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190-065
TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2V-04 50-029-21041-00 183165_2V-04_LDL_31May2023 2V-11 50-029-21311-00 185049_2V-11_Patch_13Jul2022 185049_2V-11_PPROF_28Jun2023 2W-14 50-029-21253-00 184237_2W-14_Patch_21Jun22 2W-16 50-029-21255-00 184239_2W-16_IPROF_12May2023 2X-13 50-029-21197-00 184174_2X-13_PPROF_04Jul2023 2X-18 50-029-22608-00 195160_2X-18_Patch_02Jan2023 3A-15 50-029-21491-00 185283_3A-15_IPROF_17Jan2023 3B-12 50-029-21370-00 185116_3B-12_WFL_30Mar2023 3B-13 50-029-21286-00 185023_3B-13_RCT_02Oct2022 3B-14 50-029-21287-00 185024_3B-14_SCMT_23Jun22 3G-02 50-103-20146-00 190137_3G-02_GR-CCL_02Feb2022 3G-08 50-103-20128-00 190065_3G-08_RPB_25Mar2023 8 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38383 T38384 T38385 T38386 T38387 T38388 T38389 T38390 T38391 T38392 T38393 T38394 2/29/2024 3G-08 50-103-20128-00 190065_3G-08_RPB_25Mar2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:01:58 -09'00' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 3, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Brennen Green ConocoPhillips Well Integrity Field Supervisor Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.07.03 11:18:45-08'00' Foxit PDF Editor Version: 12.1.2 Brennen Green 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8759' feet None feet true vertical 6115' feet 8540', 8542', 8545'feet Effective Depth measured 8342' feet 8071', 8148', 8260'feet true vertical 5835' feet 5658', 5708', 5782'feet 8214-8234' 8310-8350' 8366-8386' Perforation depth feet feet Tubing (size, grade, measured and true vertical depth) 3-1/2" x 2-7/8" L-80 8279' 5794' Packers and SSSV (type, measured and true vertical depth) PACKER: PACKER: PACKER: 8071' 8148' 8260' 5658' 5708' 5782' 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: Sydney Long Contact Email:sydney.long@conocophillips.com Authorized Title: RWO/CTD Engineer Contact Phone: 907-265-6312 Production 8710' Casing 6105'8745' 3657' 3057' 16" 9-5/8" Size 7" measured TVD Plugs Junk measured N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025548 Kuparuk Field/ Kuparuk Oil Pool Phillips Alaska, Inc.Conoco 115' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-065 50-103-20128-00-00 P.O. Box 100360, Anchorage, AK 995103. Address: KRU 3G-08 MD Burst Collapse measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 00 N/A N/A Length 79' 3622' 115'Conductor Surface 323-093 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf 1136 1328360 162 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 168 Baker 47B2 FHL BAKER HB Retrievable BAKER D Permanent 0 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Measured depth 5752-5765' 5814-5841' 5851-5864' True Vertical depth By Grace Christianson at 1:21 pm, Aug 11, 2023 Page 1/9 3G-08 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/9/2023 12:00 7/9/2023 20:00 8.00 MIRU, MOVE MOB P Pull pits and rig off 3G-25X, prep well to be spotted over, back over well center and level 0.0 0.0 7/9/2023 20:00 7/9/2023 23:00 3.00 MIRU, MOVE RURD P Rig up and save out rig over 3G-08 , install lines in cellar for well kill ops // Rig accepted 23:00 on 7/9/23 0.0 0.0 7/9/2023 23:00 7/10/2023 00:00 1.00 MIRU, MOVE RURD P Take on fluids to the pits 0.0 0.0 7/10/2023 00:00 7/10/2023 01:00 1.00 MIRU, WELCTL OTHR T Wait on crew to rig up electrical sensor to tiger tank // Crew did not rig up line until after job start time 0.0 0.0 7/10/2023 01:00 7/10/2023 01:30 0.50 MIRU, WELCTL PRTS P Pressure test tiger tank line 2500 psi // found block valve post choke leaking replaced gasket re-test good 0.0 0.0 7/10/2023 01:30 7/10/2023 03:00 1.50 MIRU, WELCTL DISP P Displace well with 8.4 ppg seawater // 320 bbls pumped 0.0 0.0 7/10/2023 03:00 7/10/2023 03:30 0.50 MIRU, WHDBOP OWFF P Observe well for flow // No flow prep to set BPV 0.0 0.0 7/10/2023 03:30 7/10/2023 04:00 0.50 MIRU, WHDBOP MPSP P Set BPV and test 1000 psi 0.0 0.0 7/10/2023 04:00 7/10/2023 17:30 13.50 MIRU, WHDBOP OTHR P NU BOPE and install riser. Swap 3-1/2" x 5-1/2" VBR for 2-7/8" x 5" VBR to run 2-7/8" completion on this well. 0.0 0.0 7/10/2023 17:30 7/10/2023 18:00 0.50 MIRU, WHDBOP SVRG P Service Rig BOP system 0.0 7/10/2023 18:00 7/11/2023 00:00 6.00 MIRU, WHDBOP RGRP T Blind ram bonnet leaking hydraulic oil // made decision to rig down pits pull rig forward and change out blind rams // Nipple down BOP's and nipple up tree// 0.0 0.0 7/11/2023 00:00 7/11/2023 22:00 22.00 MIRU, WHDBOP RGRP T Blind ram bonnet leaking hydraulic oil // made decision to rig down pits pull rig forward and change out blind rams // Nipple down BOP's and nipple up tree// 0.0 0.0 7/11/2023 22:00 7/12/2023 00:00 2.00 MIRU, WHDBOP RURD T Spot rig over well, spot pits, complete making up BOP lines 0.0 0.0 7/12/2023 00:00 7/12/2023 02:00 2.00 MIRU, WHDBOP NUND T Nipple down production tree, nipple up BOP's 0.0 0.0 7/12/2023 02:00 7/12/2023 02:30 0.50 MIRU, WHDBOP SVRG P Service koomy lines and hook up 0.0 0.0 7/12/2023 02:30 7/12/2023 04:30 2.00 MIRU, WHDBOP RURD P Install kill line 0.0 0.0 7/12/2023 04:30 7/12/2023 05:30 1.00 MIRU, WHDBOP RURD P Prep test equipment, flood lines, and function ram elements. 0.0 0.0 7/12/2023 05:30 7/12/2023 06:15 0.75 MIRU, WHDBOP RURD P Bleed off IA. well out of balance. 0.0 0.0 7/12/2023 06:15 7/12/2023 06:45 0.50 MIRU, WHDBOP RURD P Perform shell test of BOP 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/21/2023 Page 2/9 3G-08 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/12/2023 06:45 7/12/2023 15:00 8.25 COMPZN, RPCOMP BOPE P BOPE test All test to 250/3000 PSI F/5 min each, Test annular with 2-7/8"" test joint, Test UVBR/LVBR w/2-7/8" and 3 1/2" test joints, Test blinds rams, Choke valves #1 to #16, upper/lower IBOP valves. Test 3 1/2" HT-38 FOSV/Dart Valve, Test 3 ½ EUE FOSV, Test PH6 FOSV/Dart valve, Test 2" rig floor Demco kill valves, Test manual and HCR kill and choke valves.Test two ea 2 1/16" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3000 PSI, after closure = 1500 PSI, 200 PSI attained = 17 sec, full recovery attained = 112 sec. UVBR = 5 sec, LVBR = 5 sec, Annular = 25 sec, Simulated blinds = 5 sec, HCR choke/kill = 1 sec each, 5 back up nitrogen bottles average = 2000 PSI, Prechare bottles = 11 @ 1100 PSI, Test gas detectors, PVT and flow show. AOGCC Rep. Kam St.John witness waived Tested gas detectors 1 F/P, cellar high combustible alarm. 0.0 0.0 7/12/2023 15:00 7/12/2023 15:30 0.50 COMPZN, RPCOMP RURD P Blow down stack and choke and surface lines. LD test joint. RD testing EQ. 0.0 0.0 7/12/2023 15:30 7/12/2023 16:00 0.50 COMPZN, RPCOMP MPSP P PU T-bar. Pull BPV and dart. 0.0 0.0 7/12/2023 16:00 7/12/2023 17:00 1.00 COMPZN, RPCOMP RURD P RU floor to pull completion. move spooler to floor. 0.0 8,133.0 7/12/2023 17:00 7/12/2023 18:00 1.00 COMPZN, RPCOMP THGR P Make up landing jt // BOLDS // Pull hanger to floor 95K up wt // Cut control line 8,133.0 8,110.0 7/12/2023 18:00 7/12/2023 19:00 1.00 COMPZN, RPCOMP CIRC P Circulate B/U // 5bbls/min @ 500 psi // OWFF no flow 8,110.0 8,110.0 7/12/2023 19:00 7/12/2023 21:00 2.00 COMPZN, RPCOMP PULL P Pull 3.5" completion spooling control line on slb spool // 160' - 250' of control line left in hole // 4 clamps missing // 25 of 29 calmps recovered 8,110.0 6,300.0 7/12/2023 21:00 7/12/2023 21:30 0.50 COMPZN, RPCOMP CLEN P Remove spooler from floor, prep to continue racking completion 6,300.0 6,300.0 7/12/2023 21:30 7/12/2023 23:30 2.00 COMPZN, RPCOMP PULL P Pull 3.5" completion spooling control line on slb spool // 160' - 250' of control line left in hole // 4 clamps missing // 25 of 29 calmps recovered 8,110.0 3,000.0 7/12/2023 23:30 7/13/2023 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig // Grease TD and Blocks 3,000.0 3,000.0 7/13/2023 00:00 7/13/2023 00:45 0.75 COMPZN, RPCOMP PULL P Pull rack back 65 stands in derrick 4,000.0 2,000.0 7/13/2023 00:45 7/13/2023 03:45 3.00 COMPZN, RPCOMP MPSP P Pick up storm packer BHA // Attempt set @ 100' and 130' not able to set // Set packer @291' COE 2,000.0 2,140.0 7/13/2023 03:45 7/13/2023 04:45 1.00 COMPZN, RPCOMP PRTS P Pressure test storm packer 3000psi 30 min 2,140.0 2,250.0 7/13/2023 04:45 7/13/2023 07:45 3.00 COMPZN, RPCOMP NUND P ND BOP's rack back stack strip wellhead. 2,250.0 2,250.0 7/13/2023 07:45 7/13/2023 11:30 3.75 COMPZN, RPCOMP RURD P RU hydratite. Grow casing 28-7/8" total growth observed. 2,250.0 2,250.0 Rig: NABORS 7ES RIG RELEASE DATE 7/21/2023 Page 3/9 3G-08 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/13/2023 11:30 7/13/2023 12:00 0.50 COMPZN, RPCOMP SVRG P Service power tongs 2,250.0 2,250.0 7/13/2023 12:00 7/13/2023 16:30 4.50 COMPZN, RPCOMP HOSO P Set slips in casing spool. casing off center of casing head due to wellhead listing. set slips on 7" casing W/83K on slips. 2,250.0 2,250.0 7/13/2023 16:30 7/13/2023 19:00 2.50 COMPZN, RPCOMP RURD P Install Wachs saw and cut casing. 2,250.0 2,250.0 7/13/2023 19:00 7/13/2023 23:00 4.00 COMPZN, RPCOMP NUND P NU wellhead and test break at casing head to tubing head to 3000 PSI. Install test plug in tubing spool. **** New style seals for packoff would not go into tubing head without rolling, installed old style seal pressure tested good, leaning well proved difficult to stab packoff**** 2,250.0 2,250.0 7/13/2023 23:00 7/14/2023 00:00 1.00 COMPZN, RPCOMP NUND P NU BOP's 2,250.0 2,250.0 7/14/2023 00:00 7/14/2023 02:00 2.00 COMPZN, RPCOMP NUND P Nipple up BOPs, center stack, flood for shell test 2,250.0 2,250.0 7/14/2023 02:00 7/14/2023 03:00 1.00 COMPZN, RPCOMP BOPE P Test tubing head break 250/3000 // Lock downs leak tighten and re-test good test // rig down test equipment 2,250.0 2,250.0 7/14/2023 03:00 7/14/2023 05:00 2.00 COMPZN, RPCOMP MPSP P Pull test plug. Pick up BHA and pull storm packer 2,250.0 2,250.0 7/14/2023 05:00 7/14/2023 06:00 1.00 COMPZN, RPCOMP OWFF P OWFF no flow, oil swapping to top of hole 2,250.0 2,250.0 7/14/2023 06:00 7/14/2023 06:30 0.50 COMPZN, RPCOMP CIRC P Circulate B/U 5 BPM 80 PSI 2,250.0 2,250.0 7/14/2023 06:30 7/14/2023 10:30 4.00 COMPZN, RPCOMP TRIP P Continue to TOOH F/2250' T surface PUW=40K, SOW=40K Cut joint recovered flaired to 4.75" OD and cut OAL recovered 15.74' 6-8' of control line recovered on last mandrel pulled. 2,250.0 0.0 7/14/2023 10:30 7/14/2023 11:00 0.50 COMPZN, RPCOMP RURD P RD floor after TOOH with tubing, RU to RIH with DP. Install Bowl protector. 6- 3/8" ID 0.0 0.0 7/14/2023 11:00 7/14/2023 11:30 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor Set up to run DP. 0.0 0.0 7/14/2023 11:30 7/14/2023 12:00 0.50 COMPZN, RPCOMP SVRG P Service top drive. 0.0 0.0 7/14/2023 12:00 7/14/2023 14:00 2.00 COMPZN, RPCOMP BHAH P PU BHA #3 Wire grab fishing BHA. 147.93' OAL 0.0 147.9 7/14/2023 14:00 7/14/2023 20:30 6.50 COMPZN, RPCOMP PULD P PU 3.5" HT-38 DP From 147.9' T/ 7904' 147.9 7,904.0 7/14/2023 20:30 7/14/2023 22:15 1.75 COMPZN, RPCOMP FISH P Wash down from 7904 to 8097' // Tag top of stump P/U 10' rot slow down above stump 8091' 7,904.0 8,097.0 7/14/2023 22:15 7/14/2023 22:45 0.50 COMPZN, RPCOMP CIRC P Circulate B/U to pull out of hole 8,060.0 8,060.0 7/14/2023 22:45 7/15/2023 00:00 1.25 COMPZN, RPCOMP TRIP P POOH to inspect for fish 8,060.0 5,300.0 7/15/2023 00:00 7/15/2023 02:15 2.25 COMPZN, RPCOMP TRIP P TOOH inspect BHA for fish 5,300.0 147.9 7/15/2023 02:15 7/15/2023 02:45 0.50 COMPZN, RPCOMP BHAH P Lay down and inspect BHA for control line // Recovered ~24" of control line on cable spear // Two pieces of banding in boot baskets and ~ 24" control line in basket Total recovered control line 48" 147.9 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/21/2023 Page 4/9 3G-08 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/15/2023 02:45 7/15/2023 03:15 0.50 COMPZN, RPCOMP SVRG P Service rig // service roughneck, pump out stack inspect for control line 0.0 0.0 7/15/2023 03:15 7/15/2023 03:45 0.50 COMPZN, RPCOMP BHAH P Pick up cable grapple BHA# 4 for second run // Cable Grapple, string mill, 2 boot baskets, stand of collars Wire grab fishing BHA. 147.93' OAL 0.0 147.9 7/15/2023 03:45 7/15/2023 07:00 3.25 COMPZN, RPCOMP TRIP P TIH w/ BHA# 4 Wire grab fishing BHA. 147.93' OAL T/8090' 147.9 8,090.0 7/15/2023 07:00 7/15/2023 08:30 1.50 COMPZN, RPCOMP FISH P Establish fishing parmeters PUW=140K SOW=100K Rot at 15 RPM ROT WT= 115K Free torque= 3K Pick up single RIH to top of stump at 8097' tag set down 3K. PUH rotate PR=100 SPM at 1350 PSI. Work string while rotating down 4 reciprocations. Torque increased to 4K 8,090.0 8,097.0 7/15/2023 08:30 7/15/2023 09:15 0.75 COMPZN, RPCOMP CIRC P Circulate BUS. at 100 SPM at 1350 PSI. PJSM for TOOH. 8,090.0 8,090.0 7/15/2023 09:15 7/15/2023 09:45 0.50 COMPZN, RPCOMP TRIP P LD single and start TOOH With suspected fish. 8,090.0 6,680.0 7/15/2023 09:45 7/15/2023 10:15 0.50 COMPZN, RPCOMP SVRG P Service Top Drive 6,680.0 6,680.0 7/15/2023 10:15 7/15/2023 12:45 2.50 COMPZN, RPCOMP TRIP P TOOH with DP F/6680 T/147.9 6,680.0 147.9 7/15/2023 12:45 7/15/2023 13:45 1.00 COMPZN, RPCOMP BHAH P L/D BHA empty boot baskets recovered broken piece of control line approx 3" OAL and 2 pieces of bands from control line. 147.9 0.0 7/15/2023 13:45 7/15/2023 14:15 0.50 COMPZN, RPCOMP BHAH P MU BHA same. 0.0 147.9 7/15/2023 14:15 7/15/2023 16:30 2.25 COMPZN, RPCOMP TRIP P TIH F/147.9 T/7840 147.9 7,840.0 7/15/2023 16:30 7/15/2023 16:45 0.25 COMPZN, RPCOMP FISH P Establish fishing parmeters. PUW=135K, SOW=100K, Rotate at 15 RPM 100 STKS/Min 1300 PSI 3K free tq. 110K rot wt. 7,840.0 7,840.0 7/15/2023 16:45 7/15/2023 17:00 0.25 COMPZN, RPCOMP WASH P Wash down F/7840 T/ 8091, pick up single. 7,840.0 8,091.0 7/15/2023 17:00 7/15/2023 17:30 0.50 COMPZN, RPCOMP FISH P Attempt to grab control line with wire grab. cont to rotate down to top of fish at 8089' 8,091.0 8,098.0 7/15/2023 17:30 7/15/2023 20:30 3.00 COMPZN, RPCOMP OWFF T While observing well for flow for trip, noticed excessive show at riser // Monitor well for 30 min no pressure increase // Circulating rate 3 bpm @ 430 psi choke pressure 20 psi mud wt in 8.4 mud wt out 8.4 // Shut in well with annular monitor pressures no pressure increase on casing or drill pipe // Circulate S x S shut down monitor well 30 min // well looked to be breathing and showed slight trickle at end of flow check 8,098.0 8,098.0 7/15/2023 20:30 7/15/2023 22:30 2.00 COMPZN, RPCOMP CIRC T Circulate and weigh system up to 8.6 ppg 8,098.0 8,098.0 7/15/2023 22:30 7/15/2023 23:00 0.50 COMPZN, RPCOMP OWFF P OWFF no flow , 8,098.0 8,098.0 7/15/2023 23:00 7/16/2023 00:00 1.00 COMPZN, RPCOMP TRIP P Trip out of hole inspect BHA 8,098.0 7,000.0 7/16/2023 00:00 7/16/2023 02:00 2.00 COMPZN, RPCOMP TRIP P TOOH inspect fishing tools for fish 7,000.0 149.0 7/16/2023 02:00 7/16/2023 03:00 1.00 COMPZN, RPCOMP BHAH P Lay down and inspect fishing tools for fish 149.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/21/2023 Page 5/9 3G-08 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/16/2023 03:00 7/16/2023 04:30 1.50 COMPZN, RPCOMP BOPE P Test Annular 250/3000 w/ 2-7/8" test jt and test plug // observe no flow from IA during Annular test 0.0 0.0 7/16/2023 04:30 7/16/2023 05:00 0.50 COMPZN, RPCOMP SVRG P Service rig. 0.0 0.0 7/16/2023 05:00 7/16/2023 06:30 1.50 COMPZN, RPCOMP BHAH P Pick up venturi fishing BHA 0.0 149.0 7/16/2023 06:30 7/16/2023 09:00 2.50 COMPZN, RPCOMP TRIP P TIH F/149 T/ 7907' 149.0 7,907.0 7/16/2023 09:00 7/16/2023 10:00 1.00 COMPZN, RPCOMP FISH P Establish fishing parameters. PUW=140K SOW=100K ROT at 15 RPM, ROT WT= 117K, PR=100 STK/MIN, 1550 PSI Wash down F/7907' T/8093' 7,907.0 8,093.0 7/16/2023 10:00 7/16/2023 12:00 2.00 COMPZN, RPCOMP CIRC P Pump 20 BBL 80 Vis sweep. Circulate SxS. 8,093.0 8,093.0 7/16/2023 12:00 7/16/2023 12:15 0.25 COMPZN, RPCOMP OWFF P OWFF 15 minutes. 8,093.0 8,093.0 7/16/2023 12:15 7/16/2023 15:00 2.75 COMPZN, RPCOMP TRIP P TOOH W/DP F/8093 T/149' PUW= 140K 8,093.0 149.0 7/16/2023 15:00 7/16/2023 15:30 0.50 COMPZN, RPCOMP BHAH P LD BHA. 149.0 0.0 7/16/2023 15:30 7/16/2023 16:30 1.00 COMPZN, RPCOMP BHAH P MU BHA 0.0 155.5 7/16/2023 16:30 7/16/2023 19:45 3.25 COMPZN, RPCOMP TRIP P TIH W/Dress off mill nad string mill BHA F/155.5 T/ 155.5 8,097.0 7/16/2023 19:45 7/16/2023 21:15 1.50 COMPZN, RPCOMP MILL P Obtain milling parameters Rot 75 rpm pump 5 bbls per min @ 900 psi // Rotate over stump and mill to 8107.7' from 8097 torque from 3500 to 6500 8,097.0 8,105.0 7/16/2023 21:15 7/16/2023 22:15 1.00 COMPZN, RPCOMP CIRC P Pump sweep circulate S x S // OWFF // 8.6 in and out mud wt. 8,105.0 8,105.0 7/16/2023 22:15 7/16/2023 22:45 0.50 COMPZN, RPCOMP PULD P Lay down 2 jts for even stands // second stand pull heavy up to 150K // Stop kelly up pump 104 spm @ 965 psi Rot 63 rpm @ 3700 ft./lbs pick up @ 116K // Work area 8,105.0 8,000.0 7/16/2023 22:45 7/16/2023 23:30 0.75 COMPZN, RPCOMP REAM P Stop kelly up pump 104 spm @ 965 psi Rot 63 rpm @ 3700 ft./lbs pick up @ 116K // Work area circ B/U 8,000.0 7,941.0 7/16/2023 23:30 7/17/2023 00:00 0.50 COMPZN, RPCOMP SLPC P Slip and cut drill line // PJSM 7,941.0 7,941.0 7/17/2023 00:00 7/17/2023 00:30 0.50 COMPZN, RPCOMP SLPC P Slip and cut drill line 7,941.0 7,941.0 7/17/2023 00:30 7/17/2023 01:30 1.00 COMPZN, RPCOMP SVRG P Service rig set crown saver, grease blocks and drawworks 7,941.0 7,941.0 7/17/2023 01:30 7/17/2023 07:00 5.50 COMPZN, RPCOMP PULD P POOH laying down drill pipe F/7941' T/155' 7,941.0 155.0 7/17/2023 07:00 7/17/2023 08:00 1.00 COMPZN, RPCOMP BHAH P LD BHA F/155 T/0 150.0 0.0 7/17/2023 08:00 7/17/2023 08:30 0.50 COMPZN, RPCOMP BHAH P MU overshot to bottom of 3.5" completion 0.0 8.0 7/17/2023 08:30 7/17/2023 13:30 5.00 COMPZN, RPCOMP TRIP P TIH with 3.5" completion F/8' to 8106' bottom of overshot 8.0 8,106.0 7/17/2023 13:30 7/17/2023 15:00 1.50 COMPZN, RPCOMP HOSO P Spcae out overshot over stump to allow 1.5' of stick up above rig floor. 8,106.0 8,106.0 7/17/2023 15:00 7/17/2023 16:00 1.00 COMPZN, RPCOMP SLKL P RU Slick line 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/21/2023 Page 6/9 3G-08 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/17/2023 16:00 7/17/2023 19:00 3.00 COMPZN, RPCOMP PRTS P Pressure test FOSV and Annular to 2500 psi for 10 minutes, Pressure test Upper FOSV and upper pipe rams to 2500 PSI for 10 minutes. Stab on wire line valves and lubricator pressure test to 3500 PSI from above for 10 minutes. 0.0 0.0 7/17/2023 19:00 7/17/2023 20:45 1.75 COMPZN, RPCOMP SLKL P RIH with slick line Run# 1 // Drift and Bailer // Bailer came back with metal and cuttings // 2 cups debris recovered 0.0 8,272.0 7/17/2023 20:45 7/17/2023 22:15 1.50 COMPZN, RPCOMP SLKL P PT lubricator and re-run bailer // Bailer came back with cuttings and metsl // 3 cups debris recovered 8,272.0 8,272.0 7/17/2023 22:15 7/18/2023 00:00 1.75 COMPZN, RPCOMP SLKL P PT lubricator and re-run bailer 8,272.0 8,272.0 7/18/2023 00:00 7/18/2023 02:00 2.00 COMPZN, RPCOMP SLKL P PT riser run in with bailer // Halliburton crew changed out // extra time spent with bailer // 1.5 cups of cuttings and metal recovered // piece of control line band recovered 8,272.0 8,272.0 7/18/2023 02:00 7/18/2023 10:30 8.50 COMPZN, RPCOMP SLKL P Continue to make bailer runs till clean PT lub to 3500 PSI between runs. 6 runs total 2.5" pump bailer. 8,272.0 8,272.0 7/18/2023 10:30 7/18/2023 17:30 7.00 COMPZN, RPCOMP SLKL P Go to well with Eq. prong on baited 3" GR. stab on with lubricator PT lube to 3500 PSI. RIH retrieve IBP 1000 PSI on tubing after IBP pulled 8,272.0 8,272.0 7/18/2023 17:30 7/18/2023 19:00 1.50 COMPZN, RPCOMP SLKL P Make up slick line tools for brush and flush D nipple RIH with brush, circ at 1.5 BPM 1320 PSI , pump 20 BBLS total, bull head fluid away 8,272.0 0.0 7/18/2023 19:00 7/18/2023 20:30 1.50 COMPZN, RPCOMP SLKL P Make CA-2 plug on slick line tools Shear pin holes on running tool not lining up correctly on CA-2 plug Get another CA-2 plug from shop 0.0 0.0 7/18/2023 20:30 7/18/2023 22:00 1.50 COMPZN, RPCOMP SLKL P RIH with CA-2 plug and set in D nipple at 8,273', POOH 0.0 0.0 7/18/2023 22:00 7/18/2023 23:00 1.00 COMPZN, RPCOMP RURD P Rig up to circ down tubing and take returns thru gas buster 630 PSI on TBG 650 PSI on casing after opening to choke 0.0 0.0 7/18/2023 23:00 7/19/2023 00:00 1.00 COMPZN, RPCOMP CIRC P Circ 8.6 PPG seawater at 2 BPM 890 PSI thru gas buster Get returns at 8.8 BBLS into displacement 0.0 8,097.0 7/19/2023 00:00 7/19/2023 01:45 1.75 COMPZN, RPCOMP CIRC P Circ 8.6 PPG seawater at 2 BPM 890 PSI ICP holding 720 PSI on choke until B/U strokes, open choke FCP 2.5 BPM 260 PSI with 50 PSI on choke Pump 320 BBLS total 8,097.0 8,097.0 7/19/2023 01:45 7/19/2023 02:00 0.25 COMPZN, RPCOMP MPSP P Shut down monitor pressure, OA = 120 PSI, casing PSI = 10, no change in 15 minutes 8,097.0 8,097.0 Rig: NABORS 7ES RIG RELEASE DATE 7/21/2023 Page 7/9 3G-08 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/19/2023 02:00 7/19/2023 02:45 0.75 COMPZN, RPCOMP MPSP P Test CA-2 plug to 2500 PSI for 30 min OA/IA= 120/10 PSI at the start OA/IA = 200/2590 PSI 15 min OA/IA = 200/2550 PSI 30 min OA/IA = 200/2550 PSI Bleed off PSI 8,097.0 8,097.0 7/19/2023 02:45 7/19/2023 04:45 2.00 COMPZN, RPCOMP OWFF P Monitor well for pressure IA PSI in cellar 16 PSI, no change in 15 min, open to atmosphere start out at .14 BPM, slow to .13 BPH, drain stack, open up IA in cellar Slight flow at .08 BPH slow to .07 BPH in 1 HR. Get crude oil back Decide to weight up to 8.8 PPG 8,097.0 8,097.0 7/19/2023 04:45 7/19/2023 06:00 1.25 COMPZN, RPCOMP DISP P Weight up active pits to 8.8 PPG 8,097.0 8,097.0 7/19/2023 06:00 7/19/2023 08:15 2.25 COMPZN, RPCOMP CIRC P Circulate 8.8 In and out. 34 STKS/Min. ICP = 300 PSI. FCP=1360 PSI appears overshot packing off. Shut down pump. O PSI on tubing 20 PSI on casing. 8,097.0 8,097.0 7/19/2023 08:15 7/19/2023 10:00 1.75 COMPZN, RPCOMP OWFF P OWFF for casing flowing 4 gallons in 30 minutes. Fluid from casing at 8.7# Load pits W/290 BBL's seawater while monitoing well. Weighted up new seawater to 8.8 # 8,097.0 8,097.0 7/19/2023 10:00 7/19/2023 11:30 1.50 COMPZN, RPCOMP SLKL P PJSM to RD Slickline and RD. 8,097.0 8,097.0 7/19/2023 11:30 7/19/2023 14:00 2.50 COMPZN, RPCOMP CIRC P Circulate through gas buster at 3 BPM 485 PSI. Open monitors on tubing and casing. 8,097.0 8,097.0 7/19/2023 14:00 7/19/2023 14:30 0.50 COMPZN, RPCOMP OWFF P OWFF well flowing from casing at .18 BBL's/Hr. not deminishing in rate. Called out 12.5# spike fluid from 1B 8,097.0 8,097.0 7/19/2023 14:30 7/19/2023 22:00 7.50 COMPZN, RPCOMP CLEN T Empty pits 1 & 2 clean pits and prep for new 12.5#. only 1 truck available to support operations. round trip truck to 1B. 1st load on location at 16:30 HRS off load into pits and return to 1B at 21:00 HRS, Offload trucks and blend to 12 PPG 8,097.0 8,097.0 7/19/2023 22:00 7/20/2023 00:00 2.00 COMPZN, RPCOMP CIRC T Pump 30 BBLS Hivis spacer, chase with 330 BBLS of 12 PPG brine 3 BPM 90 PSI ICP 3 BPM 500 PSI FCP 8,097.0 8,097.0 7/20/2023 00:00 7/20/2023 01:00 1.00 COMPZN, RPCOMP OWFF T Flow check, 30 min no flow 8,097.0 8,097.0 7/20/2023 01:00 7/20/2023 02:00 1.00 COMPZN, RPCOMP OWFF P Open up rams and annular Pick up out of slips 80K Fill hole with TT flow check Blow down choke and kill lines 8,097.0 80,697.0 7/20/2023 02:00 7/20/2023 09:30 7.50 COMPZN, RPCOMP PULD P PJSM, laying down tubing to pipe shed POOH F/8097' 8,097.0 0.0 7/20/2023 09:30 7/20/2023 10:00 0.50 COMPZN, RPCOMP OWFF P OWFF while clearing floor after L/D DP. 0.0 0.0 7/20/2023 10:00 7/20/2023 11:00 1.00 COMPZN, RPCOMP PULD P PU joint of DP. MU test plug to DP attempt to pull bowl protector unable to "J" into alignment slot. L/D bowl protector R&R tool MU 7" casing spear to joint of DP. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/21/2023 Page 8/9 3G-08 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/20/2023 11:00 7/20/2023 13:30 2.50 COMPZN, RPCOMP RURD P RU floor to run completion. elevators, dress tongs, slips. Confirm completion in pipe shed vs. tally, make up X-O to bottom of overshot, move tubing hanger to the rig floor, move space out pup joints to rig floor. prep floor to piick up completion. 0.0 0.0 7/20/2023 13:30 7/20/2023 23:30 10.00 COMPZN, RPCOMP PUTB P PU 2-7/8" completion and RIH F/surface T/8,101' 70K UP 55K DN Located poor boy over shot on 3 1/2" TBG stump, see 12K shear down on brass pins at 8,105', slack off T/8,109' set DN 5K confirm no go SimOps - clean pits 0.0 8,109.0 7/20/2023 23:30 7/21/2023 00:00 0.50 COMPZN, RPCOMP RURD P Lay down JT #253, pick up 10' pup for space out Rig up head pin and circulating lines 8,109.0 8,109.0 7/21/2023 00:00 7/21/2023 01:45 1.75 COMPZN, RPCOMP DISP P Pump 255 BBLS 12 PPG CI brine Chase with 20 BBLS 12 PPG brine 3 BPM 880 PSI 8,109.0 8,109.0 7/21/2023 01:45 7/21/2023 02:30 0.75 COMPZN, RPCOMP PACK P Drop 1 5/16" ball and rod Rig up circulting lines Tag no go, pick up to neutral weigth at 8,107.50' Pressure up to 3000 PSI to set packer hold 3 min Bleed off to 1000 PSI, P/U pull T/105K on hook shear out PBR at 35K over 8,109.0 8,107.0 7/21/2023 02:30 7/21/2023 03:00 0.50 COMPZN, RPCOMP PUTB P Slack off confirn tag set down 10K Lay down 10' and 2 JTS tubing for space out Pick up 4.24' tubing pup and joint #251 Locator 2.54' off of located 70K UP 50K DN 8,107.0 8,035.0 7/21/2023 03:00 7/21/2023 04:00 1.00 COMPZN, RPCOMP THGR P Change out elevtors to 3 1/2" pick up 3 1/2" EUE landing JT Pick up Cameron tubing hanger Flow check, drain stack Slack off land tubing in well head RILDS 8,035.0 8,059.0 7/21/2023 04:00 7/21/2023 06:00 2.00 COMPZN, RPCOMP PRTS P Rig up test tubing to 3000 PSI F/30 min Bleed tubing down to 1000 PSI Test IA to 2500 PSI F/30 min Bleed off tubing pressure shear out SOV 8,059.0 8,059.0 7/21/2023 06:00 7/21/2023 06:30 0.50 COMPZN, WHDBOP MPSP P Set HP-BPV. 0.0 0.0 7/21/2023 06:30 7/21/2023 07:00 0.50 COMPZN, WHDBOP PRTS P Tested BPV to 1000 PSI for 10 minutes from IA. Bled pressure off IA 0.0 0.0 7/21/2023 07:00 7/21/2023 10:00 3.00 COMPZN, WHDBOP NUND P ND BOP's break all flanges loose. rack BOP stack on stump. 0.0 0.0 7/21/2023 10:00 7/21/2023 12:30 2.50 COMPZN, WHDBOP NUND P NU tree and adapter tested void to 5000 PSI for 15 minutes. 0.0 0.0 7/21/2023 12:30 7/21/2023 14:30 2.00 COMPZN, WHDBOP PRTS P PJSM W/LRS and Nabors. RU LRS and pressure test tree to 5000 PSI with LRS 0.0 8,059.0 7/21/2023 14:30 7/21/2023 15:00 0.50 COMPZN, WHDBOP MPSP P Pulled HP BPV and dart. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/21/2023 Page 9/9 3G-08 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/21/2023 15:00 7/21/2023 17:00 2.00 COMPZN, WHDBOP FRZP P Freeze protect down IA taking returns up the tubing at 3 BPM. Final circulating pressure 1800 PSI. Isolate LRS suck back line. RD LRS and U-Tube well for 1 hour. Siops move pits off of sub with Cruz construction. 0.0 0.0 7/21/2023 17:00 7/21/2023 18:00 1.00 COMPZN, WHDBOP RURD P Secure cellar, Prep rig floor for move Clean up cellar area Rig release at 18:00 HRS 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/21/2023 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,342.0 3G-08 7/30/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post rig install GLD, pulled B&R, RHC body, CA-2 plug, update tag depth 3G-08 7/30/2023 rogerba Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 35.0 3,657.1 3,057.4 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 8,745.3 6,105.5 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 30.8 Set Depth 8,115.7 Set Depth 5,687.1 String Ma 2 7/8 Tubing Description Tubing Completion Upper Wt (lb/ft) 6.30 Grade L-80 Top Connection EUE ID (in) 2.44 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) 30.8 30.8 0.13 Hanger 7.063 Cameron Hanger CXS 7 1/16 x 3 1/2" EUE threads Camero n CXS S/N- 1219381 14-4 2.992 494.4 494.3 0.70 2.313" X-Nipple 3.682 2 7/8" Xnipple with 2.313" profile - S/N C3137170 Haliburto n Xnipple 2.313" 2.313 2,914.9 2,629.9 54.00 MMG Mandrel 5.415 2 7/8" x 1.5" MMG W/DV/RK latch SLB MMG RK Latch 2.366 6,608.5 4,765.1 53.16 MMG Mandrel 5.415 2 7/8" x 1.5" MMG W/DV/RK latch SLB MMG RK Latch 2.366 8,021.2 5,626.1 50.04 MMG Mandrel 5.415 2 7/8" x 1.5" KBG GLM W/SOV SLB MMG RKP Latch 2.366 8,044.4 5,641.0 49.91 Locator 3.450 Baker 80-32 seal assy - W/3.45" locator - 2.54' from fully located - 22.68' long Baker 80 -32 Seal Assy 2.420 8,047.5 5,643.0 49.90 Polished Bore Receptacle 4.260 Baker 80-32 PBR W/21.83' PBR Baker 80 -32 H02474 692Y 2.450 8,070.5 5,657.8 49.78 PACKER 5.940 Baker 47B2 FHL packer W/60K release shear ring Baker 47B2 H78120 0025 2.370 8,089.5 5,670.1 49.68 2.313" X Nipple 3.682 2 7/8" Xnipple with 2.313" profile - S/N G3043191 Haliburto n X nipple 2.313" 2.313 8,108.8 5,682.6 49.55 Overshot 5.490 Baker poor boy over shot with 5.61' swallow Baker 3.620 Top (ftKB) 8,113.0 Set Depth 8,279.0 Set Depth 5,794.1 String Ma 4 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.20 Grade L-80 Top Connection EUE-MOD ID (in) 2.87 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) 8,134.5 5,699.3 49.34 PBR 5.000 BAKER 10' STROKE PBR 3.000 8,148.2 5,708.2 49.23 PACKER 6.063 BAKER HB RETRIEVABLE PACKER BAKER FHL 2.890 8,182.7 5,730.8 48.95 BLAST RING 4.500 CARBIDE BLAST RINGS (2) 2.867 8,248.4 5,774.0 49.01 NIPPLE 4.540 AVA BPL NIPPLE 2.750 8,257.1 5,779.8 49.04 XO Reducing 3.500 CROSSOVER 3.5 x 2.875, ID 2.441, 6.5#, J-55, EUE-MOD 2.875 8,257.8 5,780.2 49.05 SEAL ASSY 3.470 BAKER LOCATOR SEAL ASSEMBLY 2.406 8,259.9 5,781.6 49.06 PACKER 5.687 BAKER D PERMANENT PACKER 3.250 8,263.5 5,784.0 49.07 SBE 4.750 BAKER SEAL BORE EXTENSION 2.312 8,272.6 5,789.9 49.11 NIPPLE 4.520 CAMCO D NIPPLE NO GO 2.250 8,278.2 5,793.6 49.13 SOS 3.750 BAKER SHEAR OUT SUB 2.441 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) 8,132.0 5,697.7 49.36 TUBING LEAK TUBING LEAK LOCATED W/ RELAY LDL, 0.75 BPM AT 1100 PSI 8/13/2019 2.990 8,248.4 5,774.1 49.01 SLEEVE-C AVA BPI 12/12/2009 2.310 8,540.0 5,966.0 47.70 FISH 18" Perf Gun From 2nd Perf Gun; in Rathole 8/18/1991 0.000 8,542.0 5,967.3 47.68 FISH 6' of Perf Gun From 3rd Perf Gun; in Rathole 8/18/1991 0.000 8,545.0 5,969.3 47.65 FISH OV 1.5" OV DROPPED IN RATHOLE 10/9/2004 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,914.9 2,629.9 54.00 1 GAS LIFT GLV RK 1 1/2 1,240.0 7/29/2023 Schlumb erger REK 0.125 6,608.5 4,765.1 53.16 2 GAS LIFT GLV RK 1 1/2 1,255.0 7/28/2023 SLB REK 0.188 8,021.2 5,626.1 50.04 3 GAS LIFT OV RK 1 1/2 0.0 7/28/2023 Schlumb erger RKP 0.188 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,214.0 8,234.0 5,751.5 5,764.6 C-4, UNIT B, 3G -08 9/15/1990 10.0 IPERF 4 1/2" Csg Gun, 60° phasing 3G-08, 8/10/2023 10:35:49 AM Vertical schematic (actual) PRODUCTION; 35.0-8,745.3 FISH; 8,545.0 FISH; 8,542.0 FISH; 8,540.0 IPERF; 8,366.0-8,386.0 IPERF; 8,310.0-8,350.0 A-SAND FRAC; 8,310.0 PACKER; 8,259.9 SLEEVE-C; 8,248.4 IPERF; 8,214.0-8,234.0 PRODUCTION; 8,164.5 PACKER; 8,148.2 TUBING LEAK; 8,132.0 2.313" X Nipple; 8,089.5 PACKER; 8,070.5 MMG Mandrel; 8,021.2 MMG Mandrel; 6,608.4 SURFACE; 35.0-3,657.1 MMG Mandrel; 2,914.9 2.313" X-Nipple ; 494.4 CONDUCTOR; 36.0-115.0 Hanger; 30.8 KUP PROD KB-Grd (ft) 35.00 RR Date 5/27/1990 Other Elev 3G-08 ... TD Act Btm (ftKB) 8,759.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032012800 Wellbore Status PROD Max Angle & MD Incl (°) 56.02 MD (ftKB) 5,800.00 WELLNAME WELLBORE3G-08 Annotation Last WO: End Date 7/21/2023 H2S (ppm) 100 Date 12/4/2015 Comment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,310.0 8,350.0 5,814.4 5,840.5 A-4, A-3, 3G-08 8/18/1991 8.0 IPERF 2 1/8" Dynastrip, 90° phasing 8,366.0 8,386.0 5,850.9 5,864.0 A-2, 3G-08 9/15/1990 4.0 IPERF 4 1/2" Csg Gun, 180° phasing Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,310.0 8,350.0 1 A-SAND FRAC 11/25/2010 0.0 0.00 0.00 3G-08, 8/10/2023 10:35:50 AM Vertical schematic (actual) PRODUCTION; 35.0-8,745.3 FISH; 8,545.0 FISH; 8,542.0 FISH; 8,540.0 IPERF; 8,366.0-8,386.0 IPERF; 8,310.0-8,350.0 A-SAND FRAC; 8,310.0 PACKER; 8,259.9 SLEEVE-C; 8,248.4 IPERF; 8,214.0-8,234.0 PRODUCTION; 8,164.5 PACKER; 8,148.2 TUBING LEAK; 8,132.0 2.313" X Nipple; 8,089.5 PACKER; 8,070.5 MMG Mandrel; 8,021.2 MMG Mandrel; 6,608.4 SURFACE; 35.0-3,657.1 MMG Mandrel; 2,914.9 2.313" X-Nipple ; 494.4 CONDUCTOR; 36.0-115.0 Hanger; 30.8 KUP PROD 3G-08 ... WELLNAME WELLBORE3G-08 ConocoPhillips Alaska Inc.Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-offReport of Sundry Operations (10-404)KRUWell Name API # PTD #Initial top of cementVol. of cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant dateft bbls in gal1A-24 5002922984-0000 200-181 N/APost Conductor Ext21.5" 3/7/2022 12.7 7/2/20232L-323 5010320282-0000 198-251 N/APost Conductor Ext11" 7/31/2022 3.4 7/2/20232N-310 5010320549-0000 207-090 12' 2.3 7" 5/31/2023 4.25 7/2/20232N-322 5010320678-0000 213-179 9' 10" 1.1 6" 5/31/2023 2.1 7/2/20233G-08 5010320128-0000 190-065 10' 2" 1.0 5" 5/31/2023 1 7/2/2023Date 07/03/20231A, 2L, 2N, & 3G Pads3G-085010320128-0000190-06510' 2"1.05"5/31/202317/2/2023 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: SC Repair ConocoPhillips, Alaska, Inc. 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 8,759' feet 8,158' feet true vertical 6,115'feet 8,540' feet Effective Depth measured 8,540' feet 8,148' feet true vertical 5,966' feet 5,708' feet Perforation depth Measured depth 8,214' - 8,386'feet True Vertical depth 5,752' - 5,864 feet Tubing (size, grade, measured and true vertical depth) 3.5"x2 7/8" L-80 8,279' MD 5,794' Packers and SSSV (type, measured and true vertical depth) PackerRetrieva ble/ Baker D Perm Packer 8,148'MD /5,708' TVD. 8,260' MD/5,782' TVD SSSV: Camco - TRDP-11A-SSA 1,796' MD/ 1,781' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Roger Mouser/ Brennen Green Contact Email:N1927@conocophillips.com Authorized Title: Well Integrity Field Supervisor Contact Phone: 1-907-659-7506 measured TVD 3,057' Burst Collapse Production 8,710' Casing 6,106'8,745' 3,657' Plugs Junk measured Length 79' 3,622' 115'Conductor Surface 16" 9.625 Size 115' 7" 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025547ADL0025548 KUPARUK RIVER, KUPARUK RIVER OIL Kuparuk RIV UNIT 3G-08 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-065 50-10320128-00-00 P.O. Box100360 Anchorage, Ak 995103. Address: N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A N/A N/AN/A Gas-Mcf MD N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure N/A Water-BblOil-Bbl N/A N/AN/A 323-153 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 9:39 am, May 05, 2023 Digitally signed by Roger Mouser DN: OU=CPAI, O=Well Integrity Field Supervisor, CN=Roger Mouser, E=Roger.Mouser@contractor.conocophillips.com Reason: I am the author of this document Location: Date: 2023.05.05 07:35:08-08'00' Foxit PDF Editor Version: 12.0.1 Roger Mouser P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 5, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the Surface Casing repair on KRU 3G-08 (PTD 190-065). Please contact Brennen Green or me at 659-7506 if you have any questions. Sincerely, Roger Mouser Well Integrity Field Supervisor N1927@conocophillips.com ConocoPhillips Alaska, Inc. Digitally signed by Roger Mouser DN: OU=CPAI, O=Well Integrity Field Supervisor, CN=Roger Mouser, E= Roger.Mouser@ contractor.conocophillips.com Reason: I am the author of this document Location: Date: 2023.05.05 07:34:16-08'00' Foxit PDF Editor Version: 12.0.1 Roger Mouser 2023-0502_Surface_Csg_Repair_KRU_3G-08_ss Page 1 of 5 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: May 3, 2023 P. I. Supervisor FROM: Sully Sullivan SUBJECT: Surface Casing Repair Petroleum Inspector KRU 3G-08 CPAI PTD 1900650; Sundry 323-153 5-2-2023: I travel to Kuparuk River Unit 3G-08 and met with Conoco representative Robert Mouser to witness and verify a surface casing repair using a casing sleeve. While on site I witnessed two complete mag particle procedures of all repair welds by Mistrass technicians. I looked over welds and took measurements of repair and verified lengths as well as photo documentation. The plugged hole was 108 inches below the centerline of the OA valve. The total length of the casing sleeve was 99 inches. Repair looked to be acceptable to continue with procedure and gave okay to proceed. Attachments: Photos; Measurement Drawing 2023-0502_Surface_Csg_Repair_KRU_3G-08_ss Page 2 of 5 Surface Casing Repair – KRU 3G-08 (PTD 1900650) Photos by AOGCC Inspector S. Sullivan 5/2/2023 Prior to casing repair Mag particle inspection 2023-0502_Surface_Csg_Repair_KRU_3G-08_ss Page 3 of 5 Top of sleeve repair 2023-0502_Surface_Csg_Repair_KRU_3G-08_ss Page 4 of 5 Outer sleeve length Sleeve length with shims 2023-0502_Surface_Csg_Repair_KRU_3G-08_ss Page 5 of 5 Strap from center to OA 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: KUPARUK RIVER 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,759'8,273'8540', 8542', 8545' Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng AOGCC USE ONLY SSSV: CAMCO TRDP-1A-SSA Packer: BAKER HB RETRIEVABLE PACKER / BAKER D PERMANENT PACKER SSSV: 1,796' MD / 1,781' TVD 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: L-80 8,279' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025548 190-065 P.O. Box 100360, Anchorage, AK 99510 5010320128-0000 ConocoPhillips Alaska, Inc Other: SC Repair KUPARUK RIV UNIT 3G-08 Length Size Proposed Pools: TVD Burst KUPARUK RIVER OIL KUPARUK RIVER OIL 8,759' PRESENT WELL CONDITION SUMMARY MD 115' 3,057' 115' 3,657' 16" 9 5/8" 79' 3,622' 6,106'8,745' Perforation Depth MD (ft): 8,214' - 8,386' 8,710' 5,752' - 5,864'3 1/2" x 2 7/8" @ 8,267' 7" Baker HB Retrievable Packer: 8,148' MD / 5,708' TVD Baker D Permanent Packer: 8,260' MD / 5,782' TVD Well Integrity Field Supervisor Brennen Green & Roger Mouser N1927@conocophillips.com 907-659-7506 3/20/2023 Authorized Name and Digital Signature with Date: m n P 1 6 5 6 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 7:43 am, Mar 14, 2023 323-153 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2023.03.13 15:57:25-08'00' Foxit PDF Editor Version: 12.0.1 Brennen Green Photo document all steps of repair VTL 3/21/2023 10-404X MDG 3/15/2023 X GCW 03/24/23JLC 3/24/2023 3/24/23Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.24 12:48:31 -08'00' RBDMS JSB 033023 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 13, 2023, 2022 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Please find the enclosed 10-403 application for sundry approval from ConocoPhillips Alaska, Inc. for well KRU 3G-08 (PTD 190-065) to repair the Surface Casing. Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions. Sincerely, Brennen Green Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.03.13 15:57:02-08'00' Foxit PDF Editor Version: 12.0.1 Brennen Green P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ConocoPhillips Alaska, Inc. KUPARUK WELL 3G-08 (PTD 190-065) SUNDRY NOTICE 10-403 APPROVAL REQUEST March 13, 2023 This application for Sundry approval for Kuparuk well 3G-08 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in the tubing. 2. Remove the floor grate, well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate to ~9-24’. 4. Install nitrogen purge equipment for the conductor and OA (if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a low-pressure test to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to Injection. 13. File 10-404 with the AOGCC post repair. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,343.0 3G-08 2/9/2023 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Patches & Set Plug/Catcher 3G-08 2/9/2023 zembaej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 35.0 3,657.1 3,057.4 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 8,745.3 6,105.5 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 33.2 Set Depth … 8,279.0 Set Depth … 5,794.1 String Ma… 3 1/2 Tubing Description TUBING 3.5"x2.875" @ 8267' Wt (lb/ft) 9.20 Grade L-80 Top Connection EUE-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) 33.2 33.2 0.14 HANGER 8.000 WKM GEN IV HANGER 3.500 1,796.1 1,780.9 21.54 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 2,545.0 2,400.9 47.80 GAS LIFT 5.620 MERLA TMPD 2.875 5,106.5 3,904.6 54.37 GAS LIFT 5.620 MERLA TMPD 2.875 6,492.7 4,697.0 54.78 GAS LIFT 5.620 MERLA TMPD 2.875 7,328.2 5,197.2 52.89 GAS LIFT 5.620 MERLA TMPD 2.875 7,826.8 5,502.9 51.10 GAS LIFT 5.620 MERLA TMPD 2.875 8,087.6 5,668.9 49.69 GAS LIFT 5.793 CAMCO MMG-2 2.920 8,134.5 5,699.3 49.34 PBR 5.000 BAKER 10' STROKE PBR 3.000 8,148.2 5,708.3 49.23 PACKER 6.063 BAKER HB RETRIEVABLE PACKER 2.890 8,182.7 5,730.9 48.95 BLAST RING 4.500 CARBIDE BLAST RINGS (2) 2.867 8,248.4 5,774.1 49.01 NIPPLE 4.540 AVA BPL NIPPLE 2.750 8,257.2 5,779.8 49.04 XO Reducing 3.500 CROSSOVER 3.5 x 2.875, ID 2.441, 6.5#, J-55, EUE-MOD 2.875 8,257.9 5,780.3 49.05 SEAL ASSY 3.470 BAKER LOCATOR SEAL ASSEMBLY 2.406 8,259.9 5,781.6 49.06 PACKER 5.687 BAKER D PERMANENT PACKER 3.250 8,263.6 5,784.0 49.07 SBE 4.750 BAKER SEAL BORE EXTENSION 2.312 8,272.7 5,790.0 49.11 NIPPLE 4.520 CAMCO D NIPPLE NO GO 2.250 8,278.3 5,793.6 49.13 SOS 3.750 BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,493.0 4,697.1 54.78 GLM LEAK LEAK in GLM @ 6493 RKB 6/12/2014 6,496.0 4,698.8 54.75 TUBING LEAK TUBING LEAK LOCATED W/ RELAY LDL, 0.75 BPM AT 1100 PSI 10/1/2019 2.990 8,132.0 5,697.7 49.36 TUBING LEAK TUBING LEAK LOCATED W/ RELAY LDL, 0.75 BPM AT 1100 PSI 8/13/2019 2.990 8,248.4 5,774.1 49.01 SLEEVE-C AVA BPI 12/12/2009 2.310 8,269.0 5,787.6 49.09 CATCHER 2.25" CATCHER (49"OAL / 44" DEEP) 2/9/2023 0.000 8,273.0 5,790.2 49.11 TUBING PLUG 2.25" CA-2 PLUG (32" OAL) 2/9/2023 0.000 8,540.0 5,966.0 47.70 FISH 18" Perf Gun From 2nd Perf Gun; in Rathole 8/18/1991 0.000 8,542.0 5,967.3 47.68 FISH 6' of Perf Gun From 3rd Perf Gun; in Rathole 8/18/1991 0.000 8,545.0 5,969.3 47.65 FISH OV 1.5" OV DROPPED IN RATHOLE 10/9/2004 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,545.0 2,400.9 47.80 1 GAS LIFT GLV BK 1 1,290.0 11/1/2019 0.156 5,106.5 3,904.6 54.37 2 GAS LIFT GLV BK 1 1,321.0 11/1/2019 0.188 6,492.7 4,697.0 54.78 3 OPEN 1 10/11/2019 7,328.2 5,197.2 52.89 4 GAS LIFT DMY INT 1 8/11/2019 0.000 7,826.8 5,502.9 51.10 5 GAS LIFT DMY BK 1 0.0 9/17/1990 0.000 8,087.6 5,668.9 49.69 6 GAS LIFT DMY RK 1 1/2 8/11/2019 0.000 8,164.5 5,718.9 49.10 7 PROD DMY RKP 1 1/2 0.0 1/4/1991 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,214.0 8,234.0 5,751.5 5,764.6 C-4, UNIT B, 3G -08 9/15/1990 10.0 IPERF 4 1/2" Csg Gun, 60° phasing 8,310.0 8,350.0 5,814.4 5,840.5 A-4, A-3, 3G-08 8/18/1991 8.0 IPERF 2 1/8" Dynastrip, 90° phasing 8,366.0 8,386.0 5,850.9 5,864.0 A-2, 3G-08 9/15/1990 4.0 IPERF 4 1/2" Csg Gun, 180° phasing 3G-08, 2/10/2023 9:51:05 AM Vertical schematic (actual) PRODUCTION; 35.0-8,745.3 FISH; 8,545.0 FISH; 8,542.0 FISH; 8,540.0 IPERF; 8,366.0-8,386.0 A-SAND FRAC; 8,310.0 IPERF; 8,310.0-8,350.0 SOS; 8,278.3 TUBING PLUG; 8,273.0 NIPPLE; 8,272.7 CATCHER; 8,269.0 SBE; 8,263.6 PACKER; 8,259.9 SEAL ASSY; 8,257.9 SLEEVE-C; 8,248.4 NIPPLE; 8,248.4 IPERF; 8,214.0-8,234.0 PRODUCTION; 8,164.5 PACKER; 8,148.2 PBR; 8,134.5 TUBING LEAK; 8,132.0 GAS LIFT; 8,087.6 GAS LIFT; 7,826.8 GAS LIFT; 7,328.2 TUBING LEAK; 6,496.0 GAS LIFT; 6,492.7 GAS LIFT; 5,106.5 SURFACE; 35.0-3,657.1 GAS LIFT; 2,545.0 SAFETY VLV; 1,796.0 CONDUCTOR; 36.0-115.0 HANGER; 33.2 KUP PROD KB-Grd (ft) 35.00 RR Date 5/27/1990 Other Elev… 3G-08 ... TD Act Btm (ftKB) 8,759.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032012800 Wellbore Status PROD Max Angle & MD Incl (°) 56.02 MD (ftKB) 5,800.00 WELLNAME WELLBORE3G-08 Annotation Last WO: End DateH2S (ppm) 100 Date 12/4/2015 Comment SSSV: TRDP Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,310.0 8,350.0 1 A-SAND FRAC 11/25/2010 0.0 0.00 0.00 3G-08, 2/10/2023 9:51:06 AM Vertical schematic (actual) PRODUCTION; 35.0-8,745.3 FISH; 8,545.0 FISH; 8,542.0 FISH; 8,540.0 IPERF; 8,366.0-8,386.0 A-SAND FRAC; 8,310.0 IPERF; 8,310.0-8,350.0 SOS; 8,278.3 TUBING PLUG; 8,273.0 NIPPLE; 8,272.7 CATCHER; 8,269.0 SBE; 8,263.6 PACKER; 8,259.9 SEAL ASSY; 8,257.9 SLEEVE-C; 8,248.4 NIPPLE; 8,248.4 IPERF; 8,214.0-8,234.0 PRODUCTION; 8,164.5 PACKER; 8,148.2 PBR; 8,134.5 TUBING LEAK; 8,132.0 GAS LIFT; 8,087.6 GAS LIFT; 7,826.8 GAS LIFT; 7,328.2 TUBING LEAK; 6,496.0 GAS LIFT; 6,492.7 GAS LIFT; 5,106.5 SURFACE; 35.0-3,657.1 GAS LIFT; 2,545.0 SAFETY VLV; 1,796.0 CONDUCTOR; 36.0-115.0 HANGER; 33.2 KUP PROD 3G-08 ... WELLNAME WELLBORE3G-08 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8759'8540', 8542', 8545' Casing Collapse Conductor Surface Intermediate Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Sydney Long sydney.long@conocophillips.com (907) 265-6312 Tubing Grade: Tubing MD (ft): 6487' MD and 4694' TVD 6512' MD and 4708' TVD 8124' MD and 5692' TVD 8148' MD and 5708' TVD 8157' MD and 5714' TVD 5260' MD and 5782' TVD 1796' MD and 1781' TVD Perforation Depth TVD (ft): Tubing Size: L-80 8279' 3/1/2023 Packer: POGLM Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: Baker HB Retrvbl Packer Packer: PIIP Patch Packer Packer: Baker D Perm Packer SSSV: Camco TRDP-1A-SSA Sfty Vlv STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025548 190-065 P.O. Box 100360, Anchorage, AK 99510 50-103-20128-00-00 ConocoPhillips Alaska, Inc. KRU 3G-08 Kuparuk River Oil PoolKuparuk River Oil PoolKuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6115' 8300' 5808' 2805 psi None MD 115' 3057' 115' 3657' 6105'8745' 16" 9-5/8" 79' 3622' Perforation Depth MD (ft): 8214-8234', 8310-8350', 8366-8386' 8710' 5751-5765', 5814-5840', 5851-5864'3-1/2" x 2-7/8" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov RWO/CTD Engineer By Samantha Carlisle at 7:40 am, Feb 15, 2023 323-093 BOP test to 3000 psig Annular preventer test to 2500 psig VTL 02/27/2023 DSR-2/15/23 X 10-404 X X DLB 02/15/2023 JLC 2/27/2023 2/27/23Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.27 12:26:31 -09'00' RBDMS JSB 022823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 13, 2023 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 3G-08 (PTD# 190- 065). Well 3G-08 was drilled and completed in September of 1990 by Nordic 1 as a Producer in the Kuparuk A and C sands. The well has experienced Tubing by IA communication and two patches had been previously installed. Additional communication has been observed – the well is shut in and requires a workover to replace the tubing. The 3-1/2” upper completion will be pulled from a pre-rig cut above the packer. It will be replaced with a 2-7/8” completion including a new gas lift design, a non-sealing overshot and a stacked packer. If you have any questions or require any further information, please contact me at 907-265-6321. Sydney Long Rig Workover Engineer CPAI Drilling and Wells 3G-08 Kuparuk Producer Pull and Replace Tubing Procedure PTD: 190-065 Page 1 of 2 PPre-Rig Work 1. Pull POGLM at 6,487’ RKB – Completed on 2/8/2023 2. Pull Patch at 8,124” RKB – Completed on2/8/2023 3. Lockout SSSV – Completed on 2/9/2023 4. SBHP – Completed on 2/9/2023 5. Set plug at 8,273’ RKB – Completed on 2/9/2023 6. CMI-TxIA to 2500 psig. – Passed on 2/10/2023 7. DDT-T-IA 8. T-PPPOT and T-POT tests. 9. Cut the tubing at ~8,100’ RKB in the middle of the first full joint above the packer. 10. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3G-08. No BPV set for MIRU due to N7ES internal risk assessment. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Circulate KWF as needed. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,000 psi. Test annular 250/2,500 psi. Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the pre-rig cut at ~8,100’ RKB. Cleanout Run 6. Perform a cleanout run, based on tubing condition, and dress off 3.5” tubing stub - if necessary. Install 2-7/8” Completion with Stacked Packer 7. MU and RIH with 2-7/8” completion with GLMs, nipples, packer, 3-1/2” XO, and overshot. 8. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 9. Land tubing hanger, RILDS, PT packoffs and set packer. 10. Pressure test tubing to 3,000 PSI for 30 minutes. 11. Pressure test IA to 2,500 PSI for 30 minutes on chart. ND BOP, NU Tree 12. Confirm pressure tests, then shear out SOV with pressure differential. 13. Install BPV and test. ND BOPE. NU tree. 14. Pull BPV and freeze protect well. 15. RDMO. Post-Rig Work 1. Run GLD 2. Pull any plugs or ball/rod used for setting packer. 3G-08 Kuparuk Producer Pull and Replace Tubing Procedure PTD: 190-065 Page 2 of 2 GGeneral Well Information: Estimated Start Date: 3/1/2023. Current Operations: Shut-In Well Type: Producer Wellhead Type: WKM Gen IV, 5k PSI BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Static BHP: 3,425 psi / 6,200’ TVD measured on 2/9/2023 MPSP: 2,805 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut directly above the top packer, install a new 2-7/8” completion and stacked packer. Personnel: Workover Engineer: Sydney Long (265-6321 / Sydney.Long@conocophillips.com) Reservoir Surveillance Engineer: Lynn Aleshire Production Engineer: Brian Lewis 3G-08 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 115 115 16 15.06 62.58 H-40 Welded Welded Surface 3657.1 3057.4 9.625 8.92 36 J-55 BTC BTC Production/ Intermediate 8745.3 6105.5 7 6.28 26 J-55 BTC BTC Tubing 8279 5794 2.825 2.44 6.5 L-80 EUE EUE PROPOSED COMPLETION 2-7/8" 6.5# L-80 EUE 8rd Tubing to surface X Nipple @ ~1,720' (2.813" min ID) 2-7/8" gas lift mandrels @ TBD Packer @ ~8,020' RKB (4" ID) XO from 2-7/8" to 3-1/2" X Nipple @ ~8,080' (2.813" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Baker HB Retrievable Packer @ 8,148' RKB (2.89" ID) Blast Rings @ 8,182' RKB (2.867" ID) AVA BPL Nipple @ 8,248' RKB (2.75" ID) XO to 2.875" J-55 EUE @ 8,257' RKB (2.406" ID) Baker D Permanent Packer @ 8,259' RKB (3.25" ID) Camco D Nipple No Go @ 8,272' RKB (2.25" ID) Surface Casing Production/Intermediate Casing 8,745' MD / 6,105' TVD Conductor A-Sand Perfs 8,310' - 8,386' RKB C-Sand Perfs 8,214' - 8,234' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,300.0 3G-08 1/2/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Replaced OV in Poglm 3G-08 1/9/2023 zembaej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 35.0 3,657.1 3,057.4 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 8,745.3 6,105.5 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 33.2 Set Depth … 8,279.0 Set Depth … 5,794.1 String Ma… 3 1/2 Tubing Description TUBING 3.5"x2.875" @ 8267' Wt (lb/ft) 9.20 Grade L-80 Top Connection EUE-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) 33.2 33.2 0.14 HANGER 8.000 WKM GEN IV HANGER 3.500 1,796.1 1,780.9 21.54 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 2,545.0 2,400.9 47.80 GAS LIFT 5.620 MERLA TMPD 2.875 5,106.5 3,904.6 54.37 GAS LIFT 5.620 MERLA TMPD 2.875 6,492.7 4,697.0 54.78 GAS LIFT 5.620 MERLA TMPD 2.875 7,328.2 5,197.2 52.89 GAS LIFT 5.620 MERLA TMPD 2.875 7,826.8 5,502.9 51.10 GAS LIFT 5.620 MERLA TMPD 2.875 8,087.6 5,668.9 49.69 GAS LIFT 5.793 CAMCO MMG-2 2.920 8,134.5 5,699.3 49.34 PBR 5.000 BAKER 10' STROKE PBR 3.000 8,148.2 5,708.3 49.23 PACKER 6.063 BAKER HB RETRIEVABLE PACKER 2.890 8,182.7 5,730.9 48.95 BLAST RING 4.500 CARBIDE BLAST RINGS (2) 2.867 8,248.4 5,774.1 49.01 NIPPLE 4.540 AVA BPL NIPPLE 2.750 8,257.2 5,779.8 49.04 XO Reducing 3.500 CROSSOVER 3.5 x 2.875, ID 2.441, 6.5#, J-55, EUE-MOD 2.875 8,257.9 5,780.3 49.05 SEAL ASSY 3.470 BAKER LOCATOR SEAL ASSEMBLY 2.406 8,259.9 5,781.6 49.06 PACKER 5.687 BAKER D PERMANENT PACKER 3.250 8,263.6 5,784.0 49.07 SBE 4.750 BAKER SEAL BORE EXTENSION 2.312 8,272.7 5,790.0 49.11 NIPPLE 4.520 CAMCO D NIPPLE NO GO 2.250 8,278.3 5,793.6 49.13 SOS 3.750 BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,487.0 4,693.7 54.83 Upper patch/POGLM Upper patch/POGLM assembly consisting of PIIP packer, Spacer pipe, POGLM, spacer pipe, & anchor seal (4800# release) (OAL 24.77'. 154" from top of P2P to valve) POGLM has 1" x .25" port OV in pocket) REPLACED OV 1/9/23 10/30/2019 1.580 6,493.0 4,697.1 54.78 GLM LEAK LEAK in GLM @ 6493 RKB 6/12/2014 6,496.0 4,698.8 54.75 TUBING LEAK TUBING LEAK LOCATED W/ RELAY LDL, 0.75 BPM AT 1100 PSI 10/1/2019 2.990 6,512.0 4,708.1 54.53 LWR PACKER (ME) Set PIIP packer for the upper patch assembly 10/28/2019 1.625 8,124.0 5,692.5 49.43 PATCH - UPR PACKER (ME) UPPER PATCH PACKER, P2P,WITH EXPANSION JOINT CPEJ27001, SPACER PIPE, ANCHOR LATCH CPAL35114, OAL= 42.83' (WHEN EXP JOINT IS SHEARED & FULLY OPEN) Quadco CPP3 5216 9/29/2019 1.625 8,128.0 5,695.1 49.39 SPACER PIPE / EXPANSION JOINT 2-1/16" P110 SPACER PIPE 9/29/2019 1.590 8,132.0 5,697.7 49.36 TUBING LEAK TUBING LEAK LOCATED W/ RELAY LDL, 0.75 BPM AT 1100 PSI 8/13/2019 2.990 8,157.0 5,714.0 49.16 PATCH - LWR PACKER (ME) LOWER PATCH PACKER, P2P, OAL= 3.68' Quadco CPP3 5213 9/4/2019 1.625 8,248.4 5,774.1 49.01 SLEEVE-C AVA BPI 12/12/2009 2.310 8,540.0 5,966.0 47.70 FISH 18" Perf Gun From 2nd Perf Gun; in Rathole 8/18/1991 0.000 8,542.0 5,967.3 47.68 FISH 6' of Perf Gun From 3rd Perf Gun; in Rathole 8/18/1991 0.000 8,545.0 5,969.3 47.65 FISH OV 1.5" OV DROPPED IN RATHOLE 10/9/2004 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,545.0 2,400.9 47.80 1 GAS LIFT GLV BK 1 1,290.0 11/1/2019 0.156 3G-08, 1/11/2023 10:10:08 AM Vertical schematic (actual) PRODUCTION; 35.0-8,745.3 FISH; 8,545.0 FISH; 8,542.0 FISH; 8,540.0 IPERF; 8,366.0-8,386.0 IPERF; 8,310.0-8,350.0 A-SAND FRAC; 8,310.0 SOS; 8,278.3 NIPPLE; 8,272.7 SBE; 8,263.6 PACKER; 8,259.9 SEAL ASSY; 8,257.9 NIPPLE; 8,248.4 SLEEVE-C; 8,248.4 IPERF; 8,214.0-8,234.0 PRODUCTION; 8,164.5 PATCH - LWR PACKER (ME); 8,157.0 PACKER; 8,148.2 SPACER PIPE / EXPANSION JOINT; 8,128.0 PBR; 8,134.5 TUBING LEAK; 8,132.0 PATCH - UPR PACKER (ME); 8,124.0 GAS LIFT; 8,087.6 GAS LIFT; 7,826.8 GAS LIFT; 7,328.2 LWR PACKER (ME); 6,512.0 Upper patch/POGLM; 6,487.0 TUBING LEAK; 6,496.0 GAS LIFT; 6,492.7 GAS LIFT; 5,106.5 SURFACE; 35.0-3,657.1 GAS LIFT; 2,545.0 SAFETY VLV; 1,796.0 CONDUCTOR; 36.0-115.0 HANGER; 33.2 KUP PROD KB-Grd (ft) 35.00 RR Date 5/27/1990 Other Elev… 3G-08 ... TD Act Btm (ftKB) 8,759.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032012800 Wellbore Status PROD Max Angle & MD Incl (°) 56.02 MD (ftKB) 5,800.00 WELLNAME WELLBORE3G-08 Annotation Last WO: End DateH2S (ppm) 100 Date 12/4/2015 Comment SSSV: TRDP 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) 5,106.5 3,904.6 54.37 2 GAS LIFT GLV BK 1 1,321.0 11/1/2019 0.188 6,492.7 4,697.0 54.78 3 OPEN 1 10/11/2019 7,328.2 5,197.2 52.89 4 GAS LIFT DMY INT 1 8/11/2019 0.000 7,826.8 5,502.9 51.10 5 GAS LIFT DMY BK 1 0.0 9/17/1990 0.000 8,087.6 5,668.9 49.69 6 GAS LIFT DMY RK 1 1/2 8/11/2019 0.000 8,164.5 5,718.9 49.10 7 PROD DMY RKP 1 1/2 0.0 1/4/1991 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,214.0 8,234.0 5,751.5 5,764.6 C-4, UNIT B, 3G -08 9/15/1990 10.0 IPERF 4 1/2" Csg Gun, 60° phasing 8,310.0 8,350.0 5,814.4 5,840.5 A-4, A-3, 3G-08 8/18/1991 8.0 IPERF 2 1/8" Dynastrip, 90° phasing 8,366.0 8,386.0 5,850.9 5,864.0 A-2, 3G-08 9/15/1990 4.0 IPERF 4 1/2" Csg Gun, 180° phasing Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,310.0 8,350.0 1 A-SAND FRAC 11/25/2010 0.0 0.00 0.00 3G-08, 1/11/2023 10:10:09 AM Vertical schematic (actual) PRODUCTION; 35.0-8,745.3 FISH; 8,545.0 FISH; 8,542.0 FISH; 8,540.0 IPERF; 8,366.0-8,386.0 IPERF; 8,310.0-8,350.0 A-SAND FRAC; 8,310.0 SOS; 8,278.3 NIPPLE; 8,272.7 SBE; 8,263.6 PACKER; 8,259.9 SEAL ASSY; 8,257.9 NIPPLE; 8,248.4 SLEEVE-C; 8,248.4 IPERF; 8,214.0-8,234.0 PRODUCTION; 8,164.5 PATCH - LWR PACKER (ME); 8,157.0 PACKER; 8,148.2 SPACER PIPE / EXPANSION JOINT; 8,128.0 PBR; 8,134.5 TUBING LEAK; 8,132.0 PATCH - UPR PACKER (ME); 8,124.0 GAS LIFT; 8,087.6 GAS LIFT; 7,826.8 GAS LIFT; 7,328.2 LWR PACKER (ME); 6,512.0 Upper patch/POGLM; 6,487.0 TUBING LEAK; 6,496.0 GAS LIFT; 6,492.7 GAS LIFT; 5,106.5 SURFACE; 35.0-3,657.1 GAS LIFT; 2,545.0 SAFETY VLV; 1,796.0 CONDUCTOR; 36.0-115.0 HANGER; 33.2 KUP PROD 3G-08 ... WELLNAME WELLBORE3G-08 WELL LOG TRANSMITTAL #906036688 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Records: 3G-08 Run Date: 10/11/2019 and 10/13/2019 November 21, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 3G-08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20128-00 RECEIVE® DEC 0 9 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: Lffl-12 Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Sus p Well ❑ Other: Tubing Patch ❑✓ 2. Operator Name: ConocoPhlllips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development Exploratory ❑ p rY F-1190-065 Stratigraphic ❑ Service ❑6. 3. Address: P. O. Box 100360, Anchorage, Alaska API Number: 99510 50-103-20128-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025548 KRU 3G-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8,759 feet Plugs measured None feet true vertical 6,115 feet Junk measured None feet Effective Depth measured 0 feet Packer measured 8, 8135, 8148, Efeet true vertical 0 feet true vertical 5, 5699, 5708, 5 feet Casing Length Size MD TVD Burst Collapse CONDUCTORSUURFACE 3,622 feet 11 3,657' MID RECEIVED PRODUCTION 8,710 feet 6 8,745' MD NOV 12 2019 JEWELERY TYPI MD spth MD&TVD feet Composite gy�pp,, ,r���++p� Tubing (size, grade, measured and true vertical depth) 2.9 IF J-55 8,278' MD 5,794' TVD Packers and SSSV (type, measured and true vertical depth) UPPER PATCH/POGLM - SET UPPER 6,487' MD 4,694' TVD LWR PACKER (ME) - SET PIP PACKE 6,512' MD 4,708' TVD PATCH - UPR PACKER (ME) - UPPER 8,124' MD 5,692' TVD SPACER PIPE / EXPANSION JOINT - 2 81128' MD 5,695' TVD PBR - BAKER 10' STROKE PBR 8,135' MD 5,699' TVD 12. Stimulation or cement squeeze summary: PACKER - BAKER HB RETRIEVABLE PACKER 8,148' MD 5,708' TVD Intervals treated (measured): Treatment descriptions including volumes used and final press PACKER - BAKER D PERMANENT PACKER 8,260' MD 5,782' TVD 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments (required per20 AAC 25.070, 25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory ❑ Development Service ❑ Stratigmphic 0 Copies of Logs and Surveys Run F] 16. Well Status after work: Oil Q Gas WDSPL Printed and Electronic Fracture Stimulation Data C GSTOR 0 WIND 0 WAG ❑ GINJ 0 SUSPQ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Name: Paul Duffy / Sara Carlisle/ Rachel Kautz Authorized Name: Paul Duffy Authorized Title: Well Integrity Compliance Specialist Contact Email: N2549@conocophillips.com Contact Phone: 907-659-7126 Authorized Signature: Dat 11/10/2019 VTZ 12,1161 117 Form 10-404 Revised 4/2017 /� /y�16�I ABDMS_&N0V 13 2019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 10, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7a' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch and the POGLM set across known tubing leaks in producer KRU 3G-08 (PTD 190-065). Please contact Sara Carlisle, Rachel Kautz or me at 659-7126 if you have any questions. Sincerely, „ Paul Duffy Covering for Sara Carlisle/Rachel Kautz Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office Phone: (907) 659-7126 WI=LLS TEAM CWWAP"Ps RECEIVED' NOV 12 2019 3G-08 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 36-08 Failed a proactive TIFL on 7.5.19. A subsequent LDL showed tubing leaks @ 8132'& a gas lift mandrel leak @ 6496'. This 10-404 shows the steps taken to fix those leaks by installation of a 3-1/2", 33.97' OAL, Paragon 2 packer retrievable patch and a 3-1/2" Paragon 2 packer w/ POGLM retrievable patch covering the leaks @ 8132' & 6496', respectively, a passing CMIT-TxIA, MIT -IA, & TIFL proved integrity of the patches. Pertinent well work is copied below. 7.5.19 (AC EVAL) Proactive TIFL Failed. 9.3.19 SET LOWER 2.72" P2P @ 8157' RKB. (OAL 3.68'/ SN: CPP35213) OrNF`.1 9.29.19 10.28.19 10.29.19 10.30.19 SET 3 1/2 TTS TEST TOOL IN LOWER 2.72" P2P @ 8157' RKB, CMIT TBG x IA 2500 PSI "PASS", PULLED 3 1/2 TTS TEST TOOL @ SAME. SET UPPER 2.72" P2P w/ EXPANSION JOINT & SNAP LATCH ASSEMBLY @ 8127' RKB (ME) (SN: CPP35035 / CPEJ27001 / CPAL35114). SET TEST TOOL IN P2P @ 8127' RKB, ATTEMPTED MIT -T TO 2500 PSI "FAIL" PRESSURE GOING TO IA. RAN LDL f/ TOP OF TEST TOOL @ 8127' RKB TO GLM @ 6492' RKB. FLOW GOING THROUGH PATCH, NO OTHER LEAKS IDENTIFIED. PULLED TTS TEST TOOL & UPPER PATCH ASSEMBLY @ 8127' RKB. IN PROGRESS (2.725" P2P #CPP35216, EXPANSION JOINT #CPEJ27001, SPACER PIPE, ANCHOR LATCH #CPAL35114, 1.59" ID) MID-ELEM @ 8124' RKB. ATTEMPTED TO BLEED IA TO 500 PSI (FAIL). SET TEST TOOL IN P ***NOTE: UPPER PATCH ASSY EXPANDS TO 42.83' WHEN PULLING***2P @ 8124' RKB. LRS TO MITT TO 2500 (FAIL), CMIT TO 2500 (PASS). PRE - MIT= 1275/1260/390 INITIAL MIT= 2525/2525/400 15 -MINUTE= 2475/2475/400 PROGRESS. RUN 1: PERFORM STRINGSHOT, STRING SHOT INTERVAL = 6508'-6518'. CCL TO TOP SHOT = 4.8'. CCL STOP DEPTH = 6503.2'. CORRELATED TO TUBING TALLY DATED 9/17/1990. RUN 2: SET LOWER PACKER SERIAL# CPP35226 @ 6512. CCL TO MID - ELEMENT = 11.5'. CCL STOP DEPTH = 6500.5'. CORRELATED TO TUBING TALLY DATED 9/17/1990. SET 3 1/2" TTS TEST TOOL IN LOWER P21P @ 6512' RKB; CMIT TBG X IA TO 2500 PSI (PASS); PRE T/1/0=1300/1275/380 INITIAL T/1/0=2525/2525/400 15 MIN T/1/0=2475/2475/400 30 MIN T/1/0=2450/2450/400 (PASS) TOOK 2 BBLS TO PRESURE UP. BLED BACK TO 1400 PSI. PULLED TEST TOOL @ SAME & FLUSHED TBG W/ 60 BBLS OF HOT DIESEL. IN PROGRESS at i urr-LN rzr tcrr30115) FUGLM ASSEMBLY (27.92' OAL, 154" FROM TOP OF P2P TO DMY) ME @ 6486' RKB. MIT -IA TO 2500 PSI (PASS). PRE MIT T/1/0=1300/1300/400 INITIAL T/1/0=1325/2500/400 15 MIN T/1/0=1325/2445/400 30 MIN T/1/0=1325/2430/400 (PASS). PULLED DMY IN POGLM @ 6499' RKB, SET OV. SET TTS TEST TOOL IN UPPER P2P @ 6484' RKB. PULLED DMY @ 5107' RKB. IN PROGRESS. 11.01.19 11.05.19 3G-08 DESCRIPTION OF WORK COMPLETED SUMMARY SET GLV @ 5107' RKB. PULLED DMY, SET GLV @ 2545' RKB. MIT -T TO 2500 PSI (PASS). PRE T/1/0= 1300/1300/380 INITIAL T/1/0=2500/1300/380 15 MIN T/1/0=2440/1300/380 30 MIN T/1/0=2410/1300/380 (PASS). PULLED TTS TEST TOOL IN UPPER P2P @ 6484' RKB. JOB COMPLETE Initial T/I/O = 200/1150/730, IA FL @ 6493' (STN # 3 POGLM) SI WV and double blocked AL line. Stacked T x IA in 45 min to T/I/O = 1040/1040/660, IA FL @ same location Bled AL line. Bled IA in 30 min to T/I/O = 1100/600/580, IA FL @ same location. 15 min = 1100/600/580 30 min = 1100/600/540, IA FL @ same location 45 min = 1100/600/520 60 min = 1100/600/520, IA FL @ same location Final T/I/O = SI 1100/600/520 �- KUP PROD WELLNAME 313.08 WELLBORE 313-08 ConoeoNhillips t Q Well Dtea max nealBarao ro Fleitl Name Wellbore PPIl.W1 Wellhon Status Icl ('j MO (ttKBj MiBlm (KKBj Ad* 1, 41C.KUPA UK RIVER T 501032012 PR D 602 5,800.00 8)59.0 Comment H35 (ppm) Oete ......n End Oete KBGrtl(a) are Pelwse OMe SSSV: TRDP 100 121412015 LaSt WD 35.00 512711990 3GM, i .'s uce43AY Last Tag Veniul xM1emanE,irrelj Inehtlon1 OeptM1 (flKB) WeI1Wre IasiMM By 1EMBDate Last Tag: SUM 8,300.0 1122016 31-11pprpven • PARKER; a52 g Last Rev Reason 1 Anmtafnn Entl Dale W.B., Ded.od ey Rev Reason: Bel patch, install GLv's 11AI2019 3G-08 lergusp Casing Strings Oda fng Dssc nptlou 00 (m IDtm) TOP(cKa) Semepm (idern set Belch LTwj... VJNLen CONDUCTOR 16 15.06 36.0 115.0 115.0 62.58 l... Kratle Top Thread H-00 WELDED CONOI1GTOfl',%.0.1150 acing DescYpllon 00(inj ID(n) Tap(flKB) Set DeplM1 (flKa) Se[DepIM1 jND)... SURFACE RSIs 8.92 35.0 3,69.1 3,05).4 36.00 WLLen (I... Gratle Top iM1rem J-55 BTC sAFEry Wu: t,7X.a Casing OescriPtion OD (In) IO(In) Top (M1KB) $¢[DeplM1 (f[KB eel OepiM1(NO)_. PRODUCTION ] 6.28 35.0 8,>45.3 6,105.5 26.00 W1ILen (L.. G rade Top ThreN J-55 BTC robing Strings GAS LIFT: 1111,0 Turing 0-riplion SVIng Ma...1O(in) TUBING 31/2 3.5"x2.8]5" @ 8267' 2.99 ToP(fiKB) 33.2 3e1DapIN cu. 8,2)9.0 Set DeplF(NDj(... 1 WI(blk) 9.20 Grade L-80 Top Gonnxtion EVE -MOD Completion Details DIDa'.aiesT.t- Top WD Top mmiw n Nal Tap(flK9) MKD) n Item Das Can 10 (in) 33.2 33.2 0.14 HANGER WKM GEN IV HANGER 3.500 17961 1,780.9 21.54 SAFETYVLV CANDO TRDP-IA-SSA SAFETY -VALVE 812 GA6 UFT; 5,155 8,134.5 5,699.3 49.34 PBR BAKER ip'STROKE PBR 3.000 8.148.2 5,708.3 49.23 PACKER BAKER HB RETRIEVABLE PACKER 2.890 8,182.] 5,730.9 48.95 BLAST RTM -B DBIDE BLAST RINGS (2) 2.867 GAs uFi; s,4en 8.248.4 S,774.1 49NILE .01 PPAVA BPL NIPPLE 2.750 POINGLEA$a,4e5B 8,29.2 S,T/9.8 49.04 70Retluchi CROSSOVER 3.5 x 2.8]5, D2.M1,fi.5p, J-55, EUE-MOD 2.8]5 upw, ptl...LM, Amina 8,257.9 5,780.3 49.05 SEALASSY BAKER LOCATOR SEALASSEMBLY 2.406 GAP PACKER IME): 5512.0 8,259.9 5,781.6 49.06 PACKER BAKER D PERMANENT -PACKER 3.250 8,263.6 5,]84.0 49.0] SBE BAKER SEAL BORE EXTENSION 2.312 GAS LIFT; 732a.2 &272,7 5,790.0 49.11 NIPPLE CAMCO D NIPPLE NOGG 2250 GAS un;7,exie 8,2783 5,793.6 49.13 SOS BAKER SHEAR OUTSUB 2.441 Other In Hole (VJirellne rettlevable, plugs, valves, pumps, fish, etc:) -- IDnPY.) Topmn GAS LIFT; 5X7.6 Umff1K81 (rye.) (1) Des Cam Run Due to 6,48/.0 4,693.7 54.83 Upper p.EhJPOGLM Set Upper pe h/PGGLMB&Sembly consisting of PllP packer, Spacer pipe, POGLM, spacer pipe, 8 anchor 1WW/201 9 1,580 PATCX-DPR PAG'(ER (NEI E'.3 seal (481 release) (DAL 24.77.154" tram top of P2P toV81ve) POGLM he. V X.25- part GV In POCkat 6,496.0 4,6988 54.75 TUBING LEAK TUBING LEAK LOCATED W/RELAY LDL, 0.75 BPM AT 1100 PSI 1011120,19 2.990 TUBING LEA(; e,lsxo FBR;B,faa.E SPACER PIPE JOINI 0 JOMT5t250 NA PACKER9,t482 0512.0 4,708.1 54.53 LWRPACKER (ME) Set PIIPp.Ckerlarlheupperpetchassembiy 101281201 g 1.625 8,124.0 5,692.5 49.43 PATCH-UPR PACKEFI UPPER PATCH PACKER, P2P,CPP35216 WITH EXPANSION JOINT CPEJ27001, SPACER PIPE, 92912019 1.625 PATCH-LWR BACKER (ME). ANCHOR LATCH CPAL35114. CAL= 42.83 (WHEN EXP JOINT IS SHEARED 8 FULLY OPEN) 9AVO PRODUCTION 1 SLID5 $128.0 5,695.1 49.39 SPACERPIPE/ EXPANSION JOINT 2-1116-P110 SPACER PIPE 92912019 1.590 8,132.0 5,697) 49.36 TUBING -LEAK TUBING LEAK LOCATED WI RELAY LDL, 0.75 BPM AT 1100 PSI 81132019 2.990 IPERF;e,214043O,uD� 8.19.11 5,]14.0 49.16 PATCH-LWR PACKER(ME) 0%AER PATCH PACKERP, CPP35213, DAL= 3.63 9'42019 1.625 $248.4 S,J>4.1 49.01 SLEEVE -C AVABPI 12/12200 2.310 SLEEYE.C'. 5248.49 NIPPLE: 52459 8,540.0 5,9fi6.0 q.JO FISH IT Ped Gun From 2nd Ped Gun; Left in Rathale 811811991 0.000 8,542.0 5,99.3 47.68 FISH 6'af Ped Gun From"c Ped Gun: LeRin Ralholc 811811991 0.000 SEPLA8aY: 9,25].8 8,545.0 5.9fi9.3 4].65 FISH OV 1. GGVDRDPPED INRATHOLE 10/92004 0.000 Perforations & Slots PACKER: 8.2fl SM1OI BSE; B.M3.6 NIPPLE; B,YIl.] Top(KKB) 611-M Top Top) -75 RUNS.) (5 76) LinNeE Zone par ,ens (sM1o[sM ) Type Co. 8,214.0 8,234.0 S,J51.5 _5 7-6-4-6 CJ, UNIT B,3G -pg 911511990 10.0 'PERF 41IT Csg Gun, 60 tag. 805152]53 8,310.0 8,350.0 5,814.4 5,840 .5 A4, A-3, 3G-08 811811991 8.0 'PERF 1fiphasing 2 2118' Dynes(rip, 90 tleg. phasing 8,366.0 8,38fi.0 5,850.9 5,864.0 A -2,3G-08 911511990 d.01PERF 4112"Csg Gun, 1800¢8. phasing Frac Summary $252010 r Dale Proprynt Deselai(b) prapwnt In Fo,mallan (Ib) 11 1 MSANDERA46,310.0 Slpp Start Data Top Depan (RKBj Dtm(i Lida Lai Fired Syzlem Voleiwn(bN) Velslurry(hbp I 1 11252010, 8,350.0 IPE0.F1531.0$Jora Madonal inserts 3[ atl IPERF10355.O.B3X0- N iap (RKe TaP(TVpj Valve lamer, Pareade TRO Run (kHBj Make Modal OD TnI Sev Type Type (n) (psi Run pate Com 2,545.0 2,400.9 MERLA TMPD 1 GAS LIFT GLV Be 11.156 1,290.0 11112019 2 5,10fi.5 3,904.6 MERLq TMPD 1 GAS LIFT GLV BK 0.188 1,321.0 11/112019 3 6,492) 4,697D MERLA TMPD 1 OPEN 101112019 FISH; 5590.0 4 ],320.2 5,19).2 MERLA TMPD 1 GAS LIFT DMY INT 0.000 81112019 FlSX; e.5410 5 J,82fi8 5,502.9 MERLA TMPD 1 GAS LIFT DMV BK 0.000 0.0 9/17/1990 6 8,087.6 5.6U.9 CAMDO MMG-2 1112 GASLIFT DMV RK 0.000, 811112(119 FSH:5545.0 ] 8,164.5 5,718.9 CAMCO MMG-W 112 PROD OMY RKP 0.000 0.0 114/1991 PROWGTION; 3508,745,3 WELL LOG TRANSMITTAL #905995089 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 3G-08 Run Date: 9/30/2019 190065 3136 1 October 17, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3G-08 Digital Data in LAS format, Digital Log file RECEIVED 1 CD Rom 50-103-20128-00 OCT 2 3 2019 A®GCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: LO/2V Signed: WELL LOG TRANSMITTAL #905904055 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log and Packer Setting Records: 3G-08 Run Date: 8/13/2019 and 09/04/2019 19 00 65 3124U September 20, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3G-08 ED Digital Data in LAS format, Digital Log file SEP 2 4 RECEIVED 1 CD Rom 50-103-20128-00 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Z N �" / ` Signed: Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax Delivered to: n AOGCC . ATTN: Natural Resources Technician II r Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 -rte Anchorage, AK 99501 i TRANSMITTAL DATE, TRANSMITTAL# �.. WELL NAME AN # SERVICE ORDER FIELD NAME DESCRIPTIONDESCRIPTION DATA TYPE DATELOGGED Prints CD's 1H-114 1H-111 1H-105 1H-113 1H-116 3M-19 3G -07A 50-029-23584.00 50-029-23581-00 50-029-20727-01 50-029-23586-00 50-029-23594.00 50.029.21737-00 50-103-20127-01 EOSH-00071 EAI8-00022 E118-00075 E718-00076 E118-00077 E118-00076 E118-00079 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL WL IPROF IPROF-WFL IPROF-WFL IPROF-WFL IPROF-WFL Caliper PPROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 15-511-19 17 -Jul -19 19Ju1-19 20 -Jul -19 21 -Jul -19 22 -Jul -19 23-Ju1•19 1 1 t 1 1 1 1 3G•11 50-103.20133-00 E718-00081 KUPARUK RIVER WL (PROF FINAL FIELD 25 -Jul -19 1 3M-13 1B-16AL1 1A-17 1C-121 3N -14A 3G-08 50-029-21720-00 50-029-22457-60 50 -029.22102-00 50-029-23015-00 50-029.21589.01 50-103.20128.00 E118-00084 EDEA -00009 E1 18.00085 E118-00086 EOSH-00074 EOSH-00075 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL Memory WL WL WL WL Caliper PPROF LDL (PROF LDL,Caliper LDL,Caliper FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 28 -Jul -19 28 -Jul -19 29 -Jul -19 1 -Aug -19 2 -Aug -19 3 -Aug -19 1 1 1 1 1 1 2N-317 50-103-20266-00 USH-00076 KUPARUK RIVER WL LDL FINAL FIELD Aug 19 1 11116— lmt4� AUG fl 15 -- ----- A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the 6X package have been verified to match the media noted above. ame Sign toe Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this return via courier or sign/scan and email a copy thilliom erger and CPAI. point. 'TSPrintCenter slb.com Tom.Osterkam conoco SLB Auditor- TlJ Schlumberger -Private SCANNED AUG 0 7 2019 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ¢~_ ~_.~.~' File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: ~ Bren Vincent Nathan Lowell Is~ ~ TO RE-SCAN Notes: Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd STATE OF ALASKA ALASK, . AND GAS CONSERVATION COMMIS.) REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations fl Stimulate 17 Other Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. _ Development r Exploratory r _ s 190 -065 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 ti 50 - 103 - 20128 - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25548 , -. 3G - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8759 feet Plugs (measured) None true vertical 6115 feet Junk (measured) 8540', 8542', 8545' Effective Depth measured 8660 feet Packer (measured) 8148, 8260 true vertical 6047 feet (true vertucal) 5708, 5782 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 3622 9 -5/8" 3657 3057 PRODUCTION 8710 7 8745 6106 %AMEX DEC 30ZMMU F VED Perforation depth: Measured depth: 8214'- 8234', 8310' - 8350', 8366-8386' DEC 2 0 Zt10 True Vertical Depth: 5752'- 5765', 5814'- 5841', 5851'- 5864' OtCM1N8Sj0A t ±, ,,a a t 8S t: (size, grade, MD, and TVD) Tubing ( 9 ) 3.5 "x2.875 ", L - 80, 8278 MD, 5794 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER HB RETRIEVABLE PACKER @ 8148 MD and 5708 TVD PACKER - BAKER D PERMANENT PACKER @ 8260 MD and 5782 TVD SAFETY VLV - CAMCO TRDP -1A -SSA SAFETY VALVE @ 1796 MD and 1781 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8310' -8350' Treatment descriptions including volumes used and final pressure: 99440# of 16/20 carbolite 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 190 861 246 -- 202 Subsequent to operation 479 1169 547 -- 181 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development p - Service r Stratigraphic 15. Well Status after work: Oil 17 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GIN) r SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce 265 -6471 Printed Name John Peirce Title Wells Engineer Signature .L Phone: 265 -6471 Date 1 2 f 2 f i c ---:!- DMS f / G DEC 2 21011 4( ,z.af Form 10-404 Revised 10/2010 1 ubmit Original Only 3G -08 Well Work Summary DATE SUMMARY 11/9/10 TAGGED @ 8403' SLM, EST. 842 KB. SET 2.25" CA -2 PLUG @ 8273' RK ULLED GLVs @ 7328', 6473' & 5106' RKB. SET DVs @ SAME. IN PROGRESS. 11/10/10 PULLED GLV @ 2545' RKB & REPLACED WITH DV. PULLED OV @ 8088' RKB. LOADED TBG & CSG WITH 220 BBL SW WITH DSL FREEZE PROTECT. SET DV @ 8088' RKB. TESTED TBG & IA TO 3500 PSI, EACH PASSED. PULLED 2.25" CA -2 PLUG @ 8278' RKB. READY FOR SAND PLUG. 11/11/10 PERFORMED FULLBORE SAND PLUG TO ISOLATE A2 SAND PERFORATIONS AND LOWER PART OF THE A3. PUMPED 1650# OF 20/40 SAND IN 9.9 -BBL SLURRY. ESTIMATED SAND TOP DEPTH IS 8330'. FREEZE PROTECTED TUBING WITH 20 -BBL DIESEL CAP. 11/12/10 TAGGED SAND PLUG na EST. 8353' RKB. ESTABLISHED INJ RATE: 2 BPM @ 1300 PSI. SET ISO SLEEVE ACROSS SCSSSV @ 1796' RKB. READY FOR FRAC. 11/25/10 FRAC A3 SANDS. PUMPED A TOTAL OF 99440 LBS OF 16/20 CARBOLITE. COMPLETED FRAC WITH 9 PPA ON FORMATION. FREEZE PROTECTED WITH 15 BBL OF DIESEL. 11/26/10 PULLED FRAC SLEEVE FROM 1796' RKB, TAG TAIL AT 8267' SLM (8279' RKB) TAD TD AT 8301' SLM (8313' RKB), SET AVA CATCHER AT 8248' RKB, PULLED STA.#4 DGLV 7328' RKB 11/27/10 PULL STA. #3 FROM 6493' RKB, BRUSHED STA.#4 AND STA. #3, SET STA. #3 AT 6493' RKB 11/28/10 SET 3/16" OV AT 7328' RKB, PULL AVA CATCHER FROM 8248' RKB JOB COMPLETE READY FOR COIL 11/29/10 POST FRAC FCO. TAGGED FILL AT 8344' CTM. CLEANED DOWN 8484' (94' BELOW BOTTOM PERFS). WELL FULL OF DIESEL. 11/30/10 ATTEMPTED TAG FILL WITH 1.75" SAMPLE BAILER. ENCOUNTERED PROPPANT BRIDGE @ 2509' SLM. IN PROGRESS. 12/1/10 BAILED PROPPANT BRIDGES f/ 2500' TO 8217' SLM. PULLED ORIFICE @ 7328' RKB. ATTEMPTED SET DV @ 7328' RKB. IN PROGRESS. 12/2/10 CHASED AVA CATCHER TO 8248' RKB. SET INT LATCH DV @ 7328' RKB. PULLED GLV @ 6493' RKB, REPLACED WITH 1/4" OV. IN PROGRESS. 12/3/10 PULLED DVs @ 5106' & 2545' RKB. SET GLVs @ SAME. PULLED CATCHER @ 8246' RKB. COMPLETE. KU P 0 3G -08 ConocoPhillips * Well Attributes Max Angle & MD ;TD 1 A5S'Ka, 111Cr Wellbore API /UWI Field Name Well Status Inc! (') MO (ftKB) Act Btm (006) arm ,ukps --' 'Comment 501032012800 KUPARUKRIVER UNIT PROD I 56.02 5,80000 8,7590 _ 2 (ppm) Date Annotation I End Date KB -Grd (ft) Rig Release Date -'- Weil c fig, ,; .5 +i g2;. •;49 uM SSSV TRDP 120 12/11/2009 Last WO; I 35 00 5/27/1990 irr Sch9ma8C :Annotation I Depth (ftKB) End Date Annotation Last Mod .. End Date Last Tag: SLM I 8,406 0 11/1/2009 Rev Reason: GLV C/O Imosbor 12/5/2010 in^" I Casing Strings HANGER, 33 - --- ;,3,,,T,' ` ) - Casing Description String 0... String ID .. Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 > ' - CONDUCTOR 16 15 062 36.0 115.0 115.0 62.58 H -00 WELDED , _._..r -- i_ - - �, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... . Set Depth (TVD) ... String Wt... String ._ String Top Thrd SURFACE 9 5/8 8 921 35.0 3,657 1 3,057.3 36.00 J BTC Casing Description String 0... String ID ... Top MKS) Set Depth (f.. Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION , 7 6151 350 87453 6,105.5 26.00 J -55 BTC T Tubing Strings I Tubing Description IString 0... '.String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) . String Wt_. String ... l String Top Thrd CONDUCTOR, TUBING 3 5 x2.875" I 3 1/2 2.992 I 33.2 8,279.0 5,794.1 9 20 L -80 EUE -MOD 36 -75 Completion Details Top Depth (1VD) Top Intl Nonni... SAFETY VLV, n Top (RIM) OMB) e) „ Deacrpton Comment ID (in) 1.796 33.2 33.2 0.45 HANGER WKM GEN IV HANGER 3.500 1,796.1 1,780.9 21.54 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 Gas LIFT, x - t -. 8,134.5 5,699.4 49.34 PBR BAKER 10' STROKE PER 3.000 2,545 8,148.2 5,708.4 49.23 PACKER BAKER HB RETRIEVABLE PACKER 2.890 ,, 8,182.7 5,730.9 48.95 BLAST RING 30' CARBIDE BLAST RINGS 2.992 8,248.4 5,774.1 49.19 NIPPLE AVA BPL NIPPLE 2.750 8,257.2 5,779.8 49.20 X0 Reducing CROSSOVER 3.5 x 2.875, ID 2.441, 6.50, J -55, EUE -MOD 2.875 SURFACE, , � 8,257.9 5,780.3 4920 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.406 35 - 3,657 • 8,259.9 5,781.6 49.20 PACKER BAKER D PERMANENT PACKER 3.250 8,263.6 5,784.0 49.20 SBE BAKER SEAL BORE EXTENSION 2.441 GAS LIFT. 5,106 8,272.7 5,790.0 49.21 NIPPLE ' CAMCO D NIPPLE NO GO 2.250 8,278.3 5,793.6 49.21SOS BAKER SHEAR OUT SUB 2.441 GAS LIFE, 6,493 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth GAS LIFT, (ND) Top loci 7,328 ,._. Top(ftKBJ_ 0K8) () Description _.. ,.. Comment Run Date ID(in) - 8,248.4 5,774.1 49 19 SLEEVE -C AVA BPI 12/12/2009 2.310 GAS uFT, lit- 8,540.0 5,965.8 47 10 FISH 18 Perf Gun From 2nd Perf Gun Left in Rathole 8/18/1991 0.000 IF - 8,542.0 5,967 -1' 47.10 FISH 6' of Perf Gun From 3rd Pert Gun; Left in Rathole 8/18/1991 0.000 lit 8,545 .0 5,969.2' 47.10 FISH �OV 1.5" OV DROPPED IN RATHOLE 10/9/2004 0.000 GAS LIFT, " Perforations & Slots 8.088 . . - _. Shot Top (TVD) Btm (TVD) Dens ■ Top ((K61 Btm (ftK6) (HKB) (HKB) Zone Date ( Type Comment 8,214.0 8,234.0 5,751 .6 5,764.7 C-4, UNIT B, 9/15/1990 10 0 IPERF 4 12" Csg Gun, 60 deg. phasing 3G-08 PER, 8035 8,310.0- -- _ _ - 8,310.0 8,350.0 5,814 4 5,840.5 A-4, A -3, 3G-08 8718/1991 8 -0 IPERF 2 1/8" Dynastdp, 90 deg. phasing PACKER, 8,148 i1111ll - 0 - 8,366-0 8,3866 0 .0 5,850 .9 5,864.0 A -2, 3G -08 9!15/1990 4.0 IPERF 4 1/2" Csg Gun, 180 deg. phasing P 9000CTION, Stimulations & Treatments 8,165 _ Bottom Min Top Top Max Bt. Top Depth Depth _ Depth Depth (TVD) (TVD) (8108) (ftKB) (ftKB) MB) Typ Date Comment IPERF 1 8,310.0 8,350.0 5,814.4 5,840 -5 A -SAND FRAC 11252010 PUMPED A -SAND FRAC, 99440# OF 16/20 8,214 'u- 6 - CARBOLITE INTO PERFS k Notes: General & Safety SLEEVE -C, End Date Annotation 8,248 l 8/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 NIPPLE, 8,246 --- - - SEAL ASSY, J.. 8,258 PACKER, 8,260 -- SBE, 8,264 - NIPPLE, 8,273 - SOS, 8,278 - - - -- IPERF, A ' 8,310$350 ; AANND FRAC, 8,310 a Mandrel Details IPERF, - Top Depth Top Pod 8,366.8,386 - n (TVD) Inc! OD Valve Latch Size TRO Run Stn Top jftK6) (ftKB) (') Make Model (in) Sari Type Ty (in) (psi) Run Date Com... 1 2,545.0 2,401.6 50.16 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,168.0 12/3/2010 FISH, 8,540 - - --- 2 5,106.5 3,904 .6 54.37 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,193.0 12/3/2010 3 6,492.7 4,697 054.83 MERLA TMPD 1 GAS LIFT OV BK 0.250 0.0 12/3/2010 FISH, 8,542 4 7,3282 5,197.2 52.89 MERLA TMPD 1 GAS LIFT DMY BKO-3 0.000 0.0 12/3/2010 5 7,826.8 5,503.4 51.52 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 9/17/1990 FISH, 8.545 6 8,087.6 5,668.9 49.72 CAMCO MMG -2 1 12 GAS LIFT DMY RK 0.000 0.0 11/102010 7 8,164.5 5,719.0 49.10 CAMCO MMG -W 1 12 PROD DMY RKP 0.000 0.0 1/4/1991 PRODUCTION, 35-8,745 T il I. D, 8,759 ConocoPhllips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Searriount: • ~~~~iv~ APR 0 5' 2010 ~# Ail ~ Gas Cons. Commission 1~1~ ~ °~s 3~, Dg _ ~ Enclosed please find a spreadsheet with a list of wells from the Kupantk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 2 and 21, 2010. The corrosion inhibitor/sealant was pumped March 27, 28 and 29, 2010. The attached spreadsheet presents the well name, t'op of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, MJ L veland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/31/10 ze zR zr zr ~u ~i ~ ~ ans ~n 4 so own•~ 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 3A-02 50029214310000 1852050 Surface n/a 26" n/a 4.25 3/29/2010 3A-04 50029214330000 1852070 SF n/a 26" n/a 4.25 3/29/2010 3A-07 50029214440000 1852230 SF n/a 25" n/a 4.25 3/29/2010 3A-16 50029214920000 1852840 SF n/a 23" n/a 3.4 3/29/2010 3B-10 50029213660000 1851140 6'6" Na 6'6" n/a 25.5 3/28/2010 3C-11 50029213570000 1851020 SF Na 25" n!a 4.25 3/27/2010 36-08 50103201280000 1900650 SF 0.65 2T 32/10 5.52 3/28!2010 3G-09 50103201290000 1900670 SF 0.60 22" 312/10 4.67 3282010 3G-22 50103201470000 1901420 SF n/a 22" n/a 4.25 3/282010 3H-01 50103200840000 1871100 SF n/a 21" Na 4.25 3/282010 3H-03 50103200850000 1871110 17" 0.40 8" 321/10 1.7 3/282010 3H-146 50103200920200 2050210 SF n/a 23" n/a 3.4 3292010 31-02 50029215150000 1853080 SF n/a 22" n/a 2.97 3292010 31-10 50029219340000 1890370 39' 3.50 24" 321/10 3.4 3292010 3J-04 50029214000000 1851650 SF n/a 23" n/a 3.4 328/2010 3J-14 50029214960000 1852880 SF n/a 25" n/a 4.67 3/282010 3J-15 50029214970000 1852890 SF Na 22" n/a 3.4 3/282010 3M-05 50029217060000 1870250 SF Na 21" n/a 3.4 3/29/2010 3M-07 50029217080000 1870270 SF n/a 22" n/a 4.25 3/292010 30-09 50029218250000 1880610 SF n/a 23" n/a 4.25 3272010 30-16A 50029217960100 1880430 SF Na 22" Na 3.52 3/27/2010 3R-10A 50029222530100 1920310 SF n/a 21" n/a 4.25 3272010 3R-11 D 50029222480000 1920160 SF n/a 17" n/a 3.25 3272010 3R-15 50029222580000 1920340 SF n/a 24" n/a 3.82 327/2010 3R-19 50029222690000 1920460 1" Na 21" n/a 5.1 3/27/2010 3R-25 50029226220000 1951810 SF n/a 21" n/a 5.52 3/272010 Scblumbepgel' (JJl 08/22/07 NO. 4384 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 2, '7, ZOO7 (i.. ("'"\" ("f"'"'" Cl)l1\í\Î\~\5\Ofl. UC. ') 1 'Lt)t)1 ~":,I<,,.,)1'" . scAtlNa:> þ.. \J tJ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD 1R-27 11850425 FPIT ¡q / -/0;) 08/18/07 1 31-08 11839638 LDL )~¿'-rlh\ 07/28/07 1 2M-19 11813070 INJECTION PROFILE I ,.-" l~ I-~-::l 07/29/07 1 3G-26 11813071 LDL 1~'7 -I"I-:};.ç 07/30/07 1 1R-18 11837482 SBHP/DDL 1'11 -' ^'ñ~ 07/31/07 1 1Y-01 11813072 INJECTION PROFILE U~ - /'K3-ct')ó 07/31/07 1 2C-08 11813073 INJECTION PROFILE' I JTl' 11r.~ -(oft-\' 08/01/07 1 3H-32 11837483 LDL ~'ùV", _~.., 08/01/07 1 1Y-10 11837485 INJECTION PROFILE 'u~ Iíj(~ -r&'"" ) 08/03/07 1 3G-08 11813075 PRODUCTION PROFILE' 1~/) - (J G,s- 08/04/07 1 1A-06 11837486 INJECTION PROFILE iJT.e l"if/-It f..,. 08/04/07 1 2N-337B 11837489 PRODUCTION PROFILE . AN~ - It", ~ 08/06/07 1 2U-08 11813076 LDL wr7L ,~-^9-1 08/06/07 1 1G-12 11837490 PRODUCTION PROFILE 1153 - ~;l 08/07/07 1 2N-343 11745232 MEM INJECTION PROFILE ' ()7"('. ,t1'1( - rA::J 08/08/07 1 2N-327 11837491 SONIC SCANNER Be ~-oc.o"" 08/08/07 1 2N-327 11837491 SONIC SCANNER-FMI .:ð¡...-'ì ,..,/ L:J. 08/08/07 1 3K-01 11632749 PRODUCTION PROFILE . ¡f}Co ~ 1,)/ 08/12/07 1 2X-04 11846430 INJECTION PROFILE (Jj:(' I<j¡~ -If'7( 08/13/07 1 2Z-29 11850419 SBHP SURVEY /1r'n ..:. )::Jg 08/13/07 1 2X-19 11850420 SBHPSURVEY J~~-/~~- 08/13/07 1 1A-20 11850421 SBHP SURVEY ¡ t:)/) - II_~ 08/14/07 1 1 F-13 11850422 SBHP SURVEY l) 'I.(' I~~ -/L./¿; 08/14/07 1 1H-10 11846432 SBHP SURVEY JOJ-:(. -~ 08/14/07 1 1Q-10 11846431 SBHP SURVEY I '7'¡i¡ - It:? '7r 08/14/07 1 2U-05 11846433 INJECTION PROFILE I ~ -:rL' _ Hr./:) - (JJ~ 08/15/07 1 2D-12 11846434 PRODUCTION PROFILE I fIl./ - t".A4 08/16/07 1 2H-06 11846435 LDL J~r:; ~ /(",0, 08/17/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 'd7l . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing_ Alter casing _ Repair well _ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 89 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 100360 Stratigraphic~ Anchorage, AK 99510-0360 service__ Kuparuk .Unit 4. Location of well at surface 8. Well number 2538' FNL, 195' FWL, Sec. 24, T12N, R8E, UM (asp's 498573, 5988562) 3G-08 At top of productive interval 9. Permit number / approval number 978' FNL, 1580' FEL, Sec. 25, T12N, R8E, UM (asp's 502082, 5984843) 190-065 At effective depth 10. APl number 50-103-20128 At total depth 11. Field / Pool 12743 FNL, 1304' FEL, Sec. 25, T12N, RSE, UM (asp's 502358, 5984549) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8759 feet Plugs (measured) Tagged PBTD (9/28/00) @ 8419' MD. true vertical 6115 feet Effective depth: measured 8419 feet Junk (measured) true vertical 5886 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 220 Sx AS I 115' 115' SURF CASING 3568' 9-5/8" 1350 Sx AS Ill & 500 Sx 3657' 3057' Class G PROD CASING 8656' 7" 225 Sx Class G 8745' 6105' Perforation depth: measured 8214-8234'; 8310-8350'; 8366-8386' MAR 2 ? Z00! Alaska 0il & Gas Cons. Commission true vertical 5751 - 5765'; 5814 - 5840'; 5851 - 5864' Anchorage Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55, Tubing @ 8258' MD; 2.875", 6.5#, J-55, Tubing @ 8279' MD. Packers & SSSV (type & measured depth) Baker 'D' Perm. Packer @ 8260' MD; Baker 'HB' Retrv. Packer @ 8148' MD. Camco 'TRDP-1A-SSA' @ 1796' MD. 13. Stimulation or cement squeeze summary . Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Da ly Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 641 365 763 - 165 Subsequent to operation 734 434 374 188 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date Signed . ,¢~ Prepa~e~b; Jol~n Peiroe 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 3G-08 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT 9/22/00: RIH & tagged PBTD at 8486' MD. 9/23/00: RU & pumped 22 bbls of gelled sand slurry containing 4250 bbls of sand, to place an isolation sand plug across the open 'A' sand perforation intervals located at: 8310 - 8350' MD 8366 - 8386' MD 9124100: RIH & tagged sand plug at 8284' MD. 9~25~00: MIRU & PT equipment. Pumped a Hydraulic Fracture Treatment using 16/20 & 12/18 mesh proppants, through the 'C' sand perforation interval located above the sand plug at: 8214 - 8234' M D Pumped a Breakdown stage @ 25 bpm, followed by Shutdown. ISIP @ 1757. Resumed pumping a Scour stage w/100 bbls of 50# Crosslinked Gel, followed by 50 bbls of Scour slurry w/lppa proppant, followed by 102 bbls 20# Linear Gel Flush, followed by Shutdown. ISIP @ 1964. Got 700 psi reduction in perf friction w/Scour stage. Resumed pumping Data Frac stage w/150 bbls of 50# Crosslinked Gel, followed by 74 bbls of Linear Gel Flush, followed by Shutdown. ISIP @ 2169. Data Frac suggested possible multiple fractures. Resumed pumping Frac Treatment w/180 bbls Crosslinked Pad stage, followed by Crosslinked Slurry stages w/proppant ramped in stages from I to 8 ppa, followed by 70 bbls Flush, followed by Shutdown. Placed 100,000 lbs of proppant in the formation. RD. 9127100: RIH w/CT & jetted a proppant & sand plug fill cleanout to 8435' MD. 9/28/00: RIH & tagged fill at 8419' MD. Returned the well to production w/gas lift & obtained a valid well test. THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 E E PI~ E W M A TE R IA L U N D ER TH IS M ARK ER > .... STATE OF ALASKA " ALAS OILAND GAS CONSERVATION C©Mk ,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation' Shutdown _ Stimulate__~ Plugging _ Perforate _ Pull tubing _ Alter casing _ . Repair well _ Other _ 2, Name of Operator: 5. Type of Well: i6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development _Z~ 89' RKE 3. Address: Exploratory ~ 7. Unit or Prope'~ty: P.O. Box 100360 Stratagrapic ___, Anchorage, AK 99510-0360 Service __, Kuparuk River Unit 14. Location of well at surface: 8. Well number: 2538' FNL, 195' FWL, Sec 24, T12N, RSE, UM 3G-08 At top of productive interval: 9. Permit number/approval numbei: 978' FNL, 1580' FEL, Sec 25, T12N, R8E, UM 90-65 · At effective depth: 10. APl number: 1219' FNL, 1354' FEL, Sec 25, T12N, R8E, UM 50-103-20128-00 At total depth: 11. Field/Pool: 1273' FNL, 1304' FEL, Sec 25, T12N, R8E, UM Kuparuk,River Field / Oil Pool 12. Present well condition summory Total Depth: measured 8759 feet Plugs (measured) None true vertical 6115 feet Effective Depti measured 8660 feet Junk(measured) None true vertical 6047 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 220 Sx AS I 121' 121' Surface 3622' 9-5/8" 1350 Sx AS III & 3657' 3220' 500 Sx Class G Production 8710' 7" 225 Sx Class G 8745' 6100' Uner Perforation Depth measured 8214'-8234'; 8310'-8350'; 8366'-8386' true vertical 5751'-5765', 5814'-5840', 5851'-5864' · . Tubing (size, grade, and measured depth) 3.5", 9.3 lb/fi, J-55 @ 8258' & 2.875", 6.5 lb/fl, J-55 @ 8258'-8279' ' ' " ~ ' Packers and SSSV (type and measured depth) Packer: Baker HB @ 8148' & Baker D @ 8273'; SSSV: Camco TRDP-1A-SSA @ 1796' 13. Stimulation or cement squeeze summon/ Fracture stimulate "A" SQnd on 4/9/98 ........ 8310'-8350', 8366'-8386' Treatment description including Volumes used and final pressure Pumped 103,935 lbs of 16/20, 12/18, & 10/14 ceramic proppant into formation, fp was 4916 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 986 607 260 995 173 Subsequent to operation 1209 754 288 1004 173 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil _X Gas _ Suspended 17. I hereb,,! certify that the foregoing is true and correct to the best of my knowledge. Signed 11110: Production Engineering Supervisor Date Form 10-404 Rev I 15/88 SUBMIT IN DUPUCATE~ ARCO Alaska, Inc. ~ - KUPARUK RIVEH UNI I A K1 (3G-OS(W4-6)) WELI~' JOB SCOPE JOB NUMBER 3G-08 FRAC, FRAC SUPPORT 0403981054.4 -'DATE" DAILY WORK -UNIT NUMBER 04/09/98 PUMP "A" SANDS REFRAC --DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I (~) Yes O No .I (~) Yes O No DS-GALLEGOS JOHNS ESTIMATE KD1973 230DS36GL $90,800 $98,069 Initial Tbg Press Final Tbg Press Initial Inner Ann Finar Inner Ann, Initial Outer Allh ' I Final Ou~ Ann 467 PSI 16.7.0 PSI 450 PSI 500 PSII 10 PSI 300 PSI DALLY SUMMARY PUMPED "A" SANDS REFRAC , COMPLETED THRU FLUSH. PUMPED 103,935# PROPPANT IN PERFS. 7650# 16/20,87,545~ 12/18 AND 8,740# 10/14. LEFT 800# PROPPANT IN PIPE. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP, HOT OIL PUMP AND APC VACUUM TRUCK. 09:48 HELD TAILGATE SAFETY MEETING, DISCUSSED LIFTING PROCEDURE. 09:58 PRESSURE TEST SURFACE LINES TO 10,431 PSI. O1~ 10:00 PUMPED BREAKDOWN, 25 BPM AND 6482 PSI, PUMPED 1PPA 16/20 PROP FOR SCOUR., PUMPED 10 BBLS X-LINKED 50# GEL AND 105 BBLS STRAIGHTSEAWATER FLUSH. 15 BPM AND 3117 PSI. 10:18 SHUTDOWN FOR ISIP 1634 PSI. PUMPED PULSE TEST. 11:08 PUMPED DATA FRAC AND FLUSH. 5 TO 15 BPM, 2957 PSi. 160 BBLS FLUIDS. SHUT DOWN FOR ISIP 1666 PSI. 11:54 PUMPED 55 BBLS PAD AND LOST ACTIVATOR AND SHUT DOWN. NEED TO START OVER WITH PAD. FLUSHED GEL OUT OF TUBING. - 12:51 PUMPED PAD WITH 210 BBLS X-LINKED 50# GEL. 5 TO 15 BPM AND 4665 PSI.-. 13:14 START PUMPING PROPPANT, 16/20 PROPPANT TO 2 PPA, 15 BPM AND 4724 PSI. 13:18 13:18 13:51 13:54 PUMPED 87,545# 12/18 PROPPANT TO 8 PPA. 15 BPM AND 4784 PSI. ~ PUMPED 8740# OF 10/14 PROPPANT TO 12 PPA. 15 BPM AND 4916 PSI. PUMPED FLUSH WITH 31 BBLS GEL, FOLLOWED WITH 30 BBLS DIESEL. SHUT DOWN ISIP 1987. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $440.00 APO $7,600.00 $7,600.00 ARCO $500.00 $500.00 DOWELL $80,000.00 $80,000.00 "HALLIBURTON - $0.00 $3,829.00 'LI-I-I-LE RED $2,700.00 $5',700.00~ TOTAL FIELD ESTIMATE $90,800.00 $98,069.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISb,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 195' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 978' FNL, 1580' FEL, Sec. 25, T12N, R8E, UM At effective depth 1219' FNL, 1354' FEL, Sec. 25, T12N, R8E, UM At total depth 1273' FNL, 1304' FEL, Sec. 25, T12N, R8E, UM 12. Present well condition summary Total Depth: measured 8759' feet true vertical 6115' feet Plugs (measured) None Effective depth: measured 8660' feet Junk (measured) true vertical 6047' feet None 6. Datum elevation (DF or KB) 89' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-08 9. Permit number/approval number 90-65 10. APl number 50-103-20128 11. Field/Pool Kuparuk River Oil Pool feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 1 1 5' 1 1 5' Surface 3622' 9-5/8" 1350 Sx AS III & 3657' 3220' Intermediate 500 Sx Class G Production 8 71 0' 7" 225 SX Class G 8 7 45' 61 0 0' Liner Perforation depth: measured F. ....... ' 'bP 8330'-8350', 8310'-8330' '~- ~ ~l ,~ true vertical 5827'-5840', 5814'-5827' ,~JG '~' ~995 Tubing (size, grade, and measured depth) 3-1/2" 9.2#, EUE, ABMOD, IPC, w/Tail @ 8279' j~¢i.~&6a$O0n~C~m~i~ Packers and SSSV (type and measured depth) ---'"~.~ ~[~_-.0_~.g.l~ *"" SSSV: Camco TRDP-1A-SSA (1796'), Packer: Baker (8148'), Packer: Baker Model 'D' (8260') 13. Stimulation or cement squeeze summary Fracture Stimulate A Sands Intervals treated (measured) 8330'-8350', 8310'-8330' Treatment description including volumes used and final pressure 5.1 Mlbs 20/40, 88.9 Mlbs & 11.0 Mlbs 10/14 ceramic proppant. 14. Representative Daily Average Production or Injection Data OiloBbl Gas-Mcf Water-Bbl Casing Pressure Max pressure 6180 psi. Tubing Pressure Prior to well operation -898- -915- -20- -857- 164 Subsequent to operation -1959- -2220- -52- -913- 145 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ ~'/~'"' Title Wells Superintendent Signed Form 10-404 (~ev 09/12/90 SUBMIT IN DUPLICATE ~-~_. ARCO Alaska. Inc ..... KUPARUK RIVER UNIT .~. WELL SERVICE REPORT '~, K1(3G-08(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-08 FRAC, FRAC SUPPORT 0615951653.1 DATE DAILY WORK UNIT NUMBER 06/22/95 ASANDREFRAC DAY OPERATION COMPLETE ISUCCESSFUL KEY PERSON SUPERVISOR 2 (~ Yes O No I ~ Yes O No DS-GALLEGOS WILDER FIELD AFC# CC# DALLY COST AOOUM COST Sjg*d '~'O ' ¢/~2~'~~ ut~e ESTIMATE 998417 230DS36GL $134,781 $138,078 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer And l Final Ann ...1000 PSI 2600 PSI 500 PSI - 600 PSll 200 PSII 100 PSI DAILY SUMMARY PUMPED A SAND REFRAC. SCREENED OUT 25 BBLS. INTO DIESEL FLUSH. AVERAGE RATE 12 BPM AT 4500 PSIG. MAX. PRESS, 6179 PSlG AT 12 BPM. PUMPED A TOTAL OF 11,475 BBLS OF FLUID. PUMPED A TOTAL OF 100,011 LBS. PROP. OF WHICH 97,369 LBS. WENT INTO THE FORMATION. TIME LOG ENTRY 09:30 MIRU. HELD SAFETY MTG. 1 1:30 PRESS. TESTED LINES TO 9300 PSIG. SET TREE SAVER. ESTABLISHED PUMP RATE OF 5 BPM RATE THROUGH FORCED CLOSURE CHOKE. 1 1:50 STARTED PUMPING 50# GW CONDITIONING STAGE: AVERAGE RATE 10 BPM AT 4700 PSIG. I STAGE OF 20/40 PROP. AT 1 PPG. TOTAL FLUID PUMPED 253.5 BBLS. FORCED CLOSURE. ISIP 1900 PSIG. TOTAL PROP. PUMPED 2232#. 1 2:1 0 STARTED PUMPING 50# GW DATA FRAC.: AVERAGE RATE 10 BPM AT 4500 PSIG. SHUT DOWN. TOTAL FLUID PUMPED 171 BBLS. ISIP 1967 PSIG. 14:30 15'30 STARTED PUMPING 50#/40# GW FRAC.: AVE. RATE 12 BPM AT 4700 PSIG. SWITCHED FROM 50# SYSTEM TO A 40# SYSTEM AT 11.25 PPG STAGE. LOST AUTO RAMP AT THE END OF THE 3.5 PPG STAGE. SCREENED OUT 25 BBLS. INTO THE DIESEL FLUSH. MAX. PRESS. 6179 PSIG AT 12 BPM, TOTAL FLUID PUMPED 723 BBLS. TOTAL PROP. PUMPED 95,137 LBS. RIGGED DOWN. TOTAL FLUID PUMPED ON JOB 11,475 BBLS. TOTAL PROP. PUMPED INTO FORMATION 97,369#. 5,438# PROP. LEFT IN WELL BORE. APPROX. 5,132# 20/40, 88907#12/18, AND 11,000# 10/14. JOB WAS DESIGNED FOR 98,000#. RECOVERED ALL CUPS FROM TREE SAVER. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0 $210 APC-PUMPING $1,160 $2,060; APC-TRUCKING $1,300 $1,300 ,, , DIESEL $336 $336 DOWELL-STIMULATION $131,985 $131,985 HALLIBURTON $0 $2,187 TOTAL FIELD ESTIMATE $134,781 $138,078 · STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS;51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown m Pull tubing Alter casing 2. Name of Operator AR(;;O Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stimulate Plugging Perforate X Repair well Other 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 195' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 978' FNL, 1580' FEL, Sec. 25, T12N, R8E, UM At effective depth 1219' FNL, 1354' FEL, Sec. 25, T12N, R8E, UM At total depth 1273' FNL, 1304' FEL, Sec. 25, T12N, R8E, UM Present well condition summary Total Depth: measured true vertical 8759' 6115' feet Plugs (measured) feet None 6. Datum elevation (DF or KB) 8~)' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-08 9. Permit number/approval number 90-65 10. APl number 5o-10:~-20128 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 8 6 6 0' true vertical 6 0 4 7' feet Junk (measured) fee t None Casing Length Structural Conductor 8 0' Surface 3 6 2 2' Intermediate Production 8 71 0' Liner Perforation depth: measured 8330'-8350', true vertical 5827'-5840', Size 16" 9 -5/8" 7" Cemented 1350 Sx AS III & 500 Sx Class G 225 Sx Class G 8310'-8330' 5814'-5827' 12. Measured depth 115' 3657' True vertical depth 115' 3220' 8745' 6100' RECEIVED JAN 2 8 1992 Alaska Oil & Gas Oons. C0mnllsS~0n Anch0ra~e Baker (8148'), Packer: Ba~,er Model 'D' (8260') Tubing (size, grade, and measured depth) 3-1/2" 9.2#, EUE, ABMOD, IPC, w/Tail @ 8279' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA (1796'), Packer: 13. Stimulation or cement squeeze summary Perforate 8310-8350 Intervals treated (measured) 14. Treatment description including volumes used and final pressure Tubing Pressure Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations m -978- -575- - 1 - -825- 186 -1132-' -937- -0- -1 375- 158 Service 16. Status of well classification as: Water Injector__ Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Operations Engineer Date SUBMIT IN DUPLICATE Form 10-404 Rev 09/12/90 ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT IFIELD - DISTRICT- STATE DA~S DATE WELL ~. RACTOR REMARKS IPBDT - I OPERA3~ON'A-T REP(~R'ICT~ME I ~ CHECK THIS BLOCK IF SUMMARY CON-'I'INUE~(~N BAC'K' ' - ~'W ..... Weather l Temp. I Chill Factor Visibility l Wind vel. $,gne~ ~_~J~ Report ; 'F~ °F. miles i knots~?~.~, _.~. _.~_~_:' .~..,, .... -,_ ~ DIST: ORIG - NSK KOE FILES DS ENG KOE FEES DS FOREMAN NSK CENT FILES KUPARUK OPERATIONS ENGINEERING PERFORATION RECORD WELL NAME: ,~ ~ -o3 I J ENG REP: Z~c-/~/_~ TIED IN WffH:~DIL, DATED~7z~O& ~CBUCET, DATED COMPLETION DETAILS: z~/~ ~. '~ . GUN INFO: ~' ~v~ ~1~ SPF: ~ . P~SING: ~" -, ORIENTATION: ~ G~M ~~,7 . ~E S~E ~,~-~ ~o,~ ~ SERV. CO & ENG: /~:~ ~o~D~P-_ PERF INTERVAl.: SAND ~.5 INT ~o-~5~ 85~ SAND INT ~- ~~ SAND INT ) GUN PROPOSED PROPOSED GUN CCL CCL RUN PERFORATIONS PERFORATIONS LENGTH TO TOP SETTING NO. (md.D IL) (md'CET) ( II ) SHOT DEPTH COMMENTS TIME GUN SHOT IIIO · 1. Operation Performed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSi~ ON-' REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 2538' FNL, 195' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 978' FNL, 1580' FEL, Sec. 25, T12N, R8E, UM At effective depth 1219' FNL, 1354' FEL, Sec. 25, T12N, R8E, UM At total depth 1273' FNL, 1304' FEL, Sec. 25, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 8759' feet 61 1 5' feet Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Other 6. Datum elevation (DF or KB) feet feet 89' RKB feet 7. Unit or Property name Kuparuk River Unit 8, Well number 9. Permit number/approval number . 90-65 10. APl number 50-103-20128 11. Field/Pool Plugs (measured) None i',."h";!-'i r:::. _... measured 8 6 6 0' Junk_ _ true vertical 6047' None ' Length Size Measured dePth~--'True vertical depth 80' 16" 115' 115' 3622' 9-5/8" 1350 SxAS III & 3657' 3220' 500 Sx Class G 8710' 7" 225 Sx Class G 8745' 6100' Cemented Perforation depth: measured 8214'-8234', 8366'-8386' true vertical 5751 '-5764', 5851 '-5864' Tubing (size, grade, and measured depth) 3-1/2" 9.2#, EUE, ABMOD, IPC, w/Tail @ 8279' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA (1796'), Packer: 13. Stimulation or cement squeeze summary C Sand Acid Stimulation Intervals treated (measured) 8214'-8234' Treatment description including volumes used and final pressure Baker (8148')~ Packer: Baker Model 'D' (8260') Pumped 60 BBLS of Nitrified12% HCL Acid and 25 BBLS Diesel w/5% X¥1ene. Final BHP = 4700 psi. 14. Representative Daily Average Production or In!e(;:tion Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0- -0- -0- 500 100 Subsequent to operation 100 50 -0- 500 100 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended 17. I here/l~ certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 09/12/90 Service Date SUBMIT IN DUPLICATE ARCO Alaska, Inc Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT iDATE //-/7-¢~ o~'bo /o,zT /_~ knots r--1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA : ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well ClassificalJon of Service Well OIL ~ GAS r'~ SUSPENDED E~ ABANDONED 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-65 3Address ~ ~ F ~ l~/ tF"~ I'~ 8 APINumber P.O. Box 100360, Anchorage, AK 99510-0360 i' ...... i~.: !;;J" ~ 9 Unit or Lease Name 4 Location of well at surfacei: i ~)~'c>,7 2538' FNL, 105' FWL, SEC 24, T12N, R8E, UM; , 'i ...... v,,,R ~ 9 1~' KUPARUK RIVER At Top Producing Interval ~.--~, ~ ~ 10 Well Number 978'FNL, 1580' FEL, SEC 25, T12N, ROE, UM ,' i a, 0il & GaS U011S. 38-08 At Total DepthAnchorage. 11 Field and Pool 1273' FNL, 1304' FEL, SEC 25, T12N, R8E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 89'I ADL 25548 ALK 2662 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore J16 No. of Completions 5/18/90. 5/25/90. 9/17/90.I NA feet MSLI 1 17 Total Depth (MD+-FVD) 18 Plug Back Depth (MD+TVD) 19 DireclJonal Survey 20 Depth where SSSV set 21 Thickness of permafrost MD, 6115' TVD 8660' MD, 6047' TVD YES ~ NO ~ 1798' feet MD 1600' APPROX 8759' 22 Type Electric or Other Logs Run EWR, CN, SFD, CDT, DGR, GYRO 23 CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP DO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 220 SX AS I 9-5/8" 36~ J-55 SURF 3657' 12-1/4" 1350 SX AS III, 500 SX CLASS G 7" 26~ J-55 SURF 8745' 8-1/2" 225 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE JDEPTH SET (MD) PACKER SET (MD) 3-1/2" X 2-7/8" TAIL 8279' 8148', 8260' 8214'-8234' W/4-1/2" CSG GUN @10SPF MD 5751'-5765' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 8366'-8386' W/4-1/2" CSG GUN @4SPF MD 5851'-5864' TVD DEPTH INTERVAL (MDI I AMOUNT & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO I TEST PERIOD FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 ~NUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS · · NNVE Include interval tested, pressure dab. all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 8215' 5752' NA KUPARUK C BOTTOM 82'33' 5764' KUPARUK A TOP 8293' 5803' KUPARUK A BO'I-I'OM 8480' '5926' ; , , 31. LIST OF ATTACHMENTS GYRO, FRAC ~2. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/]~ ~ Title AREA DRILLING ENGINEER Date 3/~/ 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 ~n 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 ADDENDUM WELL: 12/1 6/90 3G-08 Frac KRU "A" sand peals from 8366'-8386' @4spf in 7 stages as follows: Stage 1. Stage 2 Stage 3 Stage 4 Stage 5 Stage 6 Stage 7 Pmp 100 bbls G/W +5% Diesel @ 25 bpm 7000-4334 psi Pmp 350 bbls G/W +5% Diesel @ 25 bpm 4400-4550 psi Pmp 37 bbls G/W + 5% Diesel 2ppg @ 25 bpm 4550-4500 psi Prop 38 bbls G/W +5% Diesel 4ppg @ 25 bpm 4500-4600 ps Pmp 36 bbls G/W +5% Diesel 6 ppg @ 25 bpm 4650-4900 psi Pmp 30 bbls G/W +5% Diesel 8ppg @ 25 bpm 4900-5325 psi Pmp 24(2.8) G/W +5% Diesel 10ppg @ 25 bpm 5325-7600 psi Fluid to recover: Sand in zone: Sand in casing: 12,000 15,281(12,000 in perfs) Date / ARCO Oil a,,d Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. ARCO ALASKA INC. IState AK District County. parish or borough NORTH SLOPE Lease or Unit ADL: 25548 ALK: 2662 Title COMP LET I ON Well no. 3G-8 KUPARUK RIVER UNIT Auth. or W.O. no. AK4958 Operator ARCO Spudded or W.O. begun ARCO w I. 55. 252072 Prior status if a W.O. SPUD Date and depth as of 8:00 a.m. 09/15/90 (11) TD: 0 PB: 8660 SUPV:DEB 09/16/90 (12) TD: 0 PB: 8660 SUPV:DEB Date ]Hour 05/18/90 12:30 Complete record for each day reported NORDIC 1 REHEAD HLS GUN #1 7"@ 8745' 'MW:ll.3 NaC1 FINISH MOVING RIG. ACCEPT RIG 14-SEP-90 23:00. FILL HOLE W/ 5 BBL BRINE. ND WKM MASTER VALVE AND T.H.A. NU 5KSI BOPE. TEST BOPE, OK. RU HLS, MU GUN #1, CUT OUT BAD LINE AND REHEAD GUN #1. DAILY:S82,464 CUM:$1,289,766 ETD:S1,289,766 EFC:$1,500,400 REPAIR WL SETTING HEAD 7"@ 8745' MW:ll.3 NaCl PERFORATE A AND C SANDS IN 4 RUNS. 8372'-8386' 4SPF; 8214'-8234' 10SPF; 8366'- 8372' 4SPF. MU AND RUN GAUGE RING AND JUNK BASKET TO 8300' OK. MU TIW 'SS' PACKER AND TAILPIPE ASSY ON WL. PACKER WON'T GO DOWN, HUNG AT 8217'. POH W/ PACKER. RIH W/ GUAGE RING AND JUNK BASKET. PUSH SLIP SEGMENT OF PACKER TO BTTM RIH W/ BAKER MODEL D PACKER ON WIRE LINE. ATTEMPT TO SET BUT SETTING TOOL MALFUNCTIONED. POOH W/ PACKER AND SETTING TOOL. REPAIR WL SETTING TOOL. DAILY:S32,382 CUM:$1,322,148 ETD:S1,322,148 EFC:$1,500,400 The above is co~...~ct Signature / I f For form preparation a~ d~t66ution. see Procedures Man,q. Secl~on 10, Drilling. Pages 86 an 87~..~_~ JTitle n,,tllinn .Ch AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO ¢., and Gas Company Daily Well History-Final Report Inslrucfions: 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 Jength of time, On workovers when an official test is not required upon completion, report completion and representative test data in b~ocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Field KUPARUK RIVER UNIT Auth. or W.O. no. AK4958 Accounting cost center code District ICounty or Parish State ARCO ALASKA INC. I NORTH SLOPE AK I Lease or Unit Well no. I ADL: 25548 ALK: 2662 3G-8 Title J COMPLETION Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 09/17/90 (13) TD: 0 PB: 8660 SUPV:DEB A.R.Co. W.I. Date I otal number Of wells (active or inactive) on this cst center prior to plugging and 55 252072 bandonment of this well our Prior status if a W.O. 12:30 ,' 05/18/90 Complete record for each day reported NORDIC 1 RIG REALEASED 7"@ 8745' MW:ll.3 NaC1 REPAIR WL SETTING HEAD, MU WL SETTING HEAD RIH W/ BAKER MODEL "D" PKR ASSY, TIE IN W/MWD LOG & PET OF 7/6/90, SET PKR @ 8260', BTM OF 2 7/8" TAIL @ 8279' POH, 'RD HLS, NU FLOW LINE & PREP TO RUN TBG, RUN 3 1/2" COMP ASSY, STAB SEALS INTO LOWER PKR & LOCATE OUT, PU FOR WEIGHT & SPACE OUT, LAND TBG, RILDS, RAN 29 SS BANDS ON CL, TEST SS CL, RU RETURN LINE, PRESS TBG TO 2500 PSI & SET PKR HOLD 10 MIN, HOLD TBG & PRESS ANNULUS TO 1000 PSI TO COMPLETE PACKOFF, HOLD 10 MIN BLEED ANNULUS HOLD TBG @ 1500 PSI, BOLDS, PU & SHEAR PBR @ 84 K, BLEED OFF TBG, RELAND HANGER & RILDS, TEST $SSV-OK, LDLJ, SET BPV, ND BOP, NU TREE, PULL BPV, SET TP, TEST PACKOFF & TREE TO 5000 PSI, PULL TP OPEN SSSV, RU LINE TO TREE, PRESS UP ON ANNULUS & TBG TO 2500 PSI, 15 MIN LOST 30 PSI-OK, PRESS ON TBG & SHEAR SOS, REV CIRC 12 BBL DIESEL INTO ANNULUS, INJECT 4 BBLS DIESEL DOWN TBG,_ SHUT IN & SECURE WELL, RIG RELEASE @ 04:00 ~1~/90 DAILY:S217,980 , E~D $~,540,1~8 EFC:$1,500,400 Anchorage Old TD New TD p8 Depth Released rig Date IK nd of rg I Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data -- Well no. Date Reservoir Producing Interval lOll or gas Test time Production Oil on test Gas per Pump size, SPM X length Choke size !T.P. C.P. I Water % GOR Gravity Allowable [EIfec:v.e ~.~'-- corrected __ __ __ The above is correct / (E~_x ,-~, 6. < z 3 t / Drilling Supt. For form prepar~ ar~distributiO~ ~ see Procedures Ma~ ~ectionl0, ~ Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. -- Dlvl~on of Atlanl~-~ ~ ~''"''""'~''e( Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77224 713/461-3146 Fax: 7i3t461-0920 0R1GINA[ August 13.1990 Mr. Steve Edwards ARCO Alaska, Inc. P.O. Box 100360 Anchorage,. Alaska 99510 Re: Kupar'uk River Unit 3G-8 (24-12-8) North Slope Borough, Alaska Dear Mr. Edwards: Enclosed please find one (!) original the survey addendum to Please let me know if ! and nine KRU 3G-8 (24-12-8). can provide further A 1 Kudr 1 e Representative Enclosures (9) copies of assistance. Gyroclata Services, Inc. Houston, TX / Lafayette, LA / New Orleans, LA/Ventura, CA / Aberdeen, U.K. / Calgary, Alberta Anchorage, AK / Kuantan, Malaysia / Buenos Aires, Argentina / Bergen, Norway GREAT LAND Client .... : Field ..... : Well ...... : Section at: Surveyor..: DIRECTIONAL DRILLING, ARCO ALASKA, INC. KUPARUK RIVER UNIT KRU 3G-8 (24-12-8) S,44.00,E BOBBY BIRSS S MEAS INCLN C DEPTH ANGLE 7 100 0.42 7 200 0.38 7 300 0.48 7 400 0.58 7 500 0.71 7 600 0.74 7 700 0.93 7 800 1.11 7 900 1.24 7 1000 2.34 7 1100 7.28 7 1200 7.70 7 1300 8.95 7 1400 9.49 7 1500 9.66 7 1600 11.22 7 1700 16.88 7 1800 21.73 7 1900 22.81 7 2000 27.46 7 '2100 29.29 'Survey Codes: (KRU3GS) INC. for Gyrodata Services, ~ ,:! VERTICAL-DEPTHS SECTION DIRECTION BKB SUB-SEA DISTNCE BEARING 100.0 11.0 200.0 111.0 300.0 211.0 400.0 311.0 500.0 411.0 600.0 511.0 700.0 611.0 799.9 710.9 899.9 810.9 999.9 910.9 1099.5 1010.5 1198.6 1109.6 1297.6 1208.6 1396.3 1307.3 1494.9 1405.9 1593.2 1504.2 1690.2 1601.2 1784.6 1695.6 1877.1 1788.1 1967.6 1878.6 2055.6 1966.6 7/GYRO Inc. Computation...: Survey Date...: RKB Elevation.: API Number .... : Job Number .... : o8/10/90 RADIUS OF CURVATURE 07/06/90 89.00 ft 50-103-20128 AKO790G235 -0.1 N 70.06 E 0.2 N 70.56 E 0.5 N 64.35 E 0.8 N 65.65 E 1.1 N 61.31 E 1.5 N 62.72 E 1.9 N 64.33 E 2.4 N 61.28 E 3.0 N 62.70 E 5.0 S 66.58 E 13.2 S 39.48 E 26.2 S 36.82 E 40.5 S 34.10 E 56.2 S 30.12 E 72.3 S 29.71 E 89.9 S 29.47 E 113.4 S 31.03 E 145.8 S 32.91 E 182.9 S 31.79 E 224.5 S 33.59 E 271.3 S 34.30 E RELATIVE-COORDINATES FROM-WELL-HEAD 0.3N 0.2E 0.5N 0.9E 0.8N 1.5E 1.2N 2.4E 1.7N 3.4E 2.3N 4.5E 2.9N 5.8E 3.8N 7.4E 4.7N 9.2E 4.8N 12.2E 0.2 S 18.9 E 10.4 S 26.9 E 22.2 S 35.3 E 35.8 S 43.8 E 50.2 S 52.1 E 66.0 S 61.1 E 86.9 S 73.3 E 115.0 S 90.8 E 147.0 S 111.1 E 182.7 S 134.0 E 222.1 S 160.5 E CLOSURE DL DISTNCE BEARING /100 0.3 N 35.03 E 0.42 1.0 N 58.83 E 0.04 1.7 N 62.53 E 0.10 2.7 N 63.39 E 0.10 3.8 N 63.41 E 0.13 5.1 N 63.06 E 0.03 6.5 N 63.17 E 0.19 8.3 N 63.09 E 0.18 10.3 N 62.87 E 0.13 13.1 N 68.49 E 1.10 18.9 S 89.47 E 4.96 28.9 S 68.83 E 0.42 41.7 S 57.83 E 1.25 56.6 S 50.77 E 0.55 72.4 S 46.08 E 0.17 89.9 S 42.80 E 1.56 113.7 S 40.14 E 5.66 146.5 S 38.30 E 4.86 184.2 S 37.08 E 1.09 226.6 S 36.26 E 4.67 274.1 S 35.86 E 1.84 KRU 3G-8 S MEAS INCLN C DEPTH ANGLE 7 2200 34.8 7 2300 36.5 7 2400 42.9 7 2500 45.4 7 2600 50.6 7 2700 51.45 7 2800 52.63 7 2900 53.83 7 3000 54.96 7 3100 54.29 7 3200 55.00 7 3300 55.30 7 3400 55.30 7 3500 54.82 7 3600 54.55 7 3700 54.26 7 3800 54.54 7 3900 54.44 7 4000 54.45 7 4100 54.28 7 4200 54.23 7 4300 54.31 7 4400 54.24 7 4500 54.30 7 4600 54.03 7 4700 53.85 RECORD OF SURVEY VERTICAL-DEPTHS SECTION DIRECTION BKB SUB-SEA DISTNCE BEARING 2140.3 2051.3 323.7 2221.5 2132.5 381.5 2298.3 2209.3 444.6 2370.0 2281.0 513.4 2436.8 2347.8 587.0 2499.7 2410.7 664.3 2561.2 2472.2 743.0 2621.0 2532.0 823.1 2679.3 2590.3 904.4 2737.2 2648.2 985.9 2795.0 2706.0 1067.5 2852.2 2763.2 1149.5 2909.1 2820.1 1231.7 2966.4 2877.4 1313.6 3024.2 2935.2 1395.1 3082.4 2993.4 1476.3 3140.6 3051.6 1557.5 3198.7 3109.7 1638.8 3256.8 3167.8 1720.0 3315.1 3226.1 1801.2 3373.5 3284.5 1882.3 3431.9 3342.9 1963.4 3490.3 3401.3 2044.5 3548.7 3459.7 2125.6 3607.2 3518.2 2206.6 3666.1 3577.1 2287.5 S 36.21 E S 35.19 E S 34.65 E S 34.15 E S 37.38 E S 39.32 E S 41.22 E S 43.16 E S 44.73 E S 43.92 E S 43.29 E S 42.10 E S 42.02 E S 41.66 E S 40.89 E S 40.63 E S 40.91 E S 40.98 E S 41.26 E S 41.52 E RELATIVE-COORDINATES FROM-WELL-HEAD 265.4 S 191.2 E 312.8 S 225.2 E 365.3 S 261.8 E 422.8 S 301.2 E 483.1 S 344.7 E 544.1 S 392.9 E 604.3 S 443.9 E 663'.6 S 497.7 E 722.2 S 554.1 E 780.5 S 611.1 E 839.5 S 667.3 E 899.9 S 723.0 E 960.9 S 778.0 E 1022.0 S 832.7 E 1083.3 S 886.5 E 1144.9 S 939.6 E 1206.5 S 992.7 E 1267.9 S 1046.1 E 1329.2 S 1099.6 E 1390.2 S 1153.3 E S 41.73 E 1450.9 S 1207.2 E S 41.35 E 1511.6 S 1261.1 E S 41'.86 E 1572.3 S 1315.0 E S 41.84 E 1632.8 S 1369.1 E S 42.24 E 1693.0 S 1423.4 E S 42.57 E 1752.7 S 1477.9 E Page 2 08/10/90 CLOSURE DISTNCE BEARING DL /lOO 327.1 S 35.76 E 5.55 385.5 S 35.75 E 1.81 449.4 S 35.63 E 6.41 519.1 S 35.47 E 2.50 593.5 S 35.50 E 5.49 671.2 S 35.83 E 1.45 749.8 S 36.30 E 1.68 829.5 S 36.87 E 1.74 910.2 S 37.50 E 1.54 991.2 S 38.06 E 0.86 1072.4 S 38.48 E 0.83 1154.3 S 38.78 E 0.86 1236.4 S 39.00 E 0.05 1318.3 S 39.17 E 0.54 1399.8 S 39.30 E 0.58 1481.1 S 39.38 E 1562.4 S 39.45 E 1643.8 S 39.52 E 1725.1 S 39.60 E 1806.3 S 39.68 E 0.34 0.34 0.11 0.19 0.24 1887.4 S 39.76 E 0.15 1968.6 S 39.84 E 0.26 2049.7 S 39.91 E 0.34 2130.9 S 39.98 E 0.06 2211.9 S 40.06 E 0.38 2292.7 S 40.14 E 0.28 ~Survey Codes: 7/GYRO KRU 3G-8 S MEAS INCLN C DEPTH ANGLE 7 4800 53.50 7 4900 54.24 7 5000 54.46 7 5100 54.38 7 5200 54.28 7 5300 54.20 7 5400 53.85 7 5500 53.90 7 5600 54.29 7 5700 55.88 7 5800 56.02 7 5900 55.74 7 6000 55.77 7 6100 55.95 7 6200 55.92 7 6300 55.87 7 6400 55.59 7 6500 54.72 7 6600 53.16 7 6700 53.18 7 6800 53.01 7 6900 52.83 7 7000 53.15 7 7100 53.15 7 7200 53.41 7 7300 52.92 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 3725.3 3636.3 2368.0 3784.3 3695.3 2448.7 3842.6 3753.6 2529.9 3900.8 3811.8 2611.2 3959.1 3870.1 2692.4 4017.5 3928.5 2773.6 4076.3 3987.3 2854.4 4135.2 4046.2 2935.2 4193.9 4104.9 3016.2 4251.1 4162.1 3098.2 4307.1 4218.1 3181.0 4363.2 4274.2 3263.8 4419.4 4330.4 3346.5 4475.6 4386.6 3429.2 4531.6 4442.6 3512.0 4587.7 4498.7 3594.8 4644.0 4555.0 3677.4 4701.1 4612.1 3759.4 4760.0 4671.0 3840.2 4819.9 4730.9 3920.2 4879.9 4790.9 4000.1 4940.2 4851.2 4079.8 5000.4 4911.4 4159.6 5060.4 4971.4 4239.5 5120.2 5031.2 4319.5 RECORD OF SURVEY 5180.2 5091.2 4399.4 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD Page 3 CLOSURE DISTNCE BEARING S 42.41 E 1812.1 S 1532.3 E 2373.2 S 40.22 E S 42.11 E 1871.9 S 1586.7 E 2453.9 S 40.29 E S 42.18 E 1932.2 S 1641.2 E 2535.1 S 40.34 E S 42.67 E 1992.2 S 1696.1 E 2616.4 S 40.41 E S 42.17 E 2052.2 S 1750.9 E 2697.6 S 40.47 E S 42.27 E S 42.49 E S 43.28 E S 43.86 E S 44.96 E 2112.3 S 1805.4 E 2172.0 S 1859.9 E 2231.2 S 1914.9 E 2289.9 S 1970.7 E 2348.5 S 2028.1 E O8/lO/9O DL /1oo 0.36 0.77 0.22 0.33 0.34 2778.7 S 40.52 E 0.10 2859.6 S 40.57 E 0.38 2940.3 S 40.64 E 0.52 3021.2 S 40.72 E 0.55 3103.0 S 40.81 E 1.76 S 44.64 E 2407.3 S 2086.5 E 3185.7 S 40.92 E S 45.44 E 2465.8 S 2145.1 E 3268.2 S 41.02 E S 44,88 E 2524.1 S 2203.7 E 3350.7 S 41.12 E S 45.13 E 2582.6 S 2262.2 E 3433,3 S 41,22 E S 45.76 E 2640.7 S 2321.2 E 3515.9 S 41.32 E 0.26 0.61 0.38 0.25 0.43 2698.6 S 2380.4 E 2756.4 S 2439.5 E 2813.5 S 2498.4 E 2869.8 S 2556.5 E 2925.2 S 2614.2 E S 45.43 E S 45.94 E S 45.82 E S 45.96 E S 46.30 E 3598.5 S 41.41 E 0.23 3680.9 S 41.51 E 0.45 3762.7 S 41.61 E 0.87 3843.3 S 41.70 E 1.56 3923.1 S 41.79 E 0.22 S 46.49 E 2980.4 S 2672.1 E 4002.8 S 41.88 E 0.21 S 46.67 E 3035.2 S 2730.0 E 4082.4 S 41.97 E 0.21 S 47.06 E 3089.8 S 2788.3 E 4161.9 S 42.06'E 0.41 S 46.86 E 3144.4 S 2846.8 E 4241.7 S 42.16 E 0.13 S 47.37 E 3199.0 S 2905.5 E 4321.5 S 42.25 E 0.42 4401.2 S 42.34 E 0.50 S 47.54 E 3253.1 S 2964.5 E 'Survey Codes: 7/GYRO KRU 3G-8 Page 4 08/10/90 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 7400 52.80 7 7500 52.78 7 7600 52.63 7 7700 51.16 7 7800 51.16 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 5240.5 5151.5 4479.0 5301.0 5212.0 4558.4 5361.6 5272.6 4637.8 5423.3 5334.3 4716.1 5486.0 5397.0 4793.6 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD 47.48 E 3306.9 S 3023.3 E 48.03 E 3360.5 S 3082.2 E 48.19 E 3413.6 S 3141.5 E 50.09 E 3465.1 S 3201.0 E 50.42 E 3514.9 S 3260.9 E CLOSURE DL DISTNCE BEARING /100 4480.6 S 42.43 E 0.13 4559.9 S 42.53 E 0.35 4639.1 S 42.62 E 0.18 4717.3 S 42.73 E 1.87 4794.5 S 42.85 E 0.20 7 7900 50.94 5548.9 5459.9 7 8000 50.15 5612.4 5523.4 7 8100 49.62 5676.9 5587.9 7 8200 48.81 5742.2 5653.2 7 8300 49.22 5807.8 5718.8 4870.9 4947.6 5023.6 5099.0 5174.4 50.22 E 3564.5 S 3320.7 E 50.20 E 3613.9 S 3380.0 E 50.44 E 3662.8 S 3438.9 E 48.01 E 3712.2 S 3496,2 E 46.66 E 3763.4 S 3551.7 E 4871.7 S 42.97 E 0.25 4948.3 S 43.08 E 0.79 5024.1 S 43.19 E 0.55 5099.4 S 43.28 E 1.60 5174.7 8 43.34 E 0.88 7 8400 49.27 5873.1 5784.1 7 8500 48.10 5939.1 5850.1 7 8600 47.10 6006.5 5917.5 X 8759 47.10 6114.7 6025.7 5250.1 5325.2 5398.9 5514.8 46.38 E 3815.5 S 3606.7 E 44.05 E 3868.4 S 3660.0 E 38.50 E 3923.9 S 3708.7 E 38.50 E 4015.0 S 3781.2 E 5250.4 S 43.39 E 0.17 5325.4 8 43.41 E 1.74 5399.2 S 43.39 E 3.14 5515.3 S 43.28 E 0.00 ~Survey Codes: 7/GYRO X/EXTRAPOLATED KRU 3G-8 DATA INTERPOLATED FOR 100 Page FT SUBSEA INTERVAL 5 08/10/90 SUBSEA DEPTH 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 220'0 2300 2400 MEAS INCLN TVD MD-TVD DEPTH ANGLE BKB DIFF 89 0.37 89 0 189 0.38 189 0 289 0.47 289 0 389 0.57 389 0 489 0.70 489 0 589 0.74 589 0 689 0.91 689 0 789 1.09 ~89 0 889 1.23 889 0 989 2.22 989 0 1089 1190 1291 1393 1494 1596 1699 1805 1913 2024 2139 2260 2387 2527 2683 6.76 1089 0 7.66 1189 1 8.84 1289 2 9.45 1389 4 9.65 1489 5 11.15 1589 7' 16.81 1689 10 21.78 1789 16 23.41 1889 24 27.90 1989 35 31.43 2089 50 35.87 2189 71 42.18 2289 98 46.89 2389 138 51.31 2489 194 VERT CRRT DIRECTION BEARING 0 N 70.06 E 0 N 70.51 E 0 N 65.03 E 0 N 65.51 E 0 N 61.79 E 0 N 62.57 E 0 N 64.15 E 0 N 61.61 E 0 N 62.54 E 0 N 32.91 W 0 S 42.35 E 1 S 37.08 E 1 S 34.34 E 1 S 30.41 E 1 S 29.73 E 2 S 29.48 E 3 S 31.01 E 6 S 32.86 E 8 S 32.02 E 11 S 33.76 E 15 S 35.04 E 21 S 35.60 E 28 S 34.72 E 40 S 35.04 E 55 S 38.99 E RELATIVE COORDINATES FROM WELL HEAD 0.22 N 0.16 E 0.49 N 0.79 E 0.77 N 1.47 E 1.15 N 2.29 E 1.63 N 3.27 E 2.23 N 4.38 E 2.86 N 5.66 E 3.65 N 7.21 E 4.61 N 9.00 E 7.03 N 9.82 E 0.73 N 17.96 E 9.39 S 26.13 E 21.11 S 34.56 E 34.73 S 43.22 E 49.33 S 51.63 E 65.23 S 60.66 E 86.61 S 73.11 E 116.45 S 91.76 E 151.28 S 113.76 E 192.05 S 140.23 E 238.23 S' 171.68 E 293.41 S 211.40 E 358.22 S 256.94 E 439.15 S 312.49 E 533.75 S 384.47 E 2500 2846 53.18 2589 257 63 S 42.11 E 631.74 S 468.33 E KRU 3G-8 Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 6 08/10/90 SUBSEA DEPTH 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 MEAS DEPTH 3017 3190 3365 3539 3711 3883 4055 4227 4398 4569 4739 4908 5080 5251 5422 5592 5768 5946 6124 6302 6479 6648 6815 6981 7148 INCLN TVD MD-TVD VERT DIRECTION ANGLE BKB DIFF CRRT BEARING 54.85 2689 328 71 S 44.59 E 54.93 2789 401 73 S 43.36 E 55.30 2889 476 75 S 42.05 E 54.71 2989 550 75 S 41.36 E 54.29 3089 622 72 S 40.66 E 54.46 3189 694 72 S 40.97 E 54.36 3289 766 72 S 41.40 E 54.25 3389 838 71 S 41.63 E 54.24 3489 909 71 S 41.85 E 54.11 3589 980 71 S 42.12 E 53.71 3689 1050 70 S 42.51 E 54.26 3789 1119 69 S 42.12 E 54.40 3889 1191 72 S 42.57 E 54.24 3989 1262 71 S 42.22 E 53.86 4089 1333 70 S 42.66 E 54.26 4189 1403 70 S 43.81 E 55.97 4289 1479 76 S 44.74 E 55.75 4389 1557 78 S 45.18 E 55.94 4489 1635 78 S 45.28 E 55.86 4589 1713 78 S 45.44 E 54.90 4689 1790 77 S 45.85 E 53.17 4789 1859 69 S 46.12 E 52.98 4889 1926. 67 S 46.52 E 53.09 4989 1992 66 S 46.99 E 53.27 5089 2059 67 S 47.10 E RELATIVE COORDINATES FROM WELL HEAD 732.00 S 563.82 E 833.29 S 661.42 E 939.34 S 758.60 E 1045.97 S 853.95 E 1151.87 S 945.63 E 1257.73 S 1037.20 E 1362.99 S 1129.26 E 1466.95 S 1221.54 E 1571.01 S 1313.77 E 1674.38 S 1406.52 E 1775.76 S 1499.07 E 1876.75 S 1591.05 E 1980.10 S 1684.94 E 2082.97 S 1778.79 E 2184.88 S 1871.74 E 2285.04 S 1966.06 E 2388.22 S 2067.65 E 2492.44 S 2172.04 E 2596.58 S 2276.32 E 2700.03 S 2381.82 E 2801.55 S 2486.14 E 2896.68 S 2584.40 E 2988.65 S 2680.80 E 3079.42 S 2777.16 E 3170.51 S 2874.75 E 5100 7315 52.90 5189 2126 67 S 47.53 E 3261.00 S 2973.13 E KRU 3G-8 Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL O8/lO/9O SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 5200 7480 52.78 5289 5300 7645 51.97 5389 5400 7805 51.15 5489 5500 7963 50.44 5589 5600 8119 49.47 5689 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 2191 65 S 47.92 E 3349.91 S 3070.50 E 2256 65 S 49.04 E 3437.05 S 3168.06 E 2316 60 S 50.41 E 3517.24 S 3263.71 E 2374 59 S 50.21 E 3595.89 S 3358.36 E 2430 55 S 49.99 E 3671.89 S 3449.83 E 5700 8271 49.10 5789 5800 8424 48.98 5889 5900 8574 47.36 5989 6000 8721 47.10 6089 2482 53 S 47.05 E 3748.53 S 3535.89 E 2535 53 S 45.81 E 3828.29 S 3619.98 E 2585 50 S 39.93 E 3909.23 S 3696.74 E 2632 47 S 38.50 E 3993.37 S 3763.97 E KRU 3G-8 Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 08/10/90 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING DL/ 100 1000 2.34 1000 911 5 S 66.58 E 5 N 2000 27.46 1968 1879 225 S 33.59 E 183 S 3000 54.96 2679 2590 904 S 44.73 E 722 S 4000 54.45 3257 3168 1720 S 41.26 E 1329 S 5000 54.46 3843 3754 2530 S 42.18 E 1932 S 12 E 13 N 68.49 E 1.1 134 E 227 S 36.26 E 4.7 554 E 910 S 37.50 E 1.5 1100 E 1725 S 39.60 E 0.2 1641 E 2535 S 40.34 E 0.2 6000 55.77 4419 4330 3346 S 44.88 E 2524 S 7000 53.15 5000 4911 4160 S 47.06 E 3090 S 8000 50.15 5612 5523 4948 S 50.20 E 3614 S 2204 E 3351 S 41.12 E 0.4 2788 E 4162 S 42.06 E 0.4 3380 E 4948 S 43.08 E 0.8 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 08/10/90 Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 3G-8 Section at: S,44.00,E Surveyor..' BOBBY BIRSS Computation...' RADIUS OF CURVATURE Survey Date...' 07/06/90 RKB Elevation.: 89.00 ft AP1 Number .... : 50-103-20128 Job Number .... : AK0790G235 INTERPOLATED MARKERS REPORT Surface Location' 253~ SNL 195 EWL S24 T12N R8E MARKER IDENTIFICATION MEAS INCLN DEPTH ANGLE VERT-DEPTHS SECT DIRECTION REL-COORDINATES BKB SUB-S DIST BEARING FROM-WELLHEAD 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A 0 0.00 0 -89 0 N 0.00 E 3657 54.38 3057 2968 1441 S 40.74 E 8215 48.87 5752 5663 5110 S 47.81 E 8233 48.95 5764 5675 5124 S 47.56 E 8293 49.19 5803 5714 5169 .S 46.75 E ON 0E 1118 S 917 E 3720 S 3505 E 3729 S 3515 E 3760 S 3548 E BASE KUPARUK A 7" CASING TD 8480 48.33 5926 5837 8745 47.10 6105 6016 8759 47.10 6115 6026 5310 S 44.52 E 5505 S 38.50 E 5515 S 38.50 E 3858 S 3650 E 4007 S 3775 E 4015 S 3781 E Great Land Directional Drilling, Inc. <KB>O 55O ilO0 i650 22O0 275O 3300 385O 4400 4§50 5500 6050 6600 7i50 7700 550 VERTICAL SECTION VIEW ARCO ALASKA. INC. KRU 3G-8 Section at: S 44.00 E TVD Scale · 1 inch = ilO0 feet Dep Scale · ! inch = !!00 feet Drawn .... · 0B/09/90 Harken Identification MD TVD SECTN INCLN A) K8 0 0 0 0.00 A ........ B) TD 8759 6i~5 55~5 47.i0 , . .., · ,, ~ .......... .... 0 550 tt00 t850 2200 2750 3300 3850 4400 4950 5500 Section Departure Greab L and Dire£bional DrilIing. _Thc. Narker Identification ND NIS A) K8 0 0 N 0 8] TD 8759 40t5 S 378t E PLAN VIEW ARCO ALASKA. INC. KRU 3G-8 CLOSURE .....: 5515 ft S 43.28 E DECLINATION.: 0.00 E SCALE .......: ! inch = 700 feet DRAWN .......: 08/09/90 A ' 350 Z · ' 0 ~ 350 700 i050 t400 t750 2t00 2450 2800 3t50 3500 3850 4200 4550 350 0 350 <- JEST ' EAST -> 700 t050 1400 t750 2t00 2450 2800 3t50 3500 3850 AOGCC GEOLOGICAL MATERIALS iNVENTORY LiST PERMIT # ~'~ - ~,.~ WELL NAME ~'"/~ ~ ~- ~ COMPLETION DATE ~ / /~ / ~o CO. CONTACT ~~ checE off or list data as it is received.*list re~ived date for 407. if not reauired list as drillinq histo~' su~cv well tests core descri cored inte~ais core analysis ditch intcwals itai data I ~ ~ 'l'%~n~' Lt.~I I I rL 9) 10,1 11! ii 13! 14! 16] 17] RUN NO. /--j INTERVALS [to the nearest foot~ SCALE [inchilO0'] -- STATE OF ., 0 R 16 ALASKA Oil AND GAS CONSERVATIC~ ~MISSION APPLICATION F'OFI SUNDFIY APPFIOVALS 1. Type of Request: Abandon 2. Name of Operator Suspend _ Alter casing _ Repair well Change approved program _ 5. Type of Well: Development Exploratory Stratigraphic 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 _ 6. Datum elevation (DF or KB) Service (approx) 4. Location of well at surface 2538' FNL, 195' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1075' FNL, 1400' FEL, Sec. 25, T12N, R8E, UM At effective depth NA At total depth 1273' FSL, 1591' FEL, Sec. 25 T12N, R8E, UM 12. Present well condition summary Total Depth: {approx) Effective depth: measured 8758' feet (approx) true vertical 6107' feet measured NA feet (approx) true vertical NA feet Plugs (measured) None Junk (measured) None RKB 89' 7. Unit or Property name Kuparuk River Unit feet 8. Well Number · 3G-8 9. Permit number 90-65 10. APl number 50-103-20128 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' 1 6" Surface 3622' 9 5/8" Intermediate Production 871 0' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented 1350 Sx AS III & 500 Sx Class G 225 Sx Class G .~ ~ Measured de~h True verticaldepth (approx) 115' 115' 3657' 322O' 13. Attachments Description summary of proposal_ Detailed operation program X BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as:, November. 1990 I Oil X Gas ~ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,/~, ~~ Title Area Drilling Encjineer Date Signed FOR COMMISSION USE ONLY Suspended Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test_ Location clearance__ Mechanical Integrity Test - Subsequent form require 10- Approved b), the order of the Commission Commissioner IApproval No. I 'g",,O- 7~ Date Form 10-403 Rev 06/15/88 Approved Copy Returr,,ed ORIGINAL SIGNED BY LONNIE C. SMITH SUBMIT IN TRIPLICATE ARCO Oil ~..,~ Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field I County, parish or borough I NORTH SLOPE I Lease or Unit KUPARUK RTVER I ADL: 25548 ALK: 2662 J Title J DRILLING Auth. or W.O. no. AK4958 IState AK Well no. G-8 Operator ARCO Date and depth as of 8:00 a.m. 05/18/90 (1) TD: 80'( 80) SUPV:WH 05/19/90 (2) TD: 1834' (1754) SUPV:WH 05/20/90 (3) TD: 3677'(1843) SUPV:WH 05/21/90 (4) TD: 3758'( 81) SUPV:WH 05/22/90 (5) TD: 6699' (2941) SUPV: WH " ~ : 05/23/90 ( 6) .. TD: 7950' (1251) SUPV: WH complete record for each day reported DOYON 14 12:30 IARCO W.I, 55. 8533 Prior status if a W.O. NU DIVERTER MW: 0.0 ViS: 0 MOVE RIG FROM 1L PAD TO 3G PAD. MOVE IN AND RU. ACCEPT RIG @ 0500 18-MAY-90. NU 20" DIVERTER. DAILY:S142,925 CUM:$142,925 ETD:S142,925 EFC:$1,500,400 DRLG MW: 9.4 VIS: 61 FIN NU 20" DIVERTER AND FLOWLINE. RU FLOOR, PU KELLY, TEST DIVERTER. PU BHA AND ORIENT MWD. WORK ON DIVERTER LINE. SPUD 1230 18-MAY-90. DRILL TO 1519'. ADT = 7.0. POH FOR BHA. CHANGE OUT MWD SENSOR, NAVIDRILL AND BIT. TIH. DRILL TO PD. ADT = 1.5. DAILY:S65,265 CUM:$208,190 ETD:S208,190 EFC:$1,500,400 LD BHA 9-5/8"@ 3657' MW: 9.6 VIS: 56 DRLG F/1834-3677' ADT -- 10.5. CIRC BU. DROP SURVEY. SHORT TRIP TO HW. TIGHT HOLE F/ 2100-1600'. TIH. HIT BRIDGE @ 1700' CIRC. WORK TIGHT HOLE 1700-1800'. POH. LD BHA. DAILY: $71,859 CUM: $280,049 ETD: $280,049 EFC: $1,500,400 DRLG 9-5/8"@ 3657' MW: 9.5 VIS: 38 RAN 94 JTS 9-5/8" 36.0 PPF J-55 BTC CSG TO 3657'. RU DOWELL. CIRC. PUMP 80 BBL FW SPACER. CEMENT W/ 1350 SX AS III + .25 PPS FLAKES. TAIL IN WITH 500 SX CL G + 2% CACL. BUMPED PLUG. FLOATS HELD. CIRC CEMENT. RD DOWELL. ND RISER, FLOWLINE, DIVERTER. NU BOP, CHOKE, FLOWLINE, RISER. PU TURBODRIL AND SURFACE TEST. PU BHA AND ORIENT. CALIBRATE RLL MWD. TIH. CUT DRILL LINE. DRILL FC. TEST CSG 2000 PSI. DO 10'. RAN FIT TO 13.5 PPG. DRILL TO PD. DAILY:S425,032 CUM:$705,081 ETD:S705,081 EFC:$1,500,400 DRLG 9-5/8"@ 3657' MW: 9.7 VIS: 37 DRLG FROM 3758 TO 3821,ARCO POWER OFF,DRLG FROM 3821-TO 6699. DAILY:S61,578 CUM:$766,659 ETD:S766,659 EFC:$1,500,400 TIH 9-5/8"@ 3657' MW: 9.7 VIS: 65 DRLG F/ 6699 TO 7950,CIRC, POOH,CIRC OUT PILL, LEAK OFF TEST,POOH TO UNLOAD RLL RECALIBRATE AND RIH. DAILY:S56,854 CUM:$823,513 ETD:S823,513 EFC:$1,500,400 PUMP LCM 9-5/8"@ 3657' MW: 9.9 VIS: 41 -''~I~'T~;~"~'/u'~zo ~'t'l'~ou;~ ~'/7950 T/8150,SURVEY, POH, LD JEWELRY,PU ROTARY ASSY,RIH TO SHOE, CBU, TIH, REAM F/8075 T/8150, WELL PACKING OFF,CIRC AND CLEAN HOLE,PUMP LCM PILL. DAILY:S61,999 CUM:$885,512 ETD:S885,512 EFC:$1,500,400 The above is correct Signatu~ ~ For fo rr~-pre parat i.e~nd' distri bution,(.~ see Procedures N~n~lal, Section 10, Drilling, Pages 86 ~rl'd 87. AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. iPage no. ARCO Oil an,. ~as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field KUPARUK RIVER Date and deptll as of 8:00 a.m. County or Parish ARCQ ALASKA INC. I NORTH SLOPE I Lease or Unit I 3~-~ Complete record for each day while drilling or workover in progress 05/25/90 ( 8) TD: 8707' ( 557 SUPV:TAB 05/26/90 (-9) TD: 8758'( 51 SUPV:TAB DOYON 14 DRILLING 9-5/8"@ 3657' MW:ll.3 VIS: 51 FINISH MIXING & CIRC LCM. POOH TO 9-5/8" SHOE. CIRC OUT DRY JOB PILL, PERFORM LOT. EMW=ll.7 PPG, HELD FOR 10 MINUTES, TIH, CIRC & WT UP TO 11.2, DRILLING DAILY:S99,200 CUM:$984.,712 ETD:S984,712 EFC:$1,500,400 RUNNING CASING 9-5/8"@ 3657' MW:ll.3 VIS: 43 DRLG F/ 8707 T/ 8758,CBU, SHORT TRIP, CBU, DROP SS,POH LDDP&DC,DOWN LOAD RLL, PULL WEAR RING, RU AND RUN 7"CSG. DAILY:S58,128 CUM:$1,042,840 ETD:S1,042,840 EFC:$1,500,400 Well no. The above is co~e~t For form preparation ~¥di~tri~'~tion ~ see Procedures Manul[l.~ection 10, Drilling, Pages 86 and"87 Date / . AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO O,~ ~,nd Gas Company Daily Well History-Final Report Inslructions: 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. Accounting cos/ center code District ICounty or Parish State ARCO ALASKA INC. I NORTH SLOPE AK Field ILease or Unit I Well no, KUPARUK RIVER I ADL: 25548 ALK: 2662 I 3G-8 Auth. or W.O. no. ITitle AK4958 I DRILLING Operator A.R.Co. W.I. ARCO 55.8533 Spudded or W.O. begun Date SPUD 05/18/90 Date and depth as of 8:00 a.m. 05/27/90 (10) TD: 8758 PB: 8660 SUPV:TAB Complete record for each day repoAed DOYON 14 I otal number of wells (active or inactive) on this ost center prior to plugging and ~ bandonment of this well I our12:30 Prior status if a W,O. RIG RELEASED 7"@ 8745' MW: 0.0 FINISH RUNNING CASING, CIRC HOLE CLEAN, CEMENT CASING, ND BOPE, INJECT 200 BBLS. DAILY:S164,462 CUM:$1,207,302 ETD:S1,207,302 EFC:$1,500,400 Old TD New TO Released rig Oate IPB Depth Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P, C.P, Water % GOR Gravity Allowable Effective date corrected The above is co~ect For form preparatio~d ~istribution, ~ / / - - I % see Procedures Ma~l, Section 10, Drilling, Pages 86 and 87, AR3B-459-3-C Number all daily well history forms consecutively I Page no. as they are prepared for each well. Dlvl,aon of AtlantlcRIchffeldCompany ARCO Alaska, Inc. Date' August 3, 1990 Transmittal #: 7839 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-111 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 G - 1 2 Pulse Echo Cement Evaluation(PET) 7 - 6 - 9 0 2 4 0 6 - 6 6 2 6 3 G -4-~c~¢/ Pulse Echo Cement Evaluation(PET) 7 - 6 - 9 0 6 4 4 8 - 8 6 3 7 3 G - 1 2 Acoustic Cement Bond Log 7 - 8 - 9 0 2 4 - 21 9 3 1 L - 1 1 Acoustic Cement Bond Log 6 - 2 3 - 9 0 81 0 4 - 9 2 6 5 1 L - 0 9 Acoustic Cement Bond Log 6 - 2 7 - 9 0 8 9 7 0 - 1 0 0 2 7 Receipt Acknowledged: DISTRIBUTION: Date: Drilling NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: JUne 15, 1990 Transmittal #: 7782 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G-08 3G-08 3G-09 3G-09 Please acknowledge receipt and return Dual GR Compensated Neutron Porosity Simultaneaous Formation Density Electromagnetic Wave Resistivity Dual Gamma Ray Dual GR Compensated Neutron Porosity Simultaneaous Formation Density Electromagnetic Wave Resistivity 5-25-90 5-25-90 6-6-90 Dual Gamma Ray Formation Exposure time 3677-8759 3677-8759 4548-10322 4548-10322 Receipt Acknowledged: DISTRIBUTION: ............................. Date: D&M Drilling Franzen RECEIVED d UN 1 5 1990 Alaska Oil & Gas Cons. Commission Anchorage Vendor Package(Johnston) NSK ,__S~_,t_ate of Alaska(+Sepia) Todd Salat ARCO Alaska, Inc. Date: June 15, 1990 Transmittal #: 7781 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G-08 LIS Tape and Listing~"'/TZ~''-~''~ 3 G- 0 9 LIS Tape and Listing Please acknowledge receipt and return 5-31-90 #90-05-18 6- 1 1 - 90 AKRB90520 Receipt Acknowledged: DISTRIBUTION: RECEIVED J U N I 5 '1990 D a t~,Jaska Oi~-~'~ns. Oommission Anchorage Lynn Goettinger State of Alaska May 17, 1990 Telecopy: (907)276-7542 P. J. Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box !00360 B_nchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3G-8 ~ARCO Alaska, 'Inc. Permit No. 90-65 Sur. Loc. 2530'F~, t95'~, Sec. 24, T12N, RSE, UM. Btmho!e Loc. 1273'FNL, 159!'FEL, Sec. 25, T12N, RgE, Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits r~qu!red by !aw from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Ver%_~tru!w ~. Chat t e~t ~n Chairman of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION dlf Enc to sure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conse~;ation w/o encl. .'~ .... STATE OF ALASKA .... ALA,.,,<A OIL AND GAS CONSERVATION COMMIbx.~,ON PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill X Redrill m I lb. Type of Well Exploratory__ Straligraphic Test -- Development Oil .~X Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 89', Pad 54' GL feet Kuparuk River Field 3. Address 6. Properly Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25548 ALK 2662 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2530' FNL, 195' FWL, Sec. 24, T12N, RSE, UM Kuparuk River Unit At top of productive interval (TARGET) 8. Well number Number 1075' FNL, 1400' FEL, Sec. 25, T12N, RSE, UM 3G-8 #U630610 At total depth 9. Approximate spud date Amount 1273' FNL, 1591' FEL, Sec 25, T12N, RSE, UM 05-17-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 8757' MD 1273' @ TD feet 8250' at SURFACEfeet 2560 6082' VD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 1 000 feet Maximum hole angle 54° Maximum surface 1 900psig At total depth (TVD) 6080' 3480 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD TVD IVD TVD (include stage data) 24 16.0" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 CF 12.25 9.625" 36.0# J-55 BTC 3711 35' 35' 3676' 3065' 1350 Sx AS III & HF-ERWi 500 Sx Class G 8.5 7" 26.0# J-55 BTC 8792' 35' 35' 8757' 6082' 225 Sx Class G HF-ERW Top 500' above Kuparuk 19. lo be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural REC[IVE Surface Intermediate Production JV/A~ 1 '" 199f Liner ,~!as~ QiJ.& Gas Cons. I:;0rnm/s~lor~ Perforation depth: measured ' true vertical "*;,~' L,-uK~Ji0ra[~ 20. Attachments Filing fee X~ Property plat ~ BOP Sketch X~ Diverter Sketch X~ Drilling program X~ Drilling fluid program ~ Time vs depth plot _ Refraction analysis _ Seabed report _20 AAC 25.050 requirements X~ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~~, ~ .._~. ~,4.~ Title Area Drilling En~lJneer Date Commission Use Only Permit Number APl number Approval date 0 5 / 1 7 / 9 0 '~:) -~'..~- 50- '/C:D ,3 - -~0 / ~ ~ other rec{uirements Conditions of approval Samples required __Y es ;3,¢"N o Mud log required__ Ye s ~ N o Hydrogen sulfide measures__ Yes ~N o Directional survey required ..~-"Yes __ N o Required working pre--for BOP,.~ __~,bl.~ _.~ 3 M; 5 M' ~ 1 0 M' __ 1 5 M Approved by ~ ! ~" /. ~ Commissioner the commission Date Form 10-401 R~v~'/~24-89 in triplicate ARCO ALASKA INC. PAD 3G- D, WELL No. 8 Kuperuk Field, North Slope, Alaska ]EASTMAN CHRISTENSEN I000 ~ I--20O0 <:!::. 3000 I-- 4000 RKB ELEVATION 90' SCALE: lINCH= I000 FT. KOP TVD=IO00 TMD=IO00 DEP=O 9° BUILD 3°/I00' 15° 2_1o B/PERMAFROST TVD=I605 TMD=1616 DEP=98 2 'o T/UGNU SANDS TVD=I795 TMD= 1820 DEP.=i73~ 33° 390 T/W SAK SANDS TVD=2400 TMD=2571 DEP= 611 45° 51° EOC TVD=2537 TMD=2786 DEP=776 B/W SAK SANDS TVD=2865 TMD=3339 DEP=I221 9 5/8" CSG PT TVD = 3065 TMD= 3676 DEP= 1492 K-lO TVD=3310 TMD=4088 DEP=1824 5O00 6000 7000 AVERAGE ANGLE 5:3 DEG :55 MIN T/ZONE C TVD=5795 TMD=8274 DEP=5192 T/ZONE A TVD=5843 TMD=8354 DEP=5257 TARGET CNTR TVD=5879 TMD=8415 DEP=5306 B/KUP TVD=5963 TMD=8557 DEP=5419 TD TVD=6082 TMD=8757 DEP=5580 I I I 1 I000 2000 3000 4000 : VERTICAL SECTION I 5000 6000 ARCO ALASKA INC. PAD SG-D, WELL No. 8 Kuparuk Field, North SlOpe, Al(~ska [EASTMAN CHRISTENSEN HORIZONTAL PROJECTION SCALE: lINCH= I000 FT. ~ ;URFAC E SURFACE LOCATION 25:30' FNL 195' FWL SEC. 24, TI2N, RSE I000 - - 2000 - ,. 3000 - 4000 - 500° - I- ri,- o z I o TARGET CENTER TVD=5879 TMD=8415 DEP =5:506 SOUTH 3817 EAST 3685 TARGET LOCATION ~'~. 1075' FNL 1400' FE L SEC 25, TI2N, R8E I I I I i 0 I000 2000 :5000 4000 TD LOCATION 127 3' FNL 159 I' FEL SEC 25, TI2N, RSE WEST - EA ST S 4'4 DEG O0 MIN E 5306' (To TARGET) 100 I ~2400 ._2450 .... .2500 ...... - . . 2550 _ I I 2600 _ I 2650 _ . I I 2700 .... I 100 150 I 2OO I 250 I / / 1100 '~oo '~oo · ~oo \500 %1300 \ \ 'N'~700 I 150 I 2OO \ ",900 \ \ \ \ · -. 1500 \. ,/ 3O0 I , / ~1500 350 i ~'1700 400 I , 450 I 5OO I \ \ \ ~,1100 , 250 \ \ · , 300 \ \ 350 I 400 I 450 I 5OO _..2400 _.-2450 __25U0 , .. _ 2550 _ 2600 _ 2650 _ 2700 DRILLING FLUID PROGRAM (3G-8) Spud to 9-5/8" Drill out to Weight up surface casing weight up to TD Density 8.6-1 0.0 8.6-9.3 10.6 PV 15-35 5-15 10-18 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 15-40 4-8 4-8 APl Filtrate 10-1 2 8-1 0 4-5 pH 9- 1 0 8.5-9 9.0-9.5 % Solids 10 +/- 4-7 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,175 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3,000 psi. The nearest well to 3G-8 is: None (Currently there are no other wells on this lease. The nearest well on another lease is Well No. 3F-12 which is approximately 8,250' away on the surface and will be approximately 2,640' away at TD.) Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 sec to drill gravel beds. ,~JPARUK RIVER UNi'~ 20" DIVERTER SCHEMATIC s I I 5 4 3 I 0 |.~,l l 2 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENAN(~E ~ OPERATION , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) ?.aAY 1 ? 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 5!aS~/_a. ~i~ &, Gas 0ohs, 3. FMC DIVERTER ASSEMBLY WITH ~O 2-1/16"- 2000 PSI BALL VALVES '-,:,-~,: ~nchora~ 4. 20"- 2000 PSI DRILLING SPOOL WITH ~O 10" OUTL~S. 5. 10" HCR BALL VALVES WITH 1~' DIVERTER LINES, A SINGLE VALVE OPENS AUTO~TICALLY UPON CLOSURE OF ANNU~R PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - ~00 PSI ANNU~R PREVENTER SRE 2/6/90 13 5/8" 5000 [-',51 BOP STACK 7 5 4 I I ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSi REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILLAND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING ALVALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM PIPE RAMS. TEST BO'FI-OM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEKAND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 ! , , . , . . . , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 36 PAD Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test B©PE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic #1. Install and test B©PE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel. Shut in and secure well. Clean location and release rig. Fracture stimulate well. 21. Re-perforate and add additional perfs. NO. Y' X I.. A r L VIC/NIT Y MA P I';' P M/. b". /V.L.,,, P$$0 '"' p,§So'"' &PO' P$$8'~'' Ip'O' Pb$O'c''' lO§' Po30'"'" I~0' P$$0'"' 98' P858'"" P..o.L. e$$8 '"" PO' ab$O"-' 48' P~$O'"' 8050'~''' I RO' PS,Sa' v' 0.0. 40,9 '$$.9 4,9.? 84.0 40,£ 4~.8 46.9 47.3 4?.£ $3. I 46, 9 $3. / 4~. 0 $,9.0 4~.8 53. O 46.4 52.9 46.3 SUPVE'¥OIO~ C£NT/F1 CA i H£~BY Cfft?TIFY THAT ! AM NffOIST~OffO AND LICeNSeD ~ P~ACTI~ ~NO $URVPYIN$ IN TO~ $P&Tff OF ALASKA ANO ~AT THIS PLAT N~P~ff~N~ ( ~2 r~ AL~ 01~N51~$ AN~ OTHPR CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE ~ ( 1 ) F e e /~/~ ~-/~ ~//~ 1. (2 thru 8) (8) (3) Admin ~zC ~/?~ 9. ~'('9 thru 13) 10. (10 and 13) 12. 13. (4) (14 thru 22) (23 thru 28) Company .. ~P~O Lease & Well No. ~pL ~~'~ ~U SE-~ YES NO / REMARKS Is the permit fee attached .......................................... .."' ... ~ ~ ~ ~ ~,~ ~ ~//? .... 2. Is well tff be located in a defined pool ............................. ~_ .... 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... .. 5. Is sufficient undedicated acreage available in this pool ............ __ .... 6. Is well. to be deviated and is wellbore plat included ................ ~_ 7. Is operator the only affected party ......... ' ....................... ~ ... 8. Can permit be approved before fifteen-day wait ...................... , , Does operator have a bond in force .................................. _~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ..................... ,... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ ,, Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... , _ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... ~ '-'- Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~,~ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to 3ooo psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. thru 31) (6) Add: Geology: Engilie~r~ing: rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. , · t INITIAL GEO, UNIT oN) 6FF" Poo~ chess STATUS ~Ea NO. S~ORZ .. ./ Additional Remarks: Dp I$o. I0 ,~, S"o o' TWO 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 APPENDIXi No special 'effort has been made to chronologically organize this category of information. ~*** LIS READ *~** (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/05/31 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER SERVICE NAME: RLL DATE: 90/05/31 ORIGIN OF DATA: 3G-8 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT END OF FILE (EOF # 1) ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G8.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/05/31 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC. WELL: 3G-8 FIELD: KUPARUK DATE: 25 MAY 1990 API #: 50-103-20128 LOCATION: 2530' FNL & 195' FEL, SEC. 24, TWP. 12N, RANGE 8E, NORTH SLOPE BOROUGH, ALASKA, USA RIG: DOYON 14 CO. REP.: HELMS RLL ENG: GALVIN & BROWN. COMMENTS **** NEUTRON & DENSITY DATA ARE CALIPER CORRECTED & CALCULATED ASSUMING A SANDSTONE MATRIX, FWS = 14,545 PPM CL, FD = 1.0 GM/CC, MATRIX = 2.65 GM/CC AND MUD SALINITY = 1600 PPM CL. KGB CALIPER VERSION APPLIED. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT ROP MWD FXE MWD NPSC MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD GRC MWD EWR MWD CAL MWD RHOB MWD DRHO MWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY 255 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) ~E SERVICE ~ SERVICE ID ORDER# DEPT ROP MWD FXE MWD NPSC MWD NFO MWD NFl MWD NN0 MWD NN1 MWD GRC MWD EWR MWD CAL MWD RH©B MWD DRHO MWD UNIT API API API API FILE SZE PROC SPL REPR LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 ** DATA VERIFICATION (every 500 FT) DEPT ROP FXE NP S C NF 0 NF 1 NN 1 GRC EWR CAL RHOB DRHO -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3500.000 -999.250 333.185 .546 38.170 87.568 7.725 9.160 4000.000 2520.000 490.430 .607 36.325 106.023 4.148 9.550 4500.000 2616.000 218.589 .518 36.603 86.752 3.042 9.780 5000.000 2584.000 227.068 .816 35.532 120.797 4.838 10.400 5500.000 2616.000 198.047 .584 36.646 109.450 2.050 9.980 6000.000 2664.000 222.829 .554 40.452 132.770 3.819 9.950 6500.000 2336.142 281.926 .400 32.248 89.059 4.759 9.400 7000.000 2856.000 90.218 1.042 31.174 104.594 3.887 10.590 7500.000 2737.481 34.730 2.104 39.110 115.243 2.934 10.390 8000.000 2437.393 35.221 1.816 39.976 105.471 2.988 8.630 8500.000 2449.560 ** 561 DATA RECORDS ** FROM ** FILE TRAILER** 1024 FILE NAME: 3G8.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/05/31 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: -999.250 -999.250 -999.250 -999.250 559.000 607.000 2.109 .011 591.000 647.000 2.304 .048 639.000 647.000 2.318 .052 647.000 695.000 2.228 .081 647.000 583.000 2.296 .059 647.000 618.322 2.308 .082 671.000 703.000 2.405 .043 708.432 763.049 2.396 .180 637.998 687.992 2.208 .095 655.201 655.047 2.417 -.004 3500.00 TO 8825.00 FT NN0 -999.250 2664.000 2648.000 2568.000 2568.000 2568.000 2462.643 2664.000 2785.481 2414.520 2404.962 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/05/31 ORIGIN OF DATA: 3G-8 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: DATE: 90/05/31 ORIGIN OF DATA: REEL NAME: ARCO CONTINUATION #: NEXT REEL NAME: COMMENTS: SSDS RLL O1 PETROLEUM COMPUTING INC.- LIS FORMAT
