV 5.938 CAMCO TRDP-1A-ENC SAFETY VALVE 2.812 8,758.8 6,025.4 49.41 GAS LIFT 5.938 OTIS LBX 2.906 8,803.3 6,054.5 48.96 PBR 5.125 BAKER PBR 3.000 8,815.0 6,062.2 48.81 PACKER 6.000 BAKER HB PACKER 3.000 8,851.8 6,086.5 48.35 INJECTION 5.390 CAMCO KBUG 2.920 8,889.8 6,111.9 47.88 BLAST JTS 3.500 STEEL BLAST JOINTS (2) 2.992 8,972.0 6,167.6 46.85 NIPPLE 4.480 AVA BPL PORTED LANDING NIPPLE 2.312 8,984.9 6,176.4 46.69 SEAL ASSY 4.000 BAKER LOCATOR SEAL ASSEMBLY 3.000 8,985.4 6,176.8 46.68 PACKER 6.150 BROWN 2B PACKER 3.000 8,995.7 6,183.8 46.55 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 9,006.8 6,191.5 46.29 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 9,018.4 6,199.5 45.95 SOS 3.750 BROWN SHEAR OUT SUB. **TTL ELMD 9000' @ IPROF 7/7/1999** 2.568 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,972.0 6,167.6 46.85 SLEEVE-C AVA BPI 8/7/2003 2.313 9,001.0 6,187.5 46.47 CATCHER Set 2.28" x 68" catcher on top of plug. 4/13/2024 0.000 9,006.0 6,190.9 46.32 TUBING PLUG Set 2.25" CA 2 plug. 4/13/2024 0.000 9,224.0 6,346.1 44.88 FISH E-Line Tool 18.5' long 10/31/1982 9,346.0 6,432.9 44.73 FISH VANN GUN 278' long 12/2/1981 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,758.8 6,025.4 49.41 1 GAS LIFT OPEN 1 1/2 11/30/2017 OTIS LBX 8,851.8 6,086.5 48.35 2 INJ DMY BK 1 0.0 6/27/1989 CAMCO KBUG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,878.0 8,918.0 6,104.0 6,130.9 C-4, C-3, C-2, C- 1, 1A-11 12/21/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph 8,930.0 8,938.0 6,139.0 6,144.4 UNIT B, 1A-11 12/21/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph 9,082.0 9,095.0 6,244.5 6,253.9 A-5, 1A-11 12/21/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph 9,108.0 9,150.0 6,263.3 6,293.6 A-4, 1A-11 12/21/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph FISH; 9 346 0 FISH; 9,224.0 IPERF; 9,108.0-9,150.0 IPERF; 9,082.0-9,095.0 TUBING PLUG; 9,006.0 CATCHER; 9,001.0 PACKER; 8,985.4 SLEEVE-C; 8,972.0 IPERF; 8,930.0-8,938.0 IPERF; 8,878.0-8,918.0 INJECTION; 8,851.8 PACKER; 8,815.0 GAS LIFT; 8,758.8 SURFACE; 31.6-2,946.7 SAFETY VLV; 1,905.4 CONDUCTOR; 33.0-80.0 • I— r- `vo (0,7. ..... i r r . . . . . r r O� oo a)• c N is) lY > C _E 7 1 w O O L , J J (" Q > I a ` v t ci N; co �O "O N J ✓ G ++ V Y > O O as 4) O N O U o, a C C C 2 a n ,C -o .W. 4 X 9 0 0 0 o v Q = Q 0 Q O a W 0 CO CO CO CO CO CO t0 CO f0 .a 4) O cr m JACO , Q Q _ <k QLVY d m d m m m d d v N Qom^ W N N co co h N_h v) C )p u L a1 VI Z 0 < ci d) O n CO C)-o ou -a a5 O vi Z 0 qi E u G:F (D a O Q +D o CC.) -Q) W U 0 0 0 O 00000 0 W - - O a J J J W J J J J J C U ,� W W v >- W W W W W W W (u �� F- U. 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CO in 6 in _ a r CO CO CO CO O) CD _ - N N N N 0 0 0 N E _ N N N N N N N N N N W c=--- • s R rn C) C) C) C) C) C) ) Orn C a 0 N N N N N N N N N fa u O Qi O 0 0O 0 0 0 0 0 0 V O U `- O O O O O O O O O a+ C OC AR [ an an N N u7 Ln in In in 'a1 w O. U co � g y 0.0 a ap W r a Q a' co C N 2 Ti -o Ert, E •spy Z m .::z N1. fh N r O O O) C N) aJ Q G r r Y Q 20 gr, _, X X X a a u_ U X E /13 a) ✓rr d Q N W N N N N N W +•+ W O O . v p Q 8 3 C � ar E. 0 0 y a it a s F.. I- • • i Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday,July 30, 2016 2:34 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv Subject: KRU 1A-11 (PTD 181-173) Report of failed MITIA Attachments: 1A-11 schematic.pdf; 1A-11 90 day TIO plot jpg Chris, Kuparuk injector 1A-11 (PTD 181-173) has failed a diagnostic MITIA. Originally there was a sudden increase in the IA pressure and Operations attempted to bleed the IA down with no success. The well was shut in at that time. A follow up MITIA failed. Further diagnostics will be done to identify the leak point and the well will be evaluated for repair. The appropriate paperwork will be submitted pending a decision on repair methods and the well will remain shut in . Attached is a wellbore schematic and a 90 day TIO plot for reference. Please let me know if you have any questions. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907) 659-7000 pgr. 909 AWELLS TEAM ------. .,.�,..,�•..�.� Coy wt4hBps SCANNED OCT 3 12006 • dwai/elioLio • p p .0 p LC) 0 C) C\J ‘•-- N--• I-0 1 ifi if i Ii , I, il -. 4 -.4,- oi -,-I 4,- 1 . ' . . .4 il , II. . _ . . . . • • • • • _ • • • • • • _ . . . . . . . . . C.0 . . . . • - _ • • • • • "4"-- • • . • • • 1 . . . . . . ....- - : . • . • 1 • • : I --) , . • • • • _ . , • . • • • • . • . • - • . , • - • • • . . , . . . : -- -:----- . . • 1 . . co - • • - • • • - •,-- . . . . • • • • - • . • . • . • _ . . . . ---) . - • ...f." • • .---.. . • • • . • • . , • . . • : "..:, . _- CI . . . . • . . • • • • • . . . • • . . . . • ' ----•:' CO - - %--- , 9r- • . ,, • • • • i .it-- • . , . . . . . . • • — D I - . . . • . . . <It • • • . • . • . . • . • . • . - CNI ir- - • ::: • • • . . . . • C\I • • • . . • a) _ • . . • . _ 4—• . . / . • . . .... • • . • • to 0 • • ..s, • • • • (....o ri • . . 0I- • • •• i. • k. . . • . 1 . • • . . r- . . . . . • — 0 - : • • ' • • • • • . • -D -......, • li • . • . _ 6 ....... - • • . • --.,..., . . . . • . . . • . C) • . • • . . . . . • - - . : • ' . . . . • • • CO . . . . - • • • • • _ '4-- • : I: . . . • 1 • . • . • • :. 1., _ 00 ,- • • . • • . .;.. 1 • 'i • . • •••, • . . :. - r',I.- 1 : • • . . . _ -k . • • ''' • i • . . . • 1 • . . . (.0 . . • • • . -,.--t_____ . . . • ..„, • • . : ......,_ -- . . . • . • - 63 Cl- 0_ : : • . .1. I— -,-• • LL ''.. • • . . . - • • • - . . . . • • • • ! . . . . • • • (....o • . . . , • • • . . _ • • • • 1 • • • . >1 Iii 1 II 11 1 li pi 1111 1 li 1 ii ' iii II I li I II III II I II ii i II iii it 1 ez, Y ...-- 0 I__ 0_ co 0 0 0 CD 1 1 1-- < CD CD 0 0 0 CD ‘•-•- 0 LI_ 0 CD I-r) CD 1.r) CD I..0 CI, C) CO (N C\J ISd MEMORANDUM • • State ofla k A s a Alaska Oil and Gas Conservation Commission TO: Jim Regg ) �� i7 DATE: Friday,January 08,2016 P.I.Supervisor t1QI 1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-11 FROM: Jeff Jones KUPARUK RIV UNIT 1A-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvj(3,4------ NON-CONFIDENTIAL LNON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-11 API Well Number 50-029-20685-00-00 Inspector Name: Jeff Jones Permit Number: 181-173-0 Inspection Date: 12/19/2015 Insp Num: mitJJ151221075656 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' 1A-11 Type Inj T w' ,TVD 6062 - Tubing 2100 . 2100 a 2100 - 2100 - PTD 1811730 - Type Test SPT Test psi 1516 - IA 1120 3000 . 2920 • 2920 - Interval 4YRTST - ,P/F P v OA 220 220 - 220 - 220 Notes: 1 well inspected;no exceptions noted. - Friday,January 08,2016 Page 1 of 1 Ima ect Well History File Cover ~,.ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a.special rescan activity or are viewable by direct inspection of the file~ J ~)/L- L ~- Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type ~3 Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other BEVERLY ROBIN VINCENT SHERYL/I~ WINDY DATE,'~'~.~ /S/ BY: Project Proofing BY; Scanning Preparation BEVERLY ROBIN VINCENT SHERYL MARIA WIND DATE /S/ BY; Production Scanning Stage 1 BY~ PAGE COUNT FROM SCANNED FILE: '(~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: .~YES NO Stage 2 IF NO IN STAGE '1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO ReScanned (individual page [,~pecial at~el~tiett] sca~ning completed) RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE; General Notes or Comments about this file: Is~ QualityI Checked ldo.a) 12/10/02Rev3NOTScanned.wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 27, 2011 TO: Jim Regg /, P.I. Supervisor e 3, / ct (,t I (( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lA -I1 FROM: Chuck Scheve KUPARUK RIV UNIT 1A-1 1 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ,T.'— NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1A - 11 API Well Number: 50 029 - 20685 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110727070223 Permit Number: 181 - 173 - Inspection Date: 7/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. T _ 1 A -11 W . 6062 9 IA 1320 2940 • 2880 _ 2860 - Well I 'Type In TVD P.T.DI 1811730 'TypeTest ! SPT 1 Test psi 1 1515 I OA 660 750 750 750 Interval 4YRTST - P/F P ' Tubing 2250 2250 2250 2250 Notes: $� tti ,.&„,;4,28M S t° F' '.r 8 2 V i Wednesday, July 27, 2011 Page 1 of 1 • ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16~', 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: • ~~~~ V ~~ ~u~_ ~ ~o~ ~sk~ ~ Gas Gets. Gtnssi~~ Q71C~`i~Jf8~8 t`~ ~ }~ 3 ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 25~' 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6~', 7~', 8th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klem ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/16110 1 A. 1 C. 7 E PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-11 50029206850000 1811730 10" Na 10" Na 3.4 7/88010 1A-12 50029206880000 1811780 2" Na 2" Na 1.7 7/88010 1A-13 50029207000000 1811950 11" n/a 11" n/a 3.4 7/88010 1A-14 50029207060000 1820100 4" n/a 4" n/a 2.1 7/88010 1 C-01 50029205260000 1801280 SF n/a 24" Na 4.3 7/68010 1 C-02 50029205320000 1801350 24" n/a 24" Na 8.5 7/6/2010 1 C-03A 50029205350100 2070630 SF n/a 16" Na 7.7 7/68010 1 C-04 50029205470000 1801550 SF n/a 5" n/a 2.6 7/6/2010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1C-09 50029208590000 1821850 38' 8.00 6" 11/258007 6.8 7/6/2010 1C-10 50029208650000 1821930 37'6" 8.00 8" 11/258007 6.8 7/68010 1E-02 50029204720000 1800500 21" n/a 21" n/a 1.7 7/78010 1E-03 50029204770000 1800560 4" n/a 4" n/a 2.4 7/78010 1 E-06 50029204930000 1800780 12" Na 12" n/a 13.6 7/78010 1E-07 50029204950000 1800800 5" n/a 5" n/a 2.6 7/78010 1 E-08 50029204960000 1800810 5" Na 5" n/a 2.6 78/2010 1 E-10 50029207250000 1820360 2" Na 2" n/a 1.7 7/78010 1 E-13 50029207500000 1820780 5" n/a 5" Na 2.6 7/7/2010 1E-19 50029209050000 1830170 1" n/a 1" Na 1.7 7/78010 1 E-21 50029208920000 1830020 3" Na 3" n/a 2.6 7/78010 1 E-24A 50029208570100 1971870 2" n/a 2" n/a 1.7 7/7/2010 1 E-25 50029208440000 1821700 3" Na 3" n/a 1.7 7/78010 1 E-28 50029208320000 1821580 4" Na 4" n/a 2.5 7/88010 1 E-29 50029208280000 1821540 7" Na 7" Na 2.5 7/88010 ~ MEMORANDUM To: Jim Regg ~ ~ ~ r ~ ]~q P.I. Supervisor ~' / ~ FROM: Jeff Jones Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 06, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-11 KUPARLTK RIV LJNIT lA-I1 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprw~ (z-- Comm Well Name: xuP.vtuK xiv tltvrr iA-11 Insp Num: mitJJ090706085658 Rel Insp Num: API Well Number: so-o29-20685-00-0o Permit Number: 181-173-0 ~ Inspector Name: Jeff Jones Inspection Date: 6/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1A-11 Type Inj. ~' TVD 6062 IA ; iaio z9oo / z~9o z~so ~ p.T.~ 18ll73~ 'f~,pe'j'QSt sP'C 'reSt pSl 1515.5 QA ~ 750 820 820 800 Interval OTf~R P~' P ~ Tubing zzZS 2225 2250 2225 Notes: 3.3 BBLS diesel pumped. 1 well inspected; no exceptions noted ~ ~ , tA`" r i r~~ 'A: 1 `! H ,,.... N ~,`t ~,'j , ~ ~ lI Ci ":t Monday, July 06, 2009 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbBrldOn ^ Repair Weli ~^ ' Plug Perforations ~ StimUlete ^ Othe~ Q set tbg patch . s Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, Inc. Development ^ Exploratory ^ 181-173 /' 3. Address: Stratigraphic ^ Service ~^ • 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20685-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' s 1A-11 . 8. Property Designation: . 10. Field/Pooi(s): ADL0025647 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9732' ' feet true vertical 6703' = feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 16" 80 80' 1640 630 SURFACE 2847' 10-3/4" 2947' 2425' 3580 2090 PRODUCTION 9613' 7" 9713' 6690' 4980 4330 A ~~~~~ V ~V . ~ ~ ~ ~~ ~ ~~~~~~`~~~'~' ~~~. ~. =y ~~~~~ ~Q~~ JUI Perforation depth: Measured depth: ~ , ~ f~~ 7~ f, bc~ true vertical depth: A~~,~k~ pj~ ~~~g ~p~~, ~tii~tmix~i~tt Ar~char~g~ Tubing (size, grade, and measured depth) 3-1/2" & 2-7/8", J-55, 8996' & 9019' MD. Tubing patch 8755' - 8730' ~ C sand patch 8893-8910 Packers & SSSV (type & measured depth) Brown 'HB' Packer Packer = as15' Camco TRDP-IA-ENC SSSV SSSV = 1905' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation O Subsequent to operation 1300 - 1410 2225 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ ~ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAGQ • GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia if C.O. Ezempt: 309-161 Contact MJ Loveland/Perry Klein Printed Name MJ Loveland Title Well Integrity Supervisor Signature Phone: 659-7043 Date ~~ a ~ u Ora 263-4612 P red b Sharo ~.~.C`~ `'~ . ~~ ~'~. .,°.~~ ~~ h L005 R ~~ ~ Form 10-404 Re ised 04/2006 ~ ~~ Submit Ori ' O~nl ~~~ • • 1 A-11 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 5/25/2009 SET A 3.5" WEATHERFORD PATCH LOWER ELEMENT. MID ELEMENT SET AT 8755', . RFi n~ni i~n-~inir_ ~i ne 5/29/2009 6/18/2009 6/24/2009 iET ER TEST TOOL IN LOWER ER PACKER @ 8755' RKB. CMIT 2500# (PASS) SET JPPER ER PACKER/SPACER PIPE/SNAP LATCH ASSY (25.09' OAL 1.75 MIN ID) @ 8755 tK6 (TOP OF UPPER PATCH ASSY @ 8730' RKB) MITIA 2500# (PASS) AITIA - passed (pre-state witnessed) Initial T/I/O/OOA= 2200/1350/750/0; Pressured up IA to !875psi. with 4bbls. of diesel T/I/O/OOA= 2200/2875/820/0; 15mir~. reading T/I/O/OOA= !200/2835/820/0; 30min. reading T/I/O/OOA= 2200/2820/810/0; Bled down IA all fluid 10min. ~inal T/1/O/OOA= 2200/1400/740/0 >tate Witnessed MITIA - Passed (AOGCC - Jeff Jones) Initial T/I/0=2225/1410/750. 'ressured up IA to 2900 psi with 3.3 bbls of diesel. Start MITIA, T/I/0=2225/2900/820, 15 mir "/I/0=2225/2790/820, 30 min T/1/0=2225/2780/800. Bled IA down. Final T/1/0=2225/900/670 ~ Summary Set retrievable tubing patch from 8730-8755', MITIA passed ~ Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ConocoPhillips Alaska Inc. Kuparuk / KRU / 1A 06/24/09 Ives/Colee Jeff Jones • Packer Depth Pretest Initial 15 Min. 30 Min. Well 1A-11 Type Inj. W TVD 6,062' Tubing 2,225 2,225 2,225 2,225 Interval O P.T.D. 1811730 Type test P Test psi 1516 Casin 1,410 2,900 2,790 2,790 P/F P Notes: Post Patch MITIA - Sundry# 309-161 OA 750 820 820 800 Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interoal P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In'. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas 1= Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Intemal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 1A-11 06-24-09.x1s `, ~~ KUP ~ 1A-11 C~C~~I~~Ip $ Weli Attributes Max An le & MD TD ,~~A ~^ ~1 1 . WellUora A 500292 PI/UWI 068500 Fleld Nama KUPARUK RIVER UNIT Well Statua INJECTING Incl (°) 57.D0 MD (ftK9~ 7,900.00 Act etm (RK9) 9,732.0 •• Comment SSSV~.TROP H23 (ppm) 0 Dab 1/1/2009 Annotatlon LastWO: Entl Oah 10/15/1985 KB~Grd (lt) 39.01 Rlg Relaaae Dab 1222/1981 WaIIConA ~. -1A-11 B!J Scnemetic- @0085'. <'OB Mtuel PM Annota[lon Dept~ (ftKB) Entl Da[e Annotn[lon Last Mo~ ey Entl Date Lasl Tag: SLM 6,970.0 4/25f2009 Rev Reason: SET 2 STRADDLE PATCHES lriplwj 6/3/20 09 Casin Strin s Caaing D ascrlptlon s«i~y oo (~n) s«i~9 io (In) Top ~RKB) Sel Depth (ftKB) s.~ o.P~n ~rvo~ (RKB) snine we ~1D~/ft) so-i~e Gratla g~~~ng Top Thrtl CONDUCTOR 1 6 15.060 39.D 80.0 80.0 65.00 H-40 coNOUCroR, SURFACE 10 3/ 4 9794 26.1 2,947.0 2,4252 45.50 K-55 ao pRODUCTION 7 6.151 26.1 9,713.0 6,690.1 26.00 K-55 Tubin Strin s SnFETY VIV. ~~5 p Tubing Oaecrlptlon Strinp OD (In) Slrinp IU (In) Top (RKB) Set Deplh (ftK9) Sat D~plh (TVD) (RKB) S[rinp Wt QGnM~ String Gratle StAng Top ThrE TUBING 3 1f 2 2.992 26.0 8,996.0 6,184.0 9.20 J-55 8TC-AB-MOD suHFnce, z.sa~ TUBING 2 7I 8 2.441 8,996.0 9,019.0 6,197.6 6.50 J-55 EUE BRD Othe~ In Hole A ll Jewel : Tubin Run 8 Retrievable, Fish etc. PACKEH,B,l30 - Top (ftKB) To0 Dept~ (TV~) (RKB) Toplncl (°) Oeecrlpllon Commenl Run Uata IU (In~ PqTCH. 8,733 1,905 7,7517 43.91 S AFETYVW CamcoTROP-IA-ENC 10I75/1985 2.813 8,730 6,006.8 49.70 P ACKER STRADDLE PATCH UPPER PACKER WFD ER 3' OAL 529/2009 1.750 PACKER.0.155 8,733 6,008.7 49.67 P ATCH STRADOLE PATCH ASSY: SPACER, SNAP LATCH OAL 22' OAL, GOOD TEST 2500P51 5/2920D9 1.750 cas uFT, e,~se 8,755 6,023.1 49.45 P ACKER STRADDLE PATCH LOWER PACKER WFD ER 3' OAL 5252008 1.750 8,758 6,025.0 49.42 G AS LIFT OTIS/LBXI1.5//T-2/// Comment: PACKOFF VALVE STA 7 7/6//990 2.906 6,803 6,055.1 48.96 P BR Brown PBR 10/15/1985 3.000 PBR.8803 6,815 6,062.8 48.81 P ACKER Brown'H8'PACKER 10l15/1985 3.000 6,857 6,0862 48.361N JECTION CAMCOMBUG/1/OMYIBK/llComment:CLOSEDSTA2 6/27/7989 2.875 8,893 6,114.0 47.84 P ACKER STRADDLE PATCH UPPER PACKER WFD ER 3' OAL 5/182009 1750 ancKeR, e.ets 8,896 6,116.1 47.80 P ATCH STRADOLE PATCH ASSV: SPACER, SNAP LATCH OAL 14' OAL. GOOD TEST 2500PSI 5/182009 1.750 8,910 6,128.0 49.20 P ACKER STRADDIE PATCH LOWER PACKER WfD ER 3'OAL 5l7/2009 1.750 8,972 6,167.8 47.34 N IPPLE AVA BPL PORTED NIPPLE 10I15/1985 2.750 INJECTION, 8.851 $,9I2 6,167.8 47.34S LEEVE-C AVABPISETB/72003 8/7/2003 2.313 8,985 6,176.6 46.95 P ACKER Brown'28'PACKER 10I75/1985 4.000 9,007 6,188.5 42.71 N IPPLE Camco'D'NippleNOGO 10175/1985 2.250 9,018 6,196.8 42.27 S OS 8rown t0115/1985 2.441 9,019 6,197.6 4229 T Tl TTL ELMD 9000' Q IPROF 7(l11999 10I75l1985 2.441 PACKEft,8.893 9,224 6,345.6 44.12 FI SH E-LineTool18.5'long 10/37I7982 IPERF. 8 B~BA 918 J,34B 6,432.8 44.73 FI SH VANN GUN 278' long 1212/1981 P/ TCM, 8 896 Perfora Nons B Slots PACKER,8910 Top(RKB) Btm(ftNB) Top ITVD) ~RKB) Blm (TVD) (RKB) Zona Oab $~~~ D~n~ (~h~~~ Typs Co mmsnt 8,878 8,918 s,ioa.o 6.133.0 C C -4, C3, C-2, -1. 1A-11 12/21/7981 4.0 IPERF 4' Vann Guns, 720deg Ph 8,930 8,938 6,140.5 6,145.6 U NIT B, 1A-11 72/21/7987 4.0 IPERF 4" Vann Guns, 720 deg Ph IPERF. 9,082 9,095 6,244.4 6,253.9 A -5, 1A-11 12/21/1987 4.0 IPERF 4" Vann Guns, 120 deg Ph e,sao-e,sse g,108 9,150 6,263.3 6,293.3 A -4, 1A-11 12/27/1981 4.0 IPERF 4" Venn Guns, 120 tleg Ph Notes: General 8~ Safe NIPPLE, 89~2 Entl Data Annolatlon SLEEVE-C, 8,912 $ISIPOOJ NOTE: LDL STOP COUNTS ABOVE 8 BELOW CONFIRMED IEAK ~ 8903' IN TBG JOINT PACKER. 8.985 NIPPLE, 9 001 SOS, 9,018 TTL.9,019 IPERF, 9 082-9 095 IPERF, 9.108-9.150 FISH, 9,220 FISH, 9.348 PRODUCTION. 9.]13 iD, 9,]32 ~ ' ~ STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~.ar~k~~~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ~ Stimulate ^ Other Q tubing patch Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4, WeA Class Before Work: 5. Permit to DriU Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ~ 181-173 / 3. Address: Stratigraphic ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-20685-00 • 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' . 1A-11 - 8. Property Designation: 10. Field/Pool(s): ADL 25647 °` Kuparuk River Field / Kuparuk River Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 9732' feet true vertical 6703' feet Plugs (measured) 9007' Effective Depth measured 9624' feet Junk (measured) 9224', 9346' true vertical 6628' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 2847' 10-3/4" 2947' 2425' PRODUCTION 9613' 7" 9713' 6690' ~~l~G~ V GQ .;L-fv 3 ii 2009 Perforation depth: Measured depth: 8878'-8918', 8930'-8938', 9082'-9095', 9108'-9150' true vertical depth: 6104'-6131', 6139'-6146', 6245'-6254', 6263'-6293~ Aiaska Dil & Gas Cons. Cammission QfFGhOta~~B Tubing (size, grade, and measured depth) 3.5" x 2-7/8" , J-55 , 8996', 9019' PaCkefs & SSSV (type & measured depth) straddle pkr upper assembly, straddle pkr lower assbly, Brown 'HB' pkr, straddle upper pkr, straddle lower pkr, Brown '2B' pkr @ 8730', 8755', 8815', 8893', 8910', 8985' Camco TRDP-1A ENC SSSV cL?i 1905' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none i~yu, ~~~~4W: ,~~i ,:. ~~ f UU~ Treatment descriptions including volumes used and finai pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 983 ~ -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~' Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ Q' WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: 309-137 contact John Peirce @ 26 5-6471 Printed Name John Peirce Title Wells Engineer Signature ,j r" ~ i Phone: 265-6471 Date ~p "~~~",ag ~i~~! Pre red b Sharon ANsu -Drake 263-4612 ~ -- i~ ~ ~~. , ~ .'.~'~ 7. ~- ``~ ~ k~ ~ ~aos Form 10-404 Revise 04/2006 ~~ Submit Origina Onic=~`// s ~ DATE SUMMARYOPS 511107 POT-OC - PASSED, PPPOT-~PASSED • 5/2/07 BLEED OA 5/3/07 BLEED OA, INSTALL JEWELRY ON OOA. 9/30/07 OC POT/PPPOT - PASSED, RE-ENERGIZE IC PO, IC POT/PPPOT - PASSED 5/30/08 RE-ENERGIZE IC PO "Y" SEAL 7/13/08 T-POT- PASSED; T-PPPOT- PASSED; IA-FL; BLEED IA FOR BUR (AC EVAL) 11/23/08 RE-ENERGIZE IC-PO " Y" SEAL. 2/1/09 TAGGED C~ 9130' SLM_ EST. 11' RATHOLE. COMPLETE. 2/6/09 T-POT - PASSED, T-PPPOT - PASSED, IA DD TEST - FAILED 2/18/09 BRUSHED AVA SLEEVE @ 8972' RKB, & D-NIPPLE @ 9007' RKB, TAGGED @ 8997' SLM, IN PROGRESS 2/19/09 SET 2.25" CA-2 (c~ 9007' RKB, RAN D&D TT, LEAK SUSPECT 4N GLM (u~ 8758' RKB,. INJ RATE 1.5 BPM @ 1625 PSI TBG, IA NOT TRACKING. IN PROGRESS, READY FOR E-LINE LDL. 3/8/09 LEAK DETECTION LOG. LEAK FOUND AT 8903' IN TUBING JOINT. LEAK CONFIRMED WITH STOP COUNTS ABOVE AND BELOW. WELL LEFT SHUT IN AND FREEZE PROTECTED. **NOTE: CA-2 PLUG IN WELL AT 9007'** 3/14/09 MITIA FAILED, LLR OF 3.36 GPM @ 2500 PSI 4/9/09 RAN TECWEL LEAK DETECT LOG. LEAK IDENTIFIED IN GLM #1 LIKELY THROUGH THE PACKOFF VALVE. 4/14/09 RAN PDS CALIPER 9007' RKB TO SURFACE. COMPLETE. 4/24/09 PULLED 225" CA-2 PLUG Ca~ 9007' RKB. ,RAN 2.8" BROACH TO 8930' SLM. IN PROGRESS. 4/25/09 DRIFTED TBG WITH 21' x 2.74" DUMMY TO 8970' SLM. READY FOR E/L. 4/27/09 ATTEMPTED TO SET LOWER PACKER OF A 3.5" WEATHERFORD PATCH. GOT STUCK 8775' WHILE RIH. SET PACKER INORDER TO GET FREE, PACKER LEFT IN HOLE. TOP OF _.,PACKER LOCATED AT 8773', MiD ELEMENT OF PACKER AT 8775'. 5/1/09 PULLED ER PACKER (c~ 8773' RKB. IN PROGRESS. 5/2/09 BRUSHED AND FLUSHED TBG TO 8972' RKB. DRIFTED TBG WITH 2.77" GAUGE & 3-1/2" WIRE BRUSH, NO OBSTRUCTIONS. READY FOR E/L. 5/7/09~SET 3.5" WEATHERFORD LOWER ER PACKER AT 8910' CORRELATED TO SLB LEAK DETECT LOG DATED 08-MAR-2009. MID-ELEMENT OF LOWER PACKER IS AT 8929' RKB (CORRELATED TO TUBING TALLY). TAGGED PACKER TO CONFIRM SET. 5/9/09 UNSUCCESSFULL ATTEMPT AT SETTING PATCH ASSY c~ 8910' RKB. HUNG UP @ SSSV. SHEARED SAFETY RELEASE ON HES 2.5" SHORTY. RECOVERED 2.5" SHORTY WITH BAKER SETTING TOOL. RECOVERED WEATHERFORD PATCH. MISSING ELEMENTS AND SEALS FROM PATCH ASSY. IN PROGRESS. 5/11/09 RECOVERED MISSING ELEMENT PIECE FROM ER PKR @ 1905' RKB.,QRUSH AND FLUSH TQ TOP c~F FR pKR (c~ 8910' RKB RECOVERED SPRING PIECE. IN PROGRESS. 5/12/09 ATTEMPT TO SET PATCH ASSY @ 8910' RKB, NO SUCCESS. HES SLICK SHOT TOOL FAILURE. IN PROGRESS. 5/18/09 fiET 3.5" ER PKR, SPAC_E PIPE, & STINGER ASSY ~(JAL=16' 2" MIN ID 1 75"? IN LOWER ER PKR ~a 8910'RKB. PERFORM 30 MIN CMIT TO 2500 PSI, GOOD TEST. JOB COMPLETE. 3~4-\~,~1 ~~p`~ es~~'`~,~,`~ ~~ 5/21/09 BRUSHED & FLUSHED TBG f/ 8700' TO 8800'. READY FOR E/L. 5/25/09 SET A 3.5" WEATHERFORD PATCH LOWER ELEMENT. MID ELEMENT SET AT 8755', BELOW LEAKING GLM. 5/29109 SET ER TEST TOOL IN LOWER ER PACKER @ 8755' RKB. CMIT 2500# (PASS) SET UPPER ER PACKER/SPACER PIPE/SNAP LATCH ASSY (25.09' OAL 1.75 MIN ID) @ 8755' RKB (TOP OF UPPER PATCH ASSY @ 8730' RKB) MITIA 2500# (PASS) JOB COMPLETE .3~~+ 1~ ` ~~~ ~ ~, f 1 Phill C KUP l i ' W M A l MD 1A-11 TD ~ps ~ onocv ,~~`.,,^ ~„', ~ ~ • e l Attr butes __ WellboreAPVUWI FieldNama 50029206850G ~KUPARUKRIVERUNIT -_ , ax ng e $ WeIlStatus Incl(°) MD((tK8) IINJECIWG 57.00 li 7.900.OU __ ActBtrn(kKB) 97320 IComment H25(ppm) Date ~ I Annofation EntlDate ",KB-Grd(H~ I R'gReleaseDa I .. W IIC f - ~~'~ n 63 ~':' U ~\f I -{SSSV.IRUP , 0 1/1/20 l 09 LastWO~ 10/1511985 39.01 ~ iZ22/1981 .___ . _ g . . > ___ Scher Aqu:il IAnno~ation ~ Depih (([KB) End Date ~Annotation ~Las~ Mod By ~ End Date SAFEfY VLV. 1.905 SURFACE. 2.96] PACKER. 8,730 PATCH, 8,]33 PACKER. 8.155 GAS LIFT, EJ5& PBR, 8,603 PACKER, 8,815 iN~ecrroN. 8.851 PAp(ER, 8.893 - ~PERF, _ 8.878-8.9~8 PATCH.8.896- PACKER, 8.910 - IPERF. 8.930~8.938 I NIPPLE.85]2-., SLEEVE-C, _ 8.972 PACKER,8,985 - NIPPLE. 9 OG7 - SOS, 9,018 - TTL. 9 019 - IPERF, 9.082~5.095 IPE4F. 9,108-5.150 -. FISH, 9.22a FISH,9,366 ~-~- PRODUCTION, 9.113 TD, 9,732 - ~- CONDUCTOR 16 15.060 39.0 80.0 80Ai 65.00 H-00 j SURFACE 10 3/4 9794 ~ 26.1 2,94~.0 2,4252I 45.50 K-55 _- _i PRODUC110N 7 6_751 26.1 . 9,713.0 6690.11 26.00 K-55 .. . _ _ __ . :_. _ _ Tubin~ Strings _ _ _ __- ~i String OD I String ID I - - - --- - Sat Dep~h Set Dep~h (TVD~ Stting Wt String j I -__ TubingD escription ~ (in~ ~ (in) , QiKB) (RKB) (IGS/H) Gratl Top(ftKB) e I StrinyTOp Thrd TUBWG 3 1,2 2992 2G.0 8,996.0 6,184.0 920 J-55 iBTC-AB-MOD TUBING _ 27IA 2441 8,996.0 9.019.0 6,19Z6 6.SO~J-55 ~ ~EUESRD _ ~ Other In Hole (A Top Depth, ll Jewelry: Tubin g Run 8 Retrievable, Fish, etc.) ~ (ND) ' Top Incl Top(ftKB)~ (ftKB) (°) ~ Description Comment ~ RunDate ID(In) 1,905 1,751.7I 4791'SAFEIYVLV ~CamcoTRDP-IA-ENC 10f15/1985 2.813 8,730 6 006.8'~, q9.70IpACKER STRADDLE PATCH UPPER PACKER WFD ER 3' OAL 5l29/2009 1750, 8733 6,0087' 49.67'PATCH STRADDLE PATCH ASSY: SPACER, SNAP LATCH OAL 5/29/2009 1750~i ~ ' ~~. I22' OAL, GOOD TEST 2500PSI ~ ~~ I 8,755 6,023.1I 49.45I PACKER STRADDLE PATCH LOWER PACKER WFD ER 3' OAL 5l25/2008 ; 1750 8758 6,025.0 49.42 GAS LIFT OTIS/LBX/1.5//T-2l/I Comment: PACKOFF VALVE STA 1 7/6/1990 ~~ 2.906 8,803 6,055.1 48_96 PBR 8rown PBR 10/15/1985 3.000 8,815 6,0628 48.81 PACKER Brown'HB' PACKER 10/15l1985 ~ 3000 8,851 6,0862 4A.36 INJECTION CAMCO/KBUG/ifDMYfBK/llCommentCLOSEDSTA2 I 6I27I7989 2.875 8,893 6,114.0 47.84 PACKER STR4DOLE PATCH UPPER PACKER WFD ER 3' OAL I 5/18J2009 1750 8,896 6,116_7 47.80 PATCH STRADDLE PATCH ASSY' SPACER, SNAP LATCH OAL ~ 5/18/2009 ~ 1750 , 14' OAL, GOOD TEST 2500PSI 8,910I 6,128 0 4920 PACKER STRADDLE PATCH LOWER PACKER WFD ER 3' OAL 5/7/2009 ~ 1750 8,972i _ 6,167.8~ 47.34I NIPPLE iAVA BPL PORTED NIPPLE ~ 10115l1985 ~ 2750 8,972~, 6,16~.8~ 47.34ISLEEV6C ~,AVA BPI SET 8/7/2003 8A/2003 ~~~. 2.313 8,985 ` 6,776.6 4fi.95~PACKER Brown'26'PACKER 10(15/1985 'i 4.000 9,007 6,188_5 42.71INIPPLE __'___ Camco'D'NippleNOGO ~ 10l15l1985 2250 9.018 6,196.8 ~ 4227~',SO5 ; . _.._Y..._ Brown 10/15I7985 2.441 9,019 6,197.6~ ~ 4229' iTL ___`.._. ITTL ELMD 9000' @ IPROF 7/7/1999 _ . 10/15/1985 ~ 2.441 9224~ 6.345.6 .. 44.12~~PISH i '~.E-LineToo118.5'long . .-.- 10/31/1982 ~ i S,:wG 6 4328 44 73 FISH '~VANN GUN 278' long 12/2/1987 PerFora tions 8 Slots _ ----- - - - __ W._.__ - sn« ---- ' Top (TVD) Btm (TVD) ~ Dens Top (ftKe) etm (ftK6) (ryKB) (ftKB) Zone Date II (sh... Type Comment 8,878i 8,918 6,104.Oi 6,133.0 CA, C-3, C-2, 12121/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph i ~ C 4.1A-11 8 930~ 8,938I 6,140.5 6,145.6 UNIT B, 1A-11 i 12/21/1981 4 0 IPERF 4' Vann Guns, 120 deg Ph ~ 9 082 9,095~~ 6,244A~~ 6,253.9 A-5, 1A-11 '~ 12/21l1981' 4.0 IPERF 4' Vann Guns, 120 deg Ph 9J08 9,150 . ti,263.3 6,293.3 A4, 1A-11 12/21/7981 4 0 . , _. . . IPERF 4' Vann Guns, 120 deg Ph _._ _-- a Notes: General _ En0 Date & Safety . ..__ . __. _ .. ~_ _ .__ . -_ Annotation --- -- ~ _ X 3/8(2009 NOTE LDL STOP COUNTS ABOVE 8 BELOW CONFIRMED LEAK @ 8903' IN TBG JOINT ~ 5 k~ a (~ ~ ., ~ ~a AI.ASSA OIL AVID GA5 CO1~15ER~ATIOIQ COM1~II551OI~I Martin Walters • fF ;'' SARAH PALIN, GOVERNOR t 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PNONE (907) 279-1433 FAX (907) 276-7542 Problem Wells Supervisor ~ ,, 4. ~,,, ,1 ,,, ~ -- ,~ ~ ConocoPhillips Alaska Inc. '"'~~"~`"~ ~~~ ~l "`~ PO Box 100360 ~ 1 Anchorage AK 99510-0360 ~ ` 1 Re: Kuparuk River Field, Kuparuk Oil Pool, 1A-11 Sundry Number: 309-161 Dear Mr. Walters: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30' PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair l s ~'~ DATED this day of 1, 2009 Encl. t • • • • ConocoPhill~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~p"- ~_ '~$ ~~8S~(8 ~1{ ~ ~a5 ~'ar ~,; _~,~ April 27, 2009 AttCt~s~t~~~ Mr. Jim Regg Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Regg, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1A-11 (PTD 181-173). The request is for approval to patch a tubing leak above the top packer. Please call Brent Rogers or myself at 659-7224 or M J Loveland / Perry Klein at 659- 7043 if you have any questions. Sincerely, ~~~'~~~a Martin Walters Problem Well Supervisor Attachments ~~' r 1' S STATE OF ALASKA !~ P ~ 3 Q ~ O O O /~ ~, ALASKA OIL AND GAS CONSERVATION COMMISSION *, 3~0 APPLICATION FOR SUNDRY APPROka OiP & Gas Cons. commission 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other After casin 9 ^ Re air well J Plu Perforations p ^ g ^ Stimulate ^ Set tubing patch Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 181-173 . 3. Address: Stratigraphic ^ Service ~ ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20685-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where 8. Well Name and Number: "- ownership or landownership changes: Spacing Exception Requires? YeS NO Q 1A-11 9. Property Designation: 10. KB Elevation (ft): 11. Field/P~I(s): ADL0025647 ~ RKB 100' . KuparukRiver Field / Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9732' • 6703' Casing Length Size MD ND Burst Collapse CONDUCTOR 16" 80 80 1640 630 SURFACE 2847' 10-3/4" 2947' 2425 3580 2090 PRODUCTION 9613' 7" 9713' 6690 4980 4330 Pertoration Depth MD (f 8878'-9150' Pertoration Depth TVD (ft): 6104'-6293' Tubing Size: Tubing Grade: Tubing MD (ft): 3-1 /2" 89911 2-7/8" J-55 9019' Packers and SSSV Type: Packers and SSSV MD (ft) Brown 'HB' Packer Packer = 8815' Cameo TRDP-1A-ENC SSSV SSSV = 1905' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ r Development ^ Service ^/ 15. Estimated Date for 16. Well Status after proposed work Commencing Operations: May 1,2009 Oil ^ Gas ^ Plu ed gg ^ Abandoned 17. Verbal Approval: Date; WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Martin Walters Printed Name Marfin Walters Title: Problem Wells Supervisor Signature ~° ; Phone 659-7224 Date: April 27, 2009 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ j ~ ~ (Q l Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ ~ ~'`` ~~ ~ `~ Other . Subsequent Form Required: APPROVED BY ~~ ~l Approved COM E OMMISSION Date: !S ~ : , __ t~ ~'. 1 • ~,. ConocoPhillips Alaska, Inc. Kuparuk We111A-11(PTD 181-173) SUNDRY NOTICE 10-403 TUBING REPAIR 04/27/09 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk Well 1A-11 (PTD 181-173) with a tubing patch. On February 8, 2009, the AOGCC was notified of suspected TxIA communication. Subsequent diagnostics have identified a tubing to IA leak at gaslift mandrel #1 at 8758' MD. The plan is to set a retrievable patch over the mandrel, conduct an MITIA, and return the well to normal WAG injection. REPAIR PLAN 1. Set 3.5" retrievable patch over gaslift mandrel at 8,758'. 2. MIT as per AOGCC requirements (0.25 x TVD to packer). 3. Submit 10-404 post-repair. NSK Problem Well Supervisor 1A-11 (PTD# 181-173) Report Of TxIA Communication Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 09, 2009 3:38 PM To: Regg, James B (DOA) Subject: RE: 1A-11 (PTD# 181-173) Report Of TxIA Communication According to RBDMS, at least until the end of the year the well was on water. From: Regg, James B (DOA) Sent: Monday, February 09, 2009 3:30 PM To: Maunder, Thomas E (DOA) Subject: FW: 1A-11 (PTD# 181-173) Report Of TxIA Communication IA pressure is 55% of MIYP (7" K55, 26ppf); left msg with them about timing for diagnostics, etc. Jim Regg AOGCC 333 W.7th Avenue, Suke 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem WeH Supv [mailtv:ni617@conornphiilips.com] Sent: Sunday, February 08, 2009 11:15 AM To: Regg, James 8 (DOA}; Maunder, Thomas E (DOA} Cc: NSK Problem Weil Supv; NSK We!! Integrity Proj; CPFl Prod Engr; CPF1 DS Lead Techs; Kvvar, Mark Subject: 1A-li (PTD# 181-i73) Report Of TxIA Communication Jim/Tom, Kuparuk WAG injector 1A-11 (PTD# 181-173) is suspected of having TxIA communication based upon recent frequent bleeds and a failed inner annulus drawdown test. The well has a current T/IA/OA/OOA of 2186/2750/950/Osnd will be added to the Monthly Failed MIT report. ConocoPhiltips intends to inject in the well as necessary to conduct additional diagnostics and will submit a 10-403 to repair or seek administrative approval to continue injection. Attached is a 90 day TIO plot and a weilbore schematic. «1R-11 TIO Plot.ppt» «1A-11 Wellbore Schematic.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 4/30/2009 ProActive Diagnostic Services, Inc, To: ACC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) fi59-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTV The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmit~;a! letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245-8952 1) Leak Detection - WLD 09-Apr~09 1 A-11 2J ~ u~G i~sl- ~~-3 50-029-206$5-00 a ~ ; -,,, a~~.. ~~~~:~ APB EDE l'~-~9~~ ~~ i ~~ ;~ Signed : ' Print Name: Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAX: (907!245-88952 -, -MAIL : -- -°_-_- - _ __.;___. __ _~_. ~, C:\Documents and Settings\Ownet!Desktop\Transnut_Conoco.docx • • ~~~ ~ ~~ ~ ~,~ ~ ~ ~~~ ~~~ II ~, ~,~ ~ ~~,1 ~..~' ,~ ~ ~ {.._ ~,~ j{} '+ i i L... ~C~ [ l ~ ~ ~~ ~ , ~-~ ~}} ~~~ SARAH PAL1N, GOVERNOR ~~7~ OIL AI~TD GAS 333 W. 7th AVENUE, SUITE 100 CO1~tSERQATIOrIT COMl-IISSIOI~T %~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 John Peirce Wells Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510-0360 ~ `.~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 1A-11 Sundry Number: 309- I37 ~~~' APR ~ ,~k 2.D(1 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~¢~ Daniel T. Seamount, Jr. S,~ Chair DATED this ~ day of April, 2009 Encl. G~~I 1/ ~~ ,0 APi~ ~ t~t'~sy ' STATE OF ALASKA ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~Laska Oi! & Gas Caps. C~~mmtsSru~'I APPLICATION FOR SUNDRY APPROVAL Anch6rage 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Alter casing ^ Repair well ^ Plug- Perforations ^ Stimulate ^ Time Extension ^ tubing patch ~~~Q~~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 181-173 3. Address: Stratigraphic ^ Service 0 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-20685-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? YeS ^ NO ^~ 1A-11 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25647 ~ RKB 100' Kuparuk River Field /Kuparuk River Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9732' 6703' • 9624' 6628' 9007' 9224', 9346' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 80' 80' SURFACE 2847' 10-3/4" 2947' 2425' PRODUCTION 8613' 7" 9713' 6690' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8878'-8918', 8930'-8938', 9082'-9095', 9108'-9150' 6104'-6131', 6139'-6146', 6245'-6254', 6263'-6293' 3.5" x 2-7/8" J-55 8996', 9019' Packers and SSSV Type: Packers and SSSV MD (ft) Brown'HB' pkr, Brown'26' pkr 8815', 8985' Cameo TRDP-1A ENC SSSV @ 1905' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat May 3, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ - WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name JOhn P@IrCe Title: Wells Engineer Signature ~ y L~° "" Phone 265-6471 Date - ''- Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ - Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Lt~l~r.-LIST a~ O~ - ' ~~ Other: " Subsequent Form Required: `fib APPROVED BY ` ~ 1 Approved by: COMMISSIONER THE COMMISSION Date: ~ Form 10-4 R is 06/2006 -d~' Submit i DupliraLe ~~ '~' ?G-~fyy/~/may ~• La g 2 CasingStrings - String OD String ID Sat Depth Set Depth Casing Description (in) (in) Top (fiKB) (ftKe) (kKE CONDUCTOR 16 16.CI(i0 39 ~, 80 . SURFACE ~ 103!41 9.794 0, 2,9471 " ~ KUP ConotoPhillips ~ ~~ weii Attributes __ _ __ Wellbore APIIU WI Field Name Well Status Prodllnj Type :~ILLaKd. hu". 50029206&500 KUPARUK RIVER UNIT INJECTING PVdI Comment M25 (ppm) ~, Date Annotation'i Entl Date ... -_____-. 'SSSV~ TRDP 0 1/1/2009 .Last WO[ ', 10!15 _ wquc ng~ _t_1,3'9rzoy~:'r,~as~~.l _,__-_ - _.._ . ShcaM1lglk-Aquel Annotation Depth (liKB) End Data Annotation st Ta : SLM I 9 130 I !1/2009 Rev Reason: ADD NOTE CONDUCTOR, 80 $AFE1V vLV, i sos SURFACE. 2.9n GAS LIFT. 8.758 PBR, fl.E(13 ACKER. 8.815 INJECTION, 8.851 IPERF, 8.878-8.918 IPERF, 8.9308,938 NIPPLE. 8,9]2 .. SLEEVE-C. _. --.. _- _ 8,9]2 PACKER. 8,985 - NIPPLE. 9,00] - PLUG, 9,00] SOS, 9,018 - TTL. 9.019 IPERF. 9,082-9.095 IPERF, 9.1089.150 FISH. 9.219 3 1!2 39.01 i-ENC -21J! Comment: PACKOFF VALVE STA 1 BPI SET 8l7/20C n '2B' PACKER :o'D' Nlpple NO long 1 A-11 1 Bim (ftKB) 9,732 I Release Date 12!22!1981 tl Date 3!9/2009 511985 C-2, 12/21/1981 4.0 IPERF 4- Vann Guns, 120 deg Ph 1 A-11 12/21/1981 4.0 IPERF 4' Vann Guns, 120 deg Ph 1 12/21!1981 ' 4.OIPERF 4' Vann Guns, 120 deg Ph 1 I~ 12!21!1981 ~ 4 OIIPERF 4' Vann Guns, 120 deg Ph _._- _:-. _. I ~ _._-- __-. -. Annotation _ E & BELOW CONFIRMED LEAK @ 8903' IN TBG JOINT 2.906 FISH, 9,38 --- PRODUCTK)N, 9,] 13 TD, 9.732 1A-11 Tubing Patch Installation Proposal 1A-11 is a C and A sand selective injector completed in 1985 with 3.5" J-55 tubing. Per this procedure, a retrievable tubing patch will be set across a large tubing leak at 8903' MD to halt all PWI entering the C sand, and to divert all PWI to the A sand. A 3-08-09 LDL shows a large leak exists in the tubing at 8903' MD, that allows almost all PWI to enter the C sand. An LDL of 4-09-09 confirms an additional small annular communication leak exists at GLM #1 at 8758' MD. This procedure only addresses isolating the tubing leak at 8903' MD. The annular communication leak at 8758' MD is to be addressed under a separate 10-403 Sundry from an NSK Problem Wells Supervisor (659-7043). Objective: Install a retrievable tubing patch across the tubing leak at 8903' MD to halt all PWI entering the C sand, and to divert all PWI to the A sand. Well Status: 1A-11 is shut-in with a plug in the tubing tail due to Tbg x IA communication through a leak at GLM #1 at 8758' MD, and due to a large tubing leak to the C sand at 8903' MD. Procedure: Slickline: 1. RIH with 2.80" broach to remove deposits of uncertain material that exist in the tubing (per Caliper of 4-14-09) restricting ID to 1.94" around 2093' MD. Run 2.80" gauge ring to 8950' MD to verify tubing is open enough to safely drift 2.74" run OD straddle packers for a tubing patch. 2. Pull the plug from the 2.25" Camco `D' Nipple at 9007' MD. 3. Brush & flush the 3.5" tubing at 8870 - 8930' MD in the area where the tubing patch will be set. E-line: Install a 15' Retrievable Tubing Patch as follows: 4. RU E-line. RIH with 3.5" Straddle Packer (2.74" run OD) and set the packer with the element at 8910' MD. Slickline: 5. RIH with an Anchor Latch assembly, ~15' spacer pipe, and 3.5" (2.74" run OD) Packer. Sting into bottom packer at 8910' MD and set the top packer element at +/- 8895' MD. Due to the tubing leak at 8758' MD, we cannot pressure test the upper packer of this patch. Notify NSK Problem Well Supv to inform 1A-11 is ready for an upper patch installation to isolate the annular communication leak at 8758' MD. John Peirce 4-77-09 • To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MT'T) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 9951 S Fax: (907) 245-8952 1 ] Caliper Report 14Apr~09 1 A-11 1 Report / E~ 50-029-20685-00 2] Caliper Report 19-AprO9 1 G11 1 Report / EDE tg Co-r t~-4d ~ `~-~F~~~ ~P~ t: ~ BOG Ii ,- ~ ~ ,; Signed : ~_ /~~ Print Name: .~ 50-029-22 7 1 400 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W, INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907245-8951 FAx: (907)245-88952 E-MAIL : __ _ : __ _ . _ _ ,_ WEBSITE D:\00_PDSANC-2009\Temporaty\2T-10\CD_Patts\Transmit_Conoco.docx • Memory Multi-finger Caliper S Lag Results summary Company: CohocoPhillips Alaska, Inc. Well: 1A-11 Log Date: April 14, 2009 Field: Kuparuk Log No.: 7316 State: Alaska Run No.: 1 API No.: 50-029-20685-00 Pipet Desc.: 3.5° 9.2 Ib. J-55 BTC-AB-MOD Top Log Intvl1.: Surtace Pipet Use: Tubing Bot. Log Intvl1.: 8,998 Ft. (MD) Inspection Type : Corrosive 8 Mechanical Damage Inspection COMMENTS : This caliper data is tied into the AVA Nipple ~ 8,972' (Drlller's Depth). This log was run to assess the condition of the tubing before making a decision to patch a known leak in GLM 1 at 8,758' and a known C sand leak a# 8,903'. A 3-D log plot of the caliper recordings across this interval is included in this report. The caliper recordings indicate the 3.5" tubing appears to be in goad to poor condition with respect to corrosive and mechanical damage. A maximum recorded wall penetration of ' 47% is recorded in an isolated pit in joint 116 (3,614'). Recorded damage appears as isolated pitting from -1,630' to 7,770`. No significant areas of cross-sectional wall foss are recorded. Deposits restrict the i.D. to 1.94" in joint 67 (2,093'). A graph illustrating minimum recorded diameters on a joint-by joint basis is included in #his report. ' The caliper recordings indicate slight buckling from _7,900' to -8,890'. ' MAXIMUM RECORDED WALL PENETRATIONS: Isolated pitting { 47%) Jt. 116 (~ 3,614 Ft. (MD) ' Isolated pitting (46°~) Jt. 82 ~ 2,563 Ft. (MD) Isolated pitting (43%) Jt. 91 ~ 2,848 Ft. (MD) Isolated pitting (40%) Jt. 79 @ 2,477 Ft. {MD) tsolated pitting (40%) Jt. 104 (~ 3,241 Ft. (MD) ' MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wall loss (> 12°~) are recorded. r MAXIMUM RECORDED ID RESTRICTIONS Deposits Minimum I.D. = 1.94" Jt. 67 @ 2,093 Ft. {MD) Deposits Minimum I.D. = 2.01" Jt. 66 (~ 2,088 Ft. (MD) Deposits Minimum I.D. = 2.13" Jt. 285.6 @ 8,974 Ft. (MD) ' No other sign cant l.D. restrictions are recorded. ~_~~'~. tie Y i ~ l~ ~~ G.. U S7~ C n 0 Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: S. Ferguson ProActive Diagnostic Services, Inc. / P.0. Box 1369, Stafford, TX 77497 Phone: (281} or (888} 565-9085 Fax: {281) 565-1369 E-mail: PDS.c memoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: {907) 659-2314 VZ~ l~~- l~3 ~~Oo~ 1 • • _~~ PDS Multifinger Caliper 3D Log Plot i Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1A-11 Date : April 14, 2009 ' Description : Detail of Caliper Recordings Across Known Leak in GLM 1(8,758) and C Sand Leak (8,903) 1 1 1 P 0° I ~' fi ~~ ~~ ~ .. ~ " .._ -•,~ r • ~ 8820 , ~ ~~ ~ --} - - -.:. _ _ -- f 8830 Joint 284 j j ' 12°k Wall j I~ ~ ~ •a Penetration 84 I i- 8 0 I I - ,{ 8850 - _ GLM 2 _ . - ~ 8860 ~ = i - - - - ~ - Joint 285 87 s _ 8 0 13°~ Wall ~_ Penetration ---t-._' -._ -+ Slight Buckling ! " 8880 __a _.. 8890 - - " - Pup Jt - ~- -- } r ` 5% Wall ~ ~~ Penetration -- r .._'.- ~" a:c 8900 ~ e. ~.: Pup Jt. bR 8910 C Sand Leak ($~~3~) ~ I ~ u' - 8920 . #~". ~ ~,.r ~. Pup Jt. I _ ~, ~u 3> 196 wall 8930 j Penetration ' ~ I ~ ~~ ~ ~` i _ . Nominal ID (1/1000 in.) 2500 3500 Min ID (1/1000 in.) 2500 3500 Comments Depth Max. Pen. (%) Max ID (1/1000 in.) 3-0 Log Ima ge Map 1ft:1701t 0 100 2500 3500 0° 0° 90° 180° 270° 0° • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (2.9' - 8994.9') Well: 1 A-11 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 14, 2009 . Approx. Tool Deviation ^ Approx. Borehole Profile 7 774 1550 2338 3104 3876 4650 ~ 5423 ~i 6191 c s Y Q 6964 ~ 7729 8505 GLM 1 I N) 2 285.9 8995 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 285.9 1 25 ` 50 ti 75 , 100 125 150 y 175 .fl E Z 200 0 225 25O 275 • • - _ `~- Minimum Diameter Profile Well: to-11 Survey Date: Apri114,2009 Field: Kuparuk Tool: UW MfC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches 1.69 0.1 5 12 79 26 33 40 47 54 60.1 67 74 81 88 95 702 709 716 123 130 137 144 Z 151 8 158 .... 165 172 179 786 793 200 207 214 221 228 235 242 249 256 263 270 277 282.2 284.1 285.6 Minimum Measured Diameters (In.) 1.94 2.79 2.44 2.69 2.94 N i PDS Report Overview -` ~w Body Region Analysis Well: 1 A-11 Survey Date: April 14, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fngers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.2 f -55 BTC-AB-MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body gr metal loss body 300 - 2 50 200 150 100 50 0 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of'oints anal se d total = 297 pene. 4 42 200 loss 36 259 2 48 3 0 0 0 0 Damage Configuration (body ) 60 40 l0 0 isolated general line ring hole / pons pitting corrosion corrosion corrosion ible hole Number of 'Dints dama ed totals 53 52 1 0 0 0 Damage Profile (°~ wall) ~ penetration body ~.aL;. metal loss body 0 50 100 IN)~ 2 Bottom of Survey = 285.9 Analysis Overview page 2 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.2 ppf )-55 BTC-AB-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • i LATI O N SHEET 1 A-11 Kuparuk ConocoPhillips Alaska, Inc USA April 14, 2009 Joint No. Jt. Depth (Ft.) I'~~n. Ul ~s~ ~t (Ins.) Pen. Body (Ins.) Pen. %~ 'v1~~t,il I cn~ ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 0 .0 I I 2.91 PU t. e si 1 7 t) 0.04 17 t, 2.8 t. De o its. 1.1 44 U 0.03 13 1 .93 PUP Lt. D sits. 1. 0 u 0.06 2~ I _' P P Cor ion. 2 60 c t .04 1' ~! 2.90 t. De osi 3 92 t~ 0.03 1:> ~ .85 t e sits. 4 123 U 0.04 14 .87 its. 5 154 a 0.04 15 -1 2.90 Lt Ue osi 6 1 t) 0. 1 4 1 2. 1 Lt. De sits. 7 215 l) 0.04 17 2.94 Lt. D osi . 8 47 l) .03 1 ~' 2.9 9 27 a 0.04 15 -! 2.96 10 30 U 0.0 1 > 2.93 11 340 U 0. 5 1 t3 ~.~ 2.96 12 3 1 t) 0.03 13 > .94 3 402 U 0.03 t l ~ .95 14 43 a 0.04 14 t .92 Lt. De osi 15 46 l) 0.04 15 5 L . sits 16 493 u 3 13 ~ .93 17 5 5 U 0.03 11 2 .87 Lt. D sits. 8 55 O 0.0 13 4 2.93 19 588 U 0.04 14 1, 2.93 20 18 l) .03 1 1 2.94 21 649 t) 0.04 14 2.92 Lt. De osi ts. t) 11 23 711 U 0.03 12 ~t 2.93 24 742 U 0.03 11 _' .9 t i . 25 774 l) 0.03 12 ~ 2.94 Lt De osits. 26 t) .03 13 5 .95 27 836 U 0.05 1 £3 t~ 2.93 Lt. D osits. 28 867 U 0.0 I ~i -1 2.8 De osits 29 899 l) 0.01 4 I 2.93 927 U 0.04 15 '~ .97 31 959 l) 0.03 I ~ I 2.86 Lt De sits. 3 90 tl 0.05 1 t3 7 2.92 osits. 33 1021 t) 0.04 15 4 2.93 34 053 t1 0.0 19 6 .88 t. osits. 35 1085 l) 0.04 14 4 2.90 Lt. De osits. 36 1116 l) 0.0 13 4 .94 L . De si . 37 1147 O 0.04 15 i 2.91 Lt. De osits. 3 1175 a 0.0 1 3 ~ .89 t D o ~ts. 39 1 05 U 0.05 19 ~ 2.96 40 1236 U 0.03 1 3 ~ 2.92 Lt. a osits. 41 1267 a 0.04 1 b i ~ 2.96 42 1299 U 0 3 1 ~ .93 43 1330 t) 0.03 1 s 2.94 44 13 0 U 0.05 19 '~ .93 Lt. D its. 45 1392 U 0.04 14 4 2.95 14 4 U 0. 12 2 .90 Lt. o f 47 1456 l l 0 03 1 1 ~' 293 _ Penetration Body Metal Loss Body Page 1 ~ • • PDS REPORT JOINT TABULATION SHEET ' Pipe: 3.5 in 9.2 ppf }.55 BTC-AB-MOD Well: 1 A-11 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhitlips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 14, 2009 Joint No. Jt. Depth (Ft) I'rn. IllsE~t (Irn.l Pen. Body (Ins.) Pen. °i° 'vtc~t~rl I cis; ~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 48 1487 t) .04 17 t~ 2.88 . De osits. 49 1 1 t) 0.04 16 (~ 2.94 5 50 t t 0.03 1 1 2.9 1 15 U 0.04 17 t~ .95 52 1612 U 0.05 1U ~1 2.95 Isolated it in . 5 1644 U 0.03 1:3 .9 e o i ts. 54 1677 O 0.05 19 -1 2.92 55 1706 C) 0.03 lU 2.91 Lt. De sits. 56 1 37 t i 0. 3 1 1 .93 57 17 8 t~ 0.04 16 5 2.93 t. D o i 8 1800 O 0.03 13 2 2.90 t. e o its. 59 18 1 tt 0. 0 39 ? .91 Isolated ittin t De 'ts. 60 1863 tt 0.0 12 -1 2.91 Lt. D sits. 6 .1 1 U 0 0 U .81 a c TR P-1 -EN SSV 6 19 4 t! 0.0 13 3 2. 6 6 933 ~ t 0.03 12 2.94 63 1965 t? 0.04 14 1 .93 Lt. D sits. 4 1996 O 0.03 1 i -1 2.7 e sits. 6 0 8 (t 0.04 14 Z 1 sits. 6 2059 t t 0.03 10 ~1 i . 67 2090 t~ 0. 3 l U 1.94 e sits. 8 2122 n 0.05 21 a 2.96 Is lated 'tti 69 152 U 0.10 i~) .96 Isola a ittin . 70 2182 U 0.09 ~~5 2.95 Isolated ittin . 1 221 U 4 l v c, .97 72 2244 tt 0.05 1 t3 I 2.91 Lt. D osils. 73 276 U 0.03 12 ~ .94 74 2307 l) 0.07 27 s 2.95 Isolated ittin . 7 338 U. 13 0.06 24 ~' 2.9 Is la ed "t' 76 2366 t) 0.03 12 3 2.96 77 396 t) .04 17 3 .94 78 2426 U 0.04 17 3 2.96 79 457 U .10 ~1U (> .9 Is lat d ittin Lt. De osits. 80 2487 tt 0.08 31 ~~ 2.93 Isolated iitin . L . De sits. 81 ' S 0 U 0.04 1-~ .1 .92 L . De sits. 82 2552 U.U~> 0.12 46 4 2.94 Isolated ittin . 83 5 2 (1 0. 9 37 ~ 2.94 Isolated itti 84 2613 a 0.08 3O `; 2.93 Isolated ittin . 5 2645 U 0.06 2> 2.95 Isolated ittin . 86 2674 U 0.04 17 -I 2.92 87 2705 tt 0.06 ?~ .93 Isol a itCn 88 2735 a 0.04 15 5 2.95 9 2766 U 0.09 34 ~' 2 I late itiin Lt. De sits. 90 2797 t) 0.06 25 -1 2.94 Isolated ittin . 91 2827 U.lt7 0.11 ~3 fi 2.9 Isolated i ti 92 2859 n 0.06 ~1 I 2.94 Isolated ittin . 93 2889 l) 0.05 LU ~ .92 94 2920 (l.l)6 0.09 3 3 7 2.90 Isolated ittin . Lt. a sits. 5 2952 t ~ 0.02 ~) ' .95 96 2982 ~~ 0.03 12 2.95 Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.2 ppf J-55 BTC-AB•MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • i CATION SHEET 1 A-11 Kuparuk ConocoPhillips Alaska, Inc USA April 14, 2009 Joint No. Jt. Depth (Ft.) N~~n. Uln~~i (Ins.) Pen. Body (Ins.) I'c~n. %, ~'vtct,~l Ica ~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 97 3 (~ 0.03 13 .94 9 3045 U 0.05 ' 1 .' .94 I ted itti 99 30 t~ 0.06 ZZ _' .94 Is lat d ittin . 100 104 t) 0.04 1 7 -1 .94 101 3137 t) 6 24 ' 2.9 Isola ed ittin . 102 66 t~ 0. 9 36 ~; 95 so at d itti 103 3195 U 0.08 i0 ~' 2. 4 Isol ted itti 104 3228 a 0.10 4t) '~ 2.96 Isol to ittin . 05 3260 U 0.0 zu I 2.95 1 6 3291 ~) 0.04 17 ~ 2 107 332 tt ~) 2.93 1 8 3352 a 0.03 1 '' 2.95 109 3384 t ~ 0.03 12 _' .95 110 3415 U 0.03 1 ~s 2.95 111 3447 U 0.06 '1 ~ .94 Isol d 11 477 tt 0.0 ~~ ' .92 13 3508 t t 0 06 .~. t -3 2. 4 1 la a itti 11 3538 l) 0.03 11 ! 2.94 115 3570 U 0.02 9 ' 116 3 99 l~ 01 47 ~ 2.95 I I t d itti 117 3629 ll.t)9 0.0 9 _' .94 118 3660 t~ 0.03 11 _' 93 e o its. 119 3693 U 0.08 3 2.93 Isol to itti 120 3722 t~ 0.03 11 2.96 1 753 a 04 16 1 2 9 122 3784 tt 0.08 tt~ ~, 2.95 Isolated itti 1 3 3813 (~ 0.0 lt) .94 124 3845 U 0.03 11 _' 2.94 125 3876 (~.US 0.04 15 s 2.9 126 3908 t) 0.03 13 s 2.95 127 938 U 0.0 12 4 2. 128 3970 t) 0.03 12 2 2.94 129 4001 l) 0.04 L5 _' .82 L D sits. 130 4031 t) 0.04 17 _' 2.81 Lt De osits. 1 1 4062 l) 0.03 11 <' .94 132 4093 (1 0.04 1(> -l 2.92 Lt De osits. 133 41 4 t) 0 04 1 ~ 4 .97 134 4156 t1 0.05 19 5 2.96 13 4186 It 0. 3 11 _' .94 136 4216 t) 0.03 13 ~1 2.95 1 7 4245 t~ 0 3 13 4 2.96 138 4276 a 0.04 17 4 2.95 39 4307 a 0.04 1 t3 _' .93 140 4339 (~ 0.03 11 _' 2.94 141 4 6 U .0 1 I ' 2.9 142 4400 t~ 0.06 ZZ _' 2.92 Isolated ittin . 143 4431 t) 0. ~) _' 2.94 144 4462 U 0.04 15 2.94 145 92 U 0 04 1 7 .9 146 4525 U 0.02 9 ' 2.95 _ Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.2 ppf J-55 BTC-AB-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEEP 1 A-11 Kuparuk ConocoPhillips Alaska, Inc. USA April 14, 2009 Joint No. Jt. Depth (Ft) I'~~n. lllne~t (In,.) Pen. Body (Ins.) Pen. % tilc~t,~l 1<KS `is> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 14 4556 U 0.10 3t3 5 6 I la d ittin . 148 4588 (1 0.04 16 i 3 149 4619 (~ 0.01 3 1 2.92 Lt. o i . 50 4650 a 0.09 t(, ~ .93 I olated itti Lt. e i 15 468 U 0.0 1 _~ 3 2.93 15 47 2 l1.Ot3 0.08 >Z 3 .94 Is ate i ~n . 15 474 U 0.03 13 ~ .96 154 4774 t1 0.06 :_'_! (, 2.94 Isolat d ittin . 15 4807 t~ .06 Z5 4 2.9 Isolat d it 156 48 9 U 0.03 1 ~~ 3 1 7 4869 U 0. 3 13 4 .96 158 4899 t I 0. 3 13 4 159 49 0 u 0.04 14 ~ 2.93 16 4 60 U 0.0 I ~ .95 161 4990 u.t~; 0.03 LS 1 2.92 162 5021 (~ 0.03 I I 2.94 163 5053 ~ ~ 0.03 I ~ 2.94 164 083 t ~ 0.03 1 t I ~ 2.94 16 1 U.Ub 0 5 I I 2.98 I laced i ti 166 5146 t 1 0.0 11 Z 2.93 167 517 t I 0. 3 I 1 ? .88 Lt. De osi 168 20 U 0.03 11 _' 2.90 Lt a os'ts. 169 236 O 0.06 24 t3 .96 Isolat d itti 170 5268 U 0.02 ~) 1 2.92 1 5298 a .0 1l) .93 172 5329 U 0.05 21 _' 2.96 Isolated ittin . 173 5359 U 0.03 1 i 2.9 174 5391 t ~ 0.03 13 ~ 2.96 17 54 3 t ~ 0.0 I i > .9 176 54 3 t ~ 0.03 12 2.96 177 54 5 t ~ 0.0 17 (, 178 5515 t ~ 0.03 1 1 2.95 179 5547 n 0.06 ?l !, 2 5 I t it "n 180 5577 U 0.01 ~ u 2.93 181 5607 0 0.06 ZZ S .94 Iso at d i 'n . 182 5640 U 0.03 11 ? 2.93 183 5670 t) 5 I ti ~ 95 184 5701 t ~ 0.04 14 5 2.95 18 573 l) .0 ~) 1 2.9 186 5762 l I 0.04 I t3 7 2.93 1 5792 tI 0.02 7 I 3 188 5820 (1 0.02 ~) 2 2.92 189 58 U 0.03 1 i _~ 2.92 190 5883 U 0.04 17 ~t 2.95 1 13 U 0. 3 13 2.94 192 5944 t I 0.03 1 1 I 2.92 1 3 5974 t) OA4 14 ~ .9 194 6008 tt 0.04 I (, ~, 2.94 195 6038 n 0.03 I1 2.93 196 6066 i ~ 0.03 13 _' 2.94 _ Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.2 ppf --55 BTC-AB-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEEP 1 A-11 Kuparuk ConocoPhillips Alaska, Inc. USA April 14, 2009 Joint No. )t. Depth (Ft.) I'c~n. Ulxet (Ins.) Pen. Body (Ins.) Pen. °/, ~1et.~l I ~,~~ ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 197 6 6 l1 0.03 I _t ~ .95 198 61 8 t1 0. 5 dO - 2.9 Isol ted itti 9 61 U 0. 3 I a _' 2.94 t. osi ts. 200 6191 l l 0.04 17 ~ 2.91 t. osi ts. 1 6221 l1 0 06 24 1 2 9 Isola ed itti 2 52 U 0. 4 14 ~ 4 203 6283 t1 0.04 14 ~ 2.9 204 6312 U 0.05 1 ~i b .96 5 644 l1 0.0 1 I ~ .93 0 6375 tl 0.06 25 5 .95 Isolated ittin . 07 6406 ii .06 ~3 (, 6 Isolated ittin . 208 6438 tt 0.0 2 i 5 2.92 Isolate ittin t. a si 209 6467 U 0. 7 Z~) ~ 2.94 Isol to itti 10 499 U 0 03 13 ~ 3 2 1 6529 t1 .05 ZU -i 2.94 21 6561 t1 0.08 ,U i, 2. I ate itti L . e sits. 213 65 2 ) 0.02 ~) I 2.94 14 662 tl 0.07 26 i, sol ted ittin . t. 215 651 t t 0.04 16 t, 2. 5 16 6683 t ~ 0.01 -t I .93 217 6713 t ~ 0.03 1 3 ! .92 t. D si 218 6744 ll 0.03 11 2.93 t e osits. 219 6775 t1 0.06 23 ~ 2.94 Isolated itti 220 6806 U 0.04 17 s 2.92 Lt. sits. 1 6 3 U 0. 0 ' (~ 2.9 a s' . 222 6868 t t 0.03 11 _' 2.92 2 3 6900 U 0.03 1 3 I Lt. D si 224 6932 U 0.04 I (~ ~' 2.93 2 5 6964 t t 0 03 1 1 ~ 2.9 226 6995 tl 0.03 1 ~! 2.91 L . De sits. 227 70 tt 0.03 11 .93 228 7055 a 0.02 ~) I 2.92 29 7 86 U 0. 3 11 .95 230 7118 U 0.03 1_' 2.91 Lt. a sits. 31 7149 l) 0.03 12 ~' 2.95 232 7181 t1 0.03 to 2.94 3 7213 11 .01 t~ I 2.9 L e os'ts. 234 7241 t~ 0.02 '~ I 2.91 235 7272 t~ 0. 3 11 ? 94 236 7301 i ~ 0.04 I ~1 t, 2.96 237 73 a 0.04 14 3 3 238 7364 a 0.01 4 l) 2.90 Lt De sits. 39 739 tt 0.03 13 ~} 2.93 240 7424 U 0.04 15 2.93 241 7456 U 06 25 -~ 2.9 I at d 242 7486 a 0.03 1 "t ~ 2.93 243 7515 t~ .0 ~~ .94 244 7545 t 1 0.04 15 2.94 245 757 U .0 I1 .93 2 7608 ~ ~ 0.03 1~ 2.94 Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.2 ppf )-55 BTC-AB•MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Cornpany: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1 A-11 Kuparuk ConocoPhillips Alaska, InG USA April 14, 2009 Joint No. )t. Depth (Ft.) I'wi. 111,c~t Ilnti.) Pen. Body (Ins.) Pen. % Mc~t~~l lc~s> ",'~. Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 247 637 l) 0.03 1 I 2.9 t. De o i 76 8 O 0.03 12 ~ .93 249 769 t ~ .03 10 1 2.9 D 772 t) 0.03 11 1 .93 i 2 1 77 9 i ~ 0.06 2 3 ? 2.92 I ( ittin t. s' 779 t) .03 1 Z .' .9' e o its. 253 7821 a 0.03 11 ~ 2.93 254 7851 tl 0.04 14 2 94 5 7883 t) 0.03 1 I 2.93 Sli t b kl' 6 791 t) 0 0 1(l .90 Lt. D si 257 794 ~~ .03 11 _' 2.91 t De osi 258 7974 i l 0.03 1 t) 1 .93 59 8006 a 0.03 12 ~' .9 SI' b cklin 0 8037 t~ 0.03 13 ~ 2.94 261 8068 t ~ 0.04 14 .9 262 810 U 0.03 1.3 2.93 263 8130 U 0.03 1 3 .91 Sli h bu kti Lt. De o i 264 8162 t) 0.03 11 2.91 I_t. De os'ts. 65 8194 a 0.03 11 ~' 2.94 66 8 3 a 0.03 11 I 3 267 8255 t~ .03 1 I s .9 li u kl' 268 8286 a 0.03 11 2.92 69 318 t) 0.0 ~~ 1 91 270 8349 l1 0.03 11 2 2.91 Lt. De osits. 1 li Il) I 272 8410 tl 0.03 1 1 _' 2.93 Sli ht bucklin . 2 73 8442 t 1 0 03 13 3 .94 274 8473 U 0.03 11 ' 2.94 27 850 t~ 0.0 13 2 .91 i 276 8536 (~ 0.03 10 1 2.90 Lt. D sits. 277 8568 (1 0.04 16 1 .89 Sli t b cklin . t s'ts 278 8600 tl 0.01 4 1 2.91 Lt. D osits. 279 8629 n 0.03 1 ~ 2 3 280 8661 U 0.03 11 Z 2.94 81 86 4 O 0.03 11 2 2.94 Sli ht b cklin . 282 8724 a 0.02 7 I 2.92 Lt. De osits. 282.1 753 t~ 0 1 ~ u .9 P P 282.2 8758 U 0 tl t~ N A GLM 1 Latch ~ 11:00 3 8764 n 0 02 ~) ~ .00 P P 283 8768 a 0.03 1 U 2 2.91 Sli ht bucklin . Lt. De osits. 83.1 8799 u 0 2 ~3 _' .98 PUP 283.2 8804 U 0 U t ~ 3.00 Brown PBR 83.3 8809 U O n 3. 0 row 'HB' Pac er 284 8821 t) 0.03 12 s .94 Lt. De osi ts. 84.1 8 1 U U t) N A a ch 4: 0 285 8858 l) 0.03 I t 4 2.96 Sli ht buckli 285.1 8890 t~ 0.01 i U .89 PUP Lt. De sits. 285.2 8901 t~ 0 U u 2.8 PUP Lt. De sits. 285 3 8921 u.t>> 0.00 1 t) 2.78 Lt. e os ts. 285.4 8941 t! 0 (1 tl 2.89 PUP Lt. De sits. _ Penetration Body Metal Loss Body Page 6 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.2 ppf )-55 BTC-AB-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1 A-11 Kuparuk ConocoPhillips Alaska, Inc. USA April 14, 2009 Joint No. Jt. Depth (Ft.) I'c~n. Uln~~t (Ins.) Pen. Body (Ins.) Pen. % 1~tc~t.il Loss "4> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 8 5 6 U 0.04 14 .9 P P 285.6 8972 u U u 2.13 VA BPL Ported Ni le. a sits. 285.7 8975 t~.t~4 004 15 -t 1 UP tD si . 28 .8 89 5 t~ 0 t) 400 wn' ' Pac er 8 .9 8995 u 0 U U .5" x 2.875" X-0ver _ Penetration Body Metal Loss Body Page 7 PDS Report Cross Sections ~~ -~ „ Well: 1A-11 Survey Date: April 14, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 __Tubing:_ ___ _ 3.5 ins 9.2 ppf J-55 BTC-AB-MOD Analyst: C. Waldrop Cross Section for Joint 116 at depth 3614.483 ft Tool speed = 43 Nominal ID = 2.942 Nominal OD = 3.500 Remaining wall area = 97 Tool deviation = 56 ° Finger 10 Penetration = 0.119 ins Isolated pitting 0.12 ins = 47°,b Wall Penetration HIGH SIDE = UP i • Cross Sections page 1 wr ~r r r r r rr rr r~ r rr rr rr rr rr rr rr r r ~c~ PDS Report Cross Sections ~N Well: to-11 Survey Date: April 14, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers; 24 Tubing: 3.5 ins 9.2 ppf J-55 BTC-AB-MOD Analyst; C. Waldrop Cross Section for Joint 82 at depth 2562.933 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 96 Tool deviation = 51 ° Finger 8 Penetration = 0.116 ins Isolated pitting 0.12 ins = 46% Wall Penetration HIGH SIDE = UP • • Cross Sections page 2 PDS Report Cross Sections Well: 1A-11 Survey Date: April 14, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: Z4 Tubing: 3.5 ins 9.2 ppf )-55 BTC-A&MOD Analyst: C. Waldrop Cross Section for Joint 67 at depth 2093.053 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 °~ Tool deviation = 50 ° Finger 23 Projection =-0.568 ins Deposits Minimum I.D. = 1.94 ins HIGH SIDE = UP ~ ~ ~ ~ ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ! ~ • • Cross Sections page 3 ~ i ~ ~ r r ~ ~ ~ ~ ~ ~ ~ ^~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~-~ - -~ . 4 Well: 1A-11 Survey Date: April 14, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA ~'~'o. of Fingers: 24 Tubin 3,5 ins 9.2 f -55 BTC-AB-MOD __ _ .Analyst: C. Waldrop Cross Section for Joint 66 at depth 2088.413 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 Tool deviation = 51 ° Finger 17 Projection =-0.581 ins Deposits Minimum I.D. = 2.01 ins HIGH SIDE = UP i Cross Sections page 4 ~. F5{ ~, r' ~ F~ _ ~ ,~•,~~~' ~~~' °~~ ~- ~' ~~~~'`~ N0.5138 Schlumberger -DCS `" ~ i 2525 Gambell Street, Suite 400 ~ ~ Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~ ~ Attn: Christine Mahnken ATTN: Beth I ~~ ~ ` 333 West 7th Ave, Suite 100 ~~ ~ ~~ !~•„~~~. Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 03/18/09 2A-26 604C-00011 OH EDIT (PEX,SSCANNER & CHFR) -(~qc/ f ~C/ 02/14/09 6 1 1 E-170 1A-11 ANHY-00057 ANHY-00058 PRODUCTION PROFILE a LDL Cr 03/06/09 03/08/09 1 1 1 1 3G-04 ANHY-00060 PRODUCTION PROFILE Q_ 03/10/09 1 1 3B-15 ANHY-00061 INJECTION PROFILE ;,} - "b 03/11/09 1 1 1 R-10 ANHY-00063 INJECTION PROFILE ~ 03/13/09 1 1 2M-16 ANHY-00064 INJECTION PROFILE ~ / 03/14/09 1 1 2G-15 ANHY-00065 PRODUCTION PROFILE 1'~Gf_ ~ 03/f5/09 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. 1A-11 (PTD# 181-173) Report Of TxIA Communication Page 1 of 1 • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] ~ ~ Ic~'~~~ ~ Z (~ol~~t, Sent: Sunday, February 08, 2009 11:15 AM ~~ "~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF1 Prod Engr; CPF1 DS Lead Techs; Kovar, Mark Subject: 1A-11 (PTD# 181-173) Report Of TxIA Communication Attachments: 1A-11 TIO Plot.ppt; 1A-11 Wellbore Schematic.pdf Jim/Tom, Kuparuk WAG injector 1A-11 (PTD# 181-173) is suspected of having TxIA communication based upon recent frequent bleeds and a failed inner annulus drawdown test. The well has a current T/IA/OA/OOA of -~ 2186/2750/950/0 and will be added to the Monthly Failed MIT report. ConocoPhillips intends to inject in the well as necessary to conduct additional diagnostics and will submit a 10-403 to repair or seek administrative approval to continue injection. Attached is a 90 day TIO plot and a Wellbore schematic. «1A-11 TIO Plot.ppt» «1A-11 Wellbore Schematic.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~_ _ -7 w ~~55 ~ Ztp~f F µ~-(P - 4~~~•: v z~~Pst ~~ 55 ~~ 6s % 7zz~j Lti~ii>, ~~ ~ ~~ s ~~-~ . C~&u~ ~ ~ c~ ~ ~ ~ ~~ ~ ~ ~5 I Zi9i2oo9 ~s?,cs w~ ll ~~k~~~ +~l~L ~~~ ~~p~- ~u~~ s . N y o~ ~_ N ~ v dwal~a~oy~ o ~ °o ° N ~- r- `n r a 0 o. O H 0 a~ 0 rn 0 0 ~. 0 ao 0 a~ 0 a. ~o ~~ w Y O N UQ ~ o ~ °o N N r r- ISd .. - Conty~t~('hillips ~` i / o ~f~ _- - - 'E_ k CONDUCTOR, I - Bo ~ ~ I ~, SAFETY VLV, ~ p ,905 I SURFACE, I 2,947 GAS LIFT, ~ ...'' 8,758 y: 1 _ --. PBR, 8,803 '. -# t f PACKER, 8,815 , l__ _.___.-.__ _J c- +. INJECTION, 8,651 IPERF, 8,878-8,916 IPERF, 8.930-8.938 NIPPLE, 8,972 SLEEVE-C, 8,972 PACKER.8985 NIPPLE.9007 505, 9,018 TTL, 9,019 IPERF, 9,062-9,095 G ' ~_' {i E • IPERF, 9,108-9,150 ' FISH, 9,224 FISH, 9,346 ~ ~ ~ ODUCTION, 9,713 TD, 9,732 KUP r~ 1 A-11 Wf 11 Attributes 'Max Angle & MD TD _ Wadbore APIIUWI Field Neme a. Well Stat Pro - d/Inj ype Inct ( -( MD (kKB) _ Act Btm (kKB) 500292068500 KUPARUK RIVER UNIT INJ PWI 57.00 7,900.00 9,732.0 Comment H25 (ppm) Date Annotation End Date KB-Grd (ft) Rig Releasa Date SSSV. TRDP 0 7/1/2008 Last WO: 10/15/1985 39.01 12/22/1981 Annotation Depth (kKB) En d Dale Annotation End Date Last Tag: SLM 9,130.0 2/1/2009 Rev Reason: TAG 2/2/2009 Casing Strings ~ St ng OD Shing ID Sel Depth Set Depth (ND) String Wt String Casing Description (in) (in) Top (kKB) (ftKB) (ft KBj (Ibs/k) Oratle String Top Thrd CONDUCTOR 16 15.060 0.0 80.0 80.0 65.00 H-00 SURFACE 103/4 9.794 0.0 2,947.0 2,425.2 45.50 K-55 PRODUCTION 7 6.151 0.0 9,713.0 6,690.1 26.00 K-55 Tubing Strin s __ Stnng OD String ID Set Depth Set Depth (TVD) String Wt String Tubing Description (in} (in) Top (kKB) (kKB) (kKB) (IbsRt) Grade String Top Thrd TUBING 31/2 2.992 0.0 8,996.0 6,184.0 9.20 J-55 BTC-AB-MOD TUBING 27/8 2.441 8,996.0 9,019.0 6,197.6 6.50 J-55 EUE 8RD dole (All Jev p Depth (ND) Top Intl (ftKB) (°( ~, Fish,_et~_ Comment ~ Run Date I ID Perforations snot Top (ND) Btm (ND) Dens Top (ftKB) Btm (ftKB) IftKB) (ftKB) Zone Date (sh... Type Comment 8,878.0 8,918.0 6,104.0 6,133.0 C-4, C-3, C-2, 12/21/1981 4.0 IPERF 4" Vann Guns, 120 deg Ph C-1, 1A-11 Vann MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim ReggV\ ¿ 'á 7/7;,/ P.I. Supervisor I "/rt :;;¡v D 7 DATE: Friday, July 20, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lA-II KUPARUK RIV UNIT lA-I! \<6\,\1~ FROM: Bob Noble Petroleum Inspector Src: Inspector Reviewed By: 'j7':? _ P.I. Suprv \. '.:>- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IA-I I API Well Number: 50-029-20685-00-00 Inspector Name: Bob Noble Insp Num: mitRCN070719 I 30625 Permit Number: 181-173-0 Inspection Date: 7/15/2007 ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. IA-lI I i /Í 2830! Well i ¡l)'pe !nj. i w TVD 6062 IA 1300 2860 2840 I 2860 /i --J.----- -- P.T.Di 1811730 :TypeTest i SPT Test psi i OA 390 400 400 400 I ~-~ I I i Interval 4YRTST P/F P ../ Tubing 2200 2250 2250 2250 - I Notes: 5CANNED AUG 0 6 2007 Friday, July 20, 2007 Page 1 of 1 . . Mike Mooney Wells Group Team Leader Drilling & Wells Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 August 4, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED AUG 1 6 2006 Alaska Oil & Gas Cons. Comrnissíon AnchoraQe Subject: Report of Sundry Well Operations for 1A-11 (APD # 181-173) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk weIl1A-11. .' If you have any questions regarding this matter, please contact me at 263-4574. ,'" (', \.j U') Sincerely, ~ .f;;- M~tfA££... M.cc.-,JE-,-/ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad . . K I:: t.; I:: I V I:: LJ AUG 1 6 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Cemmission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 'Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Opera!. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 181-1731 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20685-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' 1A-11 8. Property Designation: 10. Field/Pool(s): ADL 25647, ALK 465 Kuparuk River Field 1 Kuparuk Oil Pool . 11. Present Well Condition Summary: Total Depth measured 9732' feet . Plugs (measured) true vertical 6703' feet Effective Depth measured 9163' feet Junk (measured) 9224' & 9346' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURF CASING 2847' 10-3/4" 2947' 2425' PROD CASING 9613' 7" 9713' 6690' Perforation depth: Measured depth: 8878'-8918',8930'-8938',9082'-9095',9108'-9150' true vertical depth: 6104'-6131',6139'-6145',6245'-6254',6263'-6293' Tubing (size, grade, and measured depth) 3.5" 12-7/8", J-55, 8996' 19019' MD. Packers & SSSV (type & measured depth) pkr= BROWN 'HB'; BROWN '2B' pkr= 8815'; 8985' Cameo TRDP-1A-ENC SSSV= 1905' 12. Stimulation or cement squeeze summary; Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 650 bbls slick seawater 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation na na 175 -- Subsequent to operation na na 600 . -- 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJ0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Group Engineer ~ Signature "Zi? ~ Phone ~ .-.. ~:~:red ~h!';:L~~ke 263-4612 Form 10-404 Revised 04/2004 0 R , GIN A L RBDMS BFl AUG 1 8 2'~h" ",ib-l'¡' .c>, SUb~i¡r;~CT . Co¡nocoPhillips Alaska, Inc_ . KRU 1A-11 1A-11 API: 500292068500 Well Type: INJ Angle @ TS: 48 deç¡ @ 8878 SSSV Type: TRDP Orig 12/22/1981 Angle @ TD: 46 deg @ 9732 sssv Completion: (1905-1906, Annular Fluid: Last W/O: 10/15/1985 Rev Reason: DRIFT & TAG 00:3.500) Reference Loo: Ref Loa Date: Last Update: 12/31/2005 Last Tag: 9163 TD: 9732 ftKB Last Tao Date: 12/29/2005 Max Hole Anole: 57 deo (â) 7900 Casino Strino - ALL STRINGS Gas Lift Description Size Top Bottom TVD Wt Grade Thread MandrelNalve 1 SURF CASING 10.750 0 2947 2425 45.50 K-55 (8758~759, PROD CASING 7.000 0 9713 6690 26.00 K-55 CONDUCTOR 16.000 0 80 80 65.00 H-40 Tubino Strina - TUBING PBR C Size I Top 1 Bottom 1 TVD 1 Wt 1 Grade Thread (8803~804, 3.500 1 0 I 8996 I 6184 I 9.20 I J-55 BTC-AB-MOD 00:3,500) 2.875 1 8996 1 9019 1 6200 1 6.50 1 J-55 EUE 8RD Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment 8878 - 8918 6104 - 6131 4,C-3,C-2,C 40 4 12/21/1981 IPERF 4" Vann Guns, 120 deo Ph PKR 8930 - 8938 6139 - 6145 UNITB 8 4 12/21/1981 IPERF 4" Vann Guns, 120 deg Ph (8815~816, 9082 - 9095 6245 - 6254 A-5 13 4 12/21/1981 IPERF 4" Vann Guns, 120 deo Ph 00:6.156) 9108 - 9150 6263 - 6293 A-4 42 4 12/21/1981 IPERF 4" Vann Guns, 120 deg Ph Gas lift MandrelslValves St I MD I TVD I Man Man Type V Mfr I V Type I V OD I Latch I Port I TRO I Date Vlv Injection .. Mfr Run Cmnt ,"drel/Oummy 1 1 87581 60251 Otis 1 LBX I I 1.5 1 T-2 10.000 1 0 I 7/611990 (1 ) Valve 2 1. PackOff Valve (8851~852, Injection MandrelslValves 00:5.313) - - St I MD I TVD I Man Man Type V Mfr I V Type I V OD I Latch I Port I TRO I Date Vlv Perf Mfr Run Cmnt (8878~918) - - - - 2 I 88511 60861 Camco 1 KBUG MMH 1 DMY 1 1.0 1 BK I 0.000 1 0 16/27/1989 Closed = = Other :pluos, equip., etc.) - JEWELRY Perf DeDth TVD TVDe Description ID (8930~938) - - 1905 1752 SSSV Camco TRDP-1 A-ENC 2.813 - - 8803 6054 PBR Brown 3.000 - - 8815 6062 PKR Brown 'HB' 3.000 8972 6168 NIP AVA BPL PORTED NIP 2.750 SLEEVE-C 8972 6168 SLEEVE-C AVA BPI SET 8/7/2003 2.313 (8972~973, 002. 750) 8985 6177 PKR Brown '2B' 4.000 9007 6192 NIP Cameo'D' Nipple NO GO 2.250 9018 6200 SOS Brown 2.441 9019 6200 TTL 2.441 PKR Fish - FISH (8985~986, DeDth I DescriDtion I Comment 00:6.156) 9224 I E-Line Tool 118.5' lono 9346 IVANN GUN 1278' long NIP (9007 -9008, 00:2.875) SOS (9018-9019, J 00:2.875) TUBING (8996-9019, 00:2.875, 10:2.441 ) Perf - f-- (9082-9095) - ¡.--- - ¡.--- = ~ Perf (9108-9150) - ¡.--- - f-- - ¡.--- E-Line Tool ~ (9224-9225, 00:2.000) VANN GUN ~ (9346-9347, 002.000) . 1A-11 Well Events Summary . DATE Summary 07/13/0607:00 AM PUMP A TOTAL OF 650 BBlS OF SLICK SEAWATER DOWN TUBING FOR HIGH PRESSURE BREAKDOWN. PUMP RATE = 10.3 BPM @ 4000 PSI. BRING WEll BACK ON INJECTION FOllOWING TREATMENT. ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test 1~ \qr' Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 1A-11 07/04/05 Arend 1 Rogers AES Packer Depth Pretest Initial 15 Min. Well 1A-11 Type Inj. S TVD 6,062' Tubing 2550 2550 2550 P.T.D.1811730 Type test P Test psi 1516 Casing 1370 3075 3050 Notes: Diagnostic MIT to support potential waiver prep for minor IA x OA communication Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Test Details: SCANNED "JUl () &,7 20U5 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 MIT Report Form Revi~ed: 06/19/02 MIT KRU 1A-11 07-04-05.xls 30 Min. 2550 Interval 0 3050 P/F P Interval P/F Interval P/F Interval P/F Interval P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) ~ ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg K¿i', &(1 (tY'l P.I. Supervisor 1 { DATE: Wednesday, June 02, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lA-II FROM: Chuck Scheve Petroleum Inspector KUPARUK RIV UNIT IA-JI ¡r:¿j ~ f"73 Src: Inspector Reviewed By: ,..',,> P.I. Suprv '--.J<Y'-. Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IA-I I API Well Numbe Permit Number 50-029-20685-00-00 Inspector Name: 181 1730 Inspection Date: Chuck Scheve 5/30/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: I lA-II IType Inj.! G I TVD 6703 I IA 2150 3000 2950 2950 P.T. 1811730 TypeTest SPT Test psi 1515.5 OA 475 550 550 550 Interval 4YRTST P/F P Tubing 3400 3400 3400 3400 Notes: The pretest pressures were observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday, June 02, 2004 Page I of I To: Well Name I',og Type Run Date Kuparuk iiiver i~nii iF',-iA Kupamk River Unit lA..-11 Kuparuk River [Jnit 11= 10 Kuparuk River Unit 11,..14 Kuparuk River Unit IL...17 Kupa~uk River U,it 1L..22 Kupamk River Unit IR 04 Kuparuk River U'nit 1Y'-I0 Kuparuk Kuparuk Kuparuk Kuparuk Kupa~uk Kuparuk Kuparuk Kuparuk Kuvaruk Kuparuk Kuparuk Kuparuk R;=ceived by:, __. Dated: Copy sent to ,,;ender: Yes ,//' River Unit 1¥'-12 River Unit 1¥..-15 River Unit 2H..08 I~ver Unit 2C...02 Rive, Unit 2C--04 niver Unit 2c 05 River Unit 2C-06 River Unit 2V-I~ Riw~r Unit 3G.-12 River Unit 3H.,-02 River Unit 3G-20 Water lqow I.og (TiYI'-P) Injection Profile Injection Profile Injection Profile Injection Profile Injection P~'ofile Injection Profile Injection Profile lnjtx:tion Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection P~ofile Survey Injection Profile Survey Injection Profile Production l'.og Production I..og Injection Profile Injection Profile Survey Injeclion Profile No 07.IAN 1991 10-1-91 03 NOVEMBER1991 4 NOVEMBER 1991 4 NOVEMBER 1991 11-06.--1991 6/30/91 12-13..---1991 I I-i9.-9i 11-,17.-1991 12..2,-91 12-27-1991 26 DEC 1991 10-27.,-1991 11/25/9 l 11-16-1991 R-.IIJNE-1991 31-JU'LY-1991 11 NOV 1991 I 0/119191 11-29-1991 RECEIVED MAR Z (5 1992 Alaska 011 & Gas Cons. Commission Anchorage ( ARCO Alaska, In ~,~ Post Office ,.,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 22, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Ancho.rage, Alaska 99501 Dear Mr. Chatterton' Attached in duplicate are multiple Report of Sundry Well Operations notices in the Kuparuk field. The wells are liSted below. Well Action 2G-13 2G-15 2G-08 3H-04 1A,11 1A-16a 1A-04 1F-08 1F-15 Refracture Refracture Refracture Acidize Tbg. Leak Packer Leak Acidize WAG Conversion WAG Conversion If you have any questions, please call me at 265-6840. Sincerely, Senior Operations Engineer GBS:Rjr cc: J. Gruber J. R. Brandstetter L. L. Perini KOE1.4-9 ATO 1478 ATO 1120 ATO 1130 w/o attachments RECEIVED 1989 Alaska Oil & Gas Cons. i;ommissior; Anchora[le ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany OIL AND ~AS CONSERVATION 0 R REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Perforate _ Repair well Pull tubing Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic Service X 4. Location of well at surface 809' FSL, 490' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1626' FSL, 1197' FEL, Sec. 8, T11N, R10E, UM At effective depth 1031' FSL, 855' FEL, Sec. 8, T11N, R10E, UM At total depth 901' FSL, 735' FEL, Sec. 8, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 9732' 6703' feet Plugs (measured) feet 6. Datum elevation (DF or KB) 90' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1A-11 9. Permit number/approval number 81 -1 73/9-597 10. APl number 5o-029-20§~5 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 91 70' true vertical 6250' feet Junk (measured) feet Casing Length Size Structural 80' 1 6" Conductor 2 94 6' 1 0 Surface Intermediate Production 9 71 3' 7" Liner 3/4" Cemented Measured depth 200 Sx AS I 80' 1160 Sx AS II 2946' 1450 Sx Class G & 9 71 3' 205 Artic Pak True vertical depth 80' 2400' 6695' Perforation depth: measured 8878'-8918', 6105'-6130', Tubing (size, grade, and measured depth) 3 1/2" J-55, 9019' Packers and SSSV (type and measured depth) BOT HB @ 8797'MD, Brown 2B @ 8967'MD, TRDP-1AENC @ 1905'MD 13. Stimulation or cement squeeze summary 8930'-8938', 9082'-9095' , 9108'-9150' 6139'-6144', 6243'-6255', 6262'-6295' RECEWEO Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Average Production or In!ection Date OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations. X 16. Status of well classification as: Water Injector X Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 'Form 1D-404~ev 05/17/89 '/~ Date c~ _ ,~ ~...~.,{ ? SUBMIT IN DUPLICATE W Z S I BPR 2ASI 3BPR 4 BPR 5 BPR 6 APR 8BPR lO B PR TOTALS E T LN A LET 7 BSW SW 13 PW 14 15 ~ SW 16 A PW TOTALS: pAGE 1 KDGS HORNING WELL REPORT FOR 08/14/89 DRILLS]TE lA ( . GAS LIFT STATU~_ pRODUCTION WELL STATUS 7" 10" GAS INJ TP TT WC H2S CSO CSO TEMP METER RATE PSI CHK DEO % PPM PSI PSI DEO READING MSCF 130 176 98 91 1050 1300 700 86 0 25 1420 480 0 0 0 0 44 75 1190 980 90 32 830 960 84 140 176 120 140 176 40 5 130~ 600 86 250 176 130 83 200 90 140 17~ 76 I 25 1260 750 190 176 114 31 ~0 ilO0 950 94 150 176 107 65 43 1230 850 80 2500 ___0 104 66 2500 ~ 0 108 209 480 4000 ~4 2509 2500 92 66 2630 50o 1950 140 3o 200 2500 1m6~ t5~ 8 750 2500 2445 9~ 176 0 000 s950 t08 209 0 2500 2460 156 i76 80 INJECTION WELL STATUS 7" 10" ALLOW ACT CSG GSO INJ INJ TT PSI PSI DEG CHK PSI PSI .......... 90 70 50 240 170 150 0 360 ..... SWI: 12007 + PWI: 13434 = 25441 3.040 S/I IMPACT C HM 0 R I DE EPL S N BBLS 3892 9~8 0000 0 0 0 0 2400 63 160 0 0 5393 706 0000 4793 275 0000 0 0 3692 477 0000 0 0 1110 0000 0 0 4593 0 7593~ ~95 0000 0 7293 1 ~25 0000 0 0 ..... 160 6316 INdECTION RATE S/I INd INd H M 0 METER RATE RATE R I g READING BPD MMSCFD $ N E ........ o.ooo oooo o 839792~ 0 1 · 549 0000 0 000 0000 0 3316205 2292 O. 46~5091_ 6001 O. 000 0000 0 76;z8887 4141 O, 000 0000 0 4783 0. 000 0000 0 377945~ 0 1 · 49 $ 0000 0 2456062 3292 O· 000 0000 0 RECEIVED 1. Type of Request: STATE OF ALASKA ~' ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS, Operation Shutdown .......... Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory _ Stratigraphic Service X 4. Location of well at surface 809' FSL, 490' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1626' FSL, 1197' FEL, Sec. 8, T11N, R10E, UM At effective depth 1031' FSL, 855' FEL, Sec. 8, T11N, R10E, UM At total depth 901' FSL, 735' FEL, Sec. 8, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 9732' true vertical 6703' feet feet Plugs (measured) 6. Datum elevation (DF or KB) 90' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1A-11 ) /v Te_~ c r-~ r,- 9. Permit number/approval number 81-173/9-3~)~ 10. APl number 50-029-20685 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 91 70' feet true vertical 6250' feet Junk (measured) Casing Length Size Structural 80' 1 6" Conductor 2 94 6' 10 Surface Intermediate Production 9 71 3' 7" Liner P'erfo~at'ion depth" measured ''' 8878'-8918', true vertical 6105'-6130', Tubing (size, grade, and measured depth) 3 1/2" J-55, 9019' 3/4" Cemented Measured depth 200 Sx AS I 80' 1160 Sx AS II 2946' True vertical depth 80' 2400' 1450 Sx Class G & 9 71 3' 205 Artic Pak 8930'-8938', 9082'-9095' , 9108'-9150' 6139'-6144', 6243'-6255', 6262'-6295' 6695' Packers and SSSV (type and measured depth) DOT HB @ 8797'MD~ Brown 2B @ 8967'MD, TRDP-1AENC @ 1905'MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED 3UL2 o 19 9 Alaska 0il & 0as Cons, Commission Anchorage Representative Daily Averaae Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A .Subse,clu, ent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector ~ Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form ~ 0-~.04- ~v' 0~/1-7~9 SUBMIT IN DUPLICATE ARCO A!,ac.S.~,~. Ir~" ~ Subsidiary of Atla t ' d CompS., WELL SERVICE REPOR'I' REMARKS OPERATION AT REPORT , DATE I'--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK DESCRIPTION DAILY ACCU M. TOTAL CAMCO OTIS ' ,,~'z/_~p,..~, ~ SCHLUMBERGER DRESSER.ATLAS DOWELL ,. · HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES ........ Roustabouts Diesel Methanol Supervision .: .... Pre-Job Safety Meeting AFL TOTAL FIELD ESTIMATE - II SignoO.~,~.~~__~~__~ -"~- ARCO Alaska, Inc(O ~ .< o~. (" WELL SERVICE REPORT Subsidiary of Atlantic Richfield Company'- I-"1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. I Chill Factor Visibility I Wind Vel. Report °FI °F miles 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ ALASKA OIL AND GAS CONSERVATION COMMISSION 0 APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 809' FSL, 490' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1626' FSL, 1197' FEL, Sec. 8, T11N, R10E, UM At effective depth 1031' FSL, 855' FEL, Sec.8, T11N, R10E, UM At total depth 901' FSL, 735' FEL~ Sec. 8, T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 9 7 3 2' true vertical 6 7 0 3' Effective depth: measured 91 7 0' true vertical 6250' feet Plugs (measured) feet None feet Junk (measured) feet None Casing Length Size Structural Conductor 8 0' 1 6" Surface 2946' 10 3/4" Intermediate Production 9 71 3' 7" Liner Perforation depth: measured 8878-8918, true vertical 6105-6130, 6. Datum elevation (DF or KB) RKB 90 7. Unit or Property name Kuparuk River Unit feet 8. Well number 9. Permit number 81-173 10. APl number 50-029-20685 11. Field/Pool Kuparuk River Field Kup, aru,kd;J~ve~ ~t~ Pqol :,JUL ! 2 Measure~Ee~'' '~rue ve~ical depth Cemented 250 Sx AS I 8 0' 8 0' 1160 Sx AS II 2946' 2400' 1450 Sx Class G 971 3' 6695' & 205 Artic Pak 8930-8938, 9082-9095, 9108-9150' MD 6139-6144, 6243-6255, 6262-6295' TVD BOP sketch Tubing (size, grade, and measured depth 3 1/2" J-55 set at 9019' Packers and SSSV (type and measured depth) .. B0'I' HB @ 8797', Brown 2B @ 8967'; Camco TRDP-1AENC @ 1905' i3. Attachments Description summary of proposal _ Detailed operation program X Continue injection 14. Estimated date for commencing operation July. 1989 16. If proposal was verbally approved Date approved 15. Status of well classification as: Oil m Gas __ Suspended Service Water Injector Name of approver 17. I hereby certify that the foregoing is true and correct tome best of my knowledge. FOR COMMISSIO~ USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form require 10- ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner IlAppr°va' NO. ~,~ Approved Copy Returned SUBMIT IN TRIPLICATE Approved by the order Of the Commission Form 10-403 Rev 5/03/89 1A-Il Wotcr Injector Sundry Notice to Continue Injection Reuuest Approval to continue injection on Well lA-11. Slight communication from the tubing to production casing has been noted, yet is not enough to cause the well to fail an AOGCC witnessed MIT nor to subject the production casing to a pressure that exceeds the hoop stress regulation set forth in Rule 4 of AOGCC Area Injection Order No. 2. The present condition of the well is operationally safe and poses no threat to the integrity of the production casing. The communication will be monitored closely to note any changes in its present condition. Backeround _ This water injector was noted to have slight communication from the tubing to production casing. The production casing would be bled below 2000 psi (tubing=2550 psi), only to have the pressure increase back to 2500+ psi over the course of 5 days. Continued bleeding of the production casing was halted in fear of drawing water up into the permafrost region of the production casing. Sea_lien,ceof Events 3/3/8 8: Choked C Sand to lower pressure on packer. Did not lower annulus pressure. 4/6/88: Repacked dummy valve in GLM gl. Appeared to correct problem. 8/1/88: Passed an AOGCC witnessed MIT. Report attached. 10/1/88: Annulus pressured to above 2000 psi. Attempts to bleed down failed. 1 1 / 13/8 8: Repacked dummy valve in GLM #1. Initially appeared to correct problem, then resurfaced. 2/18/89: Repacked dummy valve in GLM gl. Did not help. 3 / 1 3/8 9: Wellhead failed test. Pumped sealant into primary seal. Tested good. 6/08/89: E-line leak detection log showed no results. 6/27/89: Dummied C Sand to lower pressure on C Sand side of upper packer. Annulus pressure continued. Conclusion: Attachments: Source of communication is from the tubing to the 7" casing. Probable cause is the SBR. 1) 2) 3) Morning Report Summary AOGCC MIT of 8/1/88 lA-11 Well Schematic MORNING REPORT SUMMARY 40 11:37 FRIDAY, JUNE 16, 1989 1A-il 18MAR86 INJECTING ABOUT 1200 BWPD @ 2000#. 19MAR86 INJECTING 2740 BWPD @ 2000#. 14APR86 SRT COMPLETE: NO BREAKDOWN BEFORE MAX INJ P=2210 PSI (1900 BWPD) 13SEP86 FL IN TBG @ SURFACE. WHP= 1198# HAD PUMPED 20 BBL MEOH TO PICKLE. 04NOV86 SRT COMPLETE: NO FBD SEEN TO 2180# (1000 BWPD), LEFT MWHIP AT 2210#. 15JAN87 SPFO COMPLETED, DATA LATER. 18JAN87 A-SD SPFO COMPLETE DATA IN 'DEDKPO.SPFO.DATA(All18701)' PBA (SURF - 1439 PSI PBA (TOP PERF - 4236 PSI KH= 292 MD-FT IIACTUAL= 1.62 S= -4.95 IIIDEAL= .68 20JAN87- 14 OPEN C-SD FOR W~. 26JAN87 COMPLETED SRT, NO FBD, MWHIP= 2140 @ 5000 BWPD --- PMAX 31JAN87 A/C-SD SPFO COMPLETE (FROM 1-28-87) DATA IN ' DEDKPO. SPFO. DATA (Al 118701 ) ' PBAR (SURF)= 1105 PSI PBAR (MID PERF)= 3833 PSI KH= 973 MD-FT IIACTUAL = 3.65 S = -3.8 IIIDEAL = 1.86 IE= 196 % A/C-SD SPFO COMPLETE (FROM 1-28-87) DATA IN ' DEDKPO. SPFO.DATA(All18701) ' PBAR (SURF)= 1105 PSI PBAR (MID PERF)= 3833 PSI KH= 973 MD-FT IIACTUAL = 3.65 S = -3.8 IIIDEAL = 1.86 JIJL. 1 28JUL87 48 HR + SIBHP. WHP = 1000 PSI FL @ SURFACE. , TBG PICKLED W/ 71 BBL MEOH. 23AUG87 WHP = 795 PSI, FL @ SURF. O8JAN88 STEP RATE TEST COMPLETED. ANALYSIS LATER. O3MAR88 PULLED AVA CS RAN ISO, PULLED DV (8883') RAN 20/64 MHHFOV. TAGGED FILL AT 9226', BTM PERF 9150'. 06APR88 PULLED.DV @ 8740'. REDRESSED W/NEW PACKING & O-RINGS 17AUG88 13NOV88 & RERAN. CONVERTED TO PW. CHANGED OUT PACKING ON DV AT 8740' 1A-Il 18FEB89 13MAR89 08JUN89 MORNING REPORT SUMMARY 41 11:37 FRIDAY, JUNE 16, 1989 PULLED DV @ 8740' RKB. INSTALLED NEW PACKING AND RERAN VLV. CHECKED WELLHEAD. PRIMARY SEAL ON 11" CSG IS LEAKING. RAN E-LINE LEAK DETECTION, NO LEAK EVIDENT. RAN WIP, INJECTION SPLIT = 20% A SD / 80% C SD. I I ! I lc. santo l- I IPlUn'EST IT~ I T31~ I T~ { 1~ I I IP[RI I I I I*ISSS I PtnS I I t 15 I I ~Gf I I :S~Z~Z I I"~)'1) , I I ~ I ~ I l~f I Z I mi~UL~ lTV!) I UTI ITB~ ITEST I ~ I ~!s,.l Cq. I Cq:. ! I I 1 I ,. t /: I" Ii ! I t I,, .I I // 11/20/1~ O].Too:I. - i i i i _ i i u,.tzzz.~ M ......... Ot~ ' KUPARUK WELL 1A-11 APl #: SPUD DATE: ORIGINAL RKB: 500292068500 12202/81 ADL LEASE: 25647 PERMIT #: COMPLETION DATE: 12/22/81 WORKOVER DATE: SURFACE LOCATION: 809-FSL,490-FWL,SEC5,T11N,R10E TOP OF KUPARUK: 1431 -FSL, 1063-FEL,SEC8,T11N,R10E TD LOCATION: 901-FSL,735-FEL,SEC8,T11N,R10E N! deiXhs are MD-RKB to top of equipment unless otherwise noted 100 TUBING SPOOL: 26.05 CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 65# H-40 80 10.75' 45.5# K-55 2947 7' 26# K-55 9713 3.5' 9.2# J-55 ABMOD 9001 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV CAMCO TRDP-1AENC 2.812' 1887 SBR BOT PBR 3.0' 8785 PKR BOT HB 8797 AVA AVA 'BPL' NIPPLE 8954 PKR BROWN 2B 8967 NOGO CAMCO 'D' NIPPLE 2.25' 8988 SHROUT BROWN 9000 WELLTYPE: STN 1 2 PAD ELEVATION: 66 GAS LIFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 8740 OTIS LBX 1.5' 8833 CAMCO KBUG 1.0' PERFORATION DATA INTERVAL ZONE FT 88788918 C 40 8930-8938 ~ 8 9082-9095 ,~1 13 9108-9150 ,~ 42 SPF PHASE 81-173 PORT SIZE COMMENTS MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: HOLE ANGLE THRU KUP: LAST TAG DATE: RATHOLE: FISH/OBSTRUCTION: PBTD: PBTDSS: DEPTH 9624 6528 REVISION DATE: 05/11/87 REASON: 1. Type of Request: Abandon _ 2. Name of Operator ALASKA OIL AND GAS CONSERVATION ~MISSION APPLICATION FOR SUNDRY APPROVALS Suspend _ Alter casing Repair well i_ :Plugging Change approved program _ Pull tubing _ Development Exploratory .Stratigraphic · 'Service Operation Shu{down _ Re-enter suspended well _ Time extension _ Stimulate _ Variance _ Perforate _ Other 6. Datum elevation (DF or KB) ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 809' FSL, 490' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1626' FSL, 1197' FEL, Sec. 8, T11N, R10E, UM At effective depth 1031' FSL, 855' FEL, $ec.8, T11N, R10E, UM At total depth 901' FSL 735' FEL~ Sec. 8~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 9 7 3 2' true vertical 6703' Effective depth: measured 91 7 0' true vertical 6 2 5 0' Casing Length Size Structural Conductor 8 0' I 6" Surface 2946' 10 3/4" Intermediate Production 9 71 3' 7" Liner Perforation depth: measured 8878-8918, true vertical 6105-6130, feet Plugs ~,(measured) feet [None feet Junk imeasured) feet ~, None Tubing (size, grade, and measured depth 3 1/2" J-55 set at 9019' RKB 90 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1A-11 ~c'~c~ 9. Permit number 81-173 10. APl number 50-029-20685 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemehted Measured depth 250 ~x AS I 8 0' 11601Sx AS II 2946' 1450!Sx Class G 971 3' & 205 Artic Pak 8930-8938, 9082+9095, 9108-9150' MD 6139-6144, 6243:6255, 6262-6295' TVD Packers and SSSV (type and measured depth) BOT HB Brown 2B @ 8967'; Camco TRDP-1AENC @ 1905' Attachments Description summary of proposal _ Detailed operation program Interim iniection during annular communication testing Estimated date for commencing operation 115~ Status of well classification as: ...May. 1989 ' 16. If proposal was verbally approved Name of approver Date approved ~ Service W~ter I n!ector 17. I hereby certify that the foregoing is true and correct to the best Of ;my knowledge. ~ ' - FOR COMMISSrON USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance__ Mechanical Integrity Test~ Subsequent form require 'ORIGINAL SIGNED BY LONNIE C. SMITH ,Approv, ed by the order of the Commission Form 10-403 Rev 5/03/89 True vertical depth 80' 2400' 6695' RECEIVE MAY 1 8 Alaska 0ii & Gas C0n~. Anchorage BOP sketch _ Suspended IApproval No. 10-~pl~.~oved Copy Ret~.rne(3 Commissioner Date SUBMIT IN ~HIPLICATE~ KUPARUK WELL 1A-11 APl #: 500292068500 SPUD DATE: 12/02/81 ADL LEASE: 25647 COMPLETION DATE: 12/22/81 PERMIT #: WORKOVER DATE: 81-173 ORIGINAL RKB: SURFACE LOCATION: 809-FSL,490-FWL,SEC5,T11 N, R10E TOP OF KUPARUK: 1431 -FSL,1063-FEL,SEC8,T11 N,R10E TD LOCATION: 901-FSL,735-FEL,SEC8,T11N,R10E All depths am MD-RKB to lop of equipment unless otherwise noted 100 TUBING SPOOL: 26.05 PAD ELEVATION: WELLTYPE: 66 CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16" 65# H-40 80 10.75" 45.5# K-55 2947 7" 26# K-55 9713 3.5' 9.2# J-55 ABMOD 9001 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV CAMCO TRDP-1AENC 2.812' 1887 SBR BOT PBR 3.0" 8785 PKR BOT HB 8797 AVA AVA 'BPL' NIPPLE 8954 PKR BROWN 2B 8967 NOGO CAMCO 'D' NIPPLE 2.25" 8988 SHROUT BROWN 9000 deg deg MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: HOLE ANGLE THRU KUP: LAST TAG DATE: RATHOLE: FISH/OBSTRUCTION: PBTD: PBTDSS: DEPTH 6528 L GAS LIFT and FLOW INFORMATION VALVE STN DEPTH MANDREL SIZE 1 8740 OTIS LBX 1.5" 2 8833 CAMCO KBUG 1.0" INTERVAL 8878-8918 8930-8938 9082-9095 9108-9150 PORT SIZE PERFORATION DATA ZONE 40 8 13 42 SPF PHASE COMMENTS REVISION DATE: 05/11/87 REASON: 1A-11 Sundry Notice Annular Communication This notice is to request approval to continue injection into water injection well IA-II. This well has tubing by 7" annulus communication and is undergoing tests to identify the source of communication. Well lA-11 passed an AOGCC wittnessed MIT on 8/1/88. The well developed annular communication problems 11/88. The dummy valve in the lone GLM has been pulled and repacked twice to no avail. The tree was found to have bad seals and sealant was pumped into to seal cavity. This eliminated the tree problem, yet failed to eliminate the source of annular communication. The 7" annular pressure on well IA-II builds to 2900 psi when the well is injecting water at a wellhead injection pressure of 2550 psi. Upon bleeding the pressure to below 2000 psi, the annular pressure builds back to 2900 psi within 1-2 days. The 2900 psi 7" annular pressure is well below the 4980 psi hoop stress rating of the casing (3400 psi at 70% hoop stress rating). The current testing program will attempt to confirm if the packer is the source of the annular problem. Further information will be provided as the testing program is performed. Mr. C.. V.' Chat/~'~': 'ton May 27, 1986~ Page 2 ATTACHMENT I. KUPARUK RIVER UNIT INJECTION LOGS o., ,~INITIAL INJECTION PROFILE~ Well Number Date of Initial Injection Date of Injection Profile lA-7 3/21/83 3/25/83 lA-9 3/1/83 3/22/83 3/7/83 3/21/83 1A-12 3/1/83 3/6/83. lA- 13 2/4/83 '10/17/83 lA- 14 2/22/83 4/11/83 1A-15 3/1/83 3/18/83 1A-16 3/1/83 3/24/83 Well Number Date of Initial Injection Date of Injection Profile 1E-lA 1E-4 ,- 1E-9 1E-13 IE-14 1E-16 1E-19 1E-21 '1E-23 1E-27 · · 1E-30 5/8/83 5/17/83 4/17/83 5/19/83 2/16/83 10/4/83 2/8/83 3/7/83 2/10/83 8/2/83 2/11/83 3/15/83 4/29/83 5/11/83 5/2/83 10/4/83 5/3/83 4/5/84 2/11/83 10/7/83 2/!4/83 10/7/83 Well 'Number Date of Initial Injection Date of Injection Profile 1F-lO 8/13/84 10/30/84 1F- 11 8/12/84 9 / 24/84 1F-13 8/16/84 9/25/84 1F- 15 8/16/84 9/26/84 ... .Well Number Date of Initial Injection Date of Injec. tion Profile ~ 1G-3 1G-6 1G-9 1G-i4 1G-16 10/25/85' 12/20/85 7/28/84 9/23/84 9/15/84 9/23/84 8/24/84 9/22/84 8/24/84 9/22/84 ATTACHMENT I I Drill Site IA Well No. 1A-4 1A-5 1A-7 1A-9 1A-12 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production Logs_ FEBRUARY 19, 1986 Log Date Drill Site Well No. Log Date 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 lB lB-1 12/26/81 lB-2 6/25/81 lB-3 11/16-18/81 3112/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84. Drill Site lC Well No. lC-1 1C-2 lC-3 lC-4 1C-5 1C-6 1C-7 1C-8' Lo9 Date 5/9/81. 5/8/81 7/t3/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date 10 10-1 ~ 1/80 5/23/83 10-3 8/5/80 10-4 7/30/80 8/13/80 10-5 6/11/81 10-6 6/9/81 10-7 6/8/81 ~=.,~10-8 {WS-8) 5/t0/78 Attachment I~ .... Page 2[ ~ Drill Site 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/2O/82 1H-8 7/22/82 Drill Site Well No. Lo9 Date lq ~1q~~12/1785: Drill Site Well No. Lo.q Date 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 iE-29 1E-30 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. Log Date 1G-1 1G-2 1G-3 1G-4 IG-5 1G-7 1G-8 Drill Site Well No. Log Date 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 3/12/83 1F 1F-1 1F-2 1F-3 1F-4 1F-5 1F-6 1F-7 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 !0/28/82 11/19/82 5/7/83 Attach.ment I~ ~ Page 3 Drill Site Well No. Log Date 1Y 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~~i1~))6/18/83 1Y-47/2/83 1Y-56/29/83 1Y-66/27/83 1Y-86/22/83 1Y-96/20/83 511o183 ~ 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2~28~85 2C-7 10/15/84 Drill Site 2Z' Well No Log Date ~ 7/10/83 2Z-2 ': 6~24~83 7/19/83 '2Z-3 ' 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF:pg-O052 Anchorage ARCO Alaska, Inc. ( Post Office ~vA I00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1A-11 Dear Mr. Chatterton. Enclosed is the Well Completion Report questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L110 Enclosure for 1A-11. If you have any ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ALASKA ', AND GAS CONSERVATION C MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE J~ 2. Name of Operator 7. Permit Number ARCO A]aska, I nc, 81-1 3. Address 8. APl Number P. 0. Box 100~60, Anchorage, AK 99510 50- 029-20685 4. Location of well at surface 9. Unit or Lease Name 809' FSL, 490' FWL, Sec.5, TllN, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1626' FSL, 1197' FEL, See.8, TllN, RIOE, UM 1A-Il At Total Depth 11. Field and Pool 901' FSL, 735' FEL, Sec.8, TllN~ RIO~ UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.)~ . Lease Designation and Serial No. Kuparuk River Oi 1 Pool 100' RKB ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~ 15. Water Depth, if offshore 16. No. of Completions 1 2/02/81 1 2/15/81 1 2/22/81'~ N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (M~D) 19;DirectionalSurvey ~ 20. Depth where SSSV set ~ 21. Thickness of Permafrost 9732'MD,6703'TVD 9624 'MD ,6628 'TVD YES ~ NO ~ 1905 feet MD 1700' (Approx~ 22. Type Electric or Other Logs Run D IL/FDC/CNL/GR/Cal, CBL/VDL, GR/CCL, RFT Tool 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65.0~ H-40 Surf 80' 24" 200 sx Permafrost 10-3/4" 45,5~ K-55 Surf 2946' 13-1/2' 1160 sx Fondu & 250 sx AS II 7" 26.0~ K-55 Surf 9713' 8-~/4" 1450 sx Class G & 205 sx Class G (Arctic Pa. 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) 8878' - 8918' 3-1/2" 9019' 8815' & 8985' 8930' - 8938' w/4 spf 9082' - 9095' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 9108' - 9150' DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production [ Method of Operation (Flowing, gas lift, etc.) 2/28/82I F1 owing Date of Test Hours Tested PRODUCTION FOR O[ LIBBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 1/9/82 17.9 TEST PER IOD ~ 430 233 -- 96/64" 634 Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 130 -- 24-HOUR RATE ~ 543 344 0 23.1 o 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE NOTE: Tubi..g w~ pulled d,,d well recump]et:ed i0/27/85. TENP3/WCS0 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. : ., . Top Kuparuk 8557' 5900' DEPTH PRESS BUILD-UP TINE Base Kuparuk 9223" 6345' 3113' 1093 psi I min. 44 sec. 3384' 1168 psi 24 sec. pressure 3714' 1252 psi 1 min. 22 'sec. test 3719' 1252 psi 2 min. 58 sec. . 3536' 1161 psi 16 min. 42 sec. fluid 4003' 1320 psi 3 min.,30 sec. test · 31. LIST OF ATTACHMENTS Well HistOry (workov~.r) . : 32. I hereby certify that the foregoing is true and correct to she best of my knowledge , .. Signed ~ 0)~/J( j.. ~~ Title Associate Engineer Date 2-i¢)'~L~ 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 i,n item 24 show the producing intervals for only the interval reported in i~em 27. Submit a separate form"~:for each additional interval to be separately produced, showing ;~he data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History- Initial Report- Daily mi Prepare and submit the "Initial Re~ll" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to sDudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. Air[ 603091 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover lO/19/85 thru 1o121185 10/22/85 10/23/85 10/24/85 10/25/85 Date and depth as of 8:00 a.m. Le~se or Unit ADL 25647 Title Recompletion State AP1 50-029-20685 ID~, 10/19/85 Complete record for each day reported 2130 hrs. IARCO W.I. Prior status if Alaska a W.O. 7" @ 9713' 9624', TOP @ 9346', POOH w/Completion String 9.2 Brine Move f/1R-13 to lA-11. RU Accept rig @ 2130 hfs, 10-19-85. RU cellar, take on brine, pull BPV, RU Camco* RIH & pull dummy vlv @ 8689' WLM. RD Camco, build wt to 9.2 brine. Press tst remote tk equip, tst surf equip. Kill well, spot Litesal pill + 28 bbls brine dn tbg, thru perfs f/8878'-9150'. ICP = 800 psi, well dead. 'Displ ann w/brine, circ & observe well; OK. PU lnd'g jr, PU & shear SBR, LD lnd'g Jt & hgt. CBU. POOH w/3-½" compl. Chg out couplings to AB Mod & std back tbg. 7" @ 9713' 9624' PBTD, TOP @ 9346', POOH w/FTA #1 9.2 ppg Brine Fin POOH w/3½" compl string. Chg out couplings to AB Mod & std back tbg in derrick; full reC'y. TIH w/PTA #1, PU 3½" DP, tag & rotate out SBRmandrel, POOH. 7" @ 9713' 9624' PBTD, TOP @ 9346' & 9080", POOH w/pkr 9.2 ppg Brine Fin POOH, LD SBRmandrI. circ, POOH w/pkr. RIH, tag 3H pkr @ 8760', mill pkr, 7" @ 9713' 9294' PBTD, POOH 9.2 ppg Brine Fin POOH w/pkr, LD pkr &FTA #2. PU FTA #3, RIH, tag top of fill @ 8946'. Wash & ream f/8946'-9294'. Circ, POOH. IWell no. lA-11 w/o 56.24% 7" @ 9713' 9294' PBTD, POOH w/BP 9.2 ppg Brine POH w/FTA #3. RIH w/BP, set @ 8800', POOH'. ND BOPE, instl 5000 psi tbg head. NU & tst BOPE to 3500 psi. RIH w/DP, engage BP, POOH. The above is correct Signature For f~rm preparation and diStributeDn,- see Procedures Manual, Se~ion 10, Drilling, Pages 86 and 87. lDate Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Field County or Parish Lease or Unit T fie North Slope Borough Accounting cost center code State Alaska IWell no. lA-11 w/o Kuparuk River ADL 25647 Auth. or W.O. no. Recomplet ion WWS 1 AP1 50-029-20685 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Workover 10/19/85 Iotal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our I Prior status if a W.O. 2130 hrs. I Date and depth as of 8:00 a.m. 10/26/85 thru 10128185 Complete record for each day reported 7" @ 9713' 9294' PBTD, RR Diesel in ann & tbg RIH'w/bit & scrpr to 9224', circ, POOH, LD DP. RU Schl, make gage ring/JB rn to 9225', POOH. RIH w/2B pkr, set @ 8967', POOH, RD Schl. Rn 285 its, 3½", 9.2#, J-55 BTC AB Mod tbg w/SSSV @ 1905', 'HB" pkr @ 8815' pkr @ 8985', "D" Nipple @ 9007', TT @ 9019'. Set top pkr @ 8814' (WLM). Shear PBR, lnd tbg. Set BPV. ND BOPE. NU & tst tree. Displ well to diesel. RR @ 0200 hrs, 10/27/85. Move rig to Prudhoe L3-5'. Old TD New TD Released rig Date 0200 hrs. Classifications (oil, gas, etc,) Oil I PB Depth 10/27/85 IKind of rig Type completion (single, dual, etc,) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 9294' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected _. The above is correct For form preparation and dis~bution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, JDate J Title Drilling Superintendent ATTACHMENT II KUPARUK RIVER UNIT Production .Logs Drill Site lA Wel 1 No. ~ 1A-4 ~1A-5 ""1A-7 ~lA-9 ~1A-11 '~1A-12 %1A-14 '~ 1A-15 ~',,1A-16A Log Date 7/6/83 10/29/83 2/8/82',,,, 5/7/82// 1/25/82--% .'~ / 3/23/83.. ,~ · 1/19/83-~-> 3/21/83 ,' 3/8/82 4/1/82 6/5/82 5/11/82-~ -~, ~ 6/8/82/} Drill Site Well No. Log Date 18 '""18-1 12/26/81 ~18-2 6/25/81 '"'18-3 11/16-18/81"--7' '" 3/12/82/~" '-18-6 11/18/81 ~. ,.-. 9/10/82/ ~ ._ ~18-7 11/23/81 '~18-8 12/28/81~, ~ 8~4~82 / ~ 6/24/82 .. ~18-9 '% 8/3/84 ~.. Drill Site 1C Wel 1 No. '"'"lC- 1 '"'-1C-2 "'1C-3 ',,~1C-4 ~~1C-5 .._ '"'~1C-6 '"'~1C-7 '",. 1C-8 Log l Date 5/9/81 5/8/81 7/13/81 1~./8/8r,~ 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 J Drill Site Well No. Log Date 1D "%1D-1 1/80~-> ~' 5/23/83 /' r'~' '""1D-3 8/5/80 1D-4 ~7/30/80'"~ ,-, ~ 8/13/80/ ~ ~1D-5 6/11/81 ~1D-6 6/9/81 ~1D-7 6/8/81 ~'J1D-8 (WS-8) 5/10/78 RECEIVED FEB 2 1 1986 Alm~km 011 & Gas Con~ Oemmi~lon Anchorage (" STATE Of ALASKA C)(,M ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-173 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20685 4. Location of Well Surface: 809' FSL, 490' FWL, Sec.5, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 100' RKB 12. I 6. Lease Designation and Serial No. ADL 25647 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-11 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made ,J[] Other Pull Tubing [] Other [] Pulling Tubing ~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 2130 hfs, 10/19/85. Killed well. ND tree. NU BOPE & tstd - ok. Pulled 3-1/2" tubing. Milled & recovered pkr. Set retrievable bridge plug ~ 8800' & tstd to 2000 psi - ok. Tstd csg to 3500 psi ok. POH w/bridge plug. Tagged top of lost E-line tool ~ 9224'; attempted to wash down. CBU ~ 9224'. Set "2B" pkr & tailpipe ~ 8967'WLM. Ran 3-1/2" completion assembly. Dropped ball & set pkr. Tstd tbg to 2500 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displace annulus & tbg w/diesel. Set BPV. Secured well & released rig ~ 0200 hfs, 10/27/85. RECEIVED 1. 4 1986 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~r ~ ~~'~ Title Associate Engineer The space below Commission use Date ~.-11-8L. Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU13/SN30 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 1A-11 Dear Mr. Chatterton- Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on October 19, 1985, your earliest approval will be appreciated. Verbal approval was received from M. Minder, AOGCC, on October 17, 1985. If you have any questions, please call me at 263-4970. Sincerely, Regional Drilling Engineer JBK/JWR/tw SN/L055 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL F~x COMPLETED WELL [] OTHER [] 2. Naj~r~c~f Qger~tor 7. Permit No. AlaSKa, Inc. 81-173 3. Ac~re~ Box 100360, Anchorage, AK 99510 8. APl Number · ' 50- 029-20685 4. Location of Well :)urtaceLocation: 809' FSL, ~90' FWL, Sec.5, T11N, R10E, UN Bottom Hole Location: 901' FSL, 735' FEL, Sec. 8, T11N, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 100' 6. Lease Designation and Serial No. ADL 256~7 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-11 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1A'11 to a selective single completion. The procedure will be as follows: 1. Well will be killed with brine. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test casing. Perforate the "~' sands· 5. The well will be completed as a selective single~ A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally t-~e'sted each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: October 19, 1985 RECEIVED 0CT2 1985 NOTE: 'Verbal approval was received from M. Hinder, AOGCC, on 10-17-85. Alaska 0~) ~ Gas Cons, C0mmJssiorl Anchorage 14. I hereby c~t1~¥ that the foreg/o~ng is true and correct to the best of my knowledge. ///~//-~/'~/~'/~.-/~'~- ~'/1/"/~ . ' Regional Drilling Engr. Signed ~ Title The space~.ow~or~o~mission use Conditions of Approval, if any: Date Approved Cop'), Returned B~ J~[RY W. KDGLER By Order of Approved by (J~R) S~]/0~h COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKAr . AND GAS CONSERVATION MISSION SUNDRY I TICES AND REPORTS ON WELLS 1. DRILLING WELL I-I COMPLETED WELL)ID OTHER 1--I 2. Name of Operator ARCO Alaska., Inc. 3. Address P. O. Box 360., Anchorage., Alaska 99510 4. L~ation of Well Surface Location' 809' FSL., T11N, R10E. Bottom Hole Location' 901' SEC. 8, T11N, R10E. 5. Elevation in feet (indicate KB, DF, etc.) 100 ' (KB) 490' FWL., SEC.. FSL, 735' FEL, 12. 6. Lease Designation and Serial No. ADL 25647 5~ 7. Permit No. 81-173 8. APl Number so4129-20685-00 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-11 i 1. Field and Pool Kuparuk River Field Kuparuk River Oi 1 Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] _ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] ( c I e a nou t (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe .Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any propOsed.work, for Abandonment see 20 AAC 25.105-170). On October 21, 1982 ARCO Alaska, Inc., attempted to cleanout wellbore fill from Kuparuk River Unit well 1A-11 with a coiled tubing unit. A foamed diesel/nitrogen mixture was used as the circulating medium. Fill had been tagged in this. well at 9039' (KB) following .a frac .job. The bottom perf. in this well is at 9150' (KB). RE[E VED FEB -9 1983 Oil & Gas C0~$ G0mmissi0~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. signed ~,-., Title Operat ! ohs Coord ! ,nator The space I~,~ow for Commission use ConditionsVof Approval, By Order of Approved by COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "ln[entions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA('- AND GAS CONSERVATION 04 ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I-1 COMPLETED WELL)[] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-173 3. Address 8. APl Number P. O. BOX 360, Anchorage, Alaska 99510 5o-029-20685-00 4. Location of Well Surface Location: 809' FSL, T11N, R10E. Bottom Hole Location: 901' SEC. 8, T11N, R10E. 490' FWL, SEC. FSL, 735' FEL, 5. Elevation in feet (indicate KB, DF, etc.) 100 ' (KB) 12. I6. Lease Designation and Serial No. ADL 25647 5, 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-1 1 11. Field and Pool Kupar.uk River Field Kuparuk River Oi I Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEOUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing I-'] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [~ Abandonment E] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing Bi Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) '13. DesCribe Proposed or Completed Operations (Clearly state all pertinent details and give pertinm3t dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On August 20, 1982, the Kuparuk sands, Kuparuk River-Unit well 1A-11 were stimulated with a gelled-diesel/bauxite fracture treatment. Th'e well was treated With 62,580 gallons o'f gelled-diesel,, 8000 lbs. of 12/20 sand, and 78,000 lbs. of 20/40 bauxite. The average treating rate was 20 BPM and the maximum treating pressure was 4450 psig. Ail surface equipment was pressure tested to 6000 psig prior to the treatment. The pre-frac producing rate for this well Following the fracture treatment the well BOPD. Recent tests on this well show that 1200 to 1300 BOPD. was approximately 450 BOPD. produced at a rate of 1385 it continues to produce at Well status following treatment' producing to CPF-1. ECE V O FEB- 9 198.3 Alaska 0il & Gas Cons Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed , Title Operat ions Coord ! nator 'The space~j~low for Commission use Conditions of Approval, if any: Date Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Subn3it "Intentions" in Triplicat, and. "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box~ Anchorage, Alaska 99510 Telephone 907 277 5637 Landon B. Kelly Kuparuk Operations Manager October 21, 1982 Chat Chatterton State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Commission Dear Chat' Attached is a notice of ARCO injectivity tests/un-propped wells 1E-10, 1E-9, and 1E-13. Al~aska, Inc.'s intent to run fracture treatments on Kuparuk These wells are low rate producers that will be converted to water injection for the Increment I Waterflood later this year. We feel that these wells need to be stimulated to ensure sufficient injection rates to prevent freezing problems. Based on our previous experience, we anticipate that creating-short, unpropped fractures by injecting water at pressures above the formation parting pressure will result in improved injectivity at pressures below the fracture pressure. Notice of our intent to clean out well 1A-11 is also attached. Please call me at 263-4528 if you have any questions. ~L. St ramp Kuparuk Operations Coord i nator RLS/b Attachments xc' L. K. Blacker - AFA 330 L. M. Sellers - ANO 332 E. A. Simonsen - AFA 331 H. C. Vickers- AFA 326 ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ' AND GAS CONSERVATION CO ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, ];nc. 8:[-173 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50-029-20685-00 4. Location of Well Surface Location' 809' T11N, R10E, Bottom Hole Location' Sec. 8, T11N, R10E. FSL, 490' FWL, Sec. 901' FSL, 735' FEL, 5. Elevation in feet (indicate KB, DF, etc.) 100 ' (KB) 6. Lease Designation and Serial No. ADL 25647 5, 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-11 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to use a coiled tubing unit to clean out Kuparuk well 1A-11. Following a fracture treatment in August, approximately 100' of fill was found across the lower sets of perforations in this well. This well is planned to be used as an injector in our Increment I Waterflood. To ensure injection into the lower Kuparuk Interval, this fill must be removed. Coiled tubing will be used to circulate a diesel/nitrogen mixture to lift the fill from the wellbore. Note' Verbal approval from Commissioner Lonnie Smith 10-21-82. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space b¢ow for Commission use Title Kuparuk Date Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 Approved ~op¥ Returned __ By Order of COMMISSIONER the Commission Date ~ ._~._%~_~__~_~ .._~"... Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TO: William VanAlen F~CM: D.W. Bose/Lorie L. Johnson Transmitted her~,ith are the follc~ing: PT.WASE NOTE: BL- B~, S- SEPIA, F- FILM, T- TAPE,~) /mchomGe D2~TD: ATIN: LORIE L. JOHNSON - AFA/311 ,, P. 0.. BOX 360 ANCHORAGE, AK. 99510 Will/am VanAlen D. W. Bose/L0rie L. Johnson Transmitted herewith are the follc~ing: FILM, T -TAPE, PC- PHOTOCOPY IPT A~,wrZ~ED: ~/PT.FAsE REIIIRN PdDCEIPT TO: R VED_ ARCO ALASKA, INC. ATIN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 A~aska Oil & Gas Cons. CommJssior~ -Anchorage ARCO Alaska, Inc.~ Post Office Bb,, 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Landon B. Kelly Kuparuk Operations Manager August 13, 1982 Mr. Chat Chatterton State of Alaska Oil and Gas Conservation Commission 5001 Porcupine Drive Anchorage, Alaska 99504 /'/zl .-// Dear Chat' Attached is a Sundry Notice indicating ARCO Alaska, Inc.'s intent to perform a fracture treatment on Kuparuk River Unit Well 1A-11. As indicated we would like to begin this work on ~day, August 18, and would therefore appre- ciate notification by phone of your approval of the Notice. Please call me at 263-4528 upon your approval or if you have any questions. Ryan L. St ramp Kuparuk Operations Coordinator RLS/b Attachments xc' L. B. Kelly E. A. Simonsen ECEIVED AUG 1 982 A!aska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany A(L/ STATE OF ALASKA ALASK IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-173 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 so_029-20685-00 4. Location of Well Surface Location' 809' T11N, R10E. Bottom Hole Location' Sec. 8, T11N, R10E. 5. Elevation in feet (indicate KB, DF, etc.) 100 ' (KB) Perforate Stimulate Repair Well Pull Tubing 12. FSL, 490 ' 901 ' FSL, FWL, Sec. 735' FEL, 9. Unit or Lease Name Kuparuk River Unit I 6 . Lease Designation and Serial No. ADL 25647 10. Well Number 1A-11 11. Field and Pool Kuparuk River Field Kuparuk River Oi 1 Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing ~ Abandon [] Stimulation [] Abandonment [] Change Plans [] Repairs Made [] Other [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 1 0-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent proposed wOrk, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to stimul with a gelled-diesel/bauxite fractur will be pressure tested to 5000 psi rained below this valve. All circul diverted to tanks on location. Temp and after the treatment to define th production logs will be run along wi the treatment to analyze the effects work will be done through a 3000 psi details and give pertinent dates, including estimated date of starting any ate the Kuparuk sands in e treatment. All pumping and treating pressures wi ated and flowed fluids wi erature logs will be run e treated intervals. A s th a pressure buildup tes of the treatment. All w lubricator. this Well equipment 11 be main- ll be both before uite of t after ireline Expected start date is August 18, 1982. RECEIVED AUG 1 3 ]982 Alaska 0il & Gas Cons. C0mmissi0r) .Anchorage 14. I hereby certify that the foregoing is true a'nd correct to the best of my knowledge. Sign . . · . Title Operations Coordinator The space b¢tw for Commission use COnditions ~l: Approval, if any: Approved Copy Date ~//$/~-~,, ORIGINAL' SIGIIEO' BY LOI~tI£ c. SMfTH By Order of Approved by. COMMISSIONER the Commission Returned Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc./" poSt Office I~. 60 Anchorage, Alaska 99510 Telephone 907 277 5637 July 6, 1982 C. V. Chatterton State of Alaska 'Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Chatterton: /~ - // Enclosed are well completion reports~for Kuparuk Wells lA-10 through IA-16A. Very .truly yours, ~. S. Dayton ~ -~~~~/~-j~ ' JSD/er cc: L. K. Blacker -AFA. 330 w/o Attachment L. M. Sellers -ANO 332 w/Attachment E. A. Simonsen -AFA 311 w/Attachment H. C. Vickers -AFA 326 w/o Attachment RECE!¥EB, i§82 ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany ~ .... STATE Of ALASKA ALASKA ,LAND GASCONSERVATION C ''~vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska. Inc. 81-17~3 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20685 4. Location of well at surface UU~Jti'SL, 49g'FWL, Sec 5, T11N: RIOE, UN 9. Unit or Lease Name Kuparuk River Un1 At Top Producing lnterval 1431'FSL, 1063'FEL, Sec 8, T11N, R10E, UM 10. WellNumber 1A-11 At Total Depth 901'FSL, 735'FEL, Sec 8, T11N, R10E, UM 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 100'RKB ADL 2.5647 ALK 46.5 Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 12/02/81 12/15/81 12/22/81I -- feetMSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9732' 6703' 9624' 66281 YES E~ NO []I 2021 I feetMD 1700' (approx) 22. Type Electric or Other Logs Run DIL/FDC/CNL/GR/Cal CBL/VDL, 6R/CCL, RFT Tool 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED · 16" 651! H-40 Surf 80 ' 24" 2flOm'x P~.rmmf'rn.~F. 10 3/4" 45.5# K-55 Surf 2947' 13 1/2" 1160sx Fondu & 250 sx AS II 7"" 26# K-55 Surf 9~1.3'. 8 13/4,, . '950sx Clmss g. lemd 500sx Class G tail 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) 88'78-8918' 3 1/2" RR51 ' R770' 8930-8938 ' ' · . · 9082-9095 ' w/4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. · 9108-9150 1 : .., ..... DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N~A : . · .. .1 27. PRODUCTION ~-EST ' ":·' ' Date, First Production , Method o~.O. peration (Flowing, gas lift, etc.) , ~ ;, , : ,' .-. · ,,,. ., , ,, ,,, .: , . . . , ., .. , 2/28/82 Flowing , .... ... , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE GAs-OIL RATIO 1/9/82 17.9 . TEST. P.ER ODJ~ , . 430 ' 233 - 9f,/4/," '634 . Flow Tubiog Casing Pressure CALCULATED ]1~ OIL-EEL_ GAS-MCF WATER-EEL OIL-~3F~VITY-API (corr) 'Press.130. ,_ 24-HOUR RATE 543 ', '34~t 0 ~' 2'~. 1 o ' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chiPs. " N/A ......... '"""' '.:. "' .. ' ' ' ' ' ':::" ' ': ~ -. _, ,~ ' ,.,.'JUL I 4 A~aska 0il & Gas Cons. Commission ':"" " "' '" ' ' .Anchorage '17 · Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE " GEOLOGIC MARKERS FORMATION TESTS NAM E ..... Inclu de interval tested, pressure data, all fluids recovered and gravity, .. MEAS. DEPTH TRUE VERT. DEPTH ' GOR, andtime of each phase. ........... Top Kuparuk 8857' 60~0' Rivet' Fo~'m. ? Base Kuparuk 9223' 6345' River 'Form. ,..- .... .. :- .. .., · · ..... 31 L'iS~ OF ATTAC"MENTS 32. . I hereby certify that the foregoing is true and correct to the best of my knowledge Signed__ ,, X .~.(~4~'1~ TitleRe§iOn 0ps Engr. Date ,, ,fl, ,// ................... 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 separ&te .productiOn'f. rom more than one interval (multiple completion), so sta~e in item 16, and in item 24'show the producing intervals f0'.r only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental rec°tds for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA - CO~iMISSION ALASKA ~,L AND GAS CONSERVATION SUNDRY NOTICES AND REPORTS ON WELLS OTHER [] 1. DRILLING WELL [] COMPLETED WELL []X 2. Name of Operator 7. Permit No. ARCO Alaska, ]:nc. 81 -1 73 3. Address P.0.Box 360, Anchorage, AK 99510 4. Location of Well SL: 809' FSL, 490' FWL, Sec 5, T11N, RIOE, UM BHL: 901' FSL, 735' FEL, Sec 7, T11N, RIOE, UM __KR:IRR ' 12. 8. APl Number 50- 029-20685 5. Elevation in feet (indicate KB, DF, etc.) ! 6. Lease Designation and Serial No. / ADI 75~7 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 9. Unit or Lease Name KuDaruk R Jver ! 10. Well Number 1A-11 11. Field and Pool Kuparuk River Kuparuk River NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation ~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] lin i t-_ Field 0il (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Poo [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On, May 5, 1982, Kuparuk Well 1A-11 was stimulated with 12% hydrochloric acid. A mud and silt remover was 'mixed with the A total of 87 bbls of acid were squeezed across the following intervals using a coiled tubing unit. 8878-8918' 8930-8938' 9082-9095' 9108-9150' MD acid. Diesel was used to displace the acid. Nitrogen was circulated intermittentiy with diesei to expedite the cieanup. Aii pressure equipment was tested to 4000 psi. Aii injected and produced fIuids were fiowed to surface vesseIs and disposed of. The well would not flow after the stimulation without nitrogen support. A-24 RECEIVED MAY 2 8 i982 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ ~u~ RegionaI Signed 'for ~(~mmission Title The space b Alaska Oil & Gas Cons. Commission, Engineer Anchorage Date ~/"~ '~/~'"~ Conditions of Approval, if any: Approved by. By Order of COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office B Anchorage, AlaSka 99510 Telephone 907 277 5637 April 21, 1982 Mr. C. V. Chatter.ton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Chatterton: Attached please find Sundry Notices of Intention for Kupaurk Wells ID-2, 1D-4, 1D-5, 1E-3, 1E-5, 1D-3, 1¢-1, lA-7, 1A-9, lA-10, and~¥1q~..~ The work on these wells is scheduled for the latter part of AprlI, 1982. Also attached .is the subsequent notice for Well 1B-gGI which was perforated in late December, 1981. We apologize for the untimeliness of this report. A recent review of our records revealed this submission had been overlooked earlier. Sincerely, 3~.~. ;ayto~ bl Attachments STATE OF ALASKA ALASKA L AND GAS CONSERVATION C ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, ]:ne. 81-160 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 5o- 029-20685 4. Location of Well SL: 809'FSL, 490'FWL, Sec 5, T11N, RIOE, UM BHL: 901'FSL, ?35'FEL, See 7, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) KB-100' I 6 . Lease Designation and Serial No. ADL 25647 12. 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-11 11. Field and Pool Kuparuk River Field Kuparuk River 0il Poo] Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate EX Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state ali pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO AIaska, Inc. proposed to stimulate the Kuparuk Sands with acid. Acid wiI1 be spotted with a coiIed tubing unit with BPO assembIy tested to 4000 psi. AI.I circuIated and fIowed fiuids wiII be dlverted to tankage on Ioeation. The weII wiII be tested subsequent to the stimuIation. Expected start date is April 25, 1982. $~uent Work Reported APR 2 6 i982 ........ Uau COIT!.rrltS~lOf~ r_,~ ~.~;~5 Oil & "' ' Cons. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed . , . Title }~ll~h_el;l~C ei°w for Commission Conditions of Approval, if any: Engineer ~/~. / Date ./ Approved by , Approved 'Topy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "IntentiOns" in Triplicate and "Subsequent Reports" in Duplicate HORTH ~LOPE E~GI~-~EERIi;G J. J. Pawelek/Ann Simonsen DATE' c~-'~- S 2.~ WELL NAME' Tran-:mi.:ted here:.:ith are the following' -... - ~Pi~, ~ - TAPE 1,0~' BL -. BLUELL~:~ PL~.z ,,~, S - S F - FILH, .. RE~,E Z F'T AP:"'n'"~CDGED x z,;'z ,,r.,,._,.,~ ,'.~-~?T TO: A~'CC ~t, Ih~. ATTIC' A;;;~ SIF~0;iSE[! - AFA/311 P.O. BOX 360 DATE' -NfAR o- -m 2 Alaska 0il & Gas Cons. Commlssba Anchorage J. J. Pa:-,'elek.lAnn Simonsen Tra::smi:~d~= here:.:ith are tk,~,,~ follev:ing' PLEASE i;OTE' BL - BLUELTiiE, S - SEPIA, F - FILH, T - TAPE - DATE' ARCO Alaska, In~, Post Olfic( ~ 360 Anchorage. ~iasl<a 9'~510 Telephone '~07 277 563'7 February 19, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Subject' State Reports Dear Sir' Enclosed please find the up-dated Completion Reports for drill sites: 11-3, 11-5, 13-8, 13-1.0, 14-12, 15-13, 15-14, iA-10, ~~.~i~.~B-6, B-9GI, B-10GI and West Sak #18. The gyro-multishot surveys enclosed are from drill sites 12-4A, 13-1.9, 14-12, 14-26, 15-14 and 15-1.5. The original gyro-multishot surveys for drill sites 11-1, 12-14, 13-6, 13-9, 14-13 and 16-1 were un- satisfactory and are scheduled to be re-run. Information to be submitted on the corresponding completion, along with the accept- able survey, will be forwarded to your office When we receive them. Also included are subsequent sundries for drill sites 14-9A, 14718, and 15-10, along with a Sundry of Intent to plug and abandon Kavik #1.' Sincerely, M. A. ~j or Area 'Drilling Engineer Enclosures MAWGLA'ss ARC{.'. Alaska. Inc ~ a ,~ub$idi,~rv (')f ^tlanticRichfJeidCompatly ALASKA '~,,,AN D GAS CONSERVATION C ,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL]~[ GAS [] SUSPENDED'[] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-173 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 5o-029-20685 4. Location of well at surface - 809' FSL, 490' FWL, Sec. 5, TllN, R10E, UI~,~LOCATIONS] 9. Unit or Lease Name VEaI~I~_D Kuparuk River Field At Top Producing Interval Surf .... [ 10. Well Number - 1A-Il 1626 FSL, 1197 FEL, Sec. 8, TllN, R10E, At Total Depth -- 11. Field and Pool 901' FSL, 735' FF, L,. Sec. 8, TllN, R10E, UM 'Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) / 6. Lease Designation and Serial No. Kuparuk Oil Pool zoo'/ 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore [ 16. No. of Completions 12/02/81 . 12/15/81 12/22/81 feet MSLI 1 17. Total Depth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurve¥ I 20. Depth where SSSV set I 21. Thickness of Permafro~t 9732' MD, 6703' TV)9624' MD, 6628'?Ft~s~l NO[] 2031 feetMD 1700' (approx.) 22~ Type Electric or Other Logs Run DIL/FDC/CNL/GR/Cal, CBL/VDL, GR/CCL, RFT Tool 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1 6" 65# ' H-40 Surf. '80' 24" 200 ~x Permafrost 10-3/4 ", 45,5# K-SS Surf. 2946' 13~" 1160 sx Fondu and 250 sx A.S~. II 7" 26# .... K-SS Surf. 9713' 8-3/4" Lead - 950 sx Class "G" Tail - 500 sx Class "G" · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD i?terval' ~ize and number) SIZE '; DEPTH SET (MD) PACKER SET (MD) 3~" 8851 ' 8774, ' 8878' - 8918' 8930 ' - 8938' w/4 spf ' 26. ' ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9082' - 9095' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9108' 9150' "" " : N/A' . 27. PRODUCTION TEsT ' ' ' Date First Production I Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested PRODUCTION FOR OIL-BBL G~S-MCF " WATER-BBL CHoKEsIzE GAS-OILRATIO ' TEST PERIOD * FlowTubing (~'asingPressure' i CALCULATED . OIL-BBL: GAS!MCF WATER-BBL OILGRAVITY-API (corr) "Press.': ' ..... ' 24-HOUR ~iATE'II~ " " ' ' ¢ ' .." " ., , 28. ' ..... ' ' CORE DATA , · - Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core Chips. ', · , , - : .', . F E [~ 1 9 i~!c, 2 . . , ,td:<:h~ 0;1 & Ga::', Cons. C0~nmjs: . ~ : .,. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate NAME Include interval tested, pressure data, all fluids recovered and gravity, ~ . MEASi DEPTH TRUE VERT. DEPTH GOR, and time of 'each phase. .. .- TOp Kupa~ 8557 ' 5900 ' . Base Kuparuk 9223' 6345 ' ,. · . 31. LIST OF ATTACHMENTS 32. · · I hereby certify that the foregoing is true and correct to the best of my knowledge ., Signed '~_~~~ ~ Senior _ Title Drilling Engineer 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 pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. 'Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 HORTH ~LOPE ~,,GI I~,G l ×,,I;_,.,ITTAL ~ DATE ~--/2 ~z_- WELL . . Tran~ · .... ~ttad herewith are the following: PLca~r rlOTE BLU:L.rlE SEPIA, J. J. Pawelek/Ann Simonsen F - FILM, T - TAPE RECE ! PT ACK:iOWLEDGED' .--,q~- ~T,.Q.. [~ ,-- . PL:_-,_: r.~,u.,~ EC~?T TO DATf~ie1011 & Gas Con° ARCO ALAS!LA, I~C. ATT:~: A;.;~i SI;.iO:ISE~I - AFA/311 P.O. BO:", 360 · ,, ,-,. .- ~:, Cc~lO TO' NORTH ~LOPE Ei:GINEERIr:G .. TRAi~SMITTAL ~ '~~ ~//~ ~ FRO;.!' J. J. Pawelek/Ann Simonsen DATE' ~-~/~_ ¢ 2__ WELL "'~';=',,~,.,,_ Transmitted herewith are the following: PLEASE HOTE BLUcL.HE SEPIA . F - FILM, T - TAPE RECkS. pT n~ .... ~"-~n~ /L ~._ ~ ~-,~., · . EA~: R~iu..,~RECE~?T TO RECEI ]) '"~ r"* o DA it. ._^,, ~ u,, & ~ ~on:~omm~sion /~ohorage ARCO ALAS~tA, INC. ATT!l: A[.~H SI;,iOHSE;! - AFA/311 P.O. BOX 360 A.,r:,n~ ~,, 9~510 · 0 RIG iN A L WELL COMPLETION OR RECOMPLETION REPORT AND LOG ' 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-173 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 so-029-20685 4. Location of well at surface 9. Unit or Lease Name 809'FSL, 490'FWL, Sec. 5, TllN, R10F., UM Kuparuk River Field At Top Producing Interval 10. Well Number To Be Submitted.', 1A-il AtTotalDepth , '/*'1~0 ,"~--~;~'~-~ ~-'~"b(::~/F '~"or~ ~, f}'~/or'~ 11.FieldandPool TO Be Submitted. '(~/~/~FSL,, ?£b-/F£Z. ~ '~ £~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Oil Pool 100' RKBI ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of CompletiOns 12/02/81 12/15/81 12/22/81 feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I :21. Thickness of Permafrost 9732' MD ~703 9624' MD YES~ NO[]I 2031 feetMDI 1700' (approx.) 22. Type Electric or Other Logs Run m ,/ DC/C /CR/Cal, CR/CCT,, TooZ 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 Surf. 80 ' 24'~ 200sx Permafrost 10-3/4" 45.5# K-55 Surf. 2946' 13~." ll60sx Fondu and 250:;x A.S. II 7" 26# 'K-55 Surf.' 97'13.· ~· ~8~3/4" Lead.·: 950sx Class Tail - 500sx Class "(;" . . . 24. Perforat .ons, .open to Production (MD+TVD of Top an,d Bottom and 25. TUBING RECORD ·: ~interval, size and number)·' SIZE · DEPTH SET (MD) PACKER SET (MD) 3~." 885i' 8774' 8878' - 8918' 8930' - 8938' ' 9082' - 9095' w/4 spf ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. · ~ . . DEPTH.,INTE,R..VA, L(MD) AMOUNT& KINDOF MATERIAL USED · N/A 9108' '- 91'50'"' -'". :: " " ' '- ~ , ~; ,.., ..- · · · . . : · 27. PRODUCTION'''TEST Date'F:]rst P¢oduction . '. ~. ' , . Method of Operation (Flowing, gas lif~,..etc.) N1A ' "~ ....... ' "~ ' '.""' ";:":' ' DateofTest HoursTeste~. PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL i'] CHOKESIZE [GAS-OILRATIO ,, .~ ': ,'. 'TEST, PERIOD Flow~Tu'bing Casing Pressure CALCULATED OIL-BBL, GAS:MCF ' WATER-BBL OIL GRAVITY-APl (corri Press, ' ' ., 24-HOUR RATE.·I~ ' . ? · . cOF~E DATA ·i. . · :28. · .r Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' '~''~'; ~' '"' ' ' ' ~" ' " '" if~"m , , , . , · .' ",. '·' ' ..".{.:L.:['~:::,:f.[·;!~'·' . , ~.r · Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,. NAME Include interval t~ted, pressure data, all fluids rocovered and §ravit¢} MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . T 0 BE S IBMI'_TTI~D N/A .. . . . . 31. LIST OF ATTACHMENTS , , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ' TitleS1'., Drlg. ~gr.. 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 ~f;~ell is completed for separate production from more ~than one interval (multiple completion), so state in item 16, and in item 24 show the producing 'intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 DS 1A-11 Dr i 11 i ng Hi story NU hydril and diverter. Spudded well @ 1600 hrs, 12/2/81. Drld 13-1/2" hole to 2955'. Ran 71 jts 10-3/4" 45.5#/ft K-55 casing w/shoe @ 2946'. Cemented 10-3/4" casing w/1160sx Fondu and 250sx AS II. ND hydril and diverter. Instld 10-3/4" packoff and tested to 2000 psi - ok. NU BOPE and tested to 2500 psi - ok. Drld FC and cement. Tested casing to 1500 psi - ok. Drilled FS and 10' new form. Tested form to 12.5 ppg EMW - bled back to 11.9 ppg - ok. Drilled 8-3/4" hole to 9524'. Ran DIL/FDC/CNL/GR/Cal. Ran RFT tool in Cretaceous Sands. Contined drilling 8-3/4" hole to 9732' Ran 235 jts 7" 26#/ft K-55 BTC casing w/shoe @ 9713'. Cemented 7" casing J/lead slurry of 950sx Class "G" followed by tail of 500sx Class "G". Installed 7" packoff and tested to 3000 psi - ok. Arctic Packed 7" x 10-3/4" annulus w/300 bbl H O, 250sx AS II and 112 bbl Arctic Pack. Drilled cement to 9624'PBTD. Teste~ 7" casing to 2000 psi - ok. Displaced well to NaC1/NaBr. RIH and ran gyro to 9600'. Ran CBL/VDL. Ran 3-1/2" Geo-Vanngun completion assembly w/tail @ 8851 and packer @ 8774'. Ran GR/CCL. Tested tubing hanger & packoff to 3000 psi - ok. Displaced well to diesel. Set packer @ 8774'. Annulus pressured to 1500 psi, tubing open to atmosphere - ok. Tested tubing to 2500 psi, close SSSV - bled to 500 psi. Open SSSV, pressure increased to 2000 psi - ok. Installed BPV. ND BOPE. NU tree and tested to 3000 psi. Open SSSV and pulled BPV. Dropped perf bar - didn't fire. RIH w/overshot and retrieve bar. TIH w/l" bailer - work to firing head, pound firehead and fire guns @ 8878'-8918', 8930'-8938', 9082'-9095', 9108-9150' w/4spf. Dropped ball, press tubing to 2300 psi. Ball sheared - guns dropped off. Closed SSSV. Secured well and released rig @ 0200 hrs., 12/22/81. ARCO Alaska, Inc. ~' Post Office B& 0 Anchorage. Alaska 99510 Telephone ~07 277 5637 February 9, 1982 Mr. Lonnie Smith State of Alaska A1 aska 0il and Gas Conservat ion Commi ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- Gyroscopic Surveys Dear Sir' Enclosed please find the completed Gyroscop'id Surveys for Drill Sites 11-3, 11-5, 12-8B, 13-10, 15-12, 15-13,~~¢, 1A-12, B-9GI and B-iOGI. Also 'included are the completion reports for Drill Sites 1A-10, ~!~ B-9GI and B-IOGI Sincerely, P. A. VanDusen District Drilling Engineer PAV 'GA' ltc ARCO Alaska, Inc. is a Subsidiary of AllanticRichfield. Company LEastman Whip st oc k P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 January 20, 1982 ARCO ALASKA, INC. P.O. Box 1479 Anchorage, Alaska 99510 well Number: A-ii Location: Kuparuk Field, North SloPe, Alaska Type of Survey: GyT..o-Multi Shot Date: 18-Dec-81 Method-Of Computation: Radius of Curvature Surveyor:' Max Lund Job Number: A1281G0170 .. Attn: Bob Hines Dear Mr. Hines, I am enclosing' the original and one copy of the Gyro-Multi Shot Survey run on the above mentioned well. We wish to take th:is opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. AhOY HICKMAN' District Surveyor A~fbb cc.' fiie enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide .::;'.'.'.::c:'.:-'::".:'.-.:;::::::::.:. :::::-. '-.'.::::.7.'::::::;-.-'.--:- .... '_ ....... '..'" .. .' ' · :.-:.c . ..:...-:: ......................................................................... 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'.':Z~::-:'..:" ::.:7'. .... "' ::::;::,::..:_.....:-:':-..::.':::::::-- ============================================================================= =========================== ,,.-.:-.:-.-.--:-:::%*.-:;:.....,.*.::-.,.-:., :::....-.-: :..- ARCO ALASK~ .TNC· KUPARUK, 'NORTH SLOPE, ALASKA GMS, 0-9500 MD, SURVEYOR; CAHERA NOt 1644, 1572 FORESIGHT; S~8E ...[tJ,r..'~ INI~ .i f4J.,,,.."L',T J, L:~L,.~,L /%.1 DATE RI..IN~ 18-[~EC-'81 Whtpstock. A PETROLANE COMPANY RECORD OF S[.II:(VE'Y RADii. IS OF' CURVATURE HETHOD ='AD A, WELL NO~ .1..1. GMS (UPARUK, .JOB NO: A1281801'70 · · TRUE , DEPTH ANGL~ DIRECTION I_ENGTFI .DEF'TFI o~..~, ,)c.~.l'~ON I'UD C 00 R D I N A l' E S DISI'ANCE DIREC'FION SEJVF'.ZF~I.T' FEET D M D FEET FEET FEET FEET FEET FEET D . ~ DB/:IO'OF' . '0. 0 0 0 O. 0,00 - 0.00 -100.00 0.00 100. 0 0 0 JO0. JO0o'00 0.00 0.00 0.00 "290~'"''0~--0-7--.----~ .......... 14)0=-----~0',0,,--~ :-~O ---.,O,,.^^~ 300. '.04~ ~ :$ 77. E 100. 300.00 0.49 200.00 0.15 400. 0 30 N 62 E .100. 399.99 1.00 299.99 0o0~ 0.00 0,00 0 0 0,00 0000 0,00 0 0 O. O0 · ,,.,,,, 0,-00 ..... -O 0 0.64 E 0.65 S 77 0 E 0.75 ~.70 E 1.70 S 89 4.4 E 0.50 500, 0 0 0 100. 499.99 1.06 399.99 600. :::-3" 0 $:41 E ' 100. 599.94 3,67 499.94 800. 11 0 S 46 E 100. 798.-29 27.36 698'29 900. 15 0. S.51E 100. 895.71 49.~1 ,795;71 0.20 N 2,08 ].78 S ~.80 7,'65 S 10 ~ 17.70 S 22.18 ~2.60 '$ ~9.02 E 2.09 N 84 ~8 E 0.~"% E -. 4.19 S 64 55 E 3.~ · E 28.~8 S 51 25 E 4.18 El 50.84 S 50 8 E 4.15 ]000, 19 30 8 46 E 1100, 22 30 S ~5 E --.-&~OO-,---26:-.O~..-~7---.E- 1300. 29 45 S 44 E . 1400. ~2 0 S 44 E 1500. 33 45 S 46 E 100. 991.19 78.25 891.19 52.23 S 6.1 ~ 0 1.34e,.,90--: ..., 2, , ~ , ' ,' E 80.47 S 49 32 E' 4.7..3 E .1.:15.94 S 46 45 E 4.94 E .1 ,J &-,-78----S--4 ~.~_~t~.~_ .. E ..... 6-',0-3 .... · . "~ S .45 18 E 4 O0 E 203 5~. ' E 254.82' S 45 ~ E 2.25 -- E' 100, ,7. 09, .10 S 4,¢':"' 2.. 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E'" ...... ,,'~.,-0 O-- lBO0 40 0 S 45 E 100. 167~.49 482.o"-- .1=' - · ,,., ,.,73.49 ~44.05 S ~48.01 E 489.37 S 45 20 E: 2.10 1900. 43 45 S 46 E .100. .1747.94 548.78 .1647.94 390.83 S ,~9,5.61 E ":'~ c, · ~,~6.11 ,.~ 45 2:1 E ,~ .1 2000. 47 0 S 44 E 100. .1.8.1.8.17 619.06 17.18.17 441.1f5 $ 44~i.9,7 .E 627.27,~c' 4'5 .19 E 3,,.,o ,=":;' 2100. 51 30 S 43 E 100. 1883.4;~ `594..16 .1783.43 496.09 S 498.06 E 702.97 ,>o 45 7 E 4.56 .... ~200-~.-~5-t-:-4~--S- 4~-- ..E-- ..... -&. 00-~ ....... t-,cz4~, ,~...' , , ,;-,-98--:~,:,-~;-t-----~.~-4-2-~ ....... ,~,~-~ , ,;,,--...-, ,.c~~-,.~-44.-~4-E--~-0.,-~,-,;~ .... 2;300, 51 0 S 42 E .100. 2007.98 8-49.60 190709,~ 6.11.02 S 604.30 E 859.38 S 44 4] E 1.08 2400. 50 ~0 S 4~ E ~00. 2071.20 926 ~" ~' .u,J 197~.20 668.11 ,, 656.62 E 936.76 S 44 30 El 0.92 2500. 50 0 S 42 E .100. 21~5.15 i002.94 2035'15 724.80 S 708.5,5 E 1013.61 2600, 50 O, S 43 E ]00. 2199.42 .1.079.06 2099.42 781.28 S 760,32 E' 1090.17 --~~9~-45-i-:-B-47~-4~ .... ---:1...00.,-: 2.2-?.~,'3-,-8:7----~.-~;4-,-~.&- 2tl-~,~-~8~ .....~r~_. ~n e __ o~_~_~ ~z _:- . .~ ~.z. _ ' "~ · * *, ~ ~ ....... · ..,~ v ~e ~. .....~ v -t~ ~ · ~w~ v ~,-~- ~.. 2800, 15 S E 100. 2328.81 1 3 +4;t 2228,8 872+81 S E 1242,44 2900. .4~ 0 S 4~' E 100. 2~e4.2~ ~0~.4~ 2294.2~ 9.48.11 S e15.89. E ~3~8,'24 s 4,{ 2.1. r.:' ,0.s'2 S 44 13 E 0.77 S 44 4 E 0.50 ~ 44 I E 0.25. -"AT~ A, WELL NO'~ .11 GMS . ,JOB WO~ A128.1GO.170 TIME PATE (UPARUi~'-NOR'TH'-St-OF'E-r-AI-'ASI~A i ...... .' ,i ,, ,.~ . .~;58~ iv "' .=v-,.,r.,,,-o,~ " TRUE '""'-"'~"'"'""-'" ...... '."'-i' - ,.',-,,,,,,.', .... ,,--",,:,~,--,,- ,.~--~.,-~,=..--~u~-~',..,,, .... C ,~'""' ,, ~-' C U I. A R C " "' ' ' ' b-:..-t3--E,--l¢--~;:---,:. DOGL-E--~ DEF'TH ANGLE DIRECTION I.ENGTH -DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECI'ION SEVERtT' FEET II M D F'EET FEET FEET FEE]' FEET FEET D N DG/10OF' 3000. 49 0 S 42 E JO0. 2459.86 1380,48 2359.86 J, 0.03.75 S 966.88 E 1393.69 S 43 56 E. 0.75 3100. 49 0 S 43 E ]00. 2525.47 1455,47 2425.47 10,.q9.~9 S 1017;86 E 1469.14 S 43 51E' .0.75 3300 49 15 S 43 E 100 2656.51 1605.27. os":" ' ' , ,,,.~o.51 ]168.99 $ 112].86 E 1620.22 S 43 49 E 0.80 3400. 50 0 S 42 E 100. 272.1.29 1680 ~7 ~6~1.~ ~ 29 ~.225.~~ . ~, S 1~.73.33 E ~696.38 S 4~ 4& E 1.07 3500. 51 0 S 41 E 100, 2784.90 1757,78 2884.90 ]282.94 S 1224.46 E ]773.48. S 43 40 E 1. 3600. 51 45 S 40 E 100. 2847.32 1835.66 2747.J2 1342.35 S ~275.20 E ~,851.49 S 43 32 E ~..0~ --~-7-00~----,~2 ...... 9----¢·~-41--~ ...... i-~O-,- ....... ~,0-9,--,,&--~.~-..2.~,-0.~-2809-,06 .,_,,~-,..~-,,~no-~z ,,° .,'~°5,,,. .-2~. ... 3800. 52 ]5 S 40 E ]00. 2970.45 1992.78 2870.45 1462.19 S 1~77,55 E 2008.8~ S 43 18 E 0.83 ~900o 52 0 S 40 E ]00. 30~],.85 2071.5~ 2931,85 1522.65 S 3.428,2? E 2087.70 S 4J 10 E 0.25 4000. 53 15 S 38 E .100 ,3092,55 21= , . .. ,.,0 89 299'2 55 .1584.4~ S 1478 29 E 2166.96 S 43 I E 2.02 4100', 53 0 S ~8 E 2246,65 S 42 50 E" 0,~..,°'"- --4-200+----53~-...O--~--~7--.E_ o o ~. ,'~ - ,.3,.~6.+.;I~L.-,.~--4~. ..... 2{.~-.. E ........ 0 +60 ..... 4300, 5:3 0 S 37 E 2405,&7 S 42 28 E' 0,00 4400, 54 0 $ 38 E 2485,76 ~' o ~" · ,., 4~ ~8 E 1,~.8 4~00, ~3 0 S 39 E .1.00, 2565,97 c., ,') "'2 . ,:) 4,...1.:I E :i, 8 4600, ~3 0 S J6 ii: .100, ....~452,. ~.,07 ,~,,..°!,=.1.,0.1 3J52,07 .1964,6°~ ,~:' .1.7'21,81 E 2645,56 .,,o 4,,.° ~ E '2,. 40 ..... ~-7-OO, .......... ~.3;--..-4f~ ............. S-40----F.,; .............. ~----tOO~ ............ 3gZ;~-.&.~ .......... ~.7-.1--....1--,¢.,O--.~4-1...-~,.-72 ~.O~-.~-~---~ p~ o-~-n~:~, p~ ~ 4.800, 54 30 S 39' E .100, J570.JJ 2792.08 3470.J5 2090.37 S 1872.75 E 2806.57 S 41 ,51 E J.lO 4?00. 54 30 S ,38 E 100. ~628 40 287~,42 3,.,~8.40 2.1.54.08 S 1923,42 E 2887.84 R 4:1 46 E 5'000. 55 0 S ,.'48 E .1 00. 3886.11 ~o~,:: ,. ...... ,03 ~586.1.1,~,~")")18.43 S .197i~;,70 E ,~.969.33,~ 41 40 E 0.50 5100. 54 30 S 37 E 100, ~743.8J 3036.66 ,.'4643,83 ,..,.,.,, ......... - .... , ........... ; .......... .--..~ ......... ~,,-.~ --2J~7~~.,_~ ..... 4..1.....2.-.E ......... 0-,-9-~ · · !¢,:' · ~ ..,4 24.12,75 ,Se 2:i. 23;,7.1 E 3;:{:1.4,27 S 4:1. 21 E 0,.,0 5300. 55 30 S 38 E' 100. 3858,54 ,3200,42 37,,8. . 5400, .55 45 S 38 E .1.00. ,3.915.00 3282.91 ,.'4815.00 2477,7? $ 2174.53 E ~o,.96.67 S 41 16 E 0.25 5500.. '56 0 $ 3'6 E 100. ,.397.1,.1.0 3J&5.&7 3871.10 254~.?0 S o,'~_na J~4 E 3J79.22 ,:.,:.,:~-. $ 4 .1 10 E' 1,6 7 5600. 55 45 S 36 E ]00. 4027.20 3448.45 ,.'4927.20 2610.87 S~.,,~")")'7'~,,.,.00 E 3461.67 S 41 3 E 0.°":''~.~ ~. ~ r.,-, ~ ~ ~ .... .:. 5900,, 53 45 ~ ~&'E: , 100, '4201.04 ~,92.92 4101,04 2807.82 8 "2417,84 E' ;S705,37 '""AD A, WELL NO: 11 GMS < U P A R U K,-N 0 R 'T-H'-~ L-O F:-E.',-- Al ;.A-SKA ~.OHF'UTAI'ION PAGE NO .JOB NO,* A128)G0170 I'IHE DATE · ~ ~'~.~ ..... , ,. ,, ~ .,, , · TRLJ'F. , DEPTH ANGLE DIRECTION I..EN(ITH DEPTH SECTION TVD C 0 0 R ~;-I N A T E S I~ISI'ANC. E I.~IRECT]'(JN SEVER'IT': FEET D' H D FEET ' FEET FEEl' FEET F'EET FEET D H lb/lOOF] ! 6000. 53 0 S 37 E ~00. 4260.~0 ~77~,~7 4160.70 28720~ S 2465~57 E ~7850 6100. 52 0 S 36 E 100. 4~21.57 ~852.50 42'21.57 29~6.10 S ~.,~2,~"' 76 E 3864, 6~00--¢~-,~:J~~~..... .-1~~ ..... ---~,,&Z,4"r,-7~-.' :'--- :~0'.:':_-__-~---8---.-~.,.,~,,~ 6700. 50 .0 $ ~& E JO0. 4447,4~ 4007.92. 4~47.47 70&1,04 ~ ,-)~:,,,.~o E 40~9. 6400, 49 0 S 37 E 100. 4512.38 4087,95 4412,38 ~1~'~.17 S 2650.44 E 4095. 41 S 40 759 E :!.10 54 S 40 33 E J,28 Z " "' " "" '~' ~-1---.. ~)--.24z- E:-----t--,-~-~ ,59 S 40 24 E :1026 45 S 40 20 E 1,26 · ~ ~ 60E 6500. 48 15 S ;37 E 100 4578.47 4158.98 4478.47 3182.09 S ,.69,.,, ~ ,~-o,_-4'z 44 "= =' ~_o :324-.:. 6600, 48 0 S :35 F.': 100, 4645,~.. --.,~...., 4.:,4..,.,,.... 3:3 S 2739,36 E' 6800. 46 0 ,.q~7 E .1.00. 4781.62 4;'~79.69 4681.62 ~60.66 S 282,5.32 E 6900~, 45 0 8 37 E 100. 4851,71 44,.=;.1..01 47,5';.t, 7:1. ~417,62 ,.,c:2868. ,~.,.,~'~' E' 41.70.37 S 40 16 E' 0.,,, 4244.62 S 40 12 E 4~°..~, i0 .... 4390,50 c, ,:, 40 ~ E 1,24 4461,72 S 40 0 E 1,00 7000. 44 30 'S 37 E 7100. 44, 0 8'37 E 7300. 45 30 S 36 E 7400.. 46 30 $ 34 E 7500. 48 0 S 34 E 7600, 50 0 S 34 E .1.00. '4922,72 4521.40 4822.72 Z473.85 S 2910'o 6i 1 J 0 =' '":' ' ' ' "':: .... ' 5206.,.?i 6:-~;~748 ( :~ ' '" ~ ';;9.2:; .1. 00. 100· 5339.64 4~52.36 5239·64 3824, ,.,0 S ,8161. Z8 .... ~' ~' ~ ' " ~' - r:' - ~ .... ~ '~ "' ,] c:' · r~ ' · - ~) "' 770 ~'..... 0'~ ....... ~1 ~ ..... ' ~ ''~ ~ "''E: ........... t'0~ ....... ~40''~'~'~ ........ ~0'3~&'7 .......... ~'¢::0t--''''7'''J;'~--78'~''''8''~'~ ....... ~''~'~*'~G~~'9--~ ........ ~&'''g'9----~9--''l:~ ......... ;~;~-4 .... 7800, 5~ 0 ~ ~4 E 100, 545~,~0 511~,1 535~ 60 ~957,85 S ~"~ .... , .~49,45 E' b:120,89 39 E 7900, 57 0,.)c' 32 E; ~00, ~"='14,79,.,,., . 5;I. 95,37 ,.,414,79 4u,:./.79 S ;f,..94.86 E 5203,76 S ;~9 17 E .. ~4 E 4,.,32,03 o 39 ~"" 50 · ., ~'~ E' O. E 4601,72 S ,¥9 55 E 0,50 ~ " I"'~:' ~", .... E 4742,00' S 39 49 E 1,22 E 4813,&7 S 39 45 E 1,75 E 4886,74 S 39 40 E .~,50 E 4961,85 S 39 ~5; E 2,00 8000, 56 30 $ ,.'4:1 E .1.00, 5569,62 5278,75 5469,62 4099,09 $ ,3338.55 E 5286,63 S 39 10 8100, 55 30 $ ,.35 E 100. 5625°54 5361,52 5525,54 4:1.68,60 $ 3383.70 E 5;.'369,05' ,S 39 4 8:300. 5:3 45 $ 3~5 E 100. 5740,43 ~525o:19 ~3640.43 4302.70 8 3477,F'J9 E 5532.34 S 38 57 8400, 52 45 S ~5 E ~()0, 5800,26 5605,30 5700,26 4;~68,3~ S .,.,~'=:')~,55 E 561.2,28 S 38 53 E 0.97 E E' 1.50 E 1,00 =.o 5861.3:1 5684 49 5761 3.1 4433,2.1S 3568,97 8500, ,.,~ 0 S 35 E :100, . 8600, 51 0 S 35 E .1.00, 5923.56 5762.74 .:,8~3.56 4497.3! S -87-00 ~n S --?,%~7.-.,-J,~-?-SS~9.J,.8~ '-~'.-:..'~'-:0 8800· ':a9 0 $ ~,5"E 100, 60~;2.:11 5915·92 5952,11 4622,.81S ~701·74 ~4 4684,04 S 3744,61 8?00, 47.45 S 35 E 100, 6118,54 59~0,~5 &OJS,., . E. 5691,30 S 38 50 E 0.75 E 5769,39 S 38 47 E 1,00 ¢ .,;,.q4~,.- ~ ,,.,~--..----, E 5922.26 S 38 4J E. 1,00 E ~996,86 S 38 38 E 1,25 -~AD A' WELL NO; 11 8MS .JOB NO; A128:[(~0170 'TIMF. DATE TRUE ~,EVERI'I: DEPTH ANOLE DIRECTION I.ENG'rH DEPTH ~ECIlON TVD C 0 (I R D I. N A 1' E S DISTANCE DIRECTION c ........ , .... , FEET 'D M D FEET 'PEET FEET FEEl' FEET" FEET D 'M DG/IO'OF'f ,, 9000, 146 30 S'33 E' 100, 6186,58 6063,89 6086,58 4744,79 S 3785,59 E 6069,90 S 38 35 E 1,93 9100, 43 30. S 29 E 100, 6257,28 6134,30 '6157,28 4805,~8 S 3821Y99 E 6~39,98 S 38 30 E 4,12 9~00,~ 44 ~0 S ~ ~ 100, 8~99,9~' ..... 8~,.,,.,,82 6299,92' 4926,15 S ~89[~,14 E 6278,82 c,~~8 19 E' 0,50 ~400, 45 0 S ~1 E ' 100, ~4470,~4 434~,~5 6~70,~4 4~84,50 S ~2~,40 E 6~48,65 S ~8 14 E 0,50 9500': : 45' 45 S.32 E 100, 654],19 6414,90 6441,15, · 5047,18 S 39.66,55, E 6417,33 S 38 10 E 1,'~ ! o 9624, 45 45 S 32 E . ,~732' MD - TD -- ' ......... F-I-NA.L---GL-.Q,~LJ-RE- ........ BZ-RE-~-i:-t-QN,' DI~'[ ANCE: A PETROI. AIVE COIVIPANY 6507,65 S 38 ~' ,~ E 0.00 6584,58 .FEET ARCO AI.ASK~ I ....... P A-D-A~,--W EE-E~.- ~,~.{---1~-1 ......... GMS ............. : ...... '" KUF'ARUK, NORTH ~LOF'E, AI..ASKA' GMS, 0-~500 MK~, ,.~URVEYOR; I..UND CAHERA NO; 1&44, ~572 FORESIGHT: 'S~SE DATE RUN: .18-DEC-81 A PE'TROLANE COMPANY .,.JOB :'AD A, WELL NO'. .11 GHS PAR U k~,--N 0 Fe-TH---St=8.PE~r--At.~-A ,St~ A [t0; A1281GO.1.70 TIME DATE ........ 14'; ~'~; 42 "'^-:' '~"~' ' ~'~ ........ MARKER ............... TRUE SUBSEA ............. NAME ...................I) EF'TH ErEF'TH D]:F'F' DEPTH C O O R D I N A l' E S DISTANCE DIRECTION THI~:':I'(NESS. F' E' E T F E E T F' E E T F' E E T F E E T F' E E T D TOF' OF KUPARUK BASE OF KUF'ARUK TD 8557.00 5896.79 2660.2 5796.79 4469.75 S 3594,56 E 57J5.8.1 S ,38 48 E 9223.00 6~45.2A 2877.8 6245.24 4877.6~ S J~8.55.22 E 6225.05 S ~8 21~ E 9772.00 6703.07 3028.9 6603.07 5188.11 S 4054.&5 E 6584.58 S 38 i E A PETROLANE COMPANY Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. 'Operator, W~I'i ~ame a~d' Number Reports and Materials to be received by: /-~ / D~te Required Date Received Remarks Completion Report Yes ~'~ ~ ~-.~_ _Samples Mud Log Core Chips . Core Description Registered Survey Plat ~nc~nat~on ~u=e~ --- ........ ., ~d y~ Pr~u~ion Test Re~rts ~s R~. Yes ALASKA oIL' AND GAS CONERVATION COMMISSION Hoyle H. Hamilton THRU :Lonnie C. Smith Commissioner Ben LeNorman Petroleum Inspector December 7, 1981 Witness BOPE test on · Arco', s Kuparuk iA-ii, Sec. 5, TllN, R10E, UM Kuparuk River ~ Friday, December 4, 1981: I departed my home at 4:30 p.m. for a 5:00 p.~. sho~up and Scheduled' 6:o0'p,m, ~departure'via wien Flight #21 for Deadhorse. "Howe~er~'the''' flight~Was delayed until 7:00 p.m. Weather: ",i'!2°~,. 1°w 0VercaSt~ '"light"wind. saturday., December 5, 1981~ ~.Sta~.~ding by..on iA-11. Sunday,. December. 6, 1981: ~Tests began at 10:00 a.m. and were completed at 11:30 a.m. BgPE %est report is attached.' '~ .I departed Deadhorse via W~en Fl%ght %20 at 8~30 p.m. arriving · n Anchorage via FiarbankS ~'at lO:~55~p.~.m, ~d. at my homel at · 11: 25 p.m. ~" ~ Monday,~ December ...7.., 1981:' "Kirk white, Arc? d~i~ling foreman advised by phone' '~he' win~ 9~'"~0ff'~ ~e' ~i~ilng spool' w&s changed out and tested t6~'' ~000 ~pSI~I ~i~ ~', :,~ In summary, I witnessed successful BOPE test On Arco's Kuparuk iA-ii. BL :vdl 4/81 ("' ?ATE OF ALAs1%\ ALASKA OIL uAS CONSERVATION C(~4bIISSION B .O. P .E. Inspection Report Operator /~F~ Well /<'~,/~,,~,~7 ,., ~tion: Sec ~il linq ~n~a~or "~0 ~_~.,~ ,7 Rig ~ ~ ''~ / RepreSentative .. Cas±ng Set @ ~.?y& £t. ~ep~esen~at±ve~e'-,~J ~,'~?,',~"'X-~,' Location, Genera] Well Sign Ceneral Housekeeping_ _ Reserve pit ~ /<~ _ Rig f)/, .... BOPE Stack Annular Preventer-- Pipe ~ams Blind Rams Choke Line Valves H.C.R. Valve Kil 1 Line Valves. Check Valve Test Pressure ACCUMUIATOR SYSTEM Full Charge Pressure_ ~OoO psig Pressure After Closure 7~, oO psig Pump incr. clos. pres. 200 psig. Ful 1 Charge Pressure Attained: ~~ t '~ O ~ psig N2 -' ~-~- ,'30..~,.C~O'..o,, / ...... Controls: Master ~:D min ~/O sec. min ,_~,-~ sec. ,., ~}/./.l.B__l._in_d%_..~itch cover ) c~..r Kelly and Floor Safety Valves - Upper KellZ .Test Pressure Lomr Kelly. Test Pressure Bal 1 Type 4f)/C Test Pressure "' ~:" Test Pres sure Ins ide BOP Choke Manifold Test Pressure No. Valves. No. flanges. ,~,J[O A~j ustable Chokes / Hydrauically operated choke Test Results: Failures / Test Tzne.' //';~ hrs... Repair or Replacement of failed equipment to be made within days and Inspector/Ccmmission office notified. Distribution orig. - AO&4CC cc - Ope'rator ' cc - Supervisor Inspector November 27, 19 81 Mr. D. S. Smiley Senior Drilling Engineer ARCO Alaska Inc. P. O. Box 360 Anchorage, Alaska 99510- Re~ Kuparuk River Field No. lA-11 ARCO Alaska Inc. Pemit No. 81-173 SUr. Loc.~ 809~FSL, 490'FWL, Sec 5, TliN, R10E, Bo~os/iole LOO.l 481'FSL, 709'FEL, Sec Dear Mr. 8miley~ Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A continuous directional survey is required as per 20 AAC 25..050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in .Alaska .and their drainage systems have. been classified as important for the spawning or migration of anadromous fish. Operations in these areas are Subject to AS 16.50.870 and the regulations promulgated thereunder (Title Alaska Administrative Code}. Prior to commencing operations you may be .oontacted by the Habitat Coordinator~s office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18- Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. D. S. Smiley -2- Kuparuk River Field No. 1A-11 November 27, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- s.entative of the Commission may be present to witness testing of blowout preventer equipment before surface casing shoe is dr tl led. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ver~ truly yours, H- Hamilton Chairman of BY O,~.9~ 07 T~ O~,.~s~o~.~ Alaska Oii & Gas Conservation Commission Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. ~HH ~be SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 25 November 1981 CC #40260 (B12) ARCO Alaska, Inc. Mr. P; B. Norgaard, President P. O. Box 360 Anchorage, Alaska 99510 Subject: REVISION TO LETTER OF NON-OBJECTION DATED NOVEMBER 19, 1981 ADL-25647 KUPARUK PROJECT - DRILL SITE A, NORTH SLOPE, ALASKA Dear Mr. Norgaard: On November 24, 1981 Mr. Ron Podboy of your Anchorage Land Department telephoned a correction of the bottomhole location for Kuparuk Well 1A-11 at the referenced drillsite. According to Mr. Podboy the revised bottomhole location is within Section 8, T11N, R10E, U.M., instead of Section 7, TllN, R10E, U.M. The distance from referenced section lines was described as unchanged. In light of this new information Sohio Alaska Petroleum Company revises its letter of non-objection of November 19, 1981 so as to grant the same non-objection to the drilling of the proposed well to the bottomhole location at 1320' FSL, 1320' i~EL Section 8, TllN, R10E, U.M. All other conditions and understandings set out in the previous non-objection letter of November 19, 1981 are otherwise unaffected by this revision. Sincerely, PR/PJN/dj cc: P. Hardwick J. Pawelek Nov Alaska 0il & Gas Cons. Commission Anchorage Paul J. 'Martin Assistant General Manager (Operations) SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 276.5111 November 19, 1981 Mr. P. B. Norgaard, President Arco Alaska Inc. P.O. Box 360 Anchorage, AK 99510 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Letter of Non-Objection ADL-25647 Kuparuk Project - Drill Site A, North Slope, Alaska Dear Mr. Norgaard: Arco Alaska Inc., by letter of November 16, 1981, has requested concurrence from Sohio Alaska Petroleum Company for the drilling of deviated well Kuparuk lA-11 (Section 5, Township 11 North, Range l0 East, Umiat Meridian 809, ft. FSL, 490 ft. FWL) with targeted bottom hole location at I320 ft. FSL, 1320 ft. FEL, Section 7, Township 11 North, Range l0 East, Umiat Meridian. The letter of non- objection has been requested pursuant to 20 AAC 25.050. This .is to advise you that Sohio Alaska Petroleum Company does not object to the drilling of the proposed well, Kuparuk 1A-~. Sohio's concurrence to the drilling of well Kuparuk 1A-Il is with the understanding that Arco Alaska, Inc., Sohio Alaska Petroleum Company and other affected Working Interest Owners will proceed in good faith toward an equitable unitization of the Kuparuk reservoir and that such unitization will be achieved prior to the commencement of production from this well. RECeiVED Sincerely, NOV 2 5 198! Paul;. Martin Alaska 0il & ~a~ C,~ ¢~r~m~sion Ancho~'~ge '" Assistant Gener~ Manager (Operations) PJM:PR:blm C: Mr. P. Hardwick Mr. J. Pawelek ... ~RCO ~ska, Inc. P. O. ~ox 99510 lB, 198I -. ~. Sylvester R. 5ai~; Lan~ l~tter of Won-Objection - ARCO Alaska Lease ADL 256&7, .~LK 465 . .: :~-~.' '.v}:.. -~..L',:. _ ' :!~:.'-i? ~ refer -to your letter of November 16, 1981, in ~h. ich you a~ised us · .'"'~:/~'~ of your h~m~ion to drill K~pa~ -s~ ~-I!, on Kupar~ Drill Site :.-:~:;:'b/'~ ........ :" 'BP' ~as~ ~.loratlon Inc., as a affected LeSse.e of Rec~rd, hereby ,,?~ ...... ~fi~ that i~-~s no objections to the application for Pe~t to .... '...::..-.- ~1 oz Deepen the above ~I1. Thi~ Letter of Non~bJection is, :'-~'.~;:~:L" ' ~ever ~itten au the ~u~etst~in~ that ii, Iv ~d bo~ide ~, :~{~:~.,:,, s~es to uttke the ~paruk ~ese~,a~ in a fai~ and equitable met ..... ~:,~:,:-;.. -.. are agopt~d by the parties ~vo~vea, ~ch that aid pa~tks ~sy agrae ::~L.~;?~ ~'~:' l~tlons there,, prior to the co~eneement of ~y production from the .,, .... .. ~-:.:.~ :..,.. Presidemt -. u.: ,~. NOV ? ~ ~ C:,q~'~ "'"~"~:~,~" ' . ~aska Oil & Gas Cons. CotnmJssb~ -..:~5:.~ _ -c.' . . ..~... . . . . , ,~:, ~ii~ ......... . ......... .~ -.r'~,~-;~]--.:.~i~-:-:;..~*.z..~,,. · ..,,:,~,.-:. ;:r.,,..,. :.., ... . . ? '?:.~.~?' .Y.' . ' ~}~:~.~:..~:;~ . .. ,... ARCO Alaska, Inc./ Post Office E . 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 5, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Kuparuk 1A-11 Dear Sir: Enclosed please find the following: · 2. 3. 4. 5. 6. 7. The application for Permit to Drill Kuparuk lA-11 and a $100.00 check for the application fee. A diagram showing the proposed horizontal and vertical projections of the wellbore. An as-built drawing of "A" pad indicating the proposed surface location. A proximity map indicating the relative locations of Kuparuk wells IA-5, lA-6, and 1A-lO. A determination of maximum pressure to which BOP equip- ment could be subjected. A diagram and description of the surface hole diverter system. A diagram and description of the BOP equipment. In addition, pl.ease note that this well's bottom hole location will require letters of Non,Objection from BP Alaska Exploration Inc. and Sohio Alaska Petroleum Company. A copy of the replies from the affected operators will be forwarded to your office as soon as possible. If you should have any questions, please do not hesitate to contact me at 263-4272. Si ncer'ely yours, D. S. Smiley Sr. Drill i.ng Engineer . DSS/TJB: 1 tc Enclosures RE .EIVF. D NOV 1 6 t~,~] A.~aska 0il & Gas Cons. Comrnissio~ Anchorags ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCornpany PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL [~ SINGLE ZONE DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name ~EC~IV'~ ~ Kuparuk River Field 809'FSL, 490'FWL, Sec. 5, TllN, R10E, UM At top of proposed producing interval 10. Well number 1320'FSL, 1320'FEL,.Sec. 8, TllN, RIOE, UM ~.~Oq_~ 61n~'!~ lA-11 '];C~11 Field and pool At total depth . 481'FSL, 709'FEL, Sec 8, TllN, RIOE, UM~las~aOi~&GasOo~.~ n~ .... ~uparuk River Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. A,~c.~orag9 _v "mSS~paruk Ri ver 0i 1 Pool 61'GL, 66'P.D, 100'RKBI ADL 25647 ALK 465 12. Bond information (see 20 AAC 25..025) Type Statewide Surety and/or number Fed. :[ns. C'o. 8088-26-2~m°unt $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW Deadhorse miles at TD 481 feet A-10/veIl -i~ 120' {'a ~llY, f,.~¢,~feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 9906' MD/6822 'TVD feet 2469 1_ 1 [27/81 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2'b~b psig@ ~)0OF Surface KICKOFF POINT 500 feet MAXIMUM HOLEANGLE51.?I (see 20 AAC 25.035 (c) (2)3170psig@ 6170 ft.'T~{TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24 16" 65# H-40 ~elded 80' Pad IPad 114' ~ 114' ~ 200CF ~Pad 3340 i 13½ 10-3/4' 45.5# K-55 BTC 3305 Pad ~ I 2700 l133sx Fondu +250sxAS] 8-3/4 7" 26# K-55 BTC 9871 Pad ~Pad 9906 I 6822 1095sx Class "G" ~ I I I I 22. Describe proposed program: ARCO Alaska, Inc. proposes to drill a Kuparuk River Field, Kuparuk River Oil Pool devel- opment well to approximately 9906'MD, 6822"TVD. Selected intervals will be logged. A 20" x.2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will .be tested upon installation and weekly thereafter Test pressure will be 3000 psig. Expected maximum surface pressure will be 2656 psig based on cooling of a gas bubble rising at constant volume. The well will be completed with 3½" 9.3# J-55 buttress tubing. Non-freezing fluids will be left on uncemented.annuli thru the permafrost interval 'Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon conclusion of job. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED TITLESr. Drilling Engineer DATE 11/6/81' The space below for ~o CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number []YES ~;~] NO []YES ~'NO ]~YES []NO[ SO- Permit number Approval date ~/.-/~/S 11/27/81 I SEE COVER LETTER FOR OTHER REQUIREMENTS . .~. ~. ~ -__ ' BY_~ ,COMMISSIONER DATE l~o~ze~z: 27. 1_981 APPROVED .."Z~r '' ~', by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 SRNI~J SPJ~S TV0~-$340 SRNDS*-! TV1~,6445 PeIN TVD~:6571 ~JGO ~T · I 1 1''---~~ ! WELL A1 Y = 5,971,467.25 X : 540,'1 78.17 ~ ' LAT = 719°19'58.741'r ~ > < , LONG = 1 49°40' 26. 679'' ~ _~ ~ WELL A2 ~ = .5,971,34'6-82 ' LAT : 70019'57-557'' ~ ~ ~ LONG = 149°40'26.693'' ~!~I ~~ '1 ~ ~, x = 5~o 178.5~ ~i~~ A~ _~~ LON~ = 149°40'-26.707" ...... '1 > WELL A~' Y = 5,971,~106.83 ~ ~~,~ x = s~o, ~78,s~ "~-- LONG = 1~9°~0'26.725'' ~ ' WELL A5 Y'= 5 970,986 86 t~i~ '" ~ X = ~0. _~ ~ ~il A~ . . LAT = 70o]9'5~.0]6'' < } ) ",~ LAT : 70°19'52.834'X: 540,1,8.71 YJi A~ LONG = 149°40'26.757'' ..... F ~~, ~.. ~ ~ELL A7 Y = 5,970,746.73 -I ~ ~] X = 540,178.55 i ; ~ ~'~ ~ ~,~ , F . LAT = 70o19'51.654" ~- '~~.~~ ']: ......... LONG = 149°40'26.781' --~-, ~~~ ---. ~ ~ ~,+ - '~ UEL: A8 ~ =. S,970,~6.78 ~ , x = 540, ]78.59 ~ S~~ i ~ LAT = 70°19'50.475' 7 ~ (T,,~, ~ ,~ , .,,. I HERE~Y CERTIFY THAT I AN --C,, i'." ':'~ · ..~,. PROPERLY REGISTERED AND LICENSED .... ,2 ...... .-c; ' TO PRACTICE LAND SURVEYING IN · t. ~:'~" ' ,': · THE STATE OF ALASKA AND THAT ~ . /' .. ~ ............ ~ ............ THIS PLAT REPRESENTS AN AS- ,' ~, L.~..h~.~i, ...,~ .:' ..~..:7'-~ ..'.'. ,.'/ DETAILS ARE CORRECT, ~S OF: . ~. .. ~ I I~: I I IIIII I - ~_/~ I - I iiii ii i ii Allan,ticRichlieldCompany ~ ,DATE: DRAWING No: NORTH AMERICAN PRODUCING DIVISION IO.~-~o. ALASKA DISTRICT--. KUPARUK i ii i, . ..... i i -'-~'-'-~, ..... ;:- .:~:~."i 'PRD i:t; 'NELL NO~ !!1' PROPOSEO ......... i ................. ! KUPRRUK FIELD, NORTH SLOPE, ~RLRSKR I ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3170 psig from RFT & pressure buildup date. This pressure @ 6070' SS = 6170'TVD will be balanced by.9.9 ppg mud wt. Normal drilling practice calls for 10.4 ppg wt prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 167 psi over- balance. It is anticipated the 'surface BOPE equipment could be subjected to a maximum of 2656 psi during drilling operations. Derivation assumes a gas kick at reservoir temperature and pressure (160°~F, 3170 psi), gas migration to the surface w/o expansion, and cooling to 60UF cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi : volume initial (reservoir) Pf = pressure final (surface) Tf = temperature final (surface) Vf = volume final (surface) PiVi. = PfVf. Ti Tf Since Vi = Vf ie no expansion = Pf Then Pf : P-T : (3185 psia)(60°F + 460) T~. Tf ~ (160OF + 460) Pf = 2671 psia = 2656 psig Surface Div( _.r System 1. 16" Bradenhead. 2. 16" x 20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/10" side outlets. 4. lO" ball valves, hyraulically actuated, w/10" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell nipple. Maintenanc~ & Operation ~' 1. Upon initial installation close annular I preventer and verify that ball valves I have opened properly. I 2. Close annular preventer and blow'air ~._ through diverter lines every 12 hours. 3. Close annular preventer in the event L 16" Conductor that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind -diverter line. Do not shut in well under any circumstances. .. RNNUL~.q PR~VENTOR ~t-5/8" 5000 PSI R~RRA~ BOP ~"'~'"~ ~a~,N/-- · 2. 3. 4. 16" Bradenhead 16" 2000 PSI x 10" 3000 PSI casing head 10" 3000 PSI tubing head 10" 3000 PSl x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 5000 PSI drilling spool w/choke and kill lines 7. 13-5/8" 5000 PSI pipe rams 8. 13-5/8" 5000 PSI blind rams 9. 13-5/8" 5000 PSI annular ~ BLIND RRMS 8 ) · IRE RRHS 7 ~DRILL!NG '~ L~ SR6OOL , ') I ACC~IULATOR CAP$CITY TEST l. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WIT'rt HYDRAULIC FLUID. 2. ASSURE THAT ACCtR~ULATOR PRESSURE IS ,~000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SI~.iULTANE- OUSLY AND RECORD THE TIME AND PRESSURE REHAIN- I[IG AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECS:;DS CLOSING TIllE AND 1200 PSI .... REMAINING PRESSURE. 1~,5/8" BOP STACK TEST FILL BOP STACk( AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DC'JN SCRE'~S ARE FULLY RE- TRACTED. PREDETEF;,1INE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELL:-:EAD. ' RUN IN LOCK DONN SCRE:JS IN HEAD. 3. CLOSE AN~IULAR PRE'IENTER AND CHOKES AND BYPASS VALVES ON NANIFgLD. 4. TEST ALL CCHPONENTS TO 250 PSI AND HOLD FOR lO MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. .INCREASE PRESSURE TO 3000 PSI AND HOLD FOR MI MUTES, 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DCWNSTRE~:~.I PRESSURE TO ZERO PSI TO TEST VALVES. TEST RFJ, IAINING UNTESTED t,!ANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREA,'4 OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. -. 9. OPEN TOP SET OF PIPE PJ~.IS AND CLOSE BOTTC.',I SET OF PIPE ,:Gq,MS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. ll. OPEN BOTTCM SET OF PIPE RAMS. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLCSE 5LIND P. ANS AND TEST TO 3000 PSI FOR 10 [IINUTES. BLEED TO ZERO PSI. 12. OPE?I BLIND RA~,IS AND RECOVER TEST PLUG. MAKE SURE NANIFOLD A~;D LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POS I T I ON. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE 80P TO 3000 PSI WITH KGC~tEY PIJ,"IP. 15. RECORD TEST I~IFO,~.tATIO;I ON BLONOUT P~EVE~ITER TEST FOR/.! SIG:i AND SEND TO C, RILLI~[G SUPER- VISOR. 16. PERFGPJ! CC~:PLETE 8OPE TEST ONCE A '~EEi( A:;D FUNCTICNALLY OPERATE BOPE C, AILY. CHLCK LIST FOR NEW WELL PE~IITS ITEM APPROVE DATE (1) Fee (2) Loc tfiru 8) (3) Admin --¢ thru 1 1) / ! (4) Casg (12~thru J/-7(~2~/20) le 4. 5. 6. 7. 8. 9~ 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. (5) BOPE ~,~ //-4~-g/ ~21 thru 24) 21. 22. 23. 24. (6) Add: 25. Company Lease & Well No. Is the permit fee attached ............................... Is well to be located in a defined pool ................. Is well located proper distance from property line ...... Is well located proper distance from other wells ........ Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore plat included'. Is operator the only affected party ....................... Can permit be approved before ten-day wait .................. Does operator have a bond in force .......................... Is a conservation order needed .............................. Is administrative approval needed ........................... Is conductor string provided .................... ' ............ Is 'enough cement used to circulate on conductor and surface . Will cement tie in surface and intermediate or production str Will cement cover all known productive horizons ............. Will surface casing protect fresh water zones ............... Will all casing give adequate safety in collapse, tension and Is this well to be kicked off from an existing wellbore ..... Is old wellbore abandonment procedure included on 10-403 .... Is adequate well bore separation proposed ................... YES NO ..... · / eleee eeeel burst eeeeeeee~. ' Is a diverter system required ................. ~ Are necessary diagrams of diverter ~ B;~ e~ip~en[ a[;~g~;~sis ' ~::"121~ Does BOPE have sufficient pressure rating - Test to ~c~cO,,~ p Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. REMARKS 14 .... // Additional requirements ............................................. ~ Additional Remarks: Geology: Eng in%e_r ing: ~ WVA · rev:'. 03/10/81 INITIAL [ GEO. UNIT 'ON/OFF POOL,, CLASS STATUS..t AREA NO. SHORE. Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. ,. No 'special 'effort has been made to chronologically organize this category of information. YE~IFICA%ION ~ISTING DVP O0~.H05 VERIFICATION LISTING PAG~ ! ** RECL HEADER ~* SERVICE NAME :$ERVIC DATE :~2/02/17 ORIGIN : CONTiNdATION # :01 PREVIOUS REEL : COMMEN~S :REEL COMMENTS *~ TA~;~ HEADER ~* SERgICE NAME :SERVIC DATE :~2/02/17 O~IGIN :1070 TAPE ~A~E :62372 CON~iNdATION ~ :01 PREVIOUS TAPE : COMmOn, TS :TAP~ COMMEN~S ** f'£h~ HEADER F!bE NAME :SERVIC.O0i SERVICE NAgE : VERSIO*~ # DATE ; MAXi~[]~ bENGTH : 1024 PREVIOUS FILE ** iMF~]RMATION RECORDS MNE~ COMTEMTS CN WN : FN RANG: SECT: COUP: STAT: CTRY: ATLANTIC RICHFIELD CO. IA-Il KUPARUK iOE 5 NO. SLOPE AhASKA MNE~ CONTENTS TYPE 047 UNIT TYPE CATE SIZE CODE 000 000 022 065 000 000 005 065 000 000 008 065 000 000 003 065 GO0 000 003 065 000 000 001 065 000 000 010 065 000 000 006 O65 000 000 004 065 ONIT TYPE CATE SIZE CODE 000 000 007 5VP ug'~.H05 VERIFfCATiOi~ LI6TING ** RECORD TYPE 047 ** RECORD TYP~] 047 ** ** CO?,I:'It;NTS ** JOB :~ t, 0707,62372 DIL RU~.I #1, L{3GG~]D 12-DEC'81 TOP LU~I I~iTERVAL CASir~G-GOGGER TYPe; Hr]hE FLUID DENSITY VISCOSITY P~ RM ~ ~iEAS. Y~MP. RMF ~ MEA$. TEMP. RMC ~ ~EAS. TEMP, RM 0 ~HT = 9300 FT. = 2947 FT. = I0.75 IN. i.a 2947 FT. -- 8.75 IN. -- SOLIDS [~ISPERSED : ! 0.4 bB/G :468 : 9.5 = 5.2 C3 : 3.86 [~ 83 F = 3.70 t.a 83 F = 2.40 ~ 83 F = 2.19 La 151 F MATRIX ~AND~TONE PAGE LVP 00<~.H05 VERIFICATION LISTING PAGE 3 ** DA$A F[)R~T RECORD ** ENTRY :~bOCK5 TYPE 9 0 DATUN MNEN DEPT SFL0 SP NPHi RHOB CALl DRHO NRAT NCNb FCNL SPECIFICATION SERVICE SERVICE ID ORDER $ i SN FDN $IZ~ 1 4 1 ** D~Ta DEPT GR NCNb DEPT SP NCNb DEPT BP GR NCNb DEPT BP GR NCNb GR 9518.000 -999.250 -999.250 20944.000 9500.000 -40.906 1170.000 20944.000 9400.000 -44.90b 113,063 2324.000 9300.000 -58.625 100.625 2004.000 920~.000 -89,93~ 88.000 2~60,000 BLOCKS UNiT API AP1 LO~'~u TYP~] FT 0 0 OHMs] 0 0 OMMM 0 0 OHMM 0 i2 MV 0 1 (;APl 7 31 PU 0 68 G/C3 0 35 GAPI 42 31 IN 42 28 G/C3 0 44 0 42 0 34 SFLU GR CADi GR CALl FCNb SFLU Ga CALl FCNh SFLU GR CADI FCNL CALI FCNb RMPR CODE 66 73 a5 66 ENTRY 1 6O ,lin 0 APl ~PI FILE SIZE CLASS MOD NO. 0 0 0 4 0 0 0 4 0 0 0 4 46 0 0 4 0 0 0 4 32 0 0 4 2 0 0 4 i 0 0 4 32 0 0 4 3 0 0 4 0 0 0 4 I 0 0 4 92 0 0 4 93 0 0 4 -999.250 ibm '999.250 NP~I 8.750 DRHO 6108.000 2.391 ibm 1170,000 NPHI 5.258 DRHO 610~,000 2,475 I~-ab~ i13.063 NPMI 9.117 DRHO 616.000 2,480 100.525 9.312 DRHO 488.750 8.438 ~.000 NPHI 9.46! DRMO 903.O00 'PROCESS SAMPLE RCPR LEVEL CODE 0 1 68 0 i 68 0 1 88 0 1 68 0 i 66 0 1 68 0 I 68 0 1 68 0 I 68 0 1 68 0 i ~8 0 1 OB 0 i 68 0 1 68 -999,250 40,625 '1.323 RHOB NRAT 2,180 40.625 -1.323 RHOB NRAT 2.572 38,336 0,042 RHOB NRAT 46,729 0.037 RHOB NRAT 5,844 31,5~3 0,020 RHO~ NRAT -999.250 0.735 3.129 2.~47 0.735 3.129 2.502 2.461 3,264 2.291 2.412 3.748 5.395 2,a02 2.922 LYP DEPT NCNL DEPT SP G~ NCNb DEPT SP NCNb DEP'i' SP NCNb DEP~ SP GR NCNL DEPT $P NCNL DEPT SP NCNL DEPT SP GR NCNL DEPT NCNb NCNL DEPT SP GR NCNL 91 88 1 18 ~7 . -9 . -9 2 -9 . -9 82 . -9 81 . -9 VERIFICATION OO.O00 SFLU 97.188 GR 91.625 CALf 88.000 FCN[, 00.000 SFLU 95,938 GR 71.000 CALI 84.000 FCNL O0,OOO SFLU 90.375 GR 45,938 CALI 54.000 FCNL 00,000 SFLU 20,063 GR 14,813 CAbI 66.000 FCNL 00,000 SFhU 54.438 GR 17.063 CALl 51.000 FCNL OU.O00 SFLU 16.641 GR 47,250 CAL~ 99.250 FCNL 00.000 SFLU 19,078 GR 08.250 CALI 99.250 FCNU 00.000 SFbU 40.~88 GR 50.375 CALI 99.250 FCNL 00.000 SFbU 34,15b GR 57.125 CALl 99,250 FCNL OO.O00 SFLU 11.469 GR 13.688 CALl 99.250 FCNb 00.000 SFLU 13.164 GR 15,688 CALl 99,250 FCNL 5ISTiNG 4,867 91.625 9.273 703.500 5,410 71,000 9.664 889.500 33,938 45,93@ 9.242 1239.000 2.059 114.813 9.922 458.500 2.232 i17.063 1i.391 481.750 3.334 ~47,250 I1,000 -999.250 4.195 308.250 10.109 -999.250 3.604 250.375 11.000 -999.250 4.652 157.125 11,188 -999,250 3.787 113,688 10.484 -999.250 3.699 115.688 11.1~5 -999.250 NPHI DRHO IbM NPHI DRHO IbM NPMI DRHO NPHI DRHO NPHI DRHO NPHI DRHO NPHI DRHO IbM NPH~ DRHO NPHI DRHO NPHI DRHO DRHO 4.8§3 35.i56 0,031 5.918 3t.494 0.008 27.813 23.828 0.039 2.021 47.656 0,019 2,469 40.234 0.027 3.207 -999.250 -9.993 3.091 -999,250 -9.993 3 53'7 -999 ~ 250 -9.993 3.801 -999,250 -9.993 3.39I -999.250 -9.993 4.535 -999.250 -9.993 I LD RHOB NRAT ILD RHOB NRAT iLD RHOB NRAT ILD RHOB NRAT ILD RHOB NRAT ILD RHOB NRAT RHOB NRAT ILD NRAT RHOB NRAT RH[IB PAGE 4.953 2.422 3.102 5.770 2'406 2.936 23.781 2.699 2.391 1.990 2 '326 ,. 2.387 2.387 3.518 3.164 -9,993 -9.993 3.584 -9.993 -9.993 3.547 -9.993 -9.993 3.668 -9.99~ -9.993 3.387 -9.993 -9.993 4.613 -9.993 -9.993 DVP 009.H05 VERIFICATION LfSTING PAGE 5 DEPT SP NCNb DEPT SP NCNb DEPT SP NCNL DEPT SP NCNb DEPT NCNb DEP? SP NCNb DEPT SP NCNb DEPT SP NCNL DEP'I' SP NCbib DEP~ SP NChL DSPT SP 8000,000 SFLU -5. ~7 GR 125. 0 CALl -999.250 FCNL 7900,000 SFLU -37,875 GR 137 250 CALI -999:250 FCN~ 7800.000 SFLO =59.688 GR 136.875 CALl -999.250 FCNL 7700.000 SFLU -~4.8a4 GR 125.500 CALl -999.250 FCNL 7500,000 SFLU -51.588 GR 177.375 CALl -999.250 FCNL 7500.000 SFLU -7.371 GR 157.875 CAGI -999.250 FCNL 7400.000 SFLU -12.422 GR I51.750 CAL~ -999,250 FCNL 7300.000 SFLU -2~.078 GR 178.375 CALl -999.250 FCNL 7200.000 SFLU -52.938 GR 205,~75 CALl -999.250 FCNL 7100.000 SFLU -54.375 GR 158.125 CALf -999.250 FCNL 7000,OOO 5FLU -59.625 GR 9~.750 CALl 2 125 10 -999 137 9 -999 3 136 ~0 -999 3 125 13 -999 4 i77 -999 2 157 i0 -999 2 151 10 -999 1 178 i0 -999 4 206 11 -999 I 15~ 11 -999 2 98 .729 ,000 .3O5 .250 .352 ,250 .883 .250 ,857 ,875 .969 .250 ,39! .500 ,203 ,250 .098 ,375 ,414 ,250 ,023 .875 .04'7 .250 ,49z .750 .094 ,250 .770 .375 .492 ,250 .020 .875 .3i2 ,250 .924 .125 .461 ,250 ,029 50 NPHI ILM DRHO IbM NPHI DRHO NPHI DRHO NPHI DRHO DRHO NPMi D~HL) NPHI DRHO NPH! DRHO ILM NPHI DRHO NPHI DRHO 2.859 -999,250 -9,993 4,328 -999,250 -9'993 3.154 -999,250 -9.993 3,973 . -999,250 -9.993 3,900 -999.250 -9.993 2,131 -999,250 -9'993 - 250 -9.993 2,047 -999.250 -9,993 3,607 -999,250 -9.993 1,813 '999.250 -9,993 2.072 -999.250 -9.993 I LD RHOB NRAT RHOB NRAT RHOB NRAT RHOB NRAT IDD RHOB NRAT ILl) RHOB NRAT RHOB NRAT ILL RHOS NRAT ILL RMO[~ NRAT ILl) NRAT RHOB NRAT 2.939 -9.993 -9.993 3,482 -9,993 -9.993 3.168 -9.993 -9.993 3.924 -9.993 -9.993 3.859 -9.993 =9.993 2.260 -9.993 -9.993 1,~64 -9,993 -9,993 2.150 -9.993 -9.993 3,602 '9.993 '9.993 1,841 -9,993 -9.993 2.092 -9.993 -9,993 LVP O0~.H05 VERIFICA']['IO~, NCNb -999,250 FCNL DCPT 6900.000 SFLU Sp -50.938 GR GR 77.188 CALI NC[~L -999.250 FCNL DBPT 6800.000 5FbU Sp -57.938 GR GA i10.250 CALl NCNb -999,250 FCNL DEPT 6700.000 SFLU SP -47.375 GR GR 67.500 CAbi NCNb -999.250 FCNL DEP~~ 6600.000 8F[~O SP '40.719 GA GR 81'000 CALl NCNb -999.250 FCNb DEPT 6500.000 SFLU Sp -51.65~ GR GA 80.250 CAbI NCNb -999,250 FCML DEPT 6400.000 SFLU Sp -31.625 GR GR 108.188 CALl NCNb -999.250 FCND DEPT 6300.000 SFLO Sp -37.906 GR GR 115.312 CAB] NCNb -999,250 FC~b DEPT b200.O00 SFbO Sp -53.688 GA GR 9~.750 CAb[ NCNb -999.250 FCNL DEPT 6100.000 SFLO Sp -47.906 GR GR 117.563 CALI NCNb -999.250 FCNb DEPT 6000.000 SFLU SP -57.906 GA GR 97.000 CALi NCNb -~99.250 FCNL DEPT 5900.000 $FLO SP -60.625 G~ LISTING -999. . 77. 10. -999. 110. 10. -999. . 67. 10. -999. . 81, 11. '999. 80. 10. -999 . 108. 10. -999. . 115. 10. -999. 94. 10. -999. t 117, 11, -999. 97. 11, -999 25O 2O5 188 8O5 250 688 250 6~1 250 939 5O0 891 25O 758 000 016 25O 199 25O 969 250 002 I88 727 250 408 3!2 844 250 527 750 828 250 355 563 672 250 531 000 750 250 270 312 NPHI DRHO IbM DRHO I~M NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHi DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM 1.975 -999.250 -9.993 2.699 -999.250 -9.993 3.~79 -999.250 -9.993 2.83B -999.250 -9.993 2,746 -999.250 -9.993 1.962 -999.250 -9,993 2.553 -999.250 -9.993 2.67~ -999,250 -9.993 2,543 -999.250 -9,993 2.039 -999.250 -9.993 3.475 -999.250 IbD RHOB NRAT ILD NRAT RHOS NRAT ill) RHOB NRAT ILl) RHDB NRAT RHOB NRAT NRAT ILD RHOB NRAT ILl') RHOB NRAT IbP RHOB NRAT IbP PAGE 1.971 -9.993 -9.993 2.738 -9.993 -9.993 3.352 -9.993 -9.993 2.988 -9,993 -9.993 2.814 -9.993 -9.993 2.035 -9,993 -9.993 2.568 -9,99~ -9.993 2.727 -9.993 -9.993 2,658 -9'993 -9'993 2.~43 -9.993 -9.993 3.637 -9.993 LVP O0~.H05 VERIFICATION LISTING PAGE 7 GR NCbL DEPT SP GR DEPY SP GR. NCN6 DEPT SP NC~:~b DEPT SP NC~L DEP:£ SP GR NCNL DEPT SP GR NCNn DEPT NC~L DEPT SP NC~L DEPT SP NC~ DEPT SP NCnb DE?T 95,312 CALl -999.250 FCN6 5800.000 SFLU '62.938 G~ 87.063 CALl -999.250 FCN5 5700.000 SF5U -50.938 G~ 72.000 CALl -999.250 FCNb 5~00.000 SFLO -55.!56 GR 113.o8~ CALl -999.250 FCNL 5500.000 SFDU -53.93~ GR 112.938 CALl -999.250 FCNb 5400.000 SFLU -6i.406 GR 98.875 CALf -999.250 FCNL 5300,000 SFLU -68,438 GR 89.813 CALl 2312.000 FCNb 5200.000 SF5O -64.938 GR 88.125 CALl 2292.000 FCNL 5100.000 SFLU -59.438 GR 80.250 CALl 2375.000 FCNL 5000.000 -44.906 GR 71.312 CALl 239~.000 FCNL 4900.000 SFLU -51.156 GR 74,438 CALf 2~00,000 FCND 4~00.000 SFLU 11.336 -999.250 4.203 87.063 12.008 -999.250 5.336 72.000 12.172 -999.250 4.000 113.688 13.398 -999.250 3.076 112.938 i3.422 -999.250 3.590 98.875 13.102 -999.250 2.715 89.813 i2,617 570.000 3.418 88.125 14.21i 601.000 4.102 80.250 15.820 580.000 3,012 71.312 14,180 648.000 4.656 74.438 14.266 761.000 3.822 DRHO DRHO NPHI DRNO IbM NPMI DRHO IbM NPMI DRHO NPHI DRHD NPHi DRMO NPHI DRHO IL~ ~PH1 DRMO IbM NPHI DRHO IL~ QRHO -9.993 4.277 -999.250 -9.993 5.266 -999,250 -9,993 4.359 -999.250 -9.993 3.342 -999.250 -9.993 3.971 -999,250 -9.993 3.275 41.699 0.076 4.047 3~.574 0.052 4,969 37.500 0,012 3.295 37.695 0.032 4,824 31.543 0.0~1 4.898 NRAT ILD RHOB NRAT ILL RHOB NRAT IbD RHOB NRAT RHOB NRAT ILO RHOB NRAT RNOB NRAT I~P RHOB NRAT RHOB NRAT ILD RHOB NRAT RHOB NRAT -9.993 4.305 -9.993 -9.993 5.199 -9.993 -9.993 3.996 -9.993 -9.993 3.662 -9.993 -9.993 4.42b -9.993 -9.993 3.473 2.309 3.633 4.164 2.334 3.498 5.422 2.281 3.482 3,545 2.297 3.451 5.199 2.244 3.117 5.059 LVP NCN6 DEPT SP NCNb DEPY SP GR NCNb DEPT SP GR NCNb DEPT GR NC~ DEPT SP GR NCWL DEPT .$p NC~ib DEPT SP GR NCNL DEPT SP NCNb D£PT SP GR NCNb DEPT SP GR NCNb OOq. M05 VERIFICATION -71.688 GR 8i.563 CALk 245~.000 FCNL 4700,000 SFLU -80.938 GR 72.688 CAbI 2292.000 FCNb 4600.000' SFLO -89.688 GR 61.375 CAbI 2450,000 FCNb 4500,000 SFbU -101,625 GR 69.938 CALI 2434.000 FCNb 4qO0.O00 SFLU -85,375 GR 86,438 CALl 2029,000 FCND 4300.000 SFLU -103,688 GR 58.375 CALl 2272,000 FCND 4200.000 SFLU -78.875 GR 86,063 CALI 268~,000 FCNb 4100,000 SFLO -95,875 GA 72,500 CALl 2266.000 FCNL 4000.000 SFbO -120.188 GR 36.469 CALl 2412.000 FCNL 3900,000 SFbU -70,125 GR 63,188 CALf 2058,000 FCN~ 3800,000 SFLU -69.625 GA 87,68~ CA~i 2090.000 FCNL UlSTING 81.563 14.719 748.500 5.801 72.688 14.242 618.000 6.352 61.375 12.992 634.000 6.445 69'938 12.297 576,000 6,1!7 86,438 12,828 539,000 5 375 11,836 613,500 7,195 86.063 15.438 673,500 6,840 72.500 14.602 590.500 36.938 36.469 13.508 646.000 6.511 63,188 11,563 496,250 10.227 87,688 11.352 586.500 NPHI DRMO NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO NPHI DRHO IbM NPHI DRHO IbM NPHI ORHO IbM NPHI DRHO IbM NPHI DRMO IbM NPHI DRHO IbM NPHI DRHO 31.689 0,021 5.402 36.182 0,028 ~,578 39,893 0,009 8.281 45,410 0.029 6,520 42,285 0,005 10,828 39.502 0,008 8.172 38,428 0,053 7,344 38,916 0,029 26.391 38.28i -0,009 6,645 47,998 0.033 10.031 35.742 0.019 RHOB NRAT IDD NRA~ RHOB NRAT RHOB NRAT ILL RHOB NRAT I bD RHOB NRAT ILL RHOB NRAT RHOB NRAT RHO8 NRAT NRAT ibp NRAT PAGE 2,268 3,139 5.598 2.246 3,367 6.465 2.164 3.539 8,398 2.225 3,828 6,586 2 309 3:670 11,117 2.098 3,488 8.242 2.309 3.523 7.766 2.289 3,529 26 953 2~094 3.463 7 113 2:275 3.953 11,141 2,258 3.268 V~]RiFICATiDN 00,000 SFLU 76.125 GR 54.344 CALl 02.000 FCNL 00.000 SF50 85,063 GR 55.78i CALI 62.000 FCNb 00.000 SFLU 98.188 GR 50,250 CAbI 02.000 ?CNh 00,000 SFLO 86,436 GR 58.815 CALI 14,000 FCNL 00.000 5FBU 87,625 GR 70.813 CALI 00.000 SFLU 88,625 GR 39.688 CALl 92.000 FCNh 00.000 SFLU 03.375 GR 42.563 CALl 40,000 FCNL 00,000 SFLU 80.625 GR 70.188 CALi 68.000 FCNL 63,906 GR 33,563 CAbI 98,000 FCNL ** FILE TRAiL~iR FILE ~AME ;SEE¥IC.001 SER¥iCE NA~E VE~SIU~< # FILE TYPE NEXT FILE iqA~E : hlSTI~G 12.875 54.344 10,953 600,500 15.563 55.781 11,898 653.000 13,289 50,250 10.789 597.500 9.789 58.813 I0,539 557.500 11.125 70.8!3 I0 719 475:250 10,688 39.688 11,14i 66~.000 12.328 42.563 ii,625 596,5(!0 6.051 12.383 410.500 3.686 33,563 270,750 Ib~ NPHi DRHO DRHO IbM NPMI DRHO ~PMI DRHO IbM NPHI DRHO IbM NPHi DHHO IbM NPHI DRHO ILM NPHI DEMO IbM DEMO 15.945 41.84~ 0.023 17.844 38.574 0.014 13.570 40.625 -0.002 10.250 42.725 0,004 1i.211 46.191 0,015 11.055 36.426 0.015 13.867 4i.846 -0.007 7.750 56.641 0.015 2000,000 58.838 '0.477 ILL RHOB NRAT RHOS NRAT RHOB NRAT ibD RMOB NRAT NRAT RHOB NRAT ILO RHOB NEAT IbD RH[]B NEAT RHOB NRAT 16,172 2.203 3.596 16.359 2.195 3.439 14.i41 2.090 3.525 i1.195 2.160 3.623 12.227 2.188 3.832 11.055 2,127 3.299 14.477 2'100 3.613 8.578 2.125 4.453 13,648 2.049 4.488 LVP O,,,'~,H05 VEHIFICATIOn LISTING *~ TAPE TRAILgH *~ SER~ iC~] NAME : S~]RVIC DATF :82/02/17 ORIG%~! :1070 TAP~ ~ A [~ E :62372 NEXT 'i'APE NAME : SER VlC%'~ NA}" E :SERVIC DATE :~2!02/17 ORIGIi'i : REEI, i.~iA~.lE :REEb iD CO~YIf,~ATIO~ ~ :01 COI~I,:~Et.,~T~ :REEL COMMENTS