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211-034
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12614'feet 10070'feet true vertical 6279' feet None feet Effective Depth measured 12614'feet 9902', 10016'feet true vertical 6279'feet 6120', 6185'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 J-55 9989' 10084' 6169' 6224' Packers and SSSV (type, measured and true vertical depth)9902' 10016' 6120' 6185' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3789' 2912' Burst Collapse Liner A 1584' 1560' Casing 1572' 6279' 1617' 12614' 3754' 115'Conductor Surface Tie-Back String 16" 9-5/8" 80' measured TVD 7" 2-3/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 211-034 50-103-20118-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025589, ADL0025588 Kuparuk River Field/ Kuparuk Oil Pool KRU 2K-19 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 499 Gas-Mcf MDSize 115' 2050 1348250 Well Shut-In 219 324-575 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: BluePack RH Max VAM Packer: BAKER HB Retrievable SSSV: None Brian Glasheen brian.glasheen@conocophillips.com (907) 545-1144 RWO Engineer 11081-11179' (slots), 11756-12614' (slots) 6302-6299', 6301-6279' Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:42 pm, Nov 19, 2024 Digitally signed by Brian Glasheen DN: OU=RWO's, O=ConocoPhillips, CN=Brian Glasheen, E=brian.glasheen@conocophillips.com Reason: I am the author of this document Location: Date: 2024.11.19 13:25:04-09'00' Foxit PDF Editor Version: 13.0.0 Brian Glasheen Page 1/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/13/2024 00:00 10/13/2024 01:00 1.00 MIRU, MOVE MOB P Spot sub over 2K-19. Level rig. Seal up cellar. Level working platform in cellar. 0.0 0.0 10/13/2024 01:00 10/13/2024 02:00 1.00 MIRU, MOVE MOB P Berm in cellar. Move in auxillary equipment. Take inital RKB's. Complete acceptance checklist. Take on 9.8 PPG NaCl into pits. Obain initial well pressures T/IA/OA = 50/0/20. 0.0 0.0 10/13/2024 02:00 10/13/2024 03:00 1.00 MIRU, WELCTL OWFF P R/U hard line T/ external tank. Take on 9.8 PPG NaCl into pits. Obtain initial well pressures T/IA/OA = 50/Vac/20. AllowT/IA to equalize diesel flowing from TBG diminishing to no flow. 30 Min no flow check. 0.0 0.0 10/13/2024 03:00 10/13/2024 04:00 1.00 MIRU, WELCTL RURD P Call out FMC. R/U testing equipment T/ IA. 0.0 0.0 10/13/2024 04:00 10/13/2024 04:15 0.25 MIRU, WELCTL MPSP P Set ISA BPV. 0.0 0.0 10/13/2024 04:15 10/13/2024 04:30 0.25 MIRU, WELCTL PRTS P PT BPV F/ below T/ 1000 PSI for 10 Min. 0.0 0.0 10/13/2024 04:30 10/13/2024 05:00 0.50 MIRU, WHDBOP RURD P B/D, R/D testing equipment. 0.0 0.0 10/13/2024 05:00 10/13/2024 07:00 2.00 MIRU, WHDBOP NUND P Nipple down - pull tree and tubing adapter, Kick out of cellar. Inspect threads in hanger - Good 0.0 0.0 10/13/2024 07:00 10/13/2024 09:00 2.00 MIRU, WHDBOP NUND P P/U Stack install onto DSA. Torque up DSA and stack 0.0 0.0 10/13/2024 09:00 10/13/2024 11:30 2.50 MIRU, WHDBOP NUND P Center stack and secure. Get RKB's, Install riser. Plumb trip tank. Grease choke manifold and mud cross. Change out door seal on DS blinds 0.0 0.0 10/13/2024 11:30 10/13/2024 21:30 10.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular, LPR w/ 7" TJ". Test UVBR's & annular w/ 3 1/2" TJ. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3050 PSI, after closure=1625 PSI, 200 PSI attained = 22 sec, full recovery attained = 123 sec. UVBR's=5 sec, Simulated LPR=5 sec. Annular= 16 sec. Simulated blinds=5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT. Test witnessed by AOGCC rep Adam Earl, 0.0 0.0 10/13/2024 21:30 10/14/2024 00:00 2.50 MIRU, WHDBOP BOPE P Kill MM #13 failed. Was rebuilt and passed retest. CMV #6, & #1 failed initial test. Greased & functioned, passed retest. HCR choke failed, Changing out HCR choke. 0.0 0.0 10/14/2024 00:00 10/14/2024 05:00 5.00 MIRU, WHDBOP BOPE T Complete installation on new HCR choke valve. Test HCR choke vlave and breaks behaind valve T/ 250/3000 PSI. Passed retest. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 2/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/14/2024 05:00 10/14/2024 06:00 1.00 MIRU, WHDBOP RURD P B/D, R/D testing equipment. Pull blanking plug. Suck out stack. Install mouse hole, Shut IA 0.0 0.0 10/14/2024 06:00 10/14/2024 06:30 0.50 COMPZN, RPCOMP MPSP P Pulll ISA BPV 0.0 0.0 10/14/2024 06:30 10/14/2024 07:30 1.00 COMPZN, RPCOMP PULL P M/U 3 1/2 EUE landing joint, Set down 10K. Back out LDS's. Pick up on completion. Pull hanger to rig floor, PUW=50K. Circ BU 3 BPM @ 830 PSI. 0.0 0.0 10/14/2024 07:30 10/14/2024 08:00 0.50 COMPZN, RPCOMP RURD P Break hanger. Rig up control line to spooler 0.0 0.0 10/14/2024 08:00 10/14/2024 11:00 3.00 COMPZN, RPCOMP PULL P Pull 3 1/2 EUE completion from jet cut @ 1782, Recoved control line to match pipe, 28 SS bands 1,782.0 0.0 10/14/2024 11:00 10/14/2024 12:30 1.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor. Load out decompletion. Load out HES spooler 0.0 0.0 10/14/2024 12:30 10/14/2024 13:00 0.50 COMPZN, RPCOMP RURD P Install wear bushing. 0.0 0.0 10/14/2024 13:00 10/14/2024 14:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #1 single 5.875 string reamer 0.0 5.0 10/14/2024 14:00 10/14/2024 16:00 2.00 COMPZN, RPCOMP PULD P Trip in hole BHA #1 5.875 string reamer, Light tag @ 1766', 5.0 1,766.0 10/14/2024 16:00 10/14/2024 16:30 0.50 COMPZN, RPCOMP CIRC P Circ BU 5 BPM @ 350 PSI 1,767.0 1,767.0 10/14/2024 16:30 10/14/2024 17:00 0.50 COMPZN, RPCOMP OTHR P Shut down pump, Retag @ 1767 OWFF 1,767.0 1,767.0 10/14/2024 17:00 10/14/2024 17:30 0.50 COMPZN, RPCOMP TRIP P Trip out of well, PUW=60K 1,767.0 0.0 10/14/2024 17:30 10/14/2024 19:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA #1 5.875" reamer. P/U BHA #2, 6.125 X 6.125" string reamers 0.0 15.0 10/14/2024 19:00 10/14/2024 20:00 1.00 COMPZN, RPCOMP TRIP P Trip in hole. Set down @ 741' Hard tag,Trip out. PUW=445K 15.0 15.0 10/14/2024 20:00 10/14/2024 20:30 0.50 COMPZN, RPCOMP BHAH P Lay down BHA #2, 15.0 8.0 10/14/2024 20:30 10/14/2024 21:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #3_ single 6" string milll longer reamer surface. 8.0 7.0 10/14/2024 21:00 10/14/2024 21:30 0.50 COMPZN, RPCOMP SEQP P PT surface lines to kill and open top tank. 2500 PSI 8.0 0.0 10/14/2024 21:30 10/14/2024 22:30 1.00 COMPZN, RPCOMP TRIP P RIH w/ BHA #3 T/ 741'. Worked through 756' w/ 15 string weight. P/U 10K over pull.. Desion made to POOH. Call out e-line. 0.0 7,141.0 10/14/2024 22:30 10/14/2024 23:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 741' T/ 7", PUW=45K. 7,141.0 7.0 10/14/2024 23:00 10/14/2024 23:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #3 7.0 0.0 10/14/2024 23:30 10/15/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig C/O oil in spinners. 0.0 0.0 10/15/2024 00:00 10/15/2024 01:30 1.50 COMPZN, RPCOMP ELNE P Spot & R/U AK E-line. 0.0 0.0 10/15/2024 01:30 10/15/2024 03:15 1.75 COMPZN, RPCOMP ELOG P Run Read 40 arm caliper. E-line was able to get T/ 1755'. Log up T/ 1500'. RIH for repeat log. E-line was able to get T/ 1715'. Log R/ 1708' T/ surface. 0.0 0.0 10/15/2024 03:15 10/15/2024 04:00 0.75 COMPZN, RPCOMP ELNE P C/O tool string. Metal shavings on 40 arm caliper. M/U CBL. Rush processes data. Field log showed damage F/ ~720'-760' 0.0 0.0 10/15/2024 04:00 10/15/2024 05:15 1.25 COMPZN, RPCOMP ELOG P Run CBL T/ 1767'. Log to surface. No cement. 0.0 0.0 10/15/2024 05:15 10/15/2024 07:45 2.50 COMPZN, RPCOMP WAIT P Wait on IBP to be mobilized from Baker in Deadhorse. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 3/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/15/2024 07:45 10/15/2024 08:30 0.75 COMPZN, RPCOMP ELNE P M/U IBP tool string. 0.0 0.0 10/15/2024 08:30 10/15/2024 09:30 1.00 COMPZN, RPCOMP ELOG P RIH w/ 3 3/8" IBP. Consult w/ town on processed data. Decision made not to set IBP and make another drift run and clean up around fish top. Likely make additional caliper run to confirm good pipe below 1690'. POOH w/ IBP. 0.0 0.0 10/15/2024 09:30 10/15/2024 10:00 0.50 COMPZN, RPCOMP ELNE P R/D E-line. Leave unit on location. 0.0 0.0 10/15/2024 10:00 10/15/2024 10:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease & inspect TD. 0.0 0.0 10/15/2024 10:30 10/15/2024 11:00 0.50 COMPZN, RPCOMP RURD P Mobilize tools to RF. 0.0 0.0 10/15/2024 11:00 10/15/2024 11:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #4 single 6" string mill w/ pups under it T/ 18' 0.0 18.0 10/15/2024 11:30 10/15/2024 12:45 1.25 COMPZN, RPCOMP TRIP P RIH F/ 18' T/ 741'. Push through problem area w/ 15K string weight, fell off @ 571'. Cont RIH T/ 1768', PUW=60K, SOW=55K 18.0 1,768.0 10/15/2024 12:45 10/15/2024 13:09 0.40 COMPZN, RPCOMP CIRC P Circ BU @ 8 BPM, 800 PSI. 1,768.0 1,768.0 10/15/2024 13:09 10/15/2024 13:15 0.10 COMPZN, RPCOMP MILL P P/U T/ 1764', Rotate @ 30 RPM, 1.6K Free Tq. ROT=56K. RIH set 5K down @ 1768'. No PSI or Tq increase. 1,768.0 1,768.0 10/15/2024 13:15 10/15/2024 13:45 0.50 COMPZN, RPCOMP CIRC P Circ 30 Bbls hi-vis pill @ 8 BPM, 760 PSI. Rot & Recip F/ 1765' T/ 1750'. 1,768.0 1,750.0 10/15/2024 13:45 10/15/2024 14:15 0.50 COMPZN, RPCOMP OWFF P P/U T/ 1689'. OWFF, B/D TD. Inspect ditch magnets, very minimal metal shavings. 1,750.0 1,689.0 10/15/2024 14:15 10/15/2024 15:00 0.75 COMPZN, RPCOMP TRIP P POOH F/ 1689' T/ 18' PUW=60K. 1,689.0 18.0 10/15/2024 15:00 10/15/2024 15:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #4. ~100 of control line wadded up around mill. Bull nose showed wear pattern constant w/ ID of tubing. 18.0 0.0 10/15/2024 15:30 10/15/2024 17:00 1.50 COMPZN, RPCOMP RURD P Load & proccess 10 4 3/4" DC's. Mobilize storm packer to pipe shed. 0.0 0.0 10/15/2024 17:00 10/15/2024 17:30 0.50 COMPZN, RPCOMP TRIP P M/U mule shoe RIH w/ 4 stand DP T/ 392'. 0.0 392.0 10/15/2024 17:30 10/15/2024 18:00 0.50 COMPZN, RPCOMP PULD P P/U 10 4 3/4" DC's to 698'. 392.0 698.0 10/15/2024 18:00 10/15/2024 18:15 0.25 COMPZN, RPCOMP BHAH P MU BHA #5 (7" Storm Packer) 698.0 720.0 10/15/2024 18:15 10/15/2024 18:30 0.25 COMPZN, RPCOMP PULD P TIH w/ 2 joints DP. PUW = 60K. SOW = 55K. 720.0 782.0 10/15/2024 18:30 10/15/2024 19:00 0.50 COMPZN, RPCOMP MPSP P Set 7" Storm Packer COE @ 71'. Top @ 57'. 782.0 782.0 10/15/2024 19:00 10/15/2024 19:15 0.25 COMPZN, RPCOMP PRTS P Close UPR's. RU sensator to test spool. PT Storm Packer to 1,000 psi for 10-min. Chart not clean. Cellar heaters causing temp effects. Decide to release from storm packer and re-test against blinds. 782.0 782.0 10/15/2024 19:15 10/15/2024 19:45 0.50 COMPZN, RPCOMP PULD P Unscrew TD. Release from Storm Packer. L/D 2 joints DP and setting tool. 782.0 0.0 10/15/2024 19:45 10/15/2024 20:00 0.25 COMPZN, RPCOMP PRTS P Close Blinds. PT Storm Packer to 1,000 psi for 10-min. Good clean test. Bleed off. 0.0 0.0 10/15/2024 20:00 10/15/2024 20:15 0.25 COMPZN, RPCOMP RURD P Drain Stack. Blowdown lines. RU OA to open bleed at bleed trailer. OWFF. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 4/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/15/2024 20:15 10/16/2024 00:00 3.75 COMPZN, RPCOMP NUND P ND BOP. Pull wear ring. Bleed pack-off void. MU Cameron tensioning tool. 0.0 0.0 10/16/2024 00:00 10/16/2024 02:45 2.75 COMPZN, RPCOMP NUND P Continue to MU Cameron tensioning tool. Allow 7" casing to grow. Measured growth = 21" flange to flange. Initial Force = 252K. Allow time to relax after grow. Remove old Tubing Head and pack-off. 0.0 0.0 10/16/2024 02:45 10/16/2024 04:15 1.50 COMPZN, RPCOMP BHAH P Load 7" Spear. Found miss-marked XO. Need 4 1/2" FH Pin x 4 1/2" IF Box. 0.0 0.0 10/16/2024 04:15 10/16/2024 05:30 1.25 COMPZN, RPCOMP WAIT T Wait on 4 1/2" FH Pin x 4 1/2" IF Box XO from Deadhorse. 0.0 0.0 10/16/2024 05:30 10/16/2024 05:45 0.25 COMPZN, RPCOMP BHAH P Load correct XO. M/U BHA #6 (7" casing spear). 0.0 0.0 10/16/2024 05:45 10/16/2024 06:45 1.00 COMPZN, RPCOMP CUTP P Screw in TD. Engage 7" casing. Pull 105K. Stretch 7" casing. Measured stretch = 9". OA - 30". Remove old slips. Re-land 7" casing in emergency slips secured with SS band. 0.0 0.0 10/16/2024 06:45 10/16/2024 07:00 0.25 COMPZN, RPCOMP BHAH P Release and L/D 7" Spear. 0.0 0.0 10/16/2024 07:00 10/16/2024 08:00 1.00 COMPZN, RPCOMP CUTP P CUt of excess 7" w/ WHACKS saw. 0.0 0.0 10/16/2024 08:00 10/16/2024 10:30 2.50 COMPZN, RPCOMP NUND P N/U ported 11" 3K x 11" 5K DSA. N/U BOP. 0.0 0.0 10/16/2024 10:30 10/16/2024 11:00 0.50 COMPZN, RPCOMP PRTS P PT stack breaks through ported DSA T/ 3000 PSI for 5 Min each. 0.0 0.0 10/16/2024 11:00 10/16/2024 12:00 1.00 COMPZN, RPCOMP NUND P Hook up trip line. Take RKB's. Center stack. Remove old TBG head to be shipped of for inspection. Hook up trip line. Install flow nipple. 0.0 0.0 10/16/2024 12:00 10/16/2024 12:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Adjust brakes. Service pipe skate. 0.0 0.0 10/16/2024 12:30 10/16/2024 13:00 0.50 COMPZN, RPCOMP PULL P M/U storm packer retrieval tool. P/U 2 singles. Close TIW. 0.0 65.0 10/16/2024 13:00 10/16/2024 13:30 0.50 COMPZN, RPCOMP PACK P Engage & equalize. Check for PSI in DP. Close annular. P/U release packer. Verify no PSI under annular. Open annular. 782.0 782.0 10/16/2024 13:30 10/16/2024 14:00 0.50 COMPZN, RPCOMP BHAH P L/D singles & storm packer. L/ D BHA #5 T/ surface. PUW=50K. 782.0 720.0 10/16/2024 14:00 10/16/2024 15:00 1.00 COMPZN, RPCOMP TRIP P Rack back DC's & Dp. 720.0 0.0 10/16/2024 15:00 10/16/2024 15:45 0.75 COMPZN, RPCOMP BHAH P M/U BHA #7 tandem 6" sting mill T/ 28' 0.0 28.0 10/16/2024 15:45 10/16/2024 16:30 0.75 COMPZN, RPCOMP TRIP P RIH T/ 742' started taking weight. Made it T/ 750' set down 25K could not pass. , 28.0 750.0 10/16/2024 16:30 10/16/2024 17:15 0.75 COMPZN, RPCOMP TRIP P TOOH stand back DP. 750.0 22.0 10/16/2024 17:15 10/16/2024 18:00 0.75 COMPZN, RPCOMP BHAH P L/D BHA #7 (Tandem 6" string mills). 22.0 0.0 10/16/2024 18:00 10/16/2024 19:00 1.00 COMPZN, RPCOMP RURD P Monitor OA loss rate on 9.8# Brine. Est. 6 BPH to shallow leak @ 642'. Crew C/O. Change out flow nipple. Start processing 7" HYD563 casing while waiting for E-line out of Deadhorse. 0.0 0.0 10/16/2024 19:00 10/16/2024 20:30 1.50 COMPZN, RPCOMP TRIP P MU Muleshoe. TIH w/ 8 stands DP and 10 Joints DC's for hanging weight (20K). 0.0 1,054.0 10/16/2024 20:30 10/16/2024 20:45 0.25 COMPZN, RPCOMP BHAH P MU BHA #8 (Test Packer). 1,054.0 1,076.0 10/16/2024 20:45 10/16/2024 21:00 0.25 COMPZN, RPCOMP TRIP P TIH on stand of DP placing Test Packer COE at 98'. 1,076.0 1,155.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 5/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/16/2024 21:00 10/16/2024 21:15 0.25 COMPZN, RPCOMP MPSP P Screw in TD. Set Test Packer @ 98' COE. 1,155.0 1,155.0 10/16/2024 21:15 10/16/2024 21:45 0.50 COMPZN, RPCOMP PRTS P RU testing equipment. Set 15K down for extra weight. PT 7" casing to 500 psi between test packer @ 100' and deep plug @ 10,035'. Good test. OA pressure @ 12 psi. Took 9 strokes to pressure up. Bleed off. 1,155.0 1,155.0 10/16/2024 21:45 10/16/2024 22:00 0.25 COMPZN, RPCOMP RURD P R/D testing equipment (3 1/2" Pump-in Sub + XO's + circ hose). P/U TD weight. Unscrew TD. 1,155.0 1,155.0 10/16/2024 22:00 10/16/2024 22:15 0.25 COMPZN, RPCOMP MPSP P Release Test Packer. 1,155.0 1,155.0 10/16/2024 22:15 10/16/2024 22:30 0.25 COMPZN, RPCOMP TRIP P TOOH w/ DP stand. 1,155.0 1,062.0 10/16/2024 22:30 10/16/2024 22:45 0.25 COMPZN, RPCOMP BHAH P L/D BHA #8 (Test Packer) 1,062.0 1,040.0 10/16/2024 22:45 10/16/2024 23:15 0.50 COMPZN, RPCOMP TRIP P TOOH and stand back 3 stands of DC's. L/D single DC. Cont TOOH standing back 8 stands DP and mule shoe. 1,040.0 0.0 10/16/2024 23:15 10/17/2024 00:00 0.75 COMPZN, RPCOMP ELNE P RU YJ E-line. M/U and function test 40- arm caliper. 0.0 0.0 10/17/2024 00:00 10/17/2024 00:30 0.50 COMPZN, RPCOMP ELNE P M/U and function test 40-arm caliper. RIH to 1,760'. 0.0 0.0 10/17/2024 00:30 10/17/2024 03:15 2.75 COMPZN, RPCOMP ELOG P Power up caliper tool to open arms. Log 40-arm caliper from 1,760' to surface @ 60 FPM. L/D 40-arm caliper @ 02:15. Download data. Send to town for quick turnaround processing. While reviewing caliper log load and M/U 3 3/8" Baker IBP. Zero at rig floor. 0.0 0.0 10/17/2024 03:15 10/17/2024 05:00 1.75 COMPZN, RPCOMP ELOG P RIH and set Baker IBP @ 1,750' COE (Top @ 1,743', Bottom @ 1,754'). CCL to COE = 24.44'. CCL Stop Depth = 1,725.6'. On depth @ 03:45AM. Tied into caliper log. Power up IBP setting tools. Inflate IBP. After setting tools sheared, POOH. 0.0 0.0 10/17/2024 05:00 10/17/2024 05:30 0.50 COMPZN, RPCOMP ELNE P R/D & release E-line & Baker. 0.0 0.0 10/17/2024 05:30 10/17/2024 06:45 1.25 COMPZN, RPCOMP TRIP P TIH w/ mule shoe, 12 DP stands, and 10 DC's for hang off weight T/ 1436', SOW=60K. 0.0 1,436.0 10/17/2024 06:45 10/17/2024 07:15 0.50 COMPZN, RPCOMP BHAH P MU BHA #9 (Test Packer). TIH w/ test packer to approx. 98' COE. .Mule shoe T/ 1524'. M/U TD set packer. 1,436.0 1,524.0 10/17/2024 07:15 10/17/2024 07:45 0.50 COMPZN, RPCOMP RURD P R/U testing equipment. 1,524.0 1,524.0 10/17/2024 07:45 10/17/2024 08:30 0.75 COMPZN, RPCOMP PRTS P PT IBP @ 1750' T/ storm packer @ 98 T/ 1000 PSI. Pressure up w/ 4 strokes. Surface leak at TIW. Tighten connecrtion. PT IBP @ 1750' T/ storm packer @ 98 T/ 1000 PSI for 10 Min. Pressure up w/ 4 strokes 1,524.0 1,524.0 10/17/2024 08:30 10/17/2024 08:45 0.25 COMPZN, RPCOMP RURD P R/D, B/D testing equipment. Break down pump in sub & XO's, 1,524.0 1,524.0 10/17/2024 08:45 10/17/2024 09:00 0.25 COMPZN, RPCOMP BHAH P Release test packer. L/D BHA #9. Rack back stand of DP. L/D storm packer. PUW=62K. 1,524.0 1,436.0 10/17/2024 09:00 10/17/2024 09:45 0.75 COMPZN, RPCOMP TRIP P L/D DC. Rack back 3 DC's T/ 1116', PUW=61K. 1,436.0 1,116.0 10/17/2024 09:45 10/17/2024 10:15 0.50 COMPZN, RPCOMP TRIP P RIH on DP T/ 1730' SOW=50K. 1,116.0 1,730.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 6/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/17/2024 10:15 10/17/2024 10:30 0.25 COMPZN, RPCOMP DISP P Pump 27 Bbls hi-vis sweep. Displace well T/ seawater @ 6 BPM, 445 PSI. 1,730.0 1,730.0 10/17/2024 10:30 10/17/2024 10:45 0.25 COMPZN, RPCOMP TRIP P Rack back stand, L/D single T/ 1642', PUW=54K. . 1,730.0 1,642.0 10/17/2024 10:45 10/17/2024 11:15 0.50 COMPZN, RPCOMP RURD P B/D TD. R/U circ equipment & sand hopper. 1,642.0 1,642.0 10/17/2024 11:15 10/17/2024 17:30 6.25 COMPZN, RPCOMP CIRC P Line up to suck out test spool with trash pump. Feed DP through fill up hose. Dump 1500# of sand for 60' of sand on top of IBP. Allow sand to settle for 1 Hr. Tag TOS @ 1,685' (2K down). PUH. Circ to confirm DP is clear. 1,642.0 1,642.0 10/17/2024 17:30 10/17/2024 18:30 1.00 COMPZN, RPCOMP TRIP P TOOH on DP to surface. Clean and clear rig floor. Cont. to heat 200 bbls hot seawater w/ LRS. 1,642.0 0.0 10/17/2024 18:30 10/17/2024 19:00 0.50 COMPZN, RPCOMP BHAH P MU BHA #10 (YJ 5 7/8" OD Multi-String Cutter). 0.0 5.0 10/17/2024 19:00 10/17/2024 20:30 1.50 COMPZN, RPCOMP TRIP P TIH w/ BHA #10 to approx. 941'. Seeing every collar from surface due to flat bottom on cutter assembly. On Stand #11, set down 15K. Repeat same set down. Attempt to rotate through tight spot. Unable. Made decision to TOOH and PU smaller OD 4 1/4" backup cutter. 5.0 941.0 10/17/2024 20:30 10/17/2024 21:00 0.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #10 (5 7/8" MSC). 941.0 5.0 10/17/2024 21:00 10/17/2024 21:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #10. Inspect cutter. Flat nose contributing to set downs at each collar. Tape stripped off cutter blades. Floating Cutters were catching collars durind TIH. See pictures. 5.0 0.0 10/17/2024 21:30 10/17/2024 21:45 0.25 COMPZN, RPCOMP BHAH P MU BHA #11 (4 1/2" MSC). 0.0 7.0 10/17/2024 21:45 10/17/2024 22:30 0.75 COMPZN, RPCOMP TRIP P TIH w/ BHA #11 to 1,585'. Kelly up. Cont. TIH. Locate collars at 1,643.5' and 1,603.50'. Repeat collar locate at 1603.50'. TIH and park cutter blades @ 1,613.50'. 7.0 1,630.0 10/17/2024 22:30 10/17/2024 23:15 0.75 COMPZN, RPCOMP CUTP P Obtain Parameters. PUW = 55K, SOW = 55K. Rotary = 60 RPM. F.T. = 1.1K. Bring pumps online @ 3 BPM / 1450 psi. Cutting Torque = 2.5-3K. Start cutting @ 10:58PM. See slight flow increase @ 11:10PM. See slight arctic pack and bubbles in returns. Torque reduced to 2-2.1K. No significant pressure indicator of cut. SD rotary @ 11:15PM. PU off cut. TIH and set 7K at cut depth to verify. SD Pumps. See bubbles and arctic pack at surface. 1,630.0 1,613.5 10/17/2024 23:15 10/18/2024 00:00 0.75 COMPZN, RPCOMP CIRC P Line up to take OA returns out to open top tank. Line up to pump off hot water truck down DP. Close annular. Circulate 200 bbls of hot 8.5# SW @ 2 BPM / 626 psi. 1,613.5 1,613.5 10/18/2024 00:00 10/18/2024 01:15 1.25 COMPZN, RPCOMP CIRC P Finish circulating 200 bbls of hot 8.5# SW @ 2 BPM / 626 psi. Blowdown return lines out to open top. 1,613.5 1,613.5 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 7/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/18/2024 01:15 10/18/2024 02:30 1.25 COMPZN, RPCOMP OWFF P Open annular. Pump 10 bbls to cuttings tank to clean arctic pack off the top. OWFF. L/D stand. Blowdown Top Drive. Load 90 bbls hot SW into Pit #1. Send Vac truck to get another load of SW. Est. LLR during NFT at approx. 5 BPH. 1,613.5 1,583.0 10/18/2024 02:30 10/18/2024 03:15 0.75 COMPZN, RPCOMP TRIP P TOOH w/ BHA #11 (4 1/4" MSC). Build 30 bbl hot hi vis pill. 1,583.0 7.0 10/18/2024 03:15 10/18/2024 03:45 0.50 COMPZN, RPCOMP BHAH P L/D BHA #11 (4 1/4" MSC). Inspect cutter blades. Found 1 blade missing (4 1/2" long x 1 3/8" wide). Found 1 blade sheared off caught in lower body of tool. Third blade still attached showed signed of wear. See pictures. 7.0 0.0 10/18/2024 03:45 10/18/2024 04:15 0.50 COMPZN, RPCOMP BHAH P MU BHA #12 (Spear w/ PO). 0.0 16.0 10/18/2024 04:15 10/18/2024 04:30 0.25 COMPZN, RPCOMP TRIP P TIH and engage 7" casing stub. 16.0 30.0 10/18/2024 04:30 10/18/2024 06:30 2.00 COMPZN, RPCOMP PULL P Confirm circulation through cut w/ charge pump. Good circulation. Attempt to pull 7" casing free from cut @ 1,613.5'. Likely a partial cut due to MSC blade damage. Pull 105K (30K over). Came free. Pulled up 5'. Pull bushings. Cont. pull another 6' dragging at 95K. Drain Stack. RU line to center up slips thru BOP stack. Cont. to pull 7" to rig floor guiding slips through BOP stack. Work up T/ 225K pupe free. PUW=87K. Pull to RF. 1,613.5 1,571.0 10/18/2024 06:30 10/18/2024 07:00 0.50 COMPZN, RPCOMP CUTP P Remove emergency slips at RF. 1,571.0 1,571.0 10/18/2024 07:00 10/18/2024 08:00 1.00 COMPZN, RPCOMP RURD P R/U GBR CSG equipment. 1,571.0 1,571.0 10/18/2024 08:00 10/18/2024 08:15 0.25 COMPZN, RPCOMP BHAH P Pull BHA #12 _7" spaear out of stirng. 1,571.0 1,571.0 10/18/2024 08:15 10/18/2024 08:45 0.50 COMPZN, RPCOMP PULD P L/D upper cut joiint 7.43' long. & BHA #12. 1,571.0 1,571.0 10/18/2024 08:45 10/18/2024 09:15 0.50 COMPZN, RPCOMP RURD P R/U circ equipment. 1,571.0 1,571.0 10/18/2024 09:15 10/18/2024 10:00 0.75 COMPZN, RPCOMP CIRC P Circ 30 Bbls heated hi-vis deep clean pill around @ 3 BPM, 90 PSI. 1,571.0 1,571.0 10/18/2024 10:00 10/18/2024 10:15 0.25 COMPZN, RPCOMP RURD P B/D , R/D circ equipment. 1,571.0 1,571.0 10/18/2024 10:15 10/18/2024 17:30 7.25 COMPZN, RPCOMP PULL P L/D 7" CSG F/ 1571' T/ Surface. Pulling tight every 39' until cut joint was above bad spot in 7" T/ 717'. Severely buckled pipe F/ joint #18 @ 740' T/ Joint #40 @ 1,603'. Cut Joint #41 measured = 9.57'. Good cut. Minimal flare. See pictures 1,571.0 0.0 10/18/2024 17:30 10/18/2024 19:00 1.50 COMPZN, RPCOMP RURD P Clean and clear rig floor. RD GBR equipment. Crew C/O. 0.0 0.0 10/18/2024 19:00 10/18/2024 20:00 1.00 COMPZN, RPCOMP WWWH P Flush stack to ensure clear of arctic pack and potential debris. Drain Stack. Unload pulled 7" casing, cut joints, and centralizers. 0.0 0.0 10/18/2024 20:00 10/18/2024 20:30 0.50 COMPZN, RPCOMP MPSP P Set 11" test plug. 0.0 0.0 10/18/2024 20:30 10/18/2024 21:00 0.50 COMPZN, RPCOMP PRTS P RU testing equipment. PT BOP breaks to 250/3000 psi. Chart. Pull 11" test plug. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 8/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/18/2024 21:00 10/18/2024 21:45 0.75 COMPZN, RPCOMP MPSP P Pull 11" test plug. Set Wear Ring. Wear Ring Measurements. ID = 9.0". OD = 10 13/16". Length = 12" 0.0 0.0 10/18/2024 21:45 10/18/2024 22:30 0.75 COMPZN, RPCOMP BHAH P MU BHA #13 (Single 8 3/8" String Mill). 0.0 19.0 10/18/2024 22:30 10/18/2024 23:15 0.75 COMPZN, RPCOMP TRIP P TIH on DP stands to 500'. Roll well over to viscosified SW. TOOH to tight spot @ 740'. Tag restriction. PUH to 729'. 19.0 740.0 10/18/2024 23:15 10/19/2024 00:00 0.75 COMPZN, RPCOMP MILL P Obtain parameters. PUW = 45K. SOW = 45K. Rotary = 60 RPM. Free Torque = 0.8K. Pump Rate = 5 BPM / 131 psi. TIH and slowly begin milling through tight spot in 9 5/8" casing @ 740'. Milling torque = 1.8K-3K. Setting 1-2K down. Mill down to 741'. 740.0 741.0 10/19/2024 00:00 10/19/2024 03:30 3.50 COMPZN, RPCOMP MILL P Continue milling through tight spot in 9 5/8" casing F/ 741' T/ 746'. Made total of 6' by 02:00. Milling Torque = 2-5K. Setting 2-5K down. Pump Rate = 5 BPM @ 120 psi. Cont. milling through tight spot to 755'. Broke through. 741.0 755.0 10/19/2024 03:30 10/19/2024 04:30 1.00 COMPZN, RPCOMP REAM P Back Ream twice through tight spot interval from 740'-755'. PUH above tight spot. 755.0 755.0 10/19/2024 04:30 10/19/2024 05:00 0.50 COMPZN, RPCOMP TRIP P With pumps on pushed through tight spot w/o rotation. Took 10K down to push through. TIH w/ BHA #13 to 851'. 755.0 851.0 10/19/2024 05:00 10/19/2024 06:00 1.00 COMPZN, RPCOMP SVRG P Leak developed on gripper box telescoping seal. Stab floor valve. Repair gripper box leak. 851.0 851.0 10/19/2024 06:00 10/19/2024 06:30 0.50 COMPZN, RPCOMP RGRP T Complete repair on gripper box leak. 851.0 851.0 10/19/2024 06:30 10/19/2024 07:15 0.75 COMPZN, RPCOMP TRIP P RIH F/ 851' T/ 1614', PUW=56K, SOW=56K. Clean drift. Tagged stump @ 1614. 851.0 1,614.0 10/19/2024 07:15 10/19/2024 07:45 0.50 COMPZN, RPCOMP CIRC P Pump 20 Bbls hi-vis pill. Circ out w/ SW.@ 9 BPM, 290 PSI. Rot on 7" stub @ 30 RPM, 1,5 K Tq. ROT=58K. to mark bull nose. P/U T/ 1594' 1,614.0 1,594.0 10/19/2024 07:45 10/19/2024 08:00 0.25 COMPZN, RPCOMP OWFF P B/D TD, OWFF. 1,594.0 1,594.0 10/19/2024 08:00 10/19/2024 08:45 0.75 COMPZN, RPCOMP TRIP P POOH F/ 1594' T/ 14', PUW=56K. Pulled 5K over ~753' 1,594.0 18.0 10/19/2024 08:45 10/19/2024 09:00 0.25 COMPZN, RPCOMP BHAH P L/D BHA #13. 18.0 0.0 10/19/2024 09:00 10/19/2024 09:30 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 10/19/2024 09:30 10/19/2024 10:30 1.00 COMPZN, RPCOMP BHAH P Mobilize M/U BHA #14. SIngle 8.5" string mill T/ 19'. C/O DP joint #1, damaged. 0.0 19.0 10/19/2024 10:30 10/19/2024 11:15 0.75 COMPZN, RPCOMP TRIP P RIH T/ 741', PUW=45, SOW=45K. Set down 5K @ 741' bull nose depth. 19.0 741.0 10/19/2024 11:15 10/19/2024 13:00 1.75 COMPZN, RPCOMP MILL P P/U T/ 725' K/U. Obtain parameters, pump @ 7 BPM, 112 PSI. Rot @ 60 RPM, 1.2K Free Tq. ROT=46K. Wash & ream down T/ 741'. Mill w/ 3-5K Tq, 1- 2K WOB. Popped through at 758'. Ream up & down through problem area. Kill Rot. Run through w/ pumps. T/ 762'. Taking 5-12K SOW. 741.0 750.0 10/19/2024 13:00 10/19/2024 13:30 0.50 COMPZN, RPCOMP TRIP P RIH F/ 750' T/ 1614', PUW=56K, SOW=56K. Clean drift. 750.0 1,614.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 9/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/19/2024 13:30 10/19/2024 13:48 0.30 COMPZN, RPCOMP CIRC P Pump 20 Bbls hi-vis pill. Circ out w/ SW.@ 9 BPM, 290 PSI. P/U T/ 1594' 1,614.0 1,564.0 10/19/2024 13:48 10/19/2024 13:54 0.10 COMPZN, RPCOMP OWFF P B/D TD. OWFF 1,564.0 1,564.0 10/19/2024 13:54 10/19/2024 14:30 0.60 COMPZN, RPCOMP TRIP P POOH F/ 1564' T/ 19', PUW=56K. 1,564.0 19.0 10/19/2024 14:30 10/19/2024 15:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #14. 19.0 0.0 10/19/2024 15:00 10/19/2024 16:15 1.25 COMPZN, RPCOMP RURD P Mobilize & process 3ea 6 1/2" DC's. Load 7" centralizer in pipe shed. 0.0 0.0 10/19/2024 16:15 10/19/2024 17:15 1.00 COMPZN, RPCOMP BHAH P M/U BHA #15. Stacked tandem 8 3/8" string mill w/ 1 stand of 6.5" DC's. SOW=45K. 0.0 115.0 10/19/2024 17:15 10/19/2024 17:45 0.50 COMPZN, RPCOMP TRIP P RIH T/ 740' RIH T/ 741', PUW=50, SOW=50K. Set down 5K @ 740' bull nose depth. 115.0 740.0 10/19/2024 17:45 10/19/2024 20:45 3.00 COMPZN, RPCOMP MILL P P/U T/ 734' . PUW = 50K. SOW = 50K. K/U. Obtain parameters, pump @ 7 BPM, 112 PSI. Rot @ 60 RPM, 1.2K Free Tq. ROT=52K. Wash & ream down T/ 740'. Mill w/ 3-6K Torque, 1-2K WOB. Popped through at 760'. Ream up & down through problem area. Kill Rot. Drift through tight spot w/ pumps T/ 760'. Pushed through interval with 5- 10K SOW. 740.0 853.0 10/19/2024 20:45 10/19/2024 21:15 0.50 COMPZN, RPCOMP TRIP P Unscrew and blowdown Top Drive. TIH F/ 854' T/ 1610', PUW = 6K, SOW = 56K. Clean drift. 853.0 1,610.0 10/19/2024 21:15 10/19/2024 21:45 0.50 COMPZN, RPCOMP CIRC P Pump hi-vis pill. Circ out. 1,610.0 1,610.0 10/19/2024 21:45 10/19/2024 22:00 0.25 COMPZN, RPCOMP OWFF P OWFF. B/D Top Drive. 1,610.0 1,610.0 10/19/2024 22:00 10/19/2024 22:45 0.75 COMPZN, RPCOMP TRIP P TOOH w/ BHA #15 (stacked 8 3/8" string mills). See 10K overpull @ 750' and 8K overpull @ 745' coming up through tight spot. 1,610.0 115.0 10/19/2024 22:45 10/19/2024 23:30 0.75 COMPZN, RPCOMP BHAH P L/D BHA #15. Found upper 8 3/8" string mill was worn down to 8 1/8" OD. Reconfigure BHA #16 to include a 8 1/2" OD mill. 115.0 0.0 10/19/2024 23:30 10/20/2024 00:00 0.50 COMPZN, RPCOMP BHAH P MU BHA #16 (8 1/2" string mill + 10 spacer + 8 3/8" string mill). Dummy drift for Casing Patch + ES Cementer. 0.0 121.0 10/20/2024 00:00 10/20/2024 00:30 0.50 COMPZN, RPCOMP BHAH P Cont. MU BHA #16 (8 1/2" string mill + 10 spacer + 8 3/8" string mill). Dummy drift for Casing Patch + ES Cementer. 0.0 121.0 10/20/2024 00:30 10/20/2024 01:00 0.50 COMPZN, RPCOMP TRIP P TIH to tight spot @ 740'. Set down xK. PUW = 50K SOW = 50K. Dry drift through tight spot. No pumps. No rotary. See 10-12K SOW @ 744' and 753'. PUH to 736'. 121.0 736.0 10/20/2024 01:00 10/20/2024 02:00 1.00 COMPZN, RPCOMP MILL P K/U. Obtain parameters, pump @ 3 BPM, 90 PSI. Rot @ 60 RPM, 1.5K Free Tq. Wash & ream down F/ 736 to T/ 760'. Mill w/ 3-5K Torque. Cleaned up below 760'. Ream up & down through problem area. Dry drift through tight spot T/ 760'. Highest SOW was 10K bobble @ 743'. 736.0 760.0 10/20/2024 02:00 10/20/2024 02:30 0.50 COMPZN, RPCOMP TRIP P Cont. TIH to 7" stub @ 1,614'. 760.0 1,610.0 10/20/2024 02:30 10/20/2024 03:00 0.50 COMPZN, RPCOMP CIRC P Kelly up. Pump hi-vis pill. Circ out w/ vis up SW. 1,610.0 1,610.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 10/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/20/2024 03:00 10/20/2024 03:15 0.25 COMPZN, RPCOMP OWFF P Unscrew TD. Blow down. OWFF. 1,610.0 1,610.0 10/20/2024 03:15 10/20/2024 04:00 0.75 COMPZN, RPCOMP TRIP P TOOH w/ BHA #16. 1,610.0 121.0 10/20/2024 04:00 10/20/2024 04:45 0.75 COMPZN, RPCOMP BHAH P L/D BHA #16 (8 1/2" string mill + 10' pup + 8 3/8" string mill). 121.0 0.0 10/20/2024 04:45 10/20/2024 05:30 0.75 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe sheet. 0.0 0.0 10/20/2024 05:30 10/20/2024 05:45 0.25 COMPZN, RPCOMP BHAH P MU BHA #17 (7" dress off shoe). 0.0 111.0 10/20/2024 05:45 10/20/2024 07:00 1.25 COMPZN, RPCOMP TRIP P TIH w/ dress off shoe to 1598'. PUW = 63K. SOW = 60K. Push through problem area F/ 740' - 758' w/ 3-5K string weight. 111.0 1,597.0 10/20/2024 07:00 10/20/2024 08:00 1.00 COMPZN, RPCOMP MILL P Obtain parameters. 2 BPM @ 55 PSIi. Rot @ = 30 RPM. Free Torque = 1.1K ROT=63K. Run in w/ pumps only. Locate top of 7" w/ 3K down @ 1614'. P/U Rot over CSG stub, saw PSI increase T/ 63 PSI as swallowed stump. Fully located @ 1618' PSI increase T/ 80 PSI. Rot up off stump and back over, same indicators. P/U off stump, kill rotary. Swallow stump w/ pumps only same pressure signature. Pump up off TBG stub T/ 1613' 1,597.0 1,613.0 10/20/2024 08:00 10/20/2024 08:45 0.75 COMPZN, RPCOMP CIRC P Circ 20 Bbls hi-vis pill around @ 9 BPM, 270 PSI. 1,613.0 1,613.0 10/20/2024 08:45 10/20/2024 09:00 0.25 COMPZN, RPCOMP OWFF P P/U T/ 1594'. B/D TD. OWFF 1,613.0 1,594.0 10/20/2024 09:00 10/20/2024 09:30 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1594' T/ 111', PUW=63K. 1,594.0 111.0 10/20/2024 09:30 10/20/2024 10:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA #17. Inspect dress of shoe. Good wear pattern on top sub. 111.0 0.0 10/20/2024 10:30 10/20/2024 10:45 0.25 COMPZN, RPCOMP RURD P Pull wear bushing. 0.0 0.0 10/20/2024 10:45 10/20/2024 11:15 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. 0.0 0.0 10/20/2024 11:15 10/20/2024 11:45 0.50 COMPZN, RPCOMP RURD P R/U GBR torque turn equipment. Verify joint count and jewelry running order. 0.0 0.0 10/20/2024 11:45 10/20/2024 12:00 0.25 COMPZN, RPCOMP SFTY P PJSM w/ GBR, Yellow Jacket & rig crew on running 7" Hyd 563 tie back string. 0.0 0.0 10/20/2024 12:00 10/20/2024 15:15 3.25 COMPZN, RPCOMP PUTB P RIH w/ 7", 26#, L-80, Hyd 563, tie back CSG T/ 1581', PUW=73K, SOW=58K. K/U wash CSG patch down @ 2 BPM, 60 PSI. @ 1614' PSI increase T/ 77. Fully locate w/ 25K down @ 1617'. P/U 50K over string. Slack off T/ neutral weight. 0.0 1,617.0 10/20/2024 15:15 10/20/2024 15:45 0.50 COMPZN, RPCOMP RURD P Break out T/D. B/D TD. R/U circ hose & testing equipment. 1,617.0 1,617.0 10/20/2024 15:45 10/20/2024 16:15 0.50 COMPZN, RPCOMP PRTS P PT 7" CSG patch T/ 2000 PSI for 15 Min. 1,617.0 1,617.0 10/20/2024 16:15 10/20/2024 18:15 2.00 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. Suck out stack. Crew C/O. 1,617.0 1,617.0 10/20/2024 18:15 10/20/2024 20:00 1.75 COMPZN, RPCOMP NUND P Latch up to 7" string. ND BOP. Pull 93K (20K over string weight). Set slips in tension. NU BOP. PT flange breaks through ported DSA to 3,000 psi. 1,617.0 1,617.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 11/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/20/2024 20:00 10/20/2024 21:30 1.50 COMPZN, RPCOMP RURD P RU HES cementers. RU cement head. Load returns tanks and pill pit with rinsate. Ensure all vac trucks are spotted and ready. Setup OA hardline configuration for sampling and OA squeeze if needed.Blowdown lines to cuttings and open top to confirm clear. 1,617.0 1,617.0 10/20/2024 21:30 10/20/2024 23:15 1.75 COMPZN, RPCOMP CIRC P PJSM. Pressure up and shear ES Cementer open. At approx 300 psi thread at HES BTC XO leaked. SD. Bleed off. Tighten up XO. Pressure up to 2,400 psi and shear open ES Cementer. Circulate 145 BBLs of hot Fresh Water @ 3 BPM and 193 psi. SD Pumps. Swap over to cementers. 1,617.0 1,617.0 10/20/2024 23:15 10/21/2024 00:00 0.75 COMPZN, RPCOMP CMNT P Pump 5 BBL fresh water to flood lines. PT cementer line to 4,000 psi. Batch up 1st tub of cement. Cement wet @ 23:31. Pump cement job as per pump schedule. 1,617.0 1,617.0 10/21/2024 00:00 10/21/2024 01:00 1.00 COMPZN, RPCOMP CMNT P Pump cement job as per pump schedule. 10 BBLS 80 deg fresh water Spacer w/ red dye. 120 BBLS of 11# ArcticCEM Lead Cement w/ 5PPB LCM. Mix 1st tub of tail cement. Cement wet @ 00:10. 52 BBLS of 15.3# Tail Cement. See red dye in returns @ 107 bbls into lead cement. See cement at 130 bbls total cement pumped. Measured 11# cement at OA. Shutdown. Drop Closing Plug. Pump 10 BBLS 80 Fresh Water behind. Swap to rig pumps to finish displacement. Pump approx. 52 BBLS 8.6# vis SW to bump closing plug. At approx. 42 BBLS away slow pump rate to 2 BPM to bump. Held 100 psi back pressure at OA valve on last 20 bbls to squeeze cement into OA leak. Bump plug. Hold 1,800 psi as per HES cementer. Initial circ pressure on lead = 375 psi. Final circ press before bump = 1658 psi. Bleed off to ensure cementer is closed and holding. Est. 95 BBLS of cement returns to cuttings tank. Cement in place @ 01:00. Tail cement Compressive Strength = 100 psi in approx. 10hrs and 14 min. 1,617.0 1,617.0 10/21/2024 01:00 10/21/2024 03:00 2.00 COMPZN, RPCOMP RURD P RD Cement head. Open LPR. Close Annular. Flush stack and hardline out to tanks through all dead legs. Pump out of pill pit through kill line to rinse stack. Clean out and blow down all cement lines and dead legs. Wash Up and RD cementing equipment. Use pressure washer to rinse cement returns off cuttings tank level sensor. 1,617.0 1,617.0 10/21/2024 03:00 10/21/2024 04:30 1.50 COMPZN, RPCOMP NUND P ND BOP. Clean residual cement out of wellhead. Cut 7" casing with WACH's saw. Set pack-off and reducer bushing. Install new tubing head. Test pack-off void to 3,000 psi for 10-min. NU 11" x 7 1/16" DSA. NU BOP. MU secondary IA valve w/ companion flange to IA. 1,617.0 1,617.0 10/21/2024 04:30 10/21/2024 06:00 1.50 COMPZN, RPCOMP CUTP P Cut 7" casing with WACH's saw. Set pack-off and reducer bushing. 1,617.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 12/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/21/2024 06:00 10/21/2024 09:00 3.00 COMPZN, RPCOMP NUND P N/U new Gen 4 TBG head. 7 1/6" 5K Top x 11" 3K BTM. Install secondary IA valve. Install test plug. 0.0 0.0 10/21/2024 09:00 10/21/2024 09:30 0.50 COMPZN, RPCOMP PRTS P Test pack-off T/ 3,000 psi for 10-min. 0.0 0.0 10/21/2024 09:30 10/21/2024 14:00 4.50 COMPZN, RPCOMP NUND P N/U, secondary IA valve. N/U 11" x 7 1/16" DSA. NU BOP. Open LPR clean out cavity. Install 2 7/8" x 5 1/2" VBR's. Install flow nipple. R/U trip hose. Process DP. 0.0 0.0 10/21/2024 14:00 10/21/2024 15:00 1.00 COMPZN, RPCOMP RURD P P/U test joint. R/U testing equipment. Fill stack w/ fresh water. 0.0 0.0 10/21/2024 15:00 10/21/2024 15:30 0.50 COMPZN, RPCOMP PRTS P PT stack breaks & LVBR's 250/3000 PSI. Perfom weekly function test on BOPE. 0.0 0.0 10/21/2024 15:30 10/21/2024 16:00 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. Suck out stack. 0.0 0.0 10/21/2024 16:00 10/21/2024 16:30 0.50 COMPZN, RPCOMP MPSP P Pull test plug. Install wear bushing. 0.0 0.0 10/21/2024 16:30 10/21/2024 18:30 2.00 COMPZN, RPCOMP RURD P C/O handling equipment for DP. Mobilize BHA #18 tools to RF. 0.0 0.0 10/21/2024 18:30 10/21/2024 19:45 1.25 COMPZN, RPCOMP BHAH P M/U BHA #18 drill out assy T/ 318', SOW=46K. 0.0 318.0 10/21/2024 19:45 10/21/2024 21:00 1.25 COMPZN, RPCOMP PULD P PUDP F/ 318' T/ 1522', PUW=63K, SOW=60K 318.0 1,522.0 10/21/2024 21:00 10/21/2024 22:00 1.00 COMPZN, RPCOMP WASH P Wash in hole #@ 3 BPM, 110 PSI. F/ 1522' T/ 1583'. Tagged cement. 1,522.0 1,583.0 10/21/2024 22:00 10/21/2024 23:30 1.50 COMPZN, RPCOMP DRLG P P/U obtain parameters. Pump @ 3 BPM, 140 PSI, Rot @ 60-90 RPM, Free Tq =1.2-1.7K. ROT=62K. Drill cement & plug w/ 2-5K Tq. #-15K WOB T/ 1,601'. Milled through cement and ES cementer. 1,583.0 1,601.0 10/21/2024 23:30 10/22/2024 00:00 0.50 COMPZN, RPCOMP CIRC P Pump hi-vis pill. Circ out. 1,601.0 1,601.0 10/22/2024 00:00 10/22/2024 00:45 0.75 COMPZN, RPCOMP WASH P Attempt to dry drift to top of sand. Unable. Washed and reamed from 1,601' to 1,675'. SD Pumps. Dry drifted to top of sand @ 1,684'. Set 10K down. 1,601.0 1,684.0 10/22/2024 00:45 10/22/2024 01:15 0.50 COMPZN, RPCOMP CIRC P PUH to 1,644'. Pump 30 bbl hi-vis pill. Circ out w/ SW @ 8 BPM and 413 psi. SD Pumps. 1,684.0 1,644.0 10/22/2024 01:15 10/22/2024 02:00 0.75 COMPZN, RPCOMP TRIP P TOOH w/ BHA #18 (cement mill out). 1,644.0 318.0 10/22/2024 02:00 10/22/2024 02:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #18 (pirahna cement mill). Minimal wear. Mill in good shape. 318.0 0.0 10/22/2024 02:30 10/22/2024 03:00 0.50 COMPZN, RPCOMP BHAH P MU BHA #19 (magnet). 0.0 39.0 10/22/2024 03:00 10/22/2024 04:15 1.25 COMPZN, RPCOMP PULD P TIH w/ BHA #19 picking up DP. 39.0 1,684.0 10/22/2024 04:15 10/22/2024 04:30 0.25 COMPZN, RPCOMP FISH P Work magnet at top of sand to attempt to fish cutter blade LIH (4 1/2" long x 1 3/8" wide) 1,684.0 1,684.0 10/22/2024 04:30 10/22/2024 05:30 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #19 (magnet) 1,684.0 39.0 10/22/2024 05:30 10/22/2024 06:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA #19. Recovered metal shavings and small debris. 39.0 0.0 10/22/2024 06:30 10/22/2024 07:45 1.25 COMPZN, RPCOMP BHAH P Crew C/O. Load and MU BHA #19 (RCJB). 0.0 138.0 10/22/2024 07:45 10/22/2024 09:15 1.50 COMPZN, RPCOMP PULD P TIH picking up DP to 1,684' (Top of Sand). 138.0 1,684.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 13/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/22/2024 09:15 10/22/2024 10:00 0.75 COMPZN, RPCOMP WASH P Obtain Parameters. PUW = 60K. SOW = 58K. Rotary = 50 RPM. Free Torque = 1.2K Ft-lbs. Pump Rate = 3.5 BPM @ 2000 psi. Wash down from top of sand at 1,684' to 1,694'. Set 10K down and let weight wash off. Take 10' bite. 1,684.0 1,694.0 10/22/2024 10:00 10/22/2024 12:00 2.00 COMPZN, RPCOMP SLPC P PUH to 1,621'. Slip and Cut Drill Line 1,694.0 1,621.0 10/22/2024 12:00 10/22/2024 12:45 0.75 COMPZN, RPCOMP TRIP P TOOH w/ BHA #20 (RCJB #1). 1,621.0 138.0 10/22/2024 12:45 10/22/2024 13:45 1.00 COMPZN, RPCOMP BHAH P L/D BHA #20. Inspect RCJB for debris. Recovered chunks of 7" casing,7" center guide centralizers, small brass pieces, and small pieces of cementer. 138.0 0.0 10/22/2024 13:45 10/22/2024 15:00 1.25 COMPZN, RPCOMP BHAH P MU BHA #21 (RCJB #2). Suck out vis'd up SW from Pit #3. Load 9.8# Brine into Pit #3. 0.0 138.0 10/22/2024 15:00 10/22/2024 16:30 1.50 COMPZN, RPCOMP PULD P TIH w/ BHA #21 picking up DP to top of sand @ 1,694'. 138.0 1,694.0 10/22/2024 16:30 10/22/2024 17:30 1.00 COMPZN, RPCOMP WASH P Obtain paramters. Wash down from top of sand at 1,694' to 1,702'. Take 6' bite to conserve sand plug. 1,694.0 1,702.0 10/22/2024 17:30 10/22/2024 18:30 1.00 COMPZN, RPCOMP CIRC P Pump hi-vis pill. Circ out. 1,700.0 1,700.0 10/22/2024 18:30 10/22/2024 19:30 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #21 (RCJB #2). 1,700.0 138.0 10/22/2024 19:30 10/22/2024 20:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA #21. Recovered cutter and misc junk from hole clean out baskets 138.0 1,702.0 10/22/2024 20:30 10/22/2024 22:00 1.50 COMPZN, RPCOMP PULD P TIH w/ BHA #22 picking up DP to top of sand @ 1,709'. 138.0 1,709.0 10/22/2024 22:00 10/22/2024 22:30 0.50 COMPZN, RPCOMP WASH P Obtain paramters. Wash down from top of sand at 1,702' to 1722'. Take 12' bite no obstructions // pump 7 bbls per min @ 1900 psi // 1,709.0 1,722.0 10/22/2024 22:30 10/22/2024 23:30 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #21 (RCJB #3). 1,722.0 138.0 10/22/2024 23:30 10/23/2024 00:00 0.50 COMPZN, RPCOMP BHAH P inspect BHA 1 small piece of metal, clean out boot baskets 138.0 138.0 10/23/2024 00:00 10/23/2024 01:30 1.50 COMPZN, RPCOMP PULD P TIH w/ BHA #23 picking up DP to top of sand @ 1,722'. 138.0 1,722.0 10/23/2024 01:30 10/23/2024 02:00 0.50 COMPZN, RPCOMP WASH P Obtain paramters. Wash down from top of sand at 1,722' to 1,733'. Take 6' bite to conserve sand plug. 1,722.0 1,733.0 10/23/2024 02:00 10/23/2024 02:30 0.50 COMPZN, RPCOMP CIRC P Pump sweep S to S 1,730.0 1,730.0 10/23/2024 02:30 10/23/2024 03:45 1.25 COMPZN, RPCOMP TRIP P TOOH w/ BHA #23 (RCJB #4). Inspect BHA no material found in basket 1,730.0 0.0 10/23/2024 03:45 10/23/2024 04:30 0.75 COMPZN, RPCOMP CLEN P Clear YJ tools from floor and clean // Bring in Baker tools 0.0 0.0 10/23/2024 04:30 10/23/2024 04:45 0.25 COMPZN, RPCOMP BHAH P Make up BHA# 24 (IBP retrieval BHA) 0.0 15.0 10/23/2024 04:45 10/23/2024 05:15 0.50 COMPZN, RPCOMP TRIP P TIH w/ IBP retrieval tool to 1,735'. 15.0 1,735.0 10/23/2024 05:15 10/23/2024 05:45 0.50 COMPZN, RPCOMP CIRC P Circ well over to 9.8# KW Brine. 1,735.0 1,735.0 10/23/2024 05:45 10/23/2024 06:45 1.00 COMPZN, RPCOMP FISH P TIH to top of IBP @ 1,743'. Latch IBP and equalize. Release IBP and allow element to relax for 30-min. 1,735.0 1,743.0 10/23/2024 06:45 10/23/2024 07:30 0.75 COMPZN, RPCOMP TRIP P TOOH w/ IBP. 1,743.0 15.0 10/23/2024 07:30 10/23/2024 07:45 0.25 COMPZN, RPCOMP BHAH P L/D IBP retrieval tool and IBP. IBP in good condition. 15.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 14/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/23/2024 07:45 10/23/2024 08:45 1.00 COMPZN, RPCOMP PRTS P RU testing equipment. Close blinds. PT 7" casing against deep plug/packer to 2,500 psi for 30-min. Chart. Pass 0.0 0.0 10/23/2024 08:45 10/23/2024 10:15 1.50 COMPZN, RPCOMP BHAH P MU BHA #25 (3 1/2" Spear) 0.0 304.0 10/23/2024 10:15 10/23/2024 10:45 0.50 COMPZN, RPCOMP TRIP P TIH on DP Stands to 1,702'. PUW = 70K. SOW = 61K. 304.0 1,767.0 10/23/2024 10:45 10/23/2024 11:15 0.50 COMPZN, RPCOMP FISH P Obtain parameters. 0.5 BPM at 100 psi. TIH and spear 3 1/2" Tubing Stub @ 1,767'. See press. indicator when speared. SD pumps. PU to confirm latched. PU 160K to get pipe moving. Drag connection to rig floor @ 125K (55K over). 1,767.0 9,984.0 10/23/2024 11:15 10/23/2024 11:45 0.50 COMPZN, RPCOMP OWFF P OWFF. Rack back stand of DP. Blowdown Top Drive. 9,984.0 9,984.0 10/23/2024 11:45 10/23/2024 13:15 1.50 COMPZN, RPCOMP TRIP P TOOH standing back DP. 9,984.0 8,217.0 10/23/2024 13:15 10/23/2024 14:30 1.25 COMPZN, RPCOMP BHAH P L/D BHA #25 (Spear) and jet cut joint (Length = 10.45'). RU pipe handling equipment for 3 1/2" Tubing. 8,217.0 8,217.0 10/23/2024 14:30 10/23/2024 14:45 0.25 COMPZN, RPCOMP OWFF P OWFF 8,217.0 8,217.0 10/23/2024 14:45 10/23/2024 15:15 0.50 COMPZN, RPCOMP RURD P Offload vis'd Seawater from pits. Load 9.8# Brine. L/D SSSV and control line. 8,217.0 8,197.0 10/23/2024 15:15 10/23/2024 23:00 7.75 COMPZN, RPCOMP PULD P TOOH L/D 3 1/2" completions F/ 8,197', Cut Jt 12.34' 8,197.0 0.0 10/23/2024 23:00 10/24/2024 00:00 1.00 COMPZN, RPCOMP CLEN P Clean and clear rig floor // Swap out tubing equipement for drill pipe equipment // Bring in BHA componants 0.0 0.0 10/24/2024 00:00 10/24/2024 01:30 1.50 COMPZN, RPCOMP BHAH P Pick up BHA# 25 drift/clean out assembly 0.0 332.4 10/24/2024 01:30 10/24/2024 05:30 4.00 COMPZN, RPCOMP TRIP P TIH stands out of derrick T/ 9,853'. Saw 10K set down and torque @ 9,832'. PU. Drifted through on elevators. Clean. 332.4 9,853.0 10/24/2024 05:30 10/24/2024 06:00 0.50 COMPZN, RPCOMP REAM P Kelly up. Obtain parameters. PUW = 163K, SOW = 88K. Pump Rate = 6 BPM @ 2400 psi. Rotary = 30 RPM. Reaming Torque = 5-6K. Clean up new packer set depth from 9850'-9950' w/ 6 1/8" string mill. 9,853.0 9,950.0 10/24/2024 06:00 10/24/2024 07:00 1.00 COMPZN, RPCOMP MILL P Cont TIH to tubing stub @ 9,968'. See pressure indicator 20' early. Press up to 2500 psi. Cont. TIH. No-go on dress off inner mill. Press up to 2,800 psi. Est top of stub @ 9,961'. Swallowed stub 7'. Confirmed stub found 20' shallow. Set 5K down. 8.5' stick up on Joint #312. PUH. Obtain parameters.PUW = 163K. SOW = 88K. TIH and dress off stub. 6 BPM @ 2,950. 30 RPM. Free Torque = 5.9-6.2K. Milling Torque = 6.5- 7.5K. Lightly dressed stub @ 9,961'. 9,950.0 9,968.0 10/24/2024 07:00 10/24/2024 08:15 1.25 COMPZN, RPCOMP CIRC P Pump 30 bbl hi-vis pill while over stub. After pill circ'd thru BHA, PUH off stub. Circ out pill. 9,968.0 9,942.0 10/24/2024 08:15 10/24/2024 08:45 0.50 COMPZN, RPCOMP OWFF P OWFF. 9,942.0 9,942.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 15/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/24/2024 08:45 10/24/2024 11:00 2.25 COMPZN, RPCOMP PRTS P RU PT equipment. Close UPR. PT 7" casing to 2,500 psi for 30-min. Chart. Monitor OA during test. See thermal rise on test chart. Re-test. Purge air. Double block at rig floor. Close UPR and LPR. Initial = 2700 psi. 15-min = 2660 psi. 30-min = 2640 psi. 45-min = 2630 psi. Stabilizing. Pass. 9,942.0 9,942.0 10/24/2024 11:00 10/24/2024 11:30 0.50 COMPZN, RPCOMP RURD P RD PT equipment. 9,942.0 9,942.0 10/24/2024 11:30 10/24/2024 20:30 9.00 COMPZN, RPCOMP PULD P TOOH L/D DP from 9,956' to 332'. 9,942.0 332.4 10/24/2024 20:30 10/24/2024 21:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA #25 (drift + dress off shoe) 332.4 0.0 10/24/2024 21:30 10/24/2024 22:30 1.00 COMPZN, RPCOMP CLEN P Clear rig floor of fishing tools, clean rig floor 0.0 0.0 10/24/2024 22:30 10/24/2024 23:00 0.50 COMPZN, RPCOMP OTHR P Pull wear ring, packed with sand 0.0 0.0 10/24/2024 23:00 10/24/2024 23:30 0.50 COMPZN, RPCOMP OTHR P Flush stack clean hanger profile 0.0 0.0 10/24/2024 23:30 10/25/2024 00:00 0.50 COMPZN, RPCOMP RURD P RU pipe handling equipment for 3 1/2" EUE Tubing. Verify 3 1/2" completions jewelry, joint count, and run order. 0.0 0.0 10/25/2024 00:00 10/25/2024 16:00 16.00 COMPZN, RPCOMP PUTB P Run 3 1/2" Completions as per Tally T/ 4,557'. Perform derrick inspection @ 7AM. Cont. run 3 1/2" Completions (@ 8:15AM) to 9,925'. 0.0 9,925.0 10/25/2024 16:00 10/25/2024 16:45 0.75 COMPZN, RPCOMP WASH P On Joint #313, Kelly up. Obtain parameters. PUW = 98K. SOW = 69K. Pump Rate = 2 BPM @ 145 psi. Wash down as precaution. MU Joint #314. Slowly TIH and wash down over Tubing Stub @ 9,970.5' N3 RKB. See pressure indicator. See shear screws @ 9,973.3' (Shear @ 10K). Cont TIH and Fully locate @ 9,975.8'. PU. Re-land to confirm. Set 10K down. Pull to neutral. Mark pipe. 9,925.0 9,976.0 10/25/2024 16:45 10/25/2024 17:45 1.00 COMPZN, RPCOMP HOSO P L/D partial Joint #314. L/D full joint #313. Calculate space out pups required. Pup Joints = 10.16' + 8.18' = 18.34'. MU space out pups and last full joint #312. MU hanger and landing joint to last full joint. 9,976.0 9,892.0 10/25/2024 17:45 10/25/2024 19:45 2.00 COMPZN, RPCOMP CIRC P Screw in TD. Reverse circulate 270 bbls 9.8# CI down the IA, taking returns from tubing to pits. SD pumps. RD circ equipment. Blowdown. Drain Stack. 9,892.0 9,892.0 10/25/2024 19:45 10/25/2024 20:15 0.50 COMPZN, RPCOMP THGR P Land Tubing Hanger. RILDS. Drop Ball and Rod. 9,892.0 9,892.0 10/25/2024 20:15 10/25/2024 21:00 0.75 COMPZN, RPCOMP RURD P MU pressure testing equipment. Tubing and IA sensators, green isolation valves and hoses. Double block at well for PT. 9,892.0 9,892.0 10/25/2024 21:00 10/25/2024 22:30 1.50 COMPZN, RPCOMP PRTS P PT surface lines to 4,000 psi. Open to the well. Pressure up and set SLB Packer per packer hand. Hold 3,500 psi for 30-min (MIT-T). Charted. Initial 3980 psi. 15-min = 3860 psi. 30-min = 3820 psi. Stabilizing trend. Bleed Tubing pressure to 1,500 psi. PT IA to 2,500 psi for 30-min. Charted. Dump tubing pressure to shear SOV. Confirm flow path. Pump 10 bbls through SOV. 0.0 0.0 10/25/2024 22:30 10/25/2024 23:30 1.00 COMPZN, RPCOMP MPSP P L/D landing joint. Set BPV. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Page 16/16 2K-19 Report Printed: 11/19/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/25/2024 23:30 10/26/2024 00:00 0.50 COMPZN, RPCOMP PRTS P PT BPV to 1,000 psi from below for 10- min. Chart. 0.0 0.0 10/26/2024 00:00 10/26/2024 01:30 1.50 COMPZN, WHDBOP NUND P Nipple down BOPs 0.0 0.0 10/26/2024 01:30 10/26/2024 04:00 2.50 COMPZN, WHDBOP NUND P Nipple up production tree, test voids 3000 psi good test , test tree 5000psi with test pump and LEPD 0.0 0.0 10/26/2024 04:00 10/26/2024 04:30 0.50 COMPZN, WHDBOP MPSP P Pull BPV. 0.0 0.0 10/26/2024 04:30 10/26/2024 08:00 3.50 COMPZN, WHDBOP FRZP P RU LRS. PT Lines. Pump 71 BBLS Diesel freeze protect down IA, taking tubing returns out to open top. 2 BPM @ 1000 psi. RD LRS. U-Tube for 1 hour. 0.0 0.0 10/26/2024 08:00 10/26/2024 09:00 1.00 DEMOB, MOVE RURD P R/D circ. hoses and hardline. Clean and clear cellar. Gather Final Pressures (T/I/O) = 250 psi / 250 psi / 0 psi. Release rig from 2K-19 @ 09:00. Disconnect rig highline @ 09:30. RDMO to 2P. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/26/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 2K-19A lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Installed GLD, Pulled B&R/RHC, Pulled catcher & RBP 2K-19A 11/2/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered well IA x OA communication with gas liift allowed. 6/4/2019 jbyrne NOTE: WELL SIDETRACKED TO A & AL1 (AL1 off main wellbore) 5/16/2011 osborl NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 4/17/2011 lmosbor 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 35.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 34.7 3,789.0 2,912.3 36.00 J-55 BTC Tie-Back String 7 6.28 33.0 1,617.0 1,572.4 26.00 L-80 HYD 563 WINDOW AL1 3 1/2 2.99 10,175.0 10,180.0 6,280.8 9.30 LINER A 2 3/8 1.99 11,054.1 12,614.0 6,278.7 4.60 L-80 STL Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth 9,988.6 String Max No 3 1/2 Set Depth 6,169.0 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L80 Top Connection EUE-M 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) 31.1 31.1 0.00 Hanger 6.980 3.5" x 7" FMC Gen 4 Tubing Hanger - 3 1/2" EUE, "H" BPV FMC Gen 4 2.920 2,993.0 2,505.9 56.51 Mandrel GAS LIFT 5.869 3.5" x 1.5" MMG GLM, SN: 24657- 11 SLB MMG 2.920 5,913.5 4,001.2 57.67 Mandrel GAS LIFT 5.936 3.5" x 1.5" MMG GLM, SN: 24758- 12 SLB MMG 2.920 7,752.3 4,981.8 58.83 Mandrel GAS LIFT 5.933 3.5" x 1.5" MMG GLM, SN: 24758- 14 SLB MMG 2.920 9,842.0 6,086.1 56.55 Mandrel GAS LIFT 5.942 3.5" x 1.5" MMG GLM, SN: 24758- 13 SLB MMG 2.920 9,902.0 6,120.0 55.42 Packer 5.993 3.5" x 7" BluePack RH Max VAM TOP B/P, SN: C24P-0244 SLB BluePac k 2.894 9,959.8 6,152.7 55.94 Nipple - X 4.502 3.5" x 2.813" X-Nipple SN: 0005011991-2 Halliburt on X 2.813 9,981.0 6,164.6 55.35 Overshot 5.790 3 1/2" x 7" Poorboy Overshot w/ 6.6' of swallow (2' space out off no-go) Baker Poorboy Oversho t 3.640 Top (ftKB) 9,984.2 Set Depth 10,084.0 String Max No 3 1/2 Set Depth 6,224.2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdABM OD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,002.7 6,177.1 54.95 PBR 5.000 BAKER 80-40 w/10' Stroke PBR w/4" SEAL BORE BAKER 80-40 3.000 10,016.4 6,184.9 55.07 PACKER 6.062 BAKER HB RETRIEVABLE PACKER BAKER HB 2.890 10,052.1 6,205.5 54.30 NIPPLE 4.540 OTIS 2.813" XN NIPPLE w/2.81" POLISHED BORE; MILLED OUT TO 2.79" 3/30/2011 OTIS XN 2.790 10,083.3 6,223.8 54.16 SOS 4.000 BAKER SHEAR OUT BAKER 3.000 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) 33.0 33.0 0.00 EMERGENCY SLIPS C-21, 11" x 7" Emergency Slips 10/21/2024 7.000 9,984.0 6,166.3 55.28 CUT WELLTEC MECHANICAL TBG CUT AT 9984' RKB 10/9/2024 2.992 10,064.0 6,212.5 54.23 LINER TOP AL1 CTD liner top (Ran 5/14/11) 5/14/2011 1.992 10,084.0 6,224.2 54.15 PILOT HIGH-SIDE PILOT HOLE MILLED IN CEMENT PLUG 4/23/2011 10,170.0 6,275.0 53.41 WHIPSTOCK WELLBORE JUNCTION - MECH WHIPSTOCK FOR LATERAL AL1 4/24/2011 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) 2,993.0 2,505.9 56.51 1 GAS LIFT GLV RK 5.99 3 1,210.0 11/2/2024 SLB MMG 0.125 5,913.5 4,001.2 57.67 2 GAS LIFT GLV RK 5.93 6 1,198.0 11/2/2024 SLB MMG 0.188 7,752.3 4,981.8 58.83 3 GAS LIFT DMY RK 5.93 3 0.0 10/25/2024 SLB MMG 0.000 9,842.0 6,086.1 56.55 4 GAS LIFT OV RK 5.94 2 0.0 11/2/2024 SLB MMG 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,601.5 1,558.8 28.74 Collar - Stage 8.255 CMTR,TYPE H ES-II, HYD 563 L- 80 Halliburto n HES II CMTR 6.125 2K-19A, 11/19/2024 11:49:34 AM Vertical schematic (actual) LINER A; 11,054.1-12,614.0 SLOTS; 11,756.0-12,614.0 SLOTS; 11,081.0-11,179.0 LINER AL1; 10,064.0-13,180.0 SLOTS; 10,216.0-11,098.0 Production; 1,614.0-10,557.0 WINDOW AL1; 10,175.0- 10,180.0 WHIPSTOCK; 10,170.0 APERF; 10,169.0-10,189.0 APERF; 10,157.0-10,159.0 PILOT; 10,084.0 CEMENT PLUG; 10,070.0 ftKB LINER TOP; 10,064.0 PACKER; 10,016.4 CUT; 9,984.0 Nipple - X; 9,959.8 Packer; 9,902.0 Mandrel GAS LIFT; 9,842.0 Mandrel GAS LIFT; 7,752.3 Mandrel GAS LIFT; 5,913.5 SURFACE; 34.7-3,789.0 Mandrel GAS LIFT; 2,993.0 Tie-Back String; 33.0-1,617.0 Remedial; 596.0 ftKB Remedial; 34.0 ftKB CONDUCTOR; 35.0-115.0 EMERGENCY SLIPS; 33.0 Hanger; 31.1 KUP PROD KB-Grd (ft) 39.99 RR Date 11/14/198 9 Other Elev 2K-19A ... TD Act Btm (ftKB) 12,614.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032011801 Wellbore Status PROD Max Angle & MD Incl (°) 96.27 MD (ftKB) 11,640.49 WELLNAME WELLBORE2K-19A Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: TRDP Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,613.1 1,569.0 29.12 Patch 8.250 7" Sealing Overshot Casing Patch, (2.97' swallow) Bowen Casing Patch 7.440 11,054.1 6,303.0 92.50 BILLET 2.625 OH Anchored Billet (2.625") Baker 1.000 11,070.2 6,302.3 91.97 DEPLOY 2.625 Shorty deployment sleeve (ran on second liner segment) Baker 1.995 11,755.3 6,301.0 94.40 DEPLOY 2.625 Shorty deployment sleeve (ran on first liner segment) Baker 1.995 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,081.0 11,179.0 6,302.0 6,299.1 A-4, 2K-19A 5/2/2011 32.0 SLOTS SLOTTED LINER 11,756.0 12,614.0 6,301.0 6,278.7 A-4, 2K-19A 5/2/2011 32.0 SLOTS SLOTTED LINER 2K-19A, 11/19/2024 11:49:35 AM Vertical schematic (actual) LINER A; 11,054.1-12,614.0 SLOTS; 11,756.0-12,614.0 SLOTS; 11,081.0-11,179.0 LINER AL1; 10,064.0-13,180.0 SLOTS; 10,216.0-11,098.0 Production; 1,614.0-10,557.0 WINDOW AL1; 10,175.0- 10,180.0 WHIPSTOCK; 10,170.0 APERF; 10,169.0-10,189.0 APERF; 10,157.0-10,159.0 PILOT; 10,084.0 CEMENT PLUG; 10,070.0 ftKB LINER TOP; 10,064.0 PACKER; 10,016.4 CUT; 9,984.0 Nipple - X; 9,959.8 Packer; 9,902.0 Mandrel GAS LIFT; 9,842.0 Mandrel GAS LIFT; 7,752.3 Mandrel GAS LIFT; 5,913.5 SURFACE; 34.7-3,789.0 Mandrel GAS LIFT; 2,993.0 Tie-Back String; 33.0-1,617.0 Remedial; 596.0 ftKB Remedial; 34.0 ftKB CONDUCTOR; 35.0-115.0 EMERGENCY SLIPS; 33.0 Hanger; 31.1 KUP PROD 2K-19A ... WELLNAME WELLBORE2K-19A Originated: Delivered to:7-Nov-24 Alaska Oil & Gas Conservation Commiss 07Nov24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 3S-03 50-103-20458-00-00 203-091 Kuparuk River WL IBC-CBL FINAL FIELD 10-Oct-24 2K-19A 50-103-20118-01-00 211-034 Kuparuk River WL Cutter FINAL FIELD 11-Oct-24 MT7-83 50-103-20891-01-00 224-102 Greater Mooses Tooth WL TTiX-USIT-CBL FINAL FIELD 19-Oct-24 1C-157 50-029-23754-00-00 223-038 Kuparuk River WL IBC-CBL FINAL FIELD 23-Oct-24 CD1-33A 50-103-20357-01-00 222-105 Colville River WL PERF FINAL FIELD 30-Oct-24 MT7-09 50-103-20837-00-00 222-011 Greater Mooses Tooth WL TTiX-Plug&Perf FINAL FIELD 1-Nov-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39755 T39756 T39757 T39758 T39759 T39760 2K-19A 50-103-20118-01-00 211-034 Kuparuk River WL Cutter FINAL FIELD 11-Oct-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.08 08:38:26 -09'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-10-15_22623_KRU_2K-19A_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22623 KRU 2K-19A 50-103-20118-01 Caliper Survey w/ Log Data (Centered and Uncentered data) 15-Oct-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 211-034 T39708 10/22/2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.22 08:40:35 -08'00' ORIGINATED TRANSMITTAL DATE: 10/21/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5112 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5112 2K-19A 50103201180100 Hoist (with logs) 9-Oct-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 211-034 T39702 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.21 15:16:20 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 10/21/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5120 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5120 2K-19A 50103201180100 Cement Bond Log 14-Oct-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 211-034 T39701 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.21 15:13:06 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 2K-19A JBR 12/13/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:4 3" demco on kill failed and was replaced. CMV 6 and 1 failed and were serviced for passing re-tests. HCR choke failed and was replaced after I left the rig. Chart sent to J Regg Test Results TEST DATA Rig Rep:Henry/RiceOperator:ConocoPhillips Alaska, Inc.Operator Rep:Newel/Barr Rig Owner/Rig No.:Nordic 3 PTD#:2110340 DATE:10/14/2024 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopAGE241016102847 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 17.5 MASP: 2294 Sundry No: 324-575 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 12 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 1 PCH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8X5 1/2"P #2 Rams 1 Blind P #3 Rams 1 7"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"F Kill Line Valves 2 3 1/8 & 3"FP Check Valve 0 NA BOP Misc 2 2 1/16"P System Pressure P3050 Pressure After Closure P1625 200 PSI Attained P22 Full Pressure Attained P123 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2050 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P16 #1 Rams P5 #2 Rams P5 #3 Rams P5 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 99 9 9999 9 9 9 9 9 9 9 7HVWFKDUWDWWDFKHG 4 FP F CMV 6 and 1 failed 3" demco on kill failed HCR choke failed Chart sent to J Regg %23(7HVW1RUGLF .58. $ 37' $2*&&,QVSERS$*( 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?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12614'6279' 6303'2294 10035' Casing Collapse Conductor Surface Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-545-1144 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Kuparuk River Field Brian Glasheen brian.glasheen@conocophillips.com RWO Engineer Subsequent Form Required: Suspension Expiration Date: J-55 TVD Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 10016'MD/6185'TVD 1798'MD/1726'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025588, ADL0025589 211-034 P.O. Box 100360, Anchorage, AK 99510 50-103-20118-01-00 ConocoPhillips Alaska, Inc Proposed Pools: 10084' MD 115' 2912' 16" 9-5/8" 80' Burst 115' 3789' 6307'7" 10/10/2024 12614'1560' 3-1/2" 6279' Baker HB Retrievable SSSV: Camco TRDP-1A Perforation Depth MD (ft): 11054' KRU 2K-19A 11081-11179' (Slots) 11756-12614' (Slots) 10522' 2-3/8" 6302-6299' 6301-6279' 3754' 10557' m n P s 2 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:02 pm, Oct 03, 2024 Digitally signed by Brian Glasheen DN: OU=RWO's, O=ConocoPhillips, CN=Brian Glasheen, E=brian.glasheen@ conocophillips.com Reason: I am the author of this document Location: Date: 2024.10.03 10:45:22-08'00' Foxit PDF Editor Version: 13.0.0 Brian Glasheen 324-575 SFD 10/4/2024 X VTL 10/10/2024 BOP test to 3000 psig Annular preventer test to 2500 psig 10-404 X DSR-10/10/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.11 10:48:41 -08'00'10/11/24 RBDMS JSB 101524 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 2, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Brian Glasheen Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 2K-19 (PTD# 211-034). Well 2K-19 was drilled and completed in November of 1989 as a gas lift producer in the A-sands. The well was ST with CTD in 2011 adding two laterals in the A sands. The well has a known surface casing leak at 642' and is a candidate for preventative subsidence repair to address the SC leak and subsidence risk. If you have any questions or require any further information, please contact me at +907-545-1144 The 3-1/2” upper completion will be pulled from a pre-rig cut above the SSSV. The 7” casing will be grown and stretched, and drift will be verified. If drift is not possible, the damaged 7” casing will be cut above SSSV, then new 7” casing will be run and the OA will be cemented to surface. Once the subsidence damage is repaired, a 3-1/2” completion including a new gas lift design, a non-sealing overshot and a stacked packer will be installed. 2K-19 Kuparuk Producer Tubing Swap with Subsidence Repair PTD: 211-034 Page 1 of 2 PPre-Rig Work 1. T-PPPOT and T-POT, IC-PPPOT and IC-POT tests 2. DMY all GLM and leave lowest GLM open for circulating 3. Tubing cut at ~1793’ RKB above the SSSV and at ~9981’ RKB above the upper packer. 4. CMIT/DDT-TxIA 5. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nordic 3 on 2K-19. 2. Record shut-in pressures on the T & IA. If pressure is observed, bleed off pressure and complete 30-minute NFT. Circulate KWF as needed. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/3,000 psi. Test annular 250/3,000 psi. Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the pre-rig cut. 6. Attempt to drift 7” casing with mill prior to attempting to pull tubing section with SSSV. a. If drift is achieved, RIH and engage tubing stub and pull remaining tubing down to pre- rig cut above packer. b. If drift is not achieved, proceed with 7” Casing Subsidence Repair section. 7” Casing Subsidence Repair 7. Set storm packer or plug above SSSV. PT to confirm plug is set. Dump sand on top of plug. 8. ND BOPE. ND old tubing head. Grow casing as needed. Pull casing in tension and land in slips. NU BOPE to casing head. a. Test break as soon as practical once test plug can be installed. b. Attempt to drift 7” casing with mill after grow/stretch. If enough drift is obtained to pull SSSV, RIH and engage tubing stub and pull remaining tubing down to lower pre-rig cut. 9. RU E-Line and log 7” casing from tubing stub to surface to verify free pipe. a. Estimated top of cement is 2020’ RKB. 10. RIH and cut 7” casing. Circulate out Arctic Pack diesel/slurry. 11. Pull 7” casing from cut. a. Make additional cuts in 7” casing to remove in sections if necessary. 12. RIH with mills to ensure drift for overshot casing patch and ES cementer. a. Bore out 9-5/8” casing to create drift as necessary. 13. MU and RIH with overshot casing patch, ES cementer, and new 7” casing. Engage overshot and PT casing to 2500 psi. 14. Cement 7” x 9-5/8” annulus to surface. 15. ND BOPE, set casing slips, cut excess 7” casing and install packoffs. NU new tubing head and BOPE. Test breaks to 250/3000 psi. 16. RIH and mill up cement and plugs in cementer. Perform additional cleanout runs if necessary. 2K-19 Kuparuk Producer Tubing Swap with Subsidence Repair PTD: 211-034 Page 2 of 2 17. RIH and wash sand from top of RBP. Retrieve RBP. 18. Pull remaining completion. Install 3-1/2” Completion with Stacked Packer 19. RIH to tubing stub and dress off stub as needed. Perform casing cleanout runs as needed. 20. MU new 3-1/2” completion with non-sealing overshot, packer, nipple profile, and GLMs. RIH to tubing stub. 21. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 22. Land tubing hanger, RILDS, PT packoffs and set packer. 23. Pressure test tubing to 3,000 PSI. 24. Pressure test IA to 2,500 PSI. ND BOP, NU Tree 25. Shear out SOV with pressure differential. 26. Install BPV and test. ND BOPE. NU tree. 27. Pull BPV and freeze protect well. 28. RDMO. PPost-Rig Work 1. Run GLD. 2. Pull any plugs and ball/rod used for setting packer. General Well Information: Estimated Start Date: 10/10/24 Current Operations: Shut-In, secured with plug below packer Well Type: Producer Wellhead Type: FMC Gen IV, 11” 3M casing head top flange. 7-1/16” 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Static BHP: 2915 psi / 6210 TVD measured on 06/25/20 MPSP: 2294 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut above the SSSV, run a CBL, cut and pull 7” casing, replace casing with overshot casing patch and cement up OA. Install a new 3-1/2” completion and stacked packer. Personnel: Workover Engineer: Brian Glasheen (907-545-1144 / Brian.Glasheen@conocophillips.com) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:2K-19A lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set RBP and Catcher 2K-19A 5/28/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered well IA x OA communication with gas liift allowed. 6/4/2019 jbyrne NOTE: WELL SIDETRACKED TO A & AL1 (AL1 off main wellbore) 5/16/2011 osborl NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 4/17/2011 lmosbor General Notes: Last 3 entries Com Date Last Mod By WAIVERED WELL: IA x OA COMMUNICATION 10/24/2004 Admin 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 35.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 34.7 3,789.0 2,912.3 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 10,557.0 6,307.1 26.00 J-55 BTC WINDOW AL1 3 1/2 2.99 10,175.0 10,180.0 6,280.8 9.30 LINER A 2 3/8 1.99 11,054.1 12,614.0 6,278.7 4.60 L-80 STL Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.1 Set Depth … 10,084.0 Set Depth … 6,224.2 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdABMO D 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) 31.1 31.1 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 1,798.0 1,726.1 32.61 SAFETY VLV 5.937 CAMCO TRDP-1A SSSV CAMCO TRDP- 1A 2.812 2,674.9 2,329.4 56.08 GAS LIFT 5.620 MERLA TMPD MERLA TMPD 2.875 5,529.6 3,800.4 59.10 GAS LIFT 5.620 MERLA TMPD MERLA TMPD 2.875 7,061.6 4,615.1 57.95 GAS LIFT 5.620 MERLA TMPD MERLA TMPD 2.875 7,833.2 5,023.6 58.58 GAS LIFT 5.620 MERLA TMPD MERLA TMPD 2.875 8,576.8 5,412.8 58.65 GAS LIFT 5.620 MERLA TMPD MERLA TMPD 2.875 9,298.5 5,789.3 58.55 GAS LIFT 5.750 CAMCO MMG-2 CAMCO MMG-2 2.920 9,959.4 6,152.5 55.91 GAS LIFT 5.750 CAMCO MMG-2 CAMCO MMG-2 2.920 10,002.7 6,177.1 54.95 PBR 5.000 BAKER 80-40 w/10' Stroke PBR w/4" SEAL BORE BAKER 80-40 3.000 10,016.4 6,184.9 55.07 PACKER 6.062 BAKER HB RETRIEVABLE PACKER BAKER HB 2.890 10,052.0 6,205.5 54.30 NIPPLE 4.540 OTIS 2.813" XN NIPPLE w/2.81" POLISHED BORE; MILLED OUT TO 2.79" 3/30/2011 OTIS XN 2.790 10,083.2 6,223.8 54.16 SOS 4.000 BAKER SHEAR OUT BAKER 3.000 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) 10,030.2 6,192.8 54.74 CATCHER Set 2.79" Catcher w/ 3.5" TTS stinger (OAL = 64") on top of RBP. 5/28/2023 0.000 10,035.6 6,195.9 54.56 RBP Set 2.73" RBP (OAL = 5.18') @ 10,038' mid element 5/28/2023 0.000 10,064.0 6,212.5 54.23 LINER TOP AL1 CTD liner top (Ran 5/14/11) 5/14/2011 1.992 10,084.0 6,224.2 54.15 PILOT HIGH-SIDE PILOT HOLE MILLED IN CEMENT PLUG 4/23/2011 10,170.0 6,275.0 53.41 WHIPSTOCK WELLBORE JUNCTION - MECH WHIPSTOCK FOR LATERAL AL1 4/24/2011 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) 2,674.9 2,329.4 56.08 1 GAS LIFT GLV BK 1 1,305.0 6/26/2020 0.156 5,529.6 3,800.4 59.10 2 GAS LIFT GLV BK 1 1,340.0 6/26/2020 0.188 7,061.6 4,615.1 57.95 3 GAS LIFT GLV BK 1 1,330.0 6/25/2020 0.188 7,833.2 5,023.6 58.58 4 GAS LIFT DMY BK 1 0.0 6/28/2015 0.000 8,576.8 5,412.8 58.65 5 GAS LIFT OV BK 1 0.0 10/13/2022 0.250 9,298.5 5,789.3 58.55 6 GAS LIFT DMY RK 1 1/2 0.0 6/25/2015 0.000 9,959.4 6,152.5 55.91 7 GAS LIFT DMY RK 1 1/2 0.0 6/25/2020 HI SEAL PKG 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,054.1 6,303.0 92.50 BILLET 2.625 OH Anchored Billet (2.625") Baker 1.000 11,070.2 6,302.3 91.97 DEPLOY 2.625 Shorty deployment sleeve (ran on second liner segment) Baker 1.995 11,755.3 6,301.0 94.40 DEPLOY 2.625 Shorty deployment sleeve (ran on first liner segment) Baker 1.995 2K-19A, 5/29/2023 6:08:29 AM Vertical schematic (actual) LINER A; 11,054.1-12,614.0 SLOTS; 11,756.0-12,614.0 SLOTS; 11,081.0-11,179.0 LINER AL1; 10,064.0-13,180.0 SLOTS; 10,216.0-11,098.0 PRODUCTION; 33.0-10,557.0 WINDOW AL1; 10,175.0- 10,180.0 WHIPSTOCK; 10,170.0 APERF; 10,169.0-10,189.0 APERF; 10,157.0-10,159.0 PILOT; 10,084.0 CEMENT PLUG; 10,070.0 ftKB LINER TOP; 10,064.0 RBP; 10,035.6 CATCHER; 10,030.2 PACKER; 10,016.4 GAS LIFT; 9,959.4 GAS LIFT; 9,298.5 GAS LIFT; 8,576.8 GAS LIFT; 7,833.2 GAS LIFT; 7,061.6 GAS LIFT; 5,529.6 SURFACE; 34.7-3,789.0 GAS LIFT; 2,674.9 SAFETY VLV; 1,798.0 CONDUCTOR; 35.0-115.0 KUP PROD KB-Grd (ft) 39.99 RR Date 11/14/198 9 Other Elev… 2K-19A ... TD Act Btm (ftKB) 12,614.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032011801 Wellbore Status PROD Max Angle & MD Incl (°) 96.27 MD (ftKB) 11,640.49 WELLNAME WELLBORE2K-19A Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: TRDP ECP 9814 1989 PET log showed cement above ECP at ~9680 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,081.0 11,179.0 6,302.0 6,299.1 A-4, 2K-19A 5/2/2011 32.0 SLOTS SLOTTED LINER 11,756.0 12,614.0 6,301.0 6,278.7 A-4, 2K-19A 5/2/2011 32.0 SLOTS SLOTTED LINER 2K-19A, 5/29/2023 6:08:30 AM Vertical schematic (actual) LINER A; 11,054.1-12,614.0 SLOTS; 11,756.0-12,614.0 SLOTS; 11,081.0-11,179.0 LINER AL1; 10,064.0-13,180.0 SLOTS; 10,216.0-11,098.0 PRODUCTION; 33.0-10,557.0 WINDOW AL1; 10,175.0- 10,180.0 WHIPSTOCK; 10,170.0 APERF; 10,169.0-10,189.0 APERF; 10,157.0-10,159.0 PILOT; 10,084.0 CEMENT PLUG; 10,070.0 ftKB LINER TOP; 10,064.0 RBP; 10,035.6 CATCHER; 10,030.2 PACKER; 10,016.4 GAS LIFT; 9,959.4 GAS LIFT; 9,298.5 GAS LIFT; 8,576.8 GAS LIFT; 7,833.2 GAS LIFT; 7,061.6 GAS LIFT; 5,529.6 SURFACE; 34.7-3,789.0 GAS LIFT; 2,674.9 SAFETY VLV; 1,798.0 CONDUCTOR; 35.0-115.0 KUP PROD 2K-19A ... WELLNAME WELLBORE2K-19A 2K-19 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 62.5 H-40 Surface 3789 2912 9.625 8.92 36 J-55 BTC BTC Production 10557 6307 7 6.28 26 J-55 BTC BTC Liner Tubing + PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @TBD' RKB Cut to Release Packer @ 9906' RKB X-nipple @ 9960' RKB (2.813" ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE 3-1/2" Tubing Stub @ 9981' RKB Baker 3-1/2" 80/40 PBR @ 10,003' RKB Baker 3-1/2" x 7" HB retrievable packer @ 10,016' RKB 3-1/2" Otis 'XN' nipple @ 10,052' RKB (2.75" min ID) (Note: Milled out to 2.80" for CTD) 3-1/2" tubing tail @ 10,084' RKB 7" 26# J-55 shoe @ 10557' MD 9-5/8" 36# J-55 shoe @ 3789' MD 16" 62# H-40 shoe @ 115' MD A4-sand perfs (Sqz'd) 10,210' -10,250' MD 'A' sidetrack KOP @ 10,170' MD Baker monobore whipstock set in pilot hole 10,170'-10,180'A5-sand perfs (Sqz'd) 10,169' - 10,189' MD Anchor-billet at 11,054' MD 2K-19AL1 TD at 13,180' MD 2-3/8" slotted liner 10,064'-13,180' 2K-19A TD at 12,614' MD 2-3/8" liner top at 10,064' MDPerfs in 3-1/2" tailpipe at 10,070' MD Top of cement at 10,070' MD 2.80" cement pilot hole drilled to 10,200' ĞƐƚ͘dKΛΕϮϬϮϬΖ ϳΗƚŝĞͲďĂĐŬ ĐĞŵĞŶƚĞĚ ƚŽƐƵƌĨĂĐĞ Loepp, Victoria T (CED) From: Sent: To: Cc: Subject: Attachments: Follow Up Flag: Flag Status: Victoria, RTV ? // - 0 3 4- NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Monday, June 3, 2019 11:08 AM Loepp, Victoria T (CED) CPA Wells Supt KRU 2K -19A (PTD 211-034) Report of internal waiver to allow 1400 psi OA pressure 2K-19A.pdf; 2K-19 90 day TIO trend 6.3.19.JPG; 2K-19 Waiver for IAxOA communication 6.3.19.xls Follow up Flagged KRU producer 2K -19A (PTD 211-034) has known slow IAxOA communication which has operated within CPAI's Well Operating Guidelines. Recently OA bleeds have exceeded allowance (2 per week). As such, CPAI intends to waiver the well, allowing the OA pressure to operate up to 1400psi, to equalize with the IA pressure. The well is completed with 26 lb/ft, J-55, 7" production casing, which has a burst rating of 4980 psi (1400psi is 28% of burst). Attached are the schematic, 90 day TIO trend, and waiver document which will be posted at the wellhead. Please let us know if you have any questions or disagree with this plan forward. Regards, Jan Byrne / Dusty Freeborn CPF1 & 2 Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM Notice of Kuparuk Waivered Well WELL: 2K-19 WELL TYPE: Producer Gasiift DATE: 06.03.'19 ...................................................................................1.................. ...................................- See "Plan of Action" section at bottom for new operation guidelines for this well REASON FOR NOTICE: Gas lift production with Inner Annulus by Outer Annulus communication TUBING x IA COMMUNICATION ON GAS ONLY YES NO X • The tubing and packer have integrity based on a passing TIFL 05.31.19. • Tubing pack off tests passed on 05.31.19. IA x OA COMMUNICATION YES X NO • There is known slow IAxOA communication (to gas). Recently OA pressure bleeds have exceeded 2 per week. • The production casing has integrity to liquid based off a passing MITIA to 2500 psi on 03.28.11. • Inner Casing pack off tests failed on 5.31.19 and may be the source of IAxOA communication. IMPORTANT CONSIDERATIONSICOMMENTS: • Well requires gas lift for production. • The surface casing has integrity based off a passing MITOA to 1800 psi on 05.31.19. • The surface casing has a cement shoe and Arctic pack pumped in 1990. PLAN OF ACTION: x Grant waiver to continue operations IA - Do Not Exceed 2000 psi OA - Do Not Exceed 1400 psi • Allow operation with gaslift as needed; • Allow OA to equalize with IA pressure up to 1400 psi; • Monitor well head pressures daily and log weekly into Setcim; • Perform the following waiver compliance testing: • 2 -year TIFL / MITOA alternating with a 2 -year OA fluid level; • A failing MITOA will void the waiver and require SI the well and securing; • A failing TIFL is required to be repaired and retested within 28 days or the well will be SI and secured. SUBMITTER(S): Well Integrity Supervisor Date: I, the undersignei acknowle ge that this well has a mechanical malfunction and is incapable of operating within the CPAI Well Operating Guidelines.Wei an Rions an diagnostics indicate sufficient control remains to warrant continued operation under the above stated specific operational guidelines, increased observation, and attention. 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GLV CIO pplwen 101W W612016 I WIGfl1: ]11� as s limp Gine oO (in) m6n) Topryuc3 aa1 DeM IR sN Dpm 8`150 Y/4L621513 w Top Tnme UCOR CONDUCTOR i6 15.062 350 115.0 1150 62.50 H-00 WELDED 11 Lul�OnmWon (NI 10 (In) Tap (RItO) aq OpN(N(BI BM CapM TOP TIIneO SURFACE 95/8 8921 34.1 3,]89.0 2,9119 36.00 Jb5 BTC COx01KTOR: 35Gn6p F. Ing .pp.- Bn pnI Tep aN D.pM ... WIM1m B.. op PROOIICT ON ] 6.2]6 330 10.5519 8,30].1 2600 J55 BTC nP DNALI n oB Dnl IOpn1 rePrytltel BapW aw wWn RYDI... LWAen P.. OnOo Tnr Tlmw WINDOW ALI 3V2 2992 1Spip) 10,180.0 fi.200.8 930 B m,,LY: 17000 calnp O.evlpBon ODlin) lOpn Tnv MNel Irpm lNNel Dnpu") "a"" ...6 Top mma LINERA 2318 1992 11,054.1 12,6140 6276] 466 LA0 STL Liner Detalle crsuFr:zarae NeTaT1ID Top 11,05 Top(1VOI W30 TOp IM IYT D! 0011 (In) Sr 11,051.1 8,303.0 91.50 BILLET OHMtl1.ed Ilei (2.825) 1.1100 11,0]0.2 8.302.3 9197 DEPLOY RBM deplOymentabev0 (mn Oniu.mffnB1 1.995 Be9ment) SUR..:30.ry0v.B- 6.561-0 94.40 DEPLOY RPM R,,,mant!peva lmn on lirslli110r 60Bmenp 1.995 GPSLIFT: S,6N6 1111,]65.3 Tubing Strings TUEIn01b+vIFBOn SMn, Ye...lR p.) Tap laN3l SN OoN11 tR. 5N Dpp111(ry0)(... w11W1D 01o0e iap Conmclion rORING 3112 2.982 31.1 10,084.0 6.224.2 9.30 JSS EUEBp ARMOO GA4 LIFT:lp818 completion Details xommu 1D GASIIFT: ).&13.2 TapIMOI Top (Np)37.1 Top M0,0 IDEOy LOn 31.1 31.1 000 PANDER F CGEN IV TUBING IawGER 3.500 3. GA9L1FT: 0.63Ba 1,]98.0 V26A 1 5 VLV TROP-1ASSSV 2.812 10, 2.1 8,171.1 54.95 PB 80-40wltp'StrpkO MRWe REAL. BORE 33M 10,Oi6A SINS 56.07 PACKER BAKER HB RETRIEVABLE PACKER -2 890 opsuFr; B.9Po.5 1.052.0 8.25.5 5490 NWPLE OTI5291S XN NIPPLE .81'Pq.LS DB 2.790 MILLED OUT TO 2.79' WOR011 10.0832 6,223.8 54.16 SOS BAKER SHEAR OUT 3.000 DiMr M Hole (YebellTm retrle"ble phgS. "tVM PUMPS, fM% etc) TopjNOl Tepinu Top PSK81 Peal f) Os C. Run peY ID in) t0,OB4.0 6, 42 54.15 PILOT HIGHSIM PILO HOLE MILLED IN CEMENT 2011 PLUG GASUFT;BYP• t0,ll0. B, ]5.0 53.41 WHtP6TOC WELLB J CTX)N-MECH WHIPSTOIX OR 41242011 LATERAL ALI PaR; 1B,009] Perfon itbro & Sleb 311. PRLMER: +0,0181 Dnp Top [PID) Bt"(8) (M0 TeP RKRI aenluel (a1t8) I.. IDm D.0 6 TYw Nnpl6 t0.au0 1,0810 11,1]90 ,302.0 6,298.1 A -0,2K-1 5 011 32.0 SLOTS SLOTTEDL UNI 11,]560 12.614.0 6.301.0 6,1>6> A -0,2K -19q 11 2.0 SLOT JSLOTPEDUNIER Mandrel Inserts a n BDe: +o.aa.z TeP(1'/D) BYn = Ppl aln 70.0 ) N TepryDml 01"15) a.A amN a001 swv Trw (WI Ron Dm cpm ,674. 2,329A MERIA 1 LI V K .159 1, 0.0 81262015 LV 01 2 5,529.6 3,8000 MERLA TMPD I iIGNSLIFT CAV 99--T 0.156 1,299.0 &2612015 3 7.W1 6 4,615.1 M 1TOASLIFT GLV BK DAN 1,3160 6262015 PY.OT+0000.8 4 7,833.2 5,0236 MERLA 1 GAS LI BK 0.000 O0 6282015 MEBF, +0.+5l010.150.0- 5 8.578. 5,1128 M 0.LA P IG AS LIFT GLV SK 0.1 1,300.0 62612015 6 9298.5 57893 CAM MMG2 1112 LI DMY RK 0. 252015 -6C2 ] 9,9594 6,1525 UR 1112 GAG LIR OV K 0.250 0.0 911112016 NI 4PFRF: 10,1BB.D101B001� CEl1EMPLUG: l0.OT1A01® WHa910CN: 10.170.0 6FfL PKG Notes: General & Safety wlxoaW u¢+B,n3o. l U.1B0Y End Wb Mn.allon ]2011 NOTE: VI EW SCHEMATIC wIQwI,a ScbemaliO9.0 5l 11 NOTE: WELLS ETRACKED TO A& ALKALI o6 main w005.e1 2016 NOTE Wai amd w0110AR AtmoWtuim rummunkaSon COnfinuetopamdon W4tll Bev lM alioWad PR00VCTION: 31.0-10,6510 T Y SLOT3;10,316.b11A0B0 LINEA nL1: 100M.0.13,1a00 aLora; ll.rol.o-n.m.p- 9LOTa; 11,IW 0.13,0140 L1NFA.\11.050.1120140 • Kat c Z-V--1 9 4 Pu Zi(0340 Regg, James B (DOA) From: NSK Fieldwide Operations Supt <n2072@conocophillips.com> Sent: Tuesday, November 22, 2016 3:50 PM To: Regg,James B (DOA) 1( � t1itiro Cc: NSK Fieldwide Operations Supt Subject: Kuparuk 2K-19 LCA Results Jim, As we discussed in our meeting last week, we have completed our investigation into the missed performance test on 2K- 19 and have the following findings and corrective actions to note: Event Well 2K-19 missed its required State SVS performance test after it was returned to service on September 28, 2016. The well had been shut in during the scheduled pad test that was completed on September 17th, and should have been identified as requiring a MISC test once the well was returned to service, which occurred on Sept 27-28. Explanation Kuparuk utilizes two systems and processes to track SVS compliance. The SAFEVLV system, which is part of our SCADA system (IP.21) utilizes manual data entry of wells that were notteeted during a scheduled test, and flags them for MISC testing when they come on line or are WAG'd to gas injection at a later date. WeIITRAK is an automated system that monitors SVS compliance requirements against electronic data, such as completed pad test results, to identify missing tests. In this instance, both systems failed to identify the required test when the well was returned to service. Findings • After completion of the pad test on September 17th, nine wells that were not tested were entered into SAFEVLV. 2K-19 was not entered as it should have been. It appears that this was just an oversight. This prevented SAFEVLV from identifying 2K-19 as needing a test when it was brought on line ten days later. • A bug in WeIITRAK was discovered that prevented some wells due for testing,-from being flagged properly. It appears that the bug was introduced into WeIITRAK at the end of May 2016 during a program update but had not been previously discovered. Actions Taken To Date • Well 2K-19 tested and passed SVS performance test on October 28. v • AOGCC notified of missed test. 1./-- • • SAFEVLV checked for any additional missed entries from 2K pad test. None found. • SAFEVLV and SVS tests checked back to May 2016 for any additional missed entries. No additional missed tests were found. • IT investigation into WeIITRAK deficiencies completed. • WeIITRAK code bug corrected. %ANNE) JUN 2 02017 Corrective Action Recommendations • Correct the software bug that prevented some wells from being properly flagged in WeIITRAK. Complete L.-- 10/28/16 10/28/16 • Change the SAFEVLV system to automatically populate at the beginning of each month the wells due for pad test during that month, and then check them out of SAFEVLV as the pad test is completed. The current system is the opposite where only the exceptions from the pad tests are manually entered into SAFEVLV by the Production Engineering Specialist. Due 3/31/17 ✓ • Add a work step for the SVS Technician to check the SAFEVLV entries by the Production Engineering Specialist from the pad test results to validate that they were entered correctly. Due 11/30/16 ,/ 1 0 • Instate a back-end master rule in WeIITRAK that is not affected by updates which will alert IT of logical discrepancies between the updated versions and non-updated versions. Due 1/31/2017 `/- • /• Setup review bi-annual review sessions with the business for all WeIITRAK rules. Due 12/31/16 • Conduct quarterly test drills of WeIITRAK in coordination with rule owners to confirm flags are triggering correctly. Establish schedule for quarterly drills by end of year 2016. Due 12/31/16 ✓ Let us know if you have any questions. Thanks Scott Fahrney/Larry Baker NSK Fieldwide Operations Superintendent (907) 659-7042 2 • • k -L4 z-14.--1 . 2-w a s4Q Regg, James B (DOA) From: NSK Fieldwide Operations Supt <n2072@conocophillips.com> Sent: Friday, October 28, 2016 9:08 AM To: Regg, James B (DOA) (\-42,161 1vfD6/4,, Subject: Kuparuk 2K-19 Missed Test Jim, This morning we discovered that we missed a SVS test on 2K-19 that should have been conducted by October 2"d. The well was shut in at the time of the pad test completed on September 17th, and was returned to service on September 28th after an initial but unsuccessful restart attempt late on September 27th. At that time, it should have been identified as requiring a MISC test, but was not correctly noted and was not discovered until this morning. We are initiating an investigation into the cause of this and will provide you with an explanation when we complete our review. We are currently working to contact the inspector to see if we can complete a test today, otherwise we will shut in the well until a test can be scheduled with your staff. Scott Fahrney/Larry Baker NSK Fieldwide Operations Superintendent (907) 659-7042 1 STATE OF ALASKA ALAIL OIL AND GAS CONSERVATION COM aSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate Alter Casing 9 r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well Re-enter Susp Well r Other: BH Weld I✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 211-034 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service r50-103-20118-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025588 ADL0025589 KRU 2K-19A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/ Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 12614 feet Plugs(measured) NA true vertical 6279 feet Junk(measured) NA Effective Depth measured 11054' feet Packer(measured) 10016 true vertical 6303 feet (true vertical) 6185 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 115' 115' SURFACE 3754' 9 5/8 3789' 2912' PRODUCTION 10524' 7 10557' 6310' Slotted liner 1560' 2 3/8 12614' 6303' RECEWED Perforation depth: Measured depth: Slotted liner 11054'-12610' MD SEP 2 7 2016 True Vertical Depth: Slotted liner 6303'-6278'TVD OGCC, . Tubing(size,grade,MD,and TVD) 3 1/2 ,J-55, 10083 MD, 6224 TVD Packers&SSSV(type,MD,and TVD) SAFETY VLV=CAMCO TRDP-1A SSSV @ 1798 MD and 1726 TVD PACKER=BAKER HB RETRIEVABLE PACKER @ 10016 MD and 6185 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): FEE-G Treatment descriptions including volumes used and final pressure: 5 ANNEE t_Ef. 3 2012, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p' Exploratory r Development 17 Service r Stratigraphic r Copies of Logs and Surveys Run ra 16.Well Status after work: Oil P Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.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: N/A Contact Aaron Applehans Email: n1927conocophillips.com Printed Name Aaron Applehans Title: WI Field Supervisor Signature de,,,eedlePhone:659-7506 Date 4,i4c__ V71 o/4 /l 1044, RBDMS 1,t' SEP 2 8 2016 Form 10-404 Revised 5/2015 ((� Submit Original Only • • ✓ • • RECEIVED ConocoPhillips Alaska SEP 2 7 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOG�i4,�+ September 26, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 2K-19A PTD 211-034 surface casing starter head repair. Please call Aaron Applehans or Roger Winter at 659-7506 if you have any questions. Sincerely, 1 Aaron Applehans ConocoPhillips Well Integrity Field Supervisor Name of Recipient Page 2 of 2 09/26/16 Delete the section break above to remove the second page e v w vt Zi S -Q 0, N Ly t 't 4- 0., Cs.' ,''S.„ Q i ,,f z ,.-- ,r t 7 ,c,:,; al 3 11 te,tea,. w xi w .� � * '' a X i _ .,,, , .,.. ,tS 2K-19A • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/21/16 Completed a 3 pass weld on the starter head connection. 09/22/16 MIT-OA to 1800 psi. (PASS) Initial T/1/0= 0+/0+/10 OA FL @ NS Bled T& IA to 0 PSI Pressured OA to 1800 psi. Starting T/I/0 = 0/0/1800 15 min T/I/O = 0/0/1760 (-40) 30 min T/I/O = 0/01750 (-10) Bled OA to 100 psi. Final T/I/O = 0/0/100 on 40 lv' • o en Doo i 0 N W a r c. \` a • .. a m N a a o _o .. a L i oro v a o a ° OaCQp . - W QSt 0 CO @ >'• a Q QU ,-. o CO m m e' co e- p r Q t7 C7 7 7 >, :n O Ca.' a O y Y v1 O 7 7 7 m 7 O an L C C ,a ) - ) _) -) E y _ HV7 F 4 .- co W O N in al _ -O O_ a Z < " <- N C i v >' N Z Q CI O O Q CC u 'O O >. H a a v a-' F v > s 0 0 0 0 0 0 0 0 +�-' L, s _, � W J J J J J J J J m v u >- W W W W W W W W pip 4-, O O H LL LL LL LL LL LL LL it. '.7 N E O Q J J J J J J J J O aU) Q Q Q Q Q Q Q < a 0oYG aZZZZZZ Z Z aN -p ,AO LL L.L. LL LL LL IL LL LL v C V a a • - a 76 ...,6 � O '-, '-' O '-' ' •;.-.. w 0 O. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. QI j - 0 3 L(- Well History File Identifier Organizing(done) ❑ Two-sided II 111111 III VIII E Rescan Needed I 1111111 111 III RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Di kettes, No. ;73 ed.yscale Items: Other, No/Type: C.9 No,I Items Scannable by VV a Large Scanner Lo9s ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Date: a, ` /s/ niP Project Proofing II 111111111011111 BY: dea. Date: valitt. /s/ Re Scanning Preparation CZ x 30 = bo + f = TOTAL PAGES (0 I (Count does not include cover sheet) m�BY: alb Date: ' 14.. /s/_ l! Production Scanning 111111111111111111 Stage I Page Count from Scanned File: ( a (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: MO Date: 1 Ix! IL+ /s/ VVIe Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II!IIUI II I II Il IIIII ReScanned 11111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 11111111111 MN a O (a11 o 2m CD d co Z Q 0 N 03 ci_ — O o p 6 iii a) 0 0 J W as E a a o Z 2 I 2 v p X2 m Q I 0 O 9 0 0 > a a) 0 0 0 0 0 0 J N co U N N N N N N -,7,- O Co co OD a0 00 00 U p J N N N N Z (o (o co co (n (� Co O d _ = a) Cl) Cl) N N Cl) EE :: Q m j Y OU 0 0 0 0 0. 0. 0 0 0 1 0 c/ J c :° U Q as 5 a v v v v v v ` O 0 y 0 0 (D Ti; co co m m z JU ' t6 N N N N 04 r r °'N a t J LU = d V) Z �/ a c n ccoo i LI U y 0 0 o Obi o () P• a W Z m V v 0 a) z CC a o z H Q R � Z to ° j N O .J Cl) C CL O ! ° m. 0 0 0 .T E N ai ZI J 2 U U U N p (i r _ Nd co d a Cl) O)Tel V 5=.1 003 CD 113 L13 J () N J Q L a I— 1 _ N Z 0 G m N I 2 COin 2 a of Q a M O I— a) Q 0 a Z Uw ww w C:1 1B OU > > > > NN Z m N N m Ce N It- N co co ��I�I cC Ct CL CC g I c c c c C C 1 j Ta y I m ° O O O O O °N) 3 R > > > > a, 1 E (No Z c c c c a) 0 0 .� Z O Ov p p ` t_ y a m Z W 0 z v) 3 N 0 O w a) O m O Q O E E E 0. E z aa)) g U .- 3 - U R m 0 a Z re +`• J Q N Z Q aN v O co O O U C D a) d Z1:3 U N. +� ) \\-: C a I- N J r a) ��•� V 0 U �- ( U E E y a a y a 0 O O p a) D OO L C N O O a CC 10 H J � �I J J _1 W � W 7 Q > U Q� 0 0 + ,t s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: May 14,2011 211-034/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 April 25,2011 50-103-20118-01 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 219'FNL,94'FEL,Sec. 11,T1ON, R8E,UM April 29,2011 2K-19A Top of Productive Horizon: 8.KB(ft above MSL): 154'RKB 15.Field/Pool(s): 1570'FSL,2417'FEL,Sec. 10,T1ON,R8E,UM GL(ft above MSL): 118.5'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1413'FSL, 1677'FWL,Sec. 10,T1ON,R8E,UM 11054'MD/6303'TVD Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-498310 y- 5938085 Zone-4 12614'MD/6279'TVD ADL 25588,25589 TPI: x-490710 y- 5934600 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit Total Depth: x-489524 y- 5934444 Zone-4 1798'MD/1726'ND 2674,2675 18.Directional Survey: Yes Q No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MDITVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1400'MD/1379'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MDTIVD GR/Res 10170'MD/6275'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 115' Surf. 115' 24" 170 sx AS II 9.625" 36# J-55 Surf. 3789' Surf. 2898' 12.25" 1200 sx AS III,450 sx Class G 7" 26# J-55 Surf. 10557' Surf. 6508' 8.5" 450 sx Class G 2.375" 4.7# L-80 11054' 12614' 6303' 6279' 3" slotted liner 24.Open to production or injection? Yes ❑✓ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 10084' 10016'MD/6185'ND slotted liner from 11054'-12610'MD 6303'-6278'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. i COMPLETION DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED i 0 I 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) May Z3,2011 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 5/29/2011 18 hours Test Period--> 947 1298 147 176 Bean 687 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 240 psi 1133 24-Hour Rate-> 1155 1827 194 24 deg 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RECEIVED' RBDMS JUN o 7 ZO 1U N 9 A ?Oil Form 10-407 Revised 12/2009 CONTINUED ON REVERAlaSk3 Oil& G8* Cens. Cora CUStloflt original only i 28. GEOLOGIC MARKERS(List all formations and markers a itered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 2 No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1400' 1379' needed,and submit detailed test information per 20 AAC 25.071. A4 10206' 6293' A5 11200' 6297' A4 11390' 6302' N/A Formation at total depth: Kuparuk A4 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J.Gary Eller @ 263 172 Printed Na�}q .Gar Title: Alaska Wells Supervisor Signature A&rYYLA.A. '• 74•In Phone X66-63e6 Z63-4ba j Date 6/3/I Sharon Allsup-Drake 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 �� 0 0 cs— rx / / \ ( ! co q 9 05 k 11 _ \ a) I I _ ) _ .9\ V co ) I I Lo ro ( f k\/ ;} _) | \ ta \§\ %7 % / /$ }E i M: \ \ \ ij N§ : \ I \/\ > q r k� // _ \ � 6 /� f 2 cL / Iƒ . z0 / 0 / 11 & 1.- §� \\ {\ f ,_ a , \ r� M M \j / . . 8 8I cv A / \§ CO Oil CO CO k �\ ( .o'7 �_ E �� 8 / iii \a. 2= k; i )§ \\ ii g \ : § s\ �| l y \ : } |A-11 W, % , - m K ` ! _ ` ° � ^ \ -- ] — _ \; 15. _ /g �` (Q u� /) 2 }@ jg k f,•;-- \| m\ _ a _ ,\ \- k# \{g (/ }§ \ }\ \\ J« KU P 2K-19A COt10Ci? !lips o Well Attributes Max Angle&MD 1TD 1 AlaA9.11N' Wellbore APW WI Field Name Well Status Incl 03 MD NIKE) Act Btm(ftKB) tonacNRBBns ' 501032011801 KUPARUK RIVER UNIT PROD 96 27 11,640.49 12,614.0 Comment 1H2S(ppm) Date Annotation End Date TKB-Grd(ft) Rig Release Date well coeli -2!1.19-A,4/1.7r-0oU 1:402s PM SSSV"I RUP I 90 1/172010 Last WO: 1I 39.99 11/14/1989 S.nemalic_Actuai Annotation Depth(ftKB) End Data AnnotationLast Mod ',End Date Rev Reason:SIDETRACK Last Tag: SIK A&AL1 I _ Imosbor ; 5/17/2011 Casing Strings HANGER,31- I Casing Description String 0... String ID...Top(9KB) Set Depth(t...Sat Depth(TVD) String Wt...String...String Top Thrd CONDUCTOR 16 15-062 35.0 115.0 115.0 62.50 H-40 . ,91. .a. Casing Description String 0._ String ID...Top(�)�Depth(1...Sat Depth(ND) .String Wt...String...String Top Third '- r SURFACE 95/8 _8.765 34.7 3,789.0 2,912.3 36.00 J-55 BTC Casing Description String O._ String ID...Top(ft103) Set Depth(f-.Set Depth(TVD) -String Wt...String_.String Top Third PRODUCTION 7 6.151 33.0 10,557.0 6,307.1 26.00 J-55 BTC in on String -- th(0. 5 _. - �;� Casing Description String 0... String ID...Top(ftK8) Set Depth(f...Set Depth(ND)...String WI...String String Top Third LINER A 2 3/8 1.992 11,054.1 12,614.0 6,278.7 4.60 L-80 STL CONDUCTOR. 35-115 Liner Details tom' Nomi... SAFETY VLV, ._. To ftK8 (0) (') item Description Comment ID(in) P Depth Top Top Incl Top ) v 1,798 ' 11,054.1 6,302.9 91.90 BILLET OH Anchored Billet(2.625') 1.000 11 070.2 6,302.3 91.96 DEPLOY Shorty deployment sleeve(ran on second liner segment) 1.995 GAS LIFT, .5.... -'--- --"-- _. -- - - 2,875 9, 11./55 3 6,301-1 94 401 DEPLOY i Shorty deployment sleeve(ran on first liner segment) 1.995 Tubing Strings 41 Tubing Description String 0... String ID...Top(ftKB) Set Depth(t...ISet Depth(ND)...String Wt..String...String Top Third TUBING 31/2 2.992 311 10,084.0 6,224.1 9.30 J-55 EUE8rdABMOD Completion Details Top Depth SURFACE, (ND) Top Incl Nomi... %-3.788 (ftK8) C) Item Description Comment ID(in) Top(MB) _.__. GAS LIFT, 31.1 31.1 -0.85 HANGER FMC GEN IV TUBING HANGER 3.500 5,530 1,798.1 1,726.1 32.61 SAFETYVLV CAMCOTRDP-1ASSSV 2.812 GAS LIFT, n... 10,002.7 6,177.2 55.71 PBR BAKER 80-40 w/10'Stroke PBR 2.890 7'062 10,016.4 6,184.9 55.23 PACKER BAKER HB REVTRIEVABLE PACKER 2.890 GAS LIFT 10,052.0 6,205.5 54.23 NIPPLE OTIS XN NIPPLE w/2 81"POUSHED BORE;MILLED OUT TO 2.79" 2.790 7,833 3!302011 L. 10.083.2 6,223.7 53.74 SOS BAKER SHEAR OUT 2.992 GAS LIFT. 8,577 ., Other In Hole eNireline retrievable ptugs,-Valves pumps,fish,etc.) Top Depth (TVD) Top Incl Top(NKB) MKB) C) Description Comment Run Date ID(In) GAS LIFT. ..... 0290 ' 10,070.0 6,216.0 54.39 PILOT high-side pilot hole milled in cement plug 4/23/2011 10,170.0 6,274.9 52.89 WHIPSTOCK WELLBORE JUNCTION MECH WS 4/24/2011 Notes:General&Safety End Date Annotation ' _ _- 4/17/2011 NOTE:VIEW SCHEMATIC wlAlaslo Schematic9.0 5/16/2011 NOTE:WELL SIDETRACKED TO A&AL1(A sidetracked off AL1) GAS LIFT, 9,%9 141 PBR,10,003 PACKER, -�>- 10,018 NIPPLE,10,052- 'ate. SOS,10,003-" PLOT,10,070 -- APERF, IA15740.193-'''...„._____ WHIPSTOCK, .._. 10,170 RPERF, 10,172.10,182 .Y APERF, 10,180.10,180 0. ,Z. CEMENT PLUG,10,070 "` PRODUCTION, 4 A 33.10,557 Mandrel Details Top Depth Top ' Port (TVD) Incl OD Valve Latch Sire TRO Run Stn Top ow) (*KB) (°) Make Model (in) San/ Type Type (In) (Pei) Run Date Cam... 1 2,674.9 2,329.4 56.08 MERLA TMPD 2 5,529.7 3,800.4 58.91 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/26/2011 1 GAS LIFT DMY BK 0.000 0.0 3/262011 3 7,061.6 4,615.1 57.95 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/26/2011 4 7,833.2 5,023.6 58.58 MERLA TMPD 1 GAS UFT DMY BK 0.000 0.0 5/3/1990 5 8,576.8 5,412.8 58.71 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/272011 Ilr•iii 6 9,298.5 5,789.3 58.71 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 9/24/2003 7 9,959.4 6,152.5 55.91 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 3/27/2011 LINER A, 11,054-12,614N____,1 TD(2K-19A), 1 I 12,814 a ej met= to.. 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N N N N N 1- " (D O (D (O (O co (O O (O (O (O O (O O (O t0 co co co (D (D (D N 03 r+ C 3- N- CO CO O 0D N N 0 10 •- 0) 10 CO N to CO 0 C' 03 V V Q D "0 ,- O 3- N- O CO 3- O O .- N O O CO M N N CO CO n 0. v (0 0 N uO M O 1- 4 O O 0 u) O c0 0 O N N (VRna -- tO N (O (N (N 1N� IN N N IN- 1N� I: 4 N Lc:', Nu) N V N V N '4etO aws(YS O W' N Y Y U i •••••ii 0) 6) 6) N 0) (0 7 V co to to O O to co to D N V 0 0naC 006 G O. a O O (0 (V uI- N 0 uO O U) .- n to O OD u) CC O G n Y U - O (`) M N NG " co O . m O N a c, O0O O O O\�fl. C.) Y Y N N N — N 0 v O kJ O (0 to CO to CO 0 M 7 0) (0 0) O 7 O (0 (0 CO n IO 0 v` 0 _. CO (0 CO V O f` u) u) CO O u) M t0 M u) O O .- M M 0 N J+ O O O O N O O O O O O O 0 0 0 0 0 O O O O V r O M to O N u) M V n O co O O N to c0 C 13-: N...O O 0 0 0 3- 01 N N CO. CO. M CO. C' V V 0 u) u) O ,O (p a) N N N N N N N N N N N N N N N N N N N N N O U E0 a- o d d d o v 0 d O) 0 U) ConocoPhiIIips Time Log & Summary Wellview Web Reporting Report Well Name: 2K-19 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 4/22/2011 11:00:00 PM Rig Release: 5/14/2011 8:00:00 PM Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 04/21/2011 24 hr Summary Move rig from 1E,MIRU 00:00 13:00 13.00 MIRU MOVE MOB P Travel to 2K-19 13:00 17:00 4.00 MIRU MOVE MOB P Remove jeeps,spot rig over well, spot pit module 17:00 23:00 6.00 MIRU WHDBO NUND P RU,nipple up BOP,call pad operator to pump open the SSV,grease tree valves ****RIG ACCEPT***** 23:00 00:00 1.00 MIRU WHDBO BOPE P Test BOP. State witness waived by John Crisp. 04/22/2011 Test BOP,state witnessing waived by John Crisp. All passed except inner reel valve which was replaced and then successfully tested. PU cement milling BHA. 00:00 11:00 11.00 0 0 MIRU WHDBO BOPE P Continue with BOP testing. b Complete test @ 11:00 execept for inner reel valve. Replaced valve R-3 11:00 11:30 0.50 0 0 MIRU WHDBO OTHR P Test rig ESD on gen and Hi-Line, restore all systems after test. All Good 11:30 14:00 2.50 0 0 MIRU WHDBO BOPE P R/U and Pull BPV, Lay down Lubricator 14:00 15:12 1.20 0 0 MIRU WHDBO PULD P P/U injector, Remove checks in upper quick connect, M/U Nozzle, stab on, Check out tiger tank line 15:12 18:30 3.30 0 0 MIRU WHDBO BOPE P Fill coil with seawater,Test and chart inner reel valve 18:30 21:30 3.00 0 0 MIRU WHDBO BOPE T Trouble shoot, replace inner reel valve and retest ***3 Hours Nabors Billable Downtime*** 21:30 22:00 0.50 0 0 MIRU WHDBO PRTS P Test PDL 22:00 22:18 0.30 0 0 PROD1 WHPST SFTY P PJSM for PU BHA 22:18 00:00 1.70 0 0 PROD1 WHPST PULD P Makeup pilot hole BHA with used 2.80"D331 mill(smooth gauge)and 0.9 deg motor 04/23/2011 Milled pilot hole from 9993'to 10200', reamed transition area from 10075'to 10095%,Ran dummy WS 00:00 02:30 2.50 0 9,993 PROD1 WHPST TRIP P RIH,circulate FP to TT,swap well to Biozan. 9900'Wt.check,37K PUW, 18K RIW 02:30 05:30 3.00 9,993 10,064 PROD1 WHPST MILL P 9993'uncorrected depth,tag cement and start milling 20 Deg ROHS, 1.4 BPM,2900 CTP,—20 FPH Page 1 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code SUbcode T Comment 05:30 11:06 5.60 10,064 10,154 PROD1 WHPST MILL P Stalled 3 times total,time mill with 1.5K WOB for 1'then aot aoina ahead @—20 FPH. 1.3 BPM @ 3300PSI FS. (Note:Stall area appears to be where made contact with 7"casing.) 11:06 12:36 1.50 10,154 10,170 PROD1 WHPST MILL P Got enough character from gamma to reset depth+16.5'correction, Continue milling cement 12:36 13:06 0.50 10,170 10,200 PROD1 WHPST MILL P Mill down to 10200', Call TD for cement pilot hole. PUW=40K, Pull up hole,circ bottoms up 13:06 13:18 0.20 10,200 10,026 PROD1 WHPST DLOG P 9990',tie into K-1 marker for 0' correction 13:18 13:48 0.50 10,026 10,162 PROD1 WHPST TRIP P RIH to dry drift transition area saw increase in WOB @ 10082-10087 13:48 17:24 3.60 10,162 10,093 PROD1 WHPST REAM P 10093 to 10075 Back ream this transition area per program. Back reamed 5 times Started @ 1400 lbs DHWOB dry, last dry pass quick blip down to 900 lbs. Perform No flow test,good test. POOH. 17:24 19:54 2.50 10,093 0 PROD1 WHPST TRIP P POOH 19:54 20:12 0.30 0 0 PROD1 WHPST SFTY P PJSM 20:12 21:12 1.00 0 0 PROD1 WHPST PULD P Lay down motor and mill,mill guaged 2.80"go,2.79"no-go. PU dummy WS. 21:12 21:48 0.60 0 0 PROD1 RPEQP1SVRG P Injector head maintenance 21:48 00:00 2.20 0 PROD1 RPEQP1TRIP P RIH 04/24/2011 Ran Dummy WS to 10199'. Ran whipstock and set at 10170'top of whipstock. Started milling window. 00:00 02:42 2.70 10,200 0 PROD1 RPEQP1TRIP P Clean run to 10200'with dummy WS, POOH 02:42 02:54 0.20 0 0 PROD1 RPEQP1SFTY P PJSM for BHA 02:54 03:30 0.60 0 0 PROD1 RPEQPI PULD P Lay down dummy WS, PU WS 03:30 04:00 0.50 0 0 PROD1 RPEQP1SVRG P Service injector 04:00 06:15 2.25 0 9,800 PROD1 RPEQP1TRIP P RIH with whipstock 06:15 06:33 0.30 9,800 10,000 PROD1 RPEQP1TRIP P Close EDC before going below TOC, 06:33 07:33 1.00 10,000 10,185 PROD1 RPEQPI DLOG P Wt Chk, PUW=40K,Tie into formation marker, PUH to 9980 re run log,peak not well defined, RIH to 10100 and log,Tie in for a+11.5 07:33 08:09 0.60 10,150 10,185 PROD1 RPEQP1DLOG P Log CCL 10050 to 10185,correlate results 08:09 08:18 0.15 10,185 10,181 PROD1 RPEQP1WPST P Pull up to set depth 10180.55,TOW @ 10170 orient to high side TF. Set whipstock @ 4030PSI, Set down 3K, l000ks all!good 08:18 10:36 2.30 10,181 88 PROD1 RPEQP1TRIP P Trip out of well, PUW=36K 10:36 10:48 0.20 88 88 PROD1 RPEQP1SFTY P PJSM/No Flo check Page 2 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:48 12:36 1.80 88 78 PROD1 RPEQP1PULD P Lay down Whipstock running tool, BHA#3 P/U Window milling BHA 12:36 15:06 2.50 78 10,100 PROD1 WHPST TRIP P Trip in well with window mill BHA#4 Start 9.7 ppg used Flopro mud down coil 15:06 15:12 0.10 10,100 10,133 PROD1 WHPST DLOG P Log Gamma tie in,+10.5' PUW=39K 15:12 15:30 0.30 10,133 10,172 PROD1 WHPST TRIP P Close EDC, RIH and dry tag PUH 10' and start pumps 15:30 22:00 6.50 10,172 10,176 PROD1 WHPST MILL P 10172.1 call pinch point,start time milling 1'/Hr 1.35 bpm @ 3800 psi FS 22:00 00:00 2.00 10,176 10,177 PROD1 WHPST MILL P Stacking weight with minimal motor work,3.5k wob,40-60 psi motor work. PU a few times and resume with same result. 1.35 bpm,400013( CTP, 12K RIW 'G V� 04/25/2011 Milled window at 10172',milled rat hole to 10193',tripped for drilling assembly,drilled build section of 2K-19A to 10430' I using is-90 hhlc/hniir 00:00 02:00 2.00 10,177 10,179 PROD1 WHPST MILL P Continue window milling. 1.35 BPM, 4000CTP, 12K RIW,having to stack 3.5K WOB to maintain motor work. Continue at 1 FPH f/„s5 02:00 04:00 2.00 10,179 10,183 PROD1 WHPST MILL P WOB decreased to 400,40 PSI /� motor work. Increase ROP to 2 j1 FPH. ' , 04:00 05:45 1.75 10,183 10,193 PROD1 WHPST MILL P Continue milling formation at-6 FPH 05:45 06:30 0.75 10,193 10,190 PROD1 WHPST REAM P PUH and make three reaming passes 06:30 06:36 0.10 10,190 10,160 PROD1 WHPST REAM P Dry Drift window in and out. Looks good 06:36 09:36 3.00 10,160 0 PROD1 WHPST TRIP P Trip out for build section BHP 09:36 11:06 1.50 0 0 PROD1 WHPST PULD P PJSM, Lay dowm window milling BHA#4 2.80 go,2.79 No-Go both mills 11:06 11:42 0.60 0 62 PROD1 DRILL PULD P P/U Build section BHA#5.2.3 degree motor Bi Center Bit Surface test tool,tag stripper, reset counters 11:42 15:00 3.30 62 10,095 PROD1 DRILL TRIP P RIH, EDC Shut Tagged up GLM @ 7828(7833),90R to get through 15:00 15:18 0.30 10,095 10,121 PROD1 DRILL DLOG P 10095',tie in for+10.0 15:18 15:48 0.50 10,121 10,193 PROD1 DRILL TRIP P trip in to pass through window,clean pass through window Pull up to circ new mud down coil, PUW=40K 15:48 16:24 0.60 9,950 10,193 PROD1 DRILL CIRC P 9950',Open EDC and circulate 50 BBIs 8.6PPG Flo Pro Shut down,shut EDC, RIH to drill 16:24 18:24 2.00 10,193 10,264 PROD1 DRILL DRLG P 10193,Clean pass through window, Drill Ahead 1.4 BPM @ 3720 PSI FS 8.6PPG mud not all the way to surface BHP=3850 Page 3 of 22 • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:24 20:54 2.50 10,264 10,281 PROD1 DRILL DRLG P Into ankerite, 1.4 BPM,3600 CTP, 3K WOB with 100 PSI motor work. After discussion with geologists decided to go down. 20:54 21:54 1.00 10,281 10,343 PROD1 DRILL DRLG P Through ankerite and drilling ahead, 1.4 BPM, 3600 CTP, 3800 CTP 21:54 23:00 1.10 10,343 10,430 PROD1 DRILL DRLG P Started losing returns, leveled out at -18 BPH, lowered pump rate to 1.3 BPM, BHP was 3700,no improvment in losses,drilling ahead 23:00 00:00 1.00 10,430 6,900 PROD1 DRILL TRIP P POOH for rib steer BHA,following MPD tripping schedule 04/26/2011 Deploy rib steer motor BHA#6. Drill A lateral 10430-10490. Unable to drill, POOH. PU BHA#7. (.8 AKO motor). Drill A Lateral 10490-10640'. Last 24hr loses=247bbrls 00:00 01:36 1.60 6,900 0 PROD1 DRILL TRIP P Continue POOH for BHA swap, following MPD tripping schedule 01:36 01:54 0.30 0 0 PROD1 DRILL SFTY P PJSM for Undeploy/deploy BHA 01:54 04:48 2.90 0 0 PROD1 DRILL PULD P Undeploy build BHA, Deploy RSM BHA 04:48 07:12 2.40 0 9,980 PROD1 DRILL TRIP P RIH with rib steer BHA 07:12 07:48 0.60 9,980 10,128 PROD1 DRILL DLOG P Tie in to formation, K-1,+10' 07:48 08:06 0.30 10,128 10,190 PROD1 DRILL TRIP P RIH through window 08:06 08:12 0.10 10,190 10,209 PROD1 DRILL DLOG P Log RA marker @ 10178,TOWS 10172 08:12 08:27 0.25 10,209 10,430 PROD1 DRILL TRIP P Trip in hole to drill 08:27 09:27 1.00 10,430 10,488 PROD1 DRILL DRLG P 10430, Drill Ahead 1.38 BPM @ 3780 PSI FS BHP=3810 09:27 10:27 1.00 10,488 10,490 PROD1 DRILL DRLG P Drilling Ahead, start losing returns, Wt checks good 36K PUW. Ratty drilling 10:27 11:27 1.00 10,490 10,490 PROD1 DRILL DRLG P Unable to get weight transfer to bit, stalling. Bore pressure increasing possible packing off instead of stalling. Losing returns,but pickups clean. Try several times to drill past. Decide to change to conventional BHA in case it's a problem with the RSM. PUH to window 36K PUW 11:27 12:12 0.75 10,490 9,863 PROD1 DRILL DLOG P MAD pass 10436-10195'. PU into casing 12:12 14:42 2.50 9,863 0 PROD1 DRILL TRIP T Open EDC, POOH 14:42 14:57 0.25 0 0 PROD1 DRILL SFTY T At surface, PJSM 14:57 18:57 4.00 0 0 PROD1 DRILL PULD T Undeploy BHA 6, Inspect EDC, check valve in UQC-all looks good. Deploy BHA 7, (0.8 AKO with same Hughes Bi-Center Bit) 18:57 19:27 0.50 0 0 PROD1 DRILL SFTY T Crew change, PJSM 19:27 21:27 2.00 0 9,980 PROD1 DRILL TRIP T RIH Page 4 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:27 21:42 0.25 9,980 9,980 PROD1 DRILL DLOG T Tie in depth with gamma+10' _correction 21:42 21:57 0.25 9,980 10,490 PROD1 DRILL TRIP T RIR to Drill 21:57 00:00 2.05 10,490 10,640 PROD1 DRILL DRLG P On bottom drilling,same situtation. Bore pressure increasing, losing returns. PUH length of BHA,36K. RIH pinch MP choke placing 50psi on WH try to Drill.Get by trouble spot at 10,488'without additonal packoff or losses. Drill Ahead 80-100FPH, 1.3 in, .98 out.2K WOB,3990 BHP. 04/27/2011 Drill A Lateral 10460-11575'. 204 bbrls=Losses past 24 hours 00:00 00:30 0.50 10,640 10,640 PROD1 DRILL WPRT P Wiper trip to window 00:30 02:00 1.50 10,640 10,790 PROD1 DRILL DRLG P Drill Ahead 100FPH,2K WOB, 1.3 in, 1.1 out. 12 ECD,3860 BHP 02:00 02:30 0.50 10,790 10,790 PROD1 DRILL WPRT P Wiper trip to window 02:30 04:00 1.50 10,790 10,940 PROD1 DRILL DRLG P Drill Ahead 100-150 FPH,2K WOB, 1.3 in, 1.1 out, 12.1 ECD,3880 BHP 04:00 05:00 1.00 10,940 10,940 PROD1 DRILL WPRT P Wiper trip to window with tie-in(+1' correction). 05:00 08:00 3.00 10,940 11,090 PROD1 DRILL DRLG P Drill ahead 100-150FPH, 1.3 BPM in, 1.1 out, 12.3 ECD,4173 3943 BHP 08:00 09:15 1.25 11,090 11,090 PROD1 DRILL WPRT P Wiper trip(#1)up to 10210'. 09:15 11:15 2.00 11,090 11,240 PROD1 DRILL DRLG P Drill ahead 34-92-fph. Mud rates: 1.38-bpm in; 1.19-bpm out.4050-psi CTP;4600-psi BHP. 9.5k#pipe wt; 2k#WOB. 11:15 12:30 1.25 11,240 11,240 PROD1 DRILL WPRT P Wiper trip(#2)up to 10212'. 12:30 15:45 3.25 11,240 11,390 PROD1 DRILL DRLG P Drill ahead 47-92-fph. Mud rates: 1.38-bpm in; 1.20-bpm out.4140-psi CTP;4532-psi BHP. 7.2k#pipe wt; 2.9k#WOB. 15:45 16:45 1.00 11,390 10,190 PROD1 DRILL WPRT P Wiper trip(#3)with tie-in. (+1' correction). 16:45 17:00 0.25 10,190 10,219 PROD1 DRILL DLOG P Log RA marker. 17:00 17:45 0.75 10,219 11,240 PROD1 DRILL WPRT P RBIH to drill. 17:45 21:30 3.75 11,390 11,540 PROD1 DRILL DRLG P Drill Ahead 1.38 BPM in, 1.23 out, 4050 CTP, 1-2K WOB, 10K CTW 21:30 23:00 1.50 11,540 11,540 PROD1 DRILL WPRT P Wiper trip to window,34K PUW 23:00 00:00 1.00 11,540 11,575 PROD1 DRILL WPRT P Drill Ahead, 1.38 BPM in 1.22 out, 4046 CTP,2K WOB,5-6K CTW 04/28/2011 Drill A Lateral 11575-12440'. Perform mud swap. Past 24 hour losses 138 bbrls.Avg./hour losses past 24 hrs 5-6 bbrls. Total Losses for Lateral 658 bbrls. 00:00 02:30 2.50 11,575 11,688 PROD1 DRILL DRLG P Drilling Ahead 40-50 FPH, 1.38 BPM in, 1.22 out,4150 CTP,6-8K CTW 02:30 04:30 2.00 11,688 11,688 PROD1 DRILL WPRT P Wiper trip back to window,34K PUW Page 5 of 22 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 04:30 07:15 2.75 11,688 11,840 PROD1 DRILL DRLG P Drill Ahead 1.37 BPM in, 1.26 out, 4000 CTP, 1-2K CTW,2-3K WOB, 12.3 ECD 07:15 08:22 1.13 11,840 10,195 PROD1 DRILL WPRT P Wiper trip(#3)with tie-in(36k#off bottom). 08:22 08:29 0.13 10,195 10,215 PROD1 DRILL DLOG P Log RA tag. (0.0'correction). 08:29 09:29 1.00 10,215 11,840 PROD1 DRILL WPRT P RBIH. RIW of 12-14k#from 11600-11800'. 09:29 12:14 2.75 11,840 11,990 PROD1 DRILL DRLG P Drill ahead 65-fph. Mud rates: 1.40-bpm in; 1.25-bpm out.4200-psi CTP;3975-psi BHP. 8.1k#pipe wt; 1.7k#WOB. 12:14 13:29 1.25 11,990 11,990 PROD1 DRILL WPRT P Wiper trip(#1)up to 10215'. (37k# off bottom). RIW 12k#through 11800-11990'. 13:29 15:14 1.75 11,990 12,140 PROD1 DRILL DRLG P Drill ahead 100-fph. Mud rates: 1.40-bpm in; 1.25-bpm out.4275-psi CTP;3990-psi BHP. 1.9k#pipe wt; 1.5k#WOB. 15:14 17:59 2.75 12,140 12,140 PROD1 DRILL WPRT P Wiper trip(#2)up to 10212'. (37k# off bottom). Swap out mud 17:59 19:44 1.75 12,140 12,290 PROD1 DRILL DRLG P Drill Ahead, 1.4 BPM in, 1.25 out, 4000 CTP,-2K CTW, 1-2K WOB 19:44 22:29 2.75 12,290 12,290 PROD1 DRILL WPRT P Wiper Trip to window,38K PUW, intial PU.Weight breaks back to 34K.Tie in depth to RA marker,0 Correction 22:29 23:59 1.50 12,290 12,440 PROD1 DRILL DRLG P Drill Ahead, 1.4 BPM in, 1.25 out. 4000 CTP,80 WHP,3965 BHP,-2K CTW, 12.4 ECD 04/29/2011 Drill A Lateral 12440-12614'.TD A Lateral 12614'. (Wiper trip to swab valves. RBIH to TD, POOH laying in liner running pill to build section. (10400'). Displace well to 12ppg KWF 10400'to surface. Perform BOPE function test.Total losses past 24 hours=86 bbrls,Cum losses for lateral=744 bbrls 00:00 02:30 2.50 12,440 12,440 PROD1 DRILL WPRT P Wiper Trip back to window,36K PUW 02:30 04:00 1.50 12,440 12,546 PROD1 DRILL DRLG P Drill Ahead, 1.4 BPM in, 1.3 out,-3K CTW, 1-2K WOB,4000 CTP,3966 BHP, 12.5 ECD. Pump 50bbrl lube pill 6%,attempt to minimize stacking surface weight. 04:00 04:30 0.50 12,546 12,546 PROD1 DRILL DRLG P PUH,stacking-7K CTW,without weight transfer, PU/RIH attempting to drill. 6%lube pill did not help stacking. 04:30 07:30 3.00 12,546 12,546 PROD1 DRILL WPRT P Unable to drill,Stacking-10K, Pull wiper trip to window. 36K PUW (8k# RIW just before back on bottom.) 07:30 09:00 1.50 12,546 12,614 PROD1 DRILL DRLG P Drill ahead 60-fph. Mud rates: 1.40-bpm in; 1.24-bpm out.4100-psi CTP;4018-psi BHP. 0-1.5k#pipe wt; 1.1k#WOB. Page 6 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 09:45 0.75 12,614 12,614 PROD1 DRILL DRLG P Stacking out again with no WOB. Attempt BHA wipers but unable to get back doen. PUH a couple hundred foot and attempt to RBIH. Unable to RBIH;stacking above with no WOB. PUH a couple hundred foot and try again. RBIH to bottom to attempt drilling. 09:45 10:15 0.50 12,614 12,614 PROD1 DRILL DRLG P On bottom again but unable to drill. PUH and time out low/high vis sweep to be at bit when back on bottom. Pump low/high sweep and pull swab wiper. 10:15 14:45 4.50 12,614 148 PROD1 DRILL WPRT P TD Lateral,Chase sweeps with wiper trip to swabs. 14:45 17:00 2.25 148 9,990 PROD1 DRILL WPRT P RBIH from surface 17:00 17:15 0.25 9,990 9,990 PROD1 DRILL DLOG P Tie in depth-7'correction 17:15 18:30 1.25 9,990 12,612 PROD1 DRILL WPRT P RIH to TD 18:30 19:00 0.50 12,612 12,612 PROD1 DRILL WPRT P Tag TD PU start pumping beads. Recip CT pumping beads to bit 19:00 23:00 4.00 12,612 10,300 PROD1 DRILL TRIP P POOH displace liner pill TD to landing point 10300', Displace KWF to surface POOH. 23:00 23:15 0.25 10,300 0 PROD1 DRILL OWFF P At surface, PJSM,Monitor well for flow 23:15 23:45 0.50 0 0 PROD1 DRILL PULD P LD lateral drilling BHA 23:45 00:00 0.25 0 0 PROD1 DRILL BOPE P Function test BOPE 04/30/2011 ✓ PU/MU Lower half"A"Liner. RIH setting on bottom 12612'. POOH. PU/MU"A"liner upper half. RIH,tag at 10755'.Stuck.Attempt to get free. 00:00 01:00 1.00 0 0 COMPZ CASING PUTB P RU floor to MU liner 01:00 03:15 2.25 0 0 COMPZ CASING PUTB P PU/MU 26 jnts of slotted Liner 03:15 06:45 3.50 903 12,614 COMPZ CASING RUNL P RIH 06:45 07:15 0.50 12,614 10,880 COMPZ CASING RUNL P Tag TD with liner segment#1. Set down 5k#surface, 1.44k#WOB. Come online pump 1.4-bpm, 4400-psi CTP. PUH 31 k#off bottom. No pull shown on WOB. All good. Stop and come offline pumping. Pump across top up to window. PUH. Liner placed 11,756'-12614'. 07:15 07:45 0.50 9,970 9,990 COMPZ CASING DLOG P Stop and correct depth to omit liner length. Tie-in. (-6'correction). 07:45 10:30 2.75 9,990 71 COMPZ CASING TRIP P POOH stopping at 9343.8'to flag pipe for OH. 10:30 10:45 0.25 71 71 COMPZ CASING SFTY P At surface,check well for flow. Conduct PJSM for lay down tools. Confirm no-flow again. 10:45 11:00 0.25 71 0 COMPZ CASING PULD P Lay down liner running tools. 11:00 11:15 0.25 0 0 COMPZ CASING SFTY P PJSM for making up liner. Page 7 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 12:15 1.00 0 0 COMPZ CASING PUTB P Make up liner segment#2 into hole for liner run. 19 jnts of solid liner,3 jnts of slotted liner, plus anchor-billet. 12:15 13:15 1.00 0 0 COMPZ CASING PUTB P Pick up liner segment#2. 13:15 14:00 0.75 0 751 COMPZ CASING PULD P Pick up anchor-billet, PU MWD. _ hang in slips. Skid Injector over well and make up tools. Make up to well, open rams and and tag stripper. 14:00 14:15 0.25 751 751 COMPZ CASING RUNL P Test MWD. Open EDC. 14:15 16:30 2.25 751 10,755 COMPZ CASING RUNL P RIH liner segment#2(BHA#9). 16:30 17:00 0.50 10,755 10,755 COMPZ CASING RUNL P Stopped at flag to correct depth. Calculate 18.8'correction. RIH to log RA marker for depth control. 17:00 18:00 1.00 10,755 10,755 COMPZ CASING RUNL T Stack weight-12K, unable to RIH. Attempt pull up a45k but unable to move. Stuck with shoe at 10755'. Total liner length=690.12'(Bull Nose to top of billet). OH anchor=10073.88'in well. 4' below TT in cement pilot hole. Aluminum billet is straddling tubing tail. EDC=10019'in wellbore. Note:Openhole anchor is limiting options. Cannot push or pull too much or will prematurely set permanent anchor in the cement pilot hole, leaving blank liner across the window and most of the productive interval. 18:00 22:00 4.00 10,755 10,755 COMPZ CASING CIRC T Pump KWF down backside equalizing diff.psi on BHA. .45 BPM, 368 WHP, PU 50K,-14K WOB.Still stuck. Discuss with Town,order mineral out from KIC. While waiting, mix up 6%lube pill in 8.6 ppg mud. 22:00 00:00 2.00 10,755 10,755 COMPZ CASING CIRC T Open EDC circ.5 BPM,4000 BHP, 13 ECD,5 bbl lube pill through EDC. Once displaced out EDC,close EDC,bullhead 3 bbl down backside displacing lube pill around BHA,try to pull free. Still stuck. 05/01/2011 Upper Section"A"Lateral liner with OH anchored billet stuck at 10755'bit depth..Multiple attempts to pull free. Swap well back to Flo-Pro,Spot 10bbrls mineral oil around liner and let soak 30 min. Pull free 50K. POOH, LD liner utilizing SSSV. Deploy BHA 10(.8 AKO w/DS331 mill. RIH to TOL#1,(11754')cleanout run. Dress cement pilot hole in transition/build section. RBIH, Lay in liner running pill TOL#1 to Tubing Tale (10071'). POOH Total Losses KWF=198 brls Total Losses FP=63 brls Total Losses well FP=807 brls Page 8 of 22 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 00:15 0.25 10,755 10,755 COMPZ CASING CIRC T 6%Lube pill displaced around liner. PU attempt to pull free.50K PUW, -14K WOB, RIH 7K CTW,8K WOB, No Luck Setting Tool limits with 15%Safety factor 13K Set down 20K PU 00:15 04:30 4.25 10,755 10,755 COMPZ CASING CIRC T Relax CT to neutral weight 21K CTW,Open EDC.Circulate well from 12.0 ppg KWF to 8.6 ppg Flo-Pro. 04:30 05:00 0.50 10,755 10,755 COMPZ CASING CIRC T Flo-Pro back to surface.Offline with pumps,close EDC, Line up and pump down backside with Flo-Pro attempt to pull free. No luck. Open EDC. 05:00 07:45 2.75 10,755 10,755 COMPZ CASING CIRC T Load mineral oil in pits. Circ 10-bbl mineral oil down CT through open EDC. Chase mineral oil with drilling mud. Spot mineral oil in well just outside tool. Close EDC and pump down the backside to move mineral oil down to liner portion in the open hole. 07:45 08:30 0.75 10,755 10,755 COMPZ CASING OWFF T Allow time for mineral oil to soak around liner/openhole interface. 08:30 09:00 0.50 10,755 9,999 COMPZ CASING PULL T Pull free with 48.8k#surface weight and-12.5k#WOB. PUH pumping down backside. 09:00 11:30 2.50 9,999 1,700 COMPZ CASING PULL T Open EDC. POOH BHA#9. 33k# pick up weight from 9999'. 11:30 12:00 0.50 1,700 1,700 COMPZ CASING OWFF T Stop at 1700'to close SSSV and perform drawdown test. Bleed down WHP in two iterations with no pressure increase and confirmed no-flow at surface. Watched well for +5-min and confirmed no flow. 12:00 12:30 0.50 1,700 781 COMPZ CASING PULL T POOH. No-flow check good. 12:30 12:45 0.25 781 781 COMPZ CASING SFTY T PJSM for laying down liner. Confirm no flow again. 12:45 13:45 1.00 781 0 COMPZ CASING PULD T Lay down BHA. 13:45 15:45 2.00 0 0 COMPZ CASING PUTB T Lay down liner. Cannot find any marks on liner or anchor-billet to indicate where we were stuck. 15:45 16:00 0.25 0 0 COMPZ CASING SFTY T PJSM for picking up tools and injector maintenance. 16:00 16:30 0.50 0 0 COMPZ CASING SVRG T Perform injector maintenance. 16:30 17:30 1.00 0 0 COMPZ CASING PULD T PU clean out BHA(BHA#10)with 0.8-deg AKO and 2.74"D331. 17:30 17:45 0.25 62 62 COMPZ CASING PULD T Check MWD tools and open EDC. 17:45 19:45 2.00 62 9,990 COMPZ CASING TRIP T RIH 19:45 20:00 0.25 9,990 10,000 COMPZ CASING DLOG T Tie in depth+8'correction Page 9 of 22 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 20:00 22:00 2.00 10,000 11,754 COMPZ CASING FCO T RIH to top of liner segment#1. Hole in good shape-no trouble getting to bottom. 22:00 00:00 2.00 11,754 11,754 COMPZ CASING WPRT T Lightly tag TOL#1 (11754.19'), Pump 10 bbrls Low/High vis pill chasing back to window. Dress cement pilot hole with 180 deg TF (10150-10071')at 5'/min.Clean-did not see any motor work. RBIH to TOL segment#1 at 11754.19'. 05/02/2011 PU/MU liner#2 utilizing SSSV. RIH releasing on depth, 11755',TOL#2 11071'. POOH, Undeploy BHA 11, Deploy BHA 12(1.0 AKO,with DS 331 mill). RIH,dress cement pilot hole. 00:00 03:00 3.00 10,755 1,800 COMPZ CASING TRIP T POOH displace liner running pill to tubing tale, POOH 03:00 04:15 1.25 1,800 0 COMPZ CASING TRIP T Close SSSV,flow check, POOH 04:15 04:45 0.50 0 0 COMPZ CASING SFTY T At surface, PJSM Monitor well for flow 04:45 06:30 1.75 0 0 COMPZ CASING PULD T LD cleanout BHA 10 06:30 06:45 0.25 0 0 COMPZ CASING SFTY T PJSM for picking up liner. 06:45 07:30 0.75 0 0 COMPZ CASING PUTB T Make up liner segment#2 minus the anchor-billet for liner run. 07:30 07:45 0.25 0 81 COMPZ CASING PUTB T Pick up liner segment#2. 07:45 08:00 0.25 81 729 COMPZ CASING PULD T PU MWD, hang in slips. Skid Injector over well and make up tools. Make up to well,open rams and and tag stripper. Make correction to depth for liner. 08:00 08:45 0.75 729 729 COMPZ CASING PULD T Tag up. Test MWD. Open EDC. Pressure up well. Close EDC. Open SSSV. 08:45 10:45 2.00 729 10,020 COMPZ CASING RUNL T RIH liner segment#2(BHA#11). 10:45 11:00 0.25 10,020 10,029 COMPZ CASING DLOG T Stop at flag. (Correction+9.4'). Weight check 35k#. Come offline pump. Close EDC. 11:00 11:15 0.25 10,029 10,755 COMPZ CASING RUNL T RIH with liner 11:15 11:40 0.42 10,755 11,754 COMPZ CASING RUNL P Continue RIH with liner 11:40 11:44 0.08 11,754 11,755 COMPZ CASING RUNL P Tag lightly and set down 3.5k# WOB. Came online 1.33-bpm 4300-psi Circ Pressure. Pull up out of liner with 32k#off bottom. TOL at • 11,070'MD. 11:44 12:04 0.34 11,755 10,849 COMPZ CASING TRIP P PUH. 12:04 12:13 0.16 10,164 10,189 COMPZ CASING DLOG P Stop and correct depth to reflect having left liner at depth. RIH to log RA marker. (0.0'correction). 12:13 14:28 2.25 10,189 0 COMPZ CASING TRIP P POOH. 14:28 14:43 0.25 0 0 COMPZ CASING TRIP P Tag stripper. Open EDC. 14:43 14:58 0.25 0 0 COMPZ CASING SFTY P PJSM for pressure undeploying liner running BHA#11. 14:58 16:28 1.50 0 0 COMPZ CASING PULD P Undeploy liner BHA#11. Page 10 of 22 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 16:28 17:58 1.50 0 0 PROD2 STK PULD T Deploy clean-out run BHA#12 17:58 18:28 0.50 0 0 PROD2 STK PULD T Crew change, PJSM, Perform injector maintenance. 18:28 20:28 2.00 0 55 PROD2 STK PULD T Undeploy BHA#12,change configuration of BHA as per town. Pull out string reamer,change AKO from 0.8 to 1.0 deg. Deploy BHA. 20:28 22:43 2.25 55 9,990 PROD2 STK TRIP T RIH, EDC closed(concern of Alpine beads strung out in wellbore). 22:43 22:58 0.25 9,990 9,990 PROD2 STK DLOG T Tie in depth with gamma,+10.5' _correction 22:58 23:58 1.00 9,990 10,085 PROD2 STK REAM T Dress Pilot hole: Differential 330psi, CTP 3850psi, Free Spin RIH,5 FPM to 10085',HS TF,Backream HS TF to 10064 1 FPM. 50psi increase motor work, 10085'on RIH,Clean on backream 34K PUW RIH,5 FPM to 10090',HS TF,Backream LS TF to 10064 1 FPM. 50psi increase motor work, 10085'on RIH,Clean on backream 34K PUW 05/03/2011 Dress cement pilot hole from 10,060-10,095 with 2.79"D331. Run dummy drift through pilot&Window- clean.Set OH Anchored billet from 11,070'-11,054'. POOH.24 hour losses=50 bbls Page 11 of 22 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 00:00 06:15 6.25 10,060 10,094 PROD2 STK REAM IT IDress Pilot Hole: Free spin diff psi 330,3900 CTP psi. *RIH at 5 fpm to 10087'at HS TF. Backream 90L TF to 10063'at 1 fpm. 50 psi increase motor work, 10080-10085'on RIH,50 psi increase backream. 34K PUW *RIH at 5 fpm to 10088'at HS TF. Backream 90R TF to 10062'at 1 fpm. 50psi increase motor work, 10080'-10085'on RIH,30psi increase backream. 34K PUW *RIH at 3 fpm to 10091'at 20R TF. Backream 160L TF at 1 fpm to 10061'. 70psi increase motor work, 10081'-10086'on RIH,40psi increase on backream. 34K PUW *RIH at 3 fpm to 10092'at 20R TF. Backream 170L at 1 fpm to 10060'. 45psi increase motor work, 10081'-10086'on RIH, 15 psi increase on backream 10075-10071'. At tubing tail observe 30psi increase. *RIH at 3 fpm to 10093'at 20R TF. Backream 150L TF at 1 FPM to 10059'. 50psi increase motor work, 10081-10086'on RIH, 15psi increase on backream to 10075'. *RIH at 3 fpm to 10094'at 20R TF. Backream 140L at 1 fpm to 10058'. 45psi increase motor work, 10081-10083'on RIH, Clean on backream. *RIH at 3 fpm to 10095'at 20R TF. Backream 160R TF at 1 fpm to 10057'. 40psi increase motor work, 10081-10084'on RIH. Clean on backream. *RIH at 3 fpm to 10096'at HS TF. Backream 160L TF at 1 fpm to 10056'. 50psi increase motor work, 10082-10085'on RIH,Clean on backream 06:15 06:30 0.25 10,094 10,055 PROD2 STK REAM T PUH to 10055'. Dry drift transition 10055-10190'. Observed 350#WOB down through 10085'and-170# _picking up through 10085'. 06:30 08:45 2.25 10,055 0 PROD2 STK TRIP T POOH. 08:45 09:00 0.25 0 0 PROD2 STK PULD T At surface. Space out 1.9'. Open EDC. 09:00 09:15 0.25 0 0 PROD2 STK SFTY T Conduct PJSM for undeploy BHA #12. 09:15 10:00 0.75 0 0 PROD2 STK PULD T Undeploy reaming BHA#12. Perform injector maintenance. 10:00 10:15 0.25 0 0 PROD2 STK SFTY T PJSM to deploy drift run for anchored billet(BHA#13). Page 12 of 22 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 10:15 11:45 1.50 0 0 PROD2 STK PULD T Deploy BHA#13. Close EDC. Continue injector maintenance. 11:45 12:50 1.09 0 9,999 PROD2 STK TRIP T RIH drift BHA(BHA#13). 12:50 12:59 0.16 9,999 10,026 PROD2 STK DLOG T Log RA marker(+9.0'correction). Weight check: 31k#. 12:59 13:14 0.25 10,026 10,161 PROD2 STK TRIP T Drift 10,026.23'through 10,161.2'. Looked good. 13:14 16:29 3.25 10,161 0 PROD2 STK TRIP T POOH. 16:29 16:44 0.25 0 0 PROD2 STK SFTY T At surface, PJSM 16:44 18:14 1.50 0 0 PROD2 STK PULD T Undeploy drift BHA 18:14 19:59 1.75 0 77 PROD2 STK PULD T Deploy BHA#14 with Anchor-Billet& BOT J-setting sleeve. 19:59 22:59 3.00 77 9,990 PROD2 STK TRIP T RIH with EDC open pumping .3 bpm hoplding MPD.Weight check 37K, Close EDC&tie in with+9.5 ft. RIH to 11070'Tag TOL 22:59 23:29 0.50 11,070 11,054 PROD2 STK ANCR T Orient 190 ROHS. Bring pumps up to 4700 psi.Set Billet WOB increased to 12K. P/U weight 38K, pump.8 bpm while POOH. Top of billet ate, 11,054'MD. 23:29 23:59 0.50 11,054 9,500 PROD2 STK TRIP T Pull through window HS,re-set counter. POOH following MPD. 05/04/2011 POOH laydown BHA#14,notcied damaged pipe above CT connector.Cut off 15 ft of CT,re-head. P/U BHA# 15 with 1.0 AKO&RR Bi-center for KO. KOTB @ 11,054'. Initial problems with slip sticking and pressures. Continue drilling build section after successful)billet exit.77 bbl losses for 24hours. 00:00 02:00 2.00 9,500 60 PROD2 STK TRIP T POOH following MPD 02:00 04:00 2.00 60 0 PROD2 STK PULD T PJSM-Undeploy BHA#14. Small indents noticed in pipe at surface on bottom side. Inspect injector chains ✓ for debris. 04:00 06:00 2.00 0 0 PROD2 STK SLPC T Found a couple of small shims and pieces of CT stringers in chains. Inspect CT above coil connector and found gouges in pipe from chains during deployments.Cut off damaged CT,total of 15ft.Start heading up CTC. 06:00 06:30 0.50 0 0 PROD2 STK SFTY T Crew change PJSM 06:30 08:00 1.50 0 0 PROD2 STK SLPC T Head up CTC and BHI drilling head, Pull test and psi test CTC 08:00 10:00 2.00 0 0 PROD2 STK SLPC T Head did not test, Rehead CTC and BHI drilling head, Pull test and psi test.40K,4500psi 10:00 11:30 1.50 0 0 PROD2 STK PULD P Deploy BHA 15(1.0 AKO with Hughes rerun Bi-center) 11:30 14:00 2.50 62 9,990 PROD2 STK TRIP P RIH 14:00 14:15 0.25 9,990 9,990 PROD2 STK DLOG P Tie in depth+8'correction 14:15 14:45 0.50 9,990 11,055 PROD2 STK TRIP P RIH to ST 14:45 15:00 0.25 11,055 11,055 PROD2 STK TRIP P Dry tag TOB. 11054.6' Page 13 of 22 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 15:00 18:00 3.00 11,055 11,054 PROD2 STK KOST P 1 fph for 1'. Stall several times due to slip sticking. Dry tag TOB once again. 10053.5'.Try to start milling, pump 6%lube pill, no change. 18:00 20:00 2.00 11,054 11,055 PROD2 STK KOST P Start to get weight transfer to bit, Start milling,pressures slightly higher than normal, 1.40 bpm, 3880psi, BHP 4240,WHP 0..-WOB transfer problems after 2 ft drilled,Al. Shavings to surface.3 tries with slip sticking. Do a 100ft wiper.Overpull 25ft up. 20:00 20:45 0.75 11,055 10,070 PROD2 STK WPRT T P/U 100ft-overpull-40K. Start working string P/U weight 45K- possibly getting differentially stuck. losing returns,Trap WHP before coming down on pump to 400 psi. Popped free-continue to wiper )14-141,1' pumping 1.3 bpm,circ 3900 psi, .9 y bpm out,WHP 0, BHP 4300,open choke to zero.Still pulling heavy. Annular bled down to 4000 psi, Rate out 1.30 bpm.Circ press 3600 psi. normal pressures after 10,480ft. 20:45 21:30 0.75 10,070 11,056 PROD2 STK WPRT T Wiped into cased hole-10,030'- During wiper had heavy blobs of slick pill roll over the shakers with Al. Shavings suspended in viscious pill. RIH,clean drift through cement& window.Tie into PIP tag+1ft correction. 21:30 22:48 1.30 11,056 11,070 PROD2 STK KOST P Milling ahead-much better WOB& pressures-1.35 BPM,3600, BHP 3980, ECD 12.4,WOB.8K,CT weight 14K,smooth milling. Increase speed @ 11059'. Drillling ahead additional 30 ft. 22:48 23:12 0.40 11,070 11,085 PROD2 STK KOST P Started to get light cement over shakers-possibly from clean out runs.-IA=390/OA=300, PH= 9.7,density of sample=11.4. Continue drilling ahead to 11085'- Drift Billet-clean. Returns cleaning up. 23:12 00:00 0.80 11,085 11,139 PROD2 DRILL DRLG P Drilling ahead-1.35 bpm,3800, BHP 3980, ECD 12.4, ROP 80,WOB 1.6k,CT weight 12K, returns 1.25 bpm. 05/05/2011 BOP test state witness waived by Lou Girmaldi. Deploy BHA#15-RSM with 2.73"Braised Bi-center.46 bbls losses for 24 hours. 00:00 01:00 1.00 11,139 11,210 PROD2 DRILL DRLG P Drilling ahead 01:00 02:15 1.25 11,210 11,210 PROD2 DRILL WPRT P Wiper trip 35K off bottom 02:15 04:15 2.00 11,210 11,355 PROD2 DRILL DRLG P Drilling ahead-1.35 bpm,3890, BHP 4030, ECD 12.6, ROP 80,WOB 1.8K,Ct weight 12K Page 14 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 08:15 4.00 11,355 0 PROD2 DRILL WPRT P Wiper trip-36K, Min. pump rate through window&cement pilot. Open EDC above pilot&POOH for BHA change and BOPE test. 08:15 08:30 0.25 0 0 PROD2 DRILL SFTY P At surface, PJSM. 08:30 10:30 2.00 0 0 PROD2 DRILL PULD P Undeploy lateral BHA#14 10:30 12:00 1.50 0 0 PROD2 DRILL SVRG P Prepare for BOPE test,Grease rig valves and tree valves �� 12:00 18:00 6.00 0 0 PROD2 DRILL BOPE P Test BOPE.Witness waived by Lou Grimaldi. 18:00 22:00 4.00 0 0 PROD2 DRILL BOPE P BOPE test completed. No failures. 22:00 23:00 1.00 0 0 PROD2 DRILL CIRC P Circulate flo-pro through CT string. Flush MP choke system as grease and debris plugged it off. 23:00 00:00 1.00 0 68 PROD2 DRILL PULD P Deploy BHA#15 with RSM& Hughes bi-center bit. 05/06/2011 Drilled ahead AL1 lateral.83 bbl losses for 24 hours. 00:00 00:30 0.50 68 68 PROD2 DRILL PULD P Complete deploying BHA#15 00:30 04:00 3.50 68 11,357 PROD2 DRILL TRIP P RIH pumping.5 bpm following MPD. Stop pumping,close EDC.Tie in @ 10,000 ft with+9 ft correction. P/U weight 36K. Clean drift throug cement&window, pump.3 bpm through build. Empty single pit of old mud for mud swap on bottom. 04:00 05:00 1.00 11,357 11,400 PROD2 DRILL DRLG P Drilling ahead-start pumping new mud-1.35 bpm,3800psi, BHP 4010, ECD 12.5, ROP 80,CT weight 7K, WOB2K, rate out 1.25 bpm. 05:00 07:45 2.75 11,400 11,515 PROD2 DRILL DRLG P Drilling ahead-new mud around- 1.40 bpm,3850, BHP 3900, ECD 12.2, ROP 20,WOB 2.4K,Ct weight 6K, rate out 1.33 bpm. 07:45 09:15 1.50 11,515 11,515 PROD2 DRILL WPRT P Wiper trip to window, 36K PUW, MADD pass 11380-11060'. 09:15 10:45 1.50 11,515 11,560 PROD2 DRILL DRLG P Drill ahead, 1.35 BPM in, 1.27 BPM out,4000 CTP,3900 BHP, 12.2 ECD,2K WOB,8-9K CTW. 10:45 12:15 1.50 11,560 11,560 PROD2 DRILL WPRT P BHA wiper 36K PUW 12:15 14:30 2.25 11,560 11,665 PROD2 DRILL DRLG P Drill ahead, 1.35 BPM in, 1.27 BPM out,4000 CTP,3900 BHP, 12.2 ECD,2K WOB,8-9K CTW. 14:30 16:30 2.00 11,665 11,665 PROD2 DRILL WPRT P Wiper trip to window 16:30 19:00 2.50 11,665 11,815 PROD2 DRILL DRLG P Drill ahead, 1.35 BPM in, 1.27 BPM out,4000 CTP,3900 BHP, 12.2 ECD,2K WOB,8-9K CTW. 19:00 21:00 2.00 11,815 11,815 PROD2 DRILL WPRT P Wiper trip-P/U weight 38K.Tie in-1 ft correction 21:00 23:00 2.00 11,815 11,965 PROD2 DRILL DRLG P Drilling ahead-1.38 bpm,3720, BHP 3900, ECD 12.3, ROP 80,WOB 1.7K,CT weight 6K, rate out 1.30 bpm. 23:00 00:00 1.00 11,965 11,965 PROD2 DRILL WPRT P Wiper trip-P/U weight 36K Page 15 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/07/2011 24 hr Summary Continue drilling ahead on AL1 lateral with RSM&2.73"Bi-center. Having weight transfer issues,pump 5/5 low/hi.h sweeps and wiper trips every 100'instead of 150'.74 bbl losses for 24 hours. 00:00 01:30 1.50 11,965 11,965 PROD2 DRILL WPRT P Wiper trip. Losing roughly 4 to 5 bbls/hour. 01:30 03:30 2.00 11,965 12,100 PROD2 DRILL DRLG P Drilling ahead-1.37bpm,3680, BHP 3950, ECD 12.4, ROP 90,WOB 1.4, CT weight 8K, rate out 1.30 bpm. Drilling depth of 12,090'notice clayballs over shakers in samples. Started to stack weight last 5ft. P/U 40K-broke over for wiper. 03:30 06:00 2.50 12,100 12,100 PROD2 DRILL WPRT P Wiper trip to window-37K-clean wiper. Losing 4 bbls/hour. 06:00 07:30 1.50 12,100 12,193 PROD2 DRILL DRLG P Drill Ahead 1.34 BPM in, 1.26 BPM out,4080 CTP,4000 BHP,7-8K CTW, 1-2K WOB, 12.5 ECD 07:30 07:36 0.10 12,193 12,193 PROD2 DRILL WPRT P Stacking CT surface weight, lose motor work and WOB. PU BHA wiper 40K PUW. 07:36 08:06 0.50 12,193 12,219 PROD2 DRILL DRLG P Drill Ahead 1.34 BPM in, 1.26 BPM out,4100 CTP,4000 BHP,5-6K CTW, 1.5K WOB, 12.5 ECD 08:06 09:36 1.50 12,219 12,219 PROD2 DRILL WPRT P Stacking CTW.41K PUW,CTW breaks back to 34K. Pump low/high vis sweeps. Unable to get back to bottom,stacking. PUH to 11400' wiping through sump in A4 silt. Increase lubes in high vis sweeps 2%776,2%Low Torq. Wiper to 11400'did a lot of good-improved weight transfer and reduced annular pressure by 100 psi. Able to get back to drilling. 09:36 10:15 0.65 12,219 12,265 PROD2 DRILL DRLG P Drill Ahead 10K CTW,3900 CTP, 3950 BHP,90 FPH 10:15 13:00 2.75 12,265 12,265 PROD2 DRILL WPRT P Wiper trip to window,39K PUW, chasing Low/High sweeps Out of OH,Tle in depth to RA marker-4' correction. 13:00 14:45 1.75 12,265 12,365 PROD2 DRILL DRLG P Drill Ahead 10K CTW,3900 CTP, 3950 BHP,90 FPH 14:45 17:15 2.50 12,365 12,365 PROD2 DRILL WPRT P Wiper trip 37K PUW,chasing low/High sweeps. Begin making wiper trips every 100'due to overpulls &trying to packoff. 17:15 19:00 1.75 12,365 12,465 PROD2 DRILL DRLG P Drill Ahead 10K CTW,3900 CTP, 3950 BHP,90 FPH, Pump Low/high prior to 100'drilled. 19:00 21:30 2.50 12,465 12,465 PROD2 DRILL WPRT P Wiper trip chasing sweep-P/U weight 36K, Hold 50 psi on choke during wiper to hold recommended MPD. Page 16 of 22 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 21:30 23:00 1.50 12,465 12,527 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3800, BHP 3990,WHP 0, ECD 12.6, ROP 70, WOB 1.6,CT weight 7K. Pump sweeps @ 12520'-weight stacking. Losing prime, BHA wiper-could not RIH due to weight stacking. P/U 44K,broke over to 36K.Wiper while sweep is coming around. 23:00 00:00 1.00 12,527 12,527 PROD2 DRILL WPRT P Wiper up to 11,200 ft,noticed annular dropped from 3920 to 3800' during wiper. RIH clean @ 14K CT weight. 05/08/2011 Continue to drill AL1 lateral. Mud swap with 1200ft on system. POOH for agitator BHA due to WOB&CT weight transfer.33 bbl losses for 24hours. 00:00 00:30 0.50 12,527 12,527 PROD2 DRILL WPRT P Wiper trip from 11,200ft 00:30 02:00 1.50 12,527 12,591 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3700, BHP 4010, ECD 12.6, ROP 80,WOB 1.6, CT weight 8K. Lo-vis sweep at bit @ 12580'.WOB&ROP increase for a brief time and then stacked out. 02:00 05:00 3.00 12,591 12,591 PROD2 DRILL WPRT P Wiper trip 37K P/U&prepare pits for Mud swap.Tie in with-4 ft correction. Mud swap at the end of the wiper with 1200 ft on old system. 05:00 08:00 3.00 12,591 12,737 PROD2 DRILL DRLG P h -new m i -1 4 Drilling ahead a mud at bit 0 9 bpm,3880, BHP 4030, ECD 12.5, ROP 88,WOB 1K,CT weight 6K. 08:00 11:15 3.25 12,737 12,737 PROD2 DRILL WPRT P Wiper trip to window 41K PUW 11:15 11:45 0.50 12,737 12,760 PROD2 DRILL DRLG P Drilling ahead-new mud at bit-1.40 bpm,3880, BHP 4030, ECD 12.5, ✓ ROP 88,WOB 1K,CT weight 6K. 11:45 12:15 0.50 12,760 12,760 PROD2 DRILL WPRT P Stacking, PU Pump low/high sweeps. 12:15 12:45 0.50 12,760 12,781 PROD2 DRILL DRLG P Drill Ahead,2-3K CTW,Stacking 12:45 13:15 0.50 12,781 12,781 PROD2 DRILL WPRT P PU,40K, BHA wiper,Sweeps at bit. RIH to drill 13:15 13:24 0.15 12,781 12,791 PROD2 DRILL DRLG P Drill Ahead, Ribs off on RSM to get drilling, 1.4 in, 1.3 out, 1K WOB,6K CTW,3380 CTP,3980 BHP 13:24 13:33 0.15 12,791 12,791 PROD2 DRILL WPRT P Stacking PUH,41K. Building Low sweeps 13:33 14:48 1.25 12,791 12,870 PROD2 DRILL DRLG P Drill ahead, 3K CTW,3897 CTP, 3960 BHP 14:48 19:30 4.70 12,870 12,870 PROD2 DRILL WPRT P Stacking, PU,41K PUW. POOH to PU agitator 19:30 21:30 2.00 12,870 68 PROD2 DRILL PULD P PJSM-undeploy RSM BHA#16 Page 17 of 22 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 23:30 2.00 0 78 PROD2 DRILL PULD P Pressure deploy BHA#17 with 2-1/8" agitator&2.73"Bi-center.Apply 900 psi prior to opening the rams,and observed an increase in injector weight to 22K(pipe tension). BHA still communicating but decision to Undeploy BHA to change EDC. Injector 1/4"gap is noticed below the pack off-connecting to the riser. Note:Appears that there was some kind of movement in the stripper/Bowen connection. Applying WH pressure(900 psi)was acting upon the stripper to put the BHA in tension. 23:30 00:00 0.50 78 0 PROD2 DRILL PULD T PJSM-Undeploy BHA& troubleshoot 1/4"gap under pack-off assembly. ***0.5 hour billable rig repair rate*** ill 05/09/2011 Deploy BHA#18 with agitator&2.73"bi-center bit. Had downtime with injector risers&weight transfer at surface. RIH&TD AL1 lateral @ 13,180ft. Pull wiper to swab valves.80 bbls lost to formation 24/hours. 00:00 01:00 1.00 0 0 PROD2 DRILL PULD T Undeploy BHA to replace EDC& inspect 1/4"gap below pack-off assembly.lay BHA down out of the way. 01:00 03:30 2.50 0 0 PROD2 DRILL RGRP T Screw the threads back up into the pack off assembly. Inspect CT& pack off rubbers.Stab on well&test. Move injector back to run&test. 03:30 06:00 2.50 0 78 PROD2 DRILL PULD T Deploy BHA#18 with 2 1/8" agitator,0.8 deg Xtreme motor& 2.73"bi-center. Injector back on well, zero weight indicator&tighten bottom 7"riser bowen above annular. Weights look better. ***6 hour billable rig repair rate*** li 06:00 09:00 3.00 78 10,000 PROD2 DRILL TRIP P RIH 09:00 09:06 0.10 10,000 10,000 PROD2 DRILL DLOG P Tie in depth with gamma, +10' correction 09:06 10:36 1.50 10,000 12,870 PROD2 DRILL TRIP P RIH to drill 10:36 13:36 3.00 12,870 13,030 PROD2 DRILL DRLG P Drill Ahead 1.3 in, 1.2 out,3940 CTP,4000 BHP, 50-70 FPH,5-8K CTW 13:36 17:06 3.50 13,030 13,030 PROD2 DRILL WPRT P Chase low/high sweeps back to window 17:06 20:36 3.50 13,030 13,180 PROD2 DRILL DRLG P Drill Ahead 1.3 in, 1.2 out,3940 CTP,4000 BHP,50-70 FPH,5-8K CTW. Pump low/high sweep on bottom. TD lateral at 13,180'. 20:36 00:00 3.40 13,180 8,000 PROD2 DRILL WPRT P Wiper trip P/U weight 39K.pump second sweep at window to flush cased hole while tripping to swab valves. Page 18 of 22 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 05/10/2011 24 hr Summary Wiper trip to swab valves, Lay in beaded liner running pill, lay in KWF to surface. BHA pulled off coil at surface. Start BHA recovery ops 00:00 02:00 2.00 8,000 68 PROD2 DRILL TRIP P Trip to swab valves to clean out cased hole, light to med cuttings while POOH.Open EDC at surface. No significant cuttings at surface. 02:00 06:00 4.00 68 13,180 PROD2 DRILL TRIP P Reset counters-RIH following MPD pumping 1.2 bpm through EDC.Tie in+8.5 ft.Close EDC-RIH 06:00 11:00 5.00 13,180 0 PROD2 DRILL DISP P POOH laying in Liner running pill, and 12.0 ppg NaBr KWF to surface 11:00 14:00 3.00 0 0 PROD2 DRILL RGRP T While tagging up at surface the injector applied--85K pounds of pull to the coiled tubing and pulled the coil connector out of the pipe. The driller did not recognize that the BHA had been lost and continued oullina OOH, pulling the coiled tubing out of the infector chains. Secure CT, RD injector. ***Start nabors downtime,first 5.5 hours are billable, next 7.5 hours are non-billable*** 14:00 16:00 2.00 0 0 PROD2 DRILL SLKL T Slick line crew on location. PJSM for RU,spot equipment. Rig crew remove Pack offs&stuffing box 16:00 18:30 2.50 0 0 PROD2 DRILL SLKL T R/U Slick Line. Hold additional PJSMs with incoming night crew 18:30 19:30 1.00 0 0 PROD2 DRILL SLKL T PJSM-P/T S/L Lubricator 19:30 22:45 3.25 0 10,114 PROD2 DRILL SLKL T RIH with 3 1/2 GR spear pulling tool, 3 1/2 Bait sub,overshot with 1.55 grapple,Set down and jar down @ 10114'SLM PUH and oil jars fired @ 10086, PUW=1450 after engaging fish. 700Lbs before, POOH 22:45 23:09 0.40 10,114 0 PROD2 DRILL SLKL T PJSM while flow checking well. Pull S/L lubricator and catch fish in C-Plate Stand back slick line equipment 23:09 00:00 0.85 0 0 PROD2 DRILL PULD T Lay down BHA#18.All tools recovered except upper E-Line anchor mandrel(2"long x 0.75" diameter) 05/11/2011 Recovered all BHA componets except for e-line anchor in Upper Quick Connect. Replace injector skates, Fish for E-Line anchor with slickline.Test repairs to injector 00:00 00:30 0.50 0 0 PROD2 DRILL PULD T Complete Blow down/lay down BHA #18 ***Continue nabors downtime,24 hours of non-billable rig repair time*** 00:30 12:30 12.00 0 0 PROD2 DRILL RGRP T Begin injector skate R&R 12:30 14:54 2.40 0 0 PROD2 DRILL RGRP T Injector repairs completed, restab CT Page 19 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:54 15:12 0.30 0 0 PROD2 DRILL SFTY T PJSM,slickline operations 15:12 16:18 1.10 0 0 PROD2 DRILL SLKL T MIRU Haliburton slickline 16:18 16:36 0.30 0 0 PROD2 DRILL SLKL T Function test BOP rams. Check for fish on top of closed swab valve,no luck 16:36 19:36 3.00 0 10,160 PROD2 DRILL SLKL T PT lubricator, RIH with 2.60 magnet, Recip through all GLM 19:36 20:06 0.50 10,160 0 PROD2 DRILL SLKL T At surface, No fish on magnet. reconfig magnet to double knuckle to allow magnet to get into belly down GLM's 20:06 21:36 1.50 0 3,000 PROD2 DRILL SLKL T PT lubricator, RIH.Get down to 3000', unable to continue in hole, POOH to repack stuffing box 21:36 22:36 1.00 3,000 0 PROD2 DRILL SLKL T At surface replace slick line packing, 22:36 00:00 1.40 0 7,000 PROD2 DRILL SLKL T PT Lubricator, RIH with double knuckle 2.6"magnet 05/12/2011 Run magnet on slickline to recover E-Line Anchor, No Fish after two runs. Perform slack management, M/U BHA#19 FCO and RIH 00:00 01:30 1.50 7,000 10,160 PROD2 DRILL SLKL T Continue to run double knuckle 2.60" magnet to 10160', POOH ***Continue nabors downtime, 3 hours of non-billable rig repair time*** 01:30 01:54 0.40 10,160 0 PROD2 DRILL SLKL T Slickline at surface, No fish on magnets 01:54 03:00 1.10 0 0 PROD2 DRILL SLKL T Rig down Slickline unit 03:00 04:15 1.25 0 0 PROD2 DRILL SLPC P PJSM-Prep for slack mgmt,test wire-good test,boot wire,stab on ***Nabors back on regular rig rates*** 04:15 05:15 1.00 0 0 PROD2 DRILL SLPC P Circ coil to water, Unstab and ensure wire is up in coil, line up and reverse circ coil 05:15 08:03 2.80 0 0 PROD2 DRILL SLPC P Reverse circulate to pump slack,cut coil to find wire.Cut 98'(+22'cut previously=-120'entered in cerberus) 08:03 10:48 2.75 0 0 PROD2 DRILL SLPC P Test e-line. Install CTC and pull test. 10:48 11:48 1.00 0 0 PROD2 DRILL SFTY P Safety meeting to discuss recent incidents. 11:48 13:18 1.50 0 0 PROD2 DRILL CIRC P PT CTC and UQC,circulate coil back to KWF 13:18 15:00 1.70 0 0 PROD2 DRILL PULD T MU FCO assembly with 0.8 deg. motor and 2.74"D331 mill 15:00 17:30 2.50 0 5,356 PROD2 DRILL TRIP T RIH with FCO assembly 17:30 19:00 1.50 5,356 5,356 PROD2 DRILL SFTY P Hold 2010 end-of-year results meeting with Dan Venhaus with day and night crews. Pre-tower meeting in Dog house with incoming night crew 19:00 20:00 1.00 5,356 9,985 PROD2 DRILL TRIP T Continue trip in well Page 20 of 22 y Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 20:00 20:06 0.10 9,985 10,011 PROD2 DRILL DLOG T Log gamma tie in for+16.5' correction 20:06 22:21 2.25 10,011 10,000 PROD2 DRILL CIRC T PUH and circulate well to 8.6 ppg Flopro mud. Lost 15 bbl of 12.0 ppg KWF during recovery. 22:21 00:00 1.65 10,000 12,807 PROD2 DRILL FCO T RIH for FCO,Good pass through window No problem past billet @ 11054 Midnight Depth 12807 05/13/2011 Run FCO BHA to TD, Pump sweeps,condition hole, Lay in beaded liner pill/KWF while tripping out.M/U and run lower liner section to 13180' 00:00 00:15 0.25 12,807 13,177 PROD2 DRILL FCO T Continue running to bottom 00:15 02:39 2.40 13,177 10,190 PROD2 DRILL FCO T Clean run to bottom @ 13177. Sweeps at mill,Chase to window PUW=46K. Had slight overpull @ 10,546' 02:39 02:45 0.10 10,190 10,206 PROD2 DRILL DLOG T Log RA marker for no correction 02:45 04:15 1.50 10,206 13,168 PROD2 DRILL FCO T Run back to bottom,clean trip. hole looks good 04:15 08:42 4.45 13,168 0 PROD2 DRILL TRIP T POOH laying in beaded liner pill followed by KWF. Paint EOP Flags @ 10,900 and 7900 08:42 08:54 0.20 0 0 PROD2 DRILL SFTY P PJSM 08:54 10:06 1.20 0 0 PROD2 DRILL PULD P Lay down BHA 10:06 11:54 1.80 0 0 COMPZ CASING PUTB P Rig up floor for liner operations. Start PU liner string 11:54 12:24 0.50 0 0 COMPZ CASING SFTY P Crew change out, PJSM 12:24 15:12 2.80 0 2,125 COMPZ CASING PUTB P Continue PU liner string,63 Joints slotted liner. 15:12 16:54 1.70 2,125 2,125 COMPZ CASING PULD P MU coiltrac tools and injector. While MU quick connect on coiltrac tools a lower connection backed off. Move injector,pull coiltrac tools up and re-torque connections. 16:54 19:24 2.50 2,125 9,898 COMPZ CASING RUNL P RIH with liner 19:24 20:00 0.60 9,898 9,898 COMPZ CASING SVRG P Stop and test/troubleshoot injector brakes 20:00 20:30 0.50 9,898 10,009 COMPZ CASING RUNL P RIH to flag depth, Make +16.1' correction 20:30 22:15 1.75 10,009 13,181 COMPZ CASING RUNL P Continue running liner to bottom @ 13181,set down 2500 Lbs. PUW=35K, Pump off deployment sleeve, POOH. 22:15 22:30 0.25 13,181 10,192 COMPZ CASING DLOG P Remove Liner length left in hole, -2081.23,tie into RA marker for a -1.5'correction, BOL=13180',TOL lower section=11098.7 Page 21 of 22 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 22:30 00:00 1.50 10,192 5,400 COMPZ CASING TRIP P POOH, Keeping hole full across the top, Paint EOP flags @ 9000& 10000 Midnight depth 5400' 05/14/2011 Complet running liner, F/P well, RDMO, Rig Release 20:00 00:00 01:30 1.50 5,400 140 COMPZ CASING TRIP P Continue tripping out of well 01:30 01:36 0.10 140 78 COMPZ CASING TRIP P PJSM, Raise injector,bring CTC to surface 01:36 01:54 0.30 78 0 COMPZ CASING PULD P Lay down BHA#20 AL1 Lower liner section running tools 01:54 04:54 3.00 0 0 COMPZ CASING PUTB P PJSM, P/U AL1 Liner Upper section 04:54 05:54 1.00 0 0 COMPZ CASING PULD P PJSM, P/U Coil track,M/U to liner 05:54 06:18 0.40 0 1,078 COMPZ CASING SFTY P Crew change and PJSM 06:18 09:54 3.60 1,078 11,100 COMPZ CASING RUNL P RIH,correct to EOP flag,+14.4'. Weight check, 37K PUW(-6K WOB). Continue RIH. Set liner and PUH to log K1. Liner top at 10064'. 09:54 11:00 1.10 11,100 10,000 DEMOB WELLPF DISP P Displace KWF with SW 11:00 13:18 2.30 10,000 0 DEMOB WELLPF FRZP P POOH. FP from 2500'with diesel. 13:18 14:06 0.80 0 0 DEMOB WELLPF PULD P Lay down liner running BHA 14:06 15:36 1.50 0 0 DEMOB WHDBO NUND P Set BPV 15:36 17:06 1.50 0 0 DEMOB WHDBO DMOB P Blow down coil and surface lines 17:06 20:00 2.90 0 DEMOB WHDBO DMOB P Nipple down, rig down,move out ***Rig Release 20:00****** L_ Page 22 of 22 2K-19A Well Summary DATE` SUMMARY 5/17/11 GAUGED TBG TO 2.75"TO LINEN. ,JP @ 10065' RKB. IN PROGRESS. 5/18/11 MEASURED BHP @_ 10000' RKB: 3509 PSI. SET CATCHER @ 10065' RKB. PULLED DV @ 9298', SET OV @ 9298' RKB. IN PROGRESS. 5/19/11 PULLED DVs @ 8576', 7833', 7061', 5529' RKB. SET GLVs @ 8576', 7833', 7061' RKB. IN PROGRESS. 5/20/11 PULLED DV @ 2674' RKB. SET GLVs @ 5529', 2674' RKB. PULLED CATCHER @ 10065' RKB. COMPLETE. Letter of Transmittal BAKER Date: May 16, 2011 HUGHES To: From: Christine Mahnken Carl Ulrich/ Sachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave Suite 100 795 East 94th Avenue Anchorage,Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2K-19A 2K-19AL1 (2) total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files RECEIVED �i $ p)fl Alaska OIE® Cone.Geli1111i/Siell Antge Note: Please feel free to send us an email in place of return mail. Sachin Gandra, Baker Hughes Operations Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes Survey Manager Carl.Ulrich@BakerHughes.com Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, April 29, 2011 10:00 AM To: 'Eller, J Gary' Cc: Gantt, Lamar L e7-6 Subject: RE: Approval to Change KOP in 2K-19AL1 (211-035) 21/-o31 Gary, Per our conversation, please submit a revised PTD application for 2K-19AL1 (PTD 211-035). You have verbal approval to proceed with 2K-19AL1 as we discussed and is outlined below. The new well trajectory will include the new proposed kickoff point at 11055' and the "possible" new BHL target if you think you can replace AL2 lateral. Please get the revised to the Commission by Monday (next working day) as stated in 20 AAC 25.005 (a) Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Friday, April 29, 2011 9:20 AM To: Schwartz, Guy L (DOA) Cc: Gantt, Lamar L Subject: Approval to Change KOP in 2K-19AL1 (21-035) Guy—Good morning. As we discussed earlier, I'd like to change the planned KOP of the 2K-19AL1 lateral (211- 035) in order to better contact the Kuparuk A4 pay. We want to move our KOP to 11,055' MD instead of the original plan of 12,350' MD. Proposed TD would remain unchanged. As is common with these Kuparuk CTD laterals, the map view will be practically identical to what was previously proposed—we should remain within 100' of the original approved well plan. The attached slides perhaps better show what I'm describing. The first slide shows a geologic cross-section for the 2K-19A sidetrack plus the AL1 and AL2 laterals in dashed lines. The second slide shows our current geologic interpretation and well status. By moving the AL1 kickoff point to 11,055' MD, we pick up a significant amount of A4 pay that was missed with the 'A' sidetrack. It's possible(but not at all certain)that we can meet our geologic objectives with this AL1 lateral such that we won't need to drill the AL2 lateral, but that remains to be seen. I think the bottom line is whether we can amend the 2K-19AL1 KOP via verbal approval or whether a new PTD is needed. If a new PTD is required, then we'll need AOGCC authorization to continue uninterrupted drilling operations over the weekend until I can provide you with a written PTD. Please call if we need to discuss any of this. 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1158 4/29/2011 * I �pj O O Q� O O u--) O O LC> U U? U M' H' CC' M i 1 l 1 1 .._ _.,i J - _ M \ 0 . _ _ _ _. 0 CI i g N - J M N - _ '- in J oM Cr) 0- r `�LC, t 'NSo r I • • M o Z N - ° � ^ Q = _ II 'I—o Q CV a J $ o 0 ai N C csi N Qr - - 2 O___ __- , ..................-,� '' o 0 JN .43 an0 ..=. � N � O Q o- a r- o C7 0 0 2 1 Y - . N _ _ W \' a = N. —0 7 o 0 O o- - IL lA in o - - a 0 0 0' s o -o IF__ I I O.=.--- .+ 1 1 1 1 m 0 y d 0 , O v m 0 1- c cC 7 0 W m N 0 2 I I I r I • O a0 o O O O o rn o .4? co 4-0 co crD cc'c+ co c o • IP a frl liE' cu 0 ' O 1:3 U o to (7, • 0.) 03 O i U 0 oc, 0 0 4, 0 aa? “-.., Le? 4? 4? CA? -. ., . cn 11 CL ..--, 0 _ 0 c., •=. a Y rm it; ,---, ..._ .--.• 0 _ _ • 2 -0 I-- ,._ -0 - a) -c <=. -6 -(y3 T.13-a ) r=, ....., ... r•-• ,._ -0 •— . co _ __ c o _ Z —I 0 Cr Lo u) < 01 ,t— I cs. I, . ° CU •C -Iii cv . I a. r 1 it , .2 .............. as < '-' CV 0: 111 2- 1 a i .v.. > — C•1 : z il - __ ... ....-, %—. . . a Y . _ • 03 NI 0) (I) = .— LiLl 0 b. ...-..... 2 - - • &-- CO D N . . C`.I 0 'T•••.• ix) 0 •— 0 . _ N. •-- . _ 0 4=. —.=, . .=. a, c:-T- '17:4 ‘e ;, g , ... N , Z2 IL' 0 a i3 P 3 V) C 05 0 1.1.1 ,Ty it! CD 8 2 -. % 1- I :--r-:3 tta co •=1 cw 4, S 4? 4? r..... C-NI 4? 4? Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 09, 2011 4:36 PM To: 'Eller, J Gary' Cc: Davies, Stephen F (DOA) Subject: RE: Correction on KRU 2K-19 CTD PTDs(PTD 211-034) Gary, The permits have already been circulated here... I will add your statement to the well files. Thanks for updating us with the most current information. Hopefully, if the MI injection has truly been that recent(first gas injection in pattern) you will not see MI gas that quickly in the tighter A sand target zone wellbore. Of course , if MI has been injected for quite awhile all bets are off!!! Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Wednesday, March 09, 2011 4:23 PM To: Schwartz, Guy L (DOA) Cc: Gantt, Lamar L; Ohlinger, James J Subject: Correction on KRU 2K-19 CTD PTDs Guy— I wanted to make you aware of an error that I made in the paperwork accompanying the drilling permits for the proposed KRU 2K-19 CTD laterals. In the Hazards section on page 4 of the summary document dated February 28, 2011 that accompanied the drilling permits, I stated that"there has been no MI gas injection in the vicinity of 2K-19, so it is unlikely that an influx will yield significant quantities of gas". That statement was incorrect. Well 2K-13, immediately to the north of 2K-19, has recently been on MI gas injection, and therefore it is likely that any influx taken during the drilling of the 2K-19 CTD laterals would contain significant quantities of gas. I have already made the correction on my own written drilling procedure. Please contact me if you have any questions. 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1158 3/9/2011 SEMEE EF PlEn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-19A ConocoPhillips Alaska, Inc. Permit No: 211-034 Surface Location: 219' FNL, 94' FEL, SEC. 11, T1ON, R8E, UM Bottomhole Location: 1562' FSL, 1093' FWL, SEC. 10, T1ON, R8E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, OFF Daniel T. Seamount, Jr. Chair DATED this iv day of March, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIvvD1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 14J I) 2 2011 PERMIT TO DRILL Alaska Oil&Gey cons.comnission 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil Q •Service-Winj ❑ Single Zone 0 1c.Specify if 4d for: Drill ❑ Re-drill CI Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 2K-19A • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 13200' • TVD: 6102' . Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:219'FNL,94'FEL,Sec. 11,T1ON,R8E,UM • ADL 2558825589 ' Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1494'FSL, 1238'FEL,Sec. 10,T1ON,R8E,UM 2674,2675 4/15/2011 Total Depth: 9.Acres in Property: 14.Distance to 1562'FSL, 1093'FWL,Sec. 10,T1ON,R8E,UM 2560 Nearest Property: 11400 ' i 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL:/9j, j4rfeet 1§.Distance to Nearest Well Open GL Elevation above MSL: .t � t t Surface:x- 498310 . y- 5938085 • Zone- 4 1l ,to Same Pool: 2K-27,2100' 16.Deviated wells: Kickoff depth: 10170' ft. 17.Maximum Anticipated Pressure n psig(see 20 AAC 25.035) Maximum Hole Angle: 970 deg Downhole:4078 psig • Surface:3512 psig • 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade . Couplin.g Length MD ND MD ND (including stage data) III 3" 2.375" 4.7# L-80 ST-L 850' 12350' 6136' 13200' 6102' slotted liner / 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 10659' 6576' 10500' 6474' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 170 sx AS II 115' 115' Surface 3754' 9.625" 1200 sx AS III,450 sx Class G 3789' 2898' Intermediate Production 10524' 7" 450 sx Class G 10557' 6508' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 10169'-10189', 10210'-10250' 6259'-6271,6285'-6309' 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑.i 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263-4172 .,3 I q(l Printed Name V. Cawv Title Alaska Wells Manager \\v Signature 2 Phon 265-6306 Date 2/2.1!N 1 r Commission Use Only J Permit to DrillAPI N er: Permit Appro al See cover letter l ! .�. / Number: 50-f(" '' /1f' ()< Date: 6�,b " for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed me ane,gas hydrates,or gas contained in shales: L�r-,/ . 415Oo ,SZ AP --re--St-t" Samples req'd: Yes ❑ o t Mud log req'd: Yes ❑ No LSI Other: 4 / /H2S,mIasures: Yes [7No ❑ Directional svy req'd: Yes No ❑ 1-2 6OO �ssc. "1n.w `yse..� _ ` APPROVED BY THE COMMISSION 9,//a 1 DATE: '' ? ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is vali for'24 months from the date of approval(20 AAC 25,005(g)) •/( 5 005(9)) •!r Submit in Duplicate_ . ii .��Ylll r , s Conoco hilli p Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 28, 2011 RECEIVED'. Commissioner-State of Alaska � l�l Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil&Gas Cons.Conmision Anch©fegs Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill applications for three coiled tubing drilling (CTD) laterals out of Kuparuk well 2K-19 (PTD# 189-109) using the Nabors CDR2-AC coiled tubing drilling rig. The objective is to drill three producing A-sand laterals: 2K-19A, 2K-19AL1, and 2K-19AL2. Work is scheduled to begin in April 2011. Also included is the sundry for plugging the existing 2K-19 perfs with cement in order to v perform these CTD sidetracks. S 4A?, y 311-OS-13 Ps;d 11 Attached to this application are the following documents that explain the proposed job operations: - Permit to Drill Application Forms for 2K-19A, 2K-19AL1, 2K-19AL2 - Proposed &Current Wellbore Schematic - BOP Schematic - Detailed Summary of Operations - Directional Plans - 10-403 for plugging the existing 2K-19 wellbore with cement If you have any questions or require additional information please contact me at my office 907-263-4172. Sincerely, Gary Eller Conoco fillips Alaska Coiled Tubing Drilling Engineer KRU 2K-19A, AL1, AL2 — Coiled Tubing Drilling Summary of Operations: Well 2K-19 is a Kuparuk A-sand production well equipped with 31/2"tubing and 7"production casing. Three proposed A-sand CTD laterals will increase reservoir exposure and offset the planned 2K-13 CTD injection laterals. Prior to drilling,the existing A-Sand perfs in 2K-19 will be squeezed with cement to provide a means ✓ to kick out of the 7"casing. After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 10,220' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 2K-19A sidetrack ✓ will exit the 7"casing at 10,170' MD and will target the A4 sand west of the existing well with a 3030' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,200' MD with an aluminum billet at 12,350' MD. The 2K-19AL1 lateral will kick off from the aluminum billet at 12,350' MD and will target the A4 sand west of the existing well with a 750' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,100' MD with an aluminum billet at 11,600' MD. The 2K-19AL2 lateral will kick off from the aluminum billet at 11,600' MD and will target the Alsand west of the existing well with an 850' lateral. The hole will be completed with a 2%" slotted liner to the TD of 12,450' MD with the final liner top located just inside the 3V2"tubing at 10,060' MD. CTD Drill and Complete 2K-19 Laterals: April 2011 • Pre-CTD Work 1. Positive pressure and drawdown tests on master valve& swab valve 2. RU slickline. Obtain updated static BHP on A-sand. Dummy off all GLMs. RD slickline. 3. RU e-line. Perf holes in 3'h"tubing tail at 10,070' MD. RD e-line. 4. RU coil. Mill out XN-nipple in tubing tail to 2.80"ID. Plug the A-sand perfs with cement up to ✓ 10,070' MD. RD coil. 5. RU slickline. Tag top of cement. RD slickline. 6. Prep site for Nabors CDR2-AC, including setting BPV Ria WorkL�-tq 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. f f1 2. 2K-19A Sidetrack(A4 sand,west) a. Drill 2.80"high-side pilot hole through cement to 10,220 MD'. b. Drift pilot hole with whipstock dummy • c. Set whipstock at 10,170' MD with high-side orientation. 7-`D d. Mill 2.80"window with high-side orientation at 10,170' MD. ►' ( 5 1 -140 e. Drill 2.70"x 3"bi-center lateral to TD of 13,200' MD - f. Run 2%"slotted liner with an aluminum billet from TD up to 12,350' T 3. 2K-19AL1 Lateral(A4 sand,west) a. Kick off of the aluminum billet at 12,350' MD b. Drill 2.70"x 3"bi-center lateral to TD of 13,100' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 11,600' 4. 2K-19AL2 Lateral (A4 sand,west) a. Kick off of the aluminum billet at 11,600' MD b. Drill 2.70"x 3"bi-center lateral to TD of 12,450' MD c. Run 2%" slotted liner from TD up to 10,060' MD, up inside the 3'/2"tubing tail 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Page 2 of 4 € ERI GENA L February 28,2011, FINAL KRU 2K-19A, AL1, AL2 —Coiled Tubing Drilling Post-Ri2 Work 1. Pull BPV 2. Obtain static BHP • 3. Put well on production Mud Program: / • Will use chloride-based Biozan brine or used drilling mud(8.6 ppg)for milling operations,and chloride- based Flo-Pro mud(8.6 ppg)for drilling operations. We will have to kill the well with weighted brine in • order to deploy 2%" slotted liner in the three laterals. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • • Class II drill solids to Grind&Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 2K-19A: 2%",4.7#,L-80, ST-L slotted/solid liner from 12,350' MD to 13,200' MD • 2K-19AL1: 2%",4.7#,L-80, ST-L slotted/solid liner from 11,600' MD to 13,100' MD • 2K-19AL2: 2%",4.7#,L-80, ST-L slotted/solid liner from 10,060' MD to 12,450' MD Existing Casing/Liner Information Surface: 9%",J-55, 36 ppf Burst 3520 psi Collapse 2020 psi Production: 7",J-55, 26 ppf Burst 4980 psi Collapse 4320 psi Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static BHP survey in well 2K-19 was taken November 2010. The A-sand reservoir pressure was measured at 2355 psi at 10,050' MD, 6050' SSTVD,corresponding to 7 3,ppg EMW. We generally expect to encounter increasing pressure as laterals are drilled away from the mother well. Well Control: • Two well bore volumes(-230 bbl)of KWF will be available to the rig during drilling operations. The kill f weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2"coil tubing. • Pipe rams,blind rams and the CT pack off will be pressure tested to 250 psi and to 4500 psi. Maximum potential surface pressure in 2K-19 is 3512 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on a pressure measurement of 4078 psi at 6122' TVD taken in offset injection well 2K-13 in January 2011,corresponding to 12.8 ppg formation pressure. • The annular preventer will be tested to 250 psi and 2500 psi. Page 3 of 4 OR ! G I N` L February 28,2011, FINAL KRU 2K-19A, AL1, AL2 — Coiled Tubing Drilling Directional: • See attached directional plans: 1. 2K-19A, plan#3 2. 2K-19AL1, plan#2 3. 2K-19AL2, plan#2 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 2K-19 CTD laterals(A,AL1 &AL2): 11,400' to property line,—2100' to well 2K-27 Hazards • Shale stability is the most significant problem expected due to somewhat low reservoir pressure and the • significant number of fault crossings expected. It will be mitigated by directional planning to minimize exposure to the worst shales and by applying MPD pressure to maintain hole stability. • There has been no MI gas injection in the vicinity of 2K-19, so it is unlikely that an influx will yield significant quantities of gas. j • Well 2K-19 has 90 ppm measured H25 as of January 2010. Well 2K-18 is located 25' to the right side ,/ and 2K-20 is 25' to the left side of the 2K-19 surface location. Neither well has any measured H2S since they are both injectors. The maximum H25 level on the pad is 400 ppm from well 2K-27(1/13/09). All H2S monitoring equipment will be operational. ✓ Managed Pressure Drilling Managed pressure drilling(MPD)techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be used to reduce pressure fluctuations to help with hole stability. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 23/8"BHA will be accomplished utilizing the 2%"pipe rams and slip rams. The annular preventer will act as a secondary isolation during deployment and not as a stripper. Well 2K-19 will have to be killed prior to deploying slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Expected reservoir pressure is 2382 psi at 10,170' MD(6275' TVD), or 7.3 ppg EMW. • Expected annular friction losses while circulating: 1017 psi(assuming annular friction of 100 psi/1000 ft due to the 31/2"tubing) • Planned mud density of 8.6 ppg equates to 2806 psi hydrostatic bottom hole pressure at 6275' TVD. Mud hydrostatic pressure alone is expected to be sufficient to overbalance formation pressure. • While circulating 8.6 ppg mud, bottom hole circulating pressure is estimated to be 3823 psi or 11.7 ppg EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 2K-19. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight / may also be employed for improved borehole stability, but not necessarily for well control. • When circulation is stopped,—1000 psi of surface pressure would have to be applied to maintain the same borehole pressure as during drilling operations. II', Page 4 of 4 t" I ifk February 28,2011, FINAL , KUP 2K-19 C011ACoPhillips 1 N Well Attributes Max Angle&MD 'TO r Wellbore API/UWI Field Name Well Status Incl(") MD(ItKB) Act Btm(ftKB) Alaska,Ira_ 501032011800 KUPARUK RIVER UNIT PROD 60.35 3,700 00 10,659 0 J Comment H2S(ppm) 'Date I Annotation End Date IKB-Grd(ft) Rig Release Date -'- - SSSV 1 RDP 200 1/13/2009 'Last WO: 39.99 11/14/1989 C-009.---41.-18 9131RAt4,19:33.30 AM __..- w.. A -- __ Annotation Depth(ftKB) 'End Date Annotation Lost Mod By End Date Last Tag:SLM 10,346 0 2/14/2010 Rev Reason:PERFORATIONS Imosbor 3/2/2010 Casing Strings _- String OD String ID Set Depth Set Depth(TVD) String Wt String -^ I Casing Dec_.r' (in) TopjftKBL_.-_. (ftKB) (ftKB) (Ib6fl)__Grade String Top The CONDUCTOR 16 15.062 0.0 115-0 115.0 62.50 H-40 CONDUCTOR,_ '�",y'` 115 SURFACE 9 5/8 8.765 0.0 3,789.0 2,897.5 36.00 J-55 PRODUCI ION 7 6.151 0.010,557.0 6,508.0 26.00 J-55 Tubing Strings Safety Valve -_- String OD String ID I Set Depth Set Depth(TVD) String Wt String 1,796 Tubing Description (in) (in) Top(1180) (ft KB) (ftKB) (Ws/ft) Grade Shing TopThrd TUBING 31/2 2 692 0 0 10 084 0 6.209.0 9.30 J-55 EUE8rdABMOD Other In Hole(All Jewel Tubing Run&Retrievable,Fish,etc. 0ary . 1;. Top Depth . (TVD) 'Top Incl GAS LIFT, Top(ftKB) (RKB) () DenMption Comment _.. Run Dab ID(In) 2,675 - 1,798 1,721.8 33.62 Safety Valve Camra TRDP-1ASSA 5/3/1990 2.812 2,675 2,317.5 56.05 GAS LIFT MERLA/tMPD/1/GLVBK/.125/1350/Comment STA 1 9/21/2003 2.875 5,530 3,784.8 58.98 GAS UFT MERLA/TMPD/1/GLVBK/.156/1363/Comment:STA 2 9/21/2003 2.875 SURFACE, _ 3,769 7,062 4,598.8 57.84 GAS UFT MERLAJTMPD/1/GLVBK/.156/1341/Comment:STA 3 9/21/2003 2.875 7,833 5,007.4 57.73 GAS LIFT MERLA/TMPD/1/DMY/BW//Comment:STA 4 5/3/1990 2.875 8,577 5,397.1 58.70 GAS UFT MERLA/TMPD/1/GLVBK/.188/1355/Comment:STA5 9/21/2003 2.875 GAS LIFT, _ 9,298 5,773.2 57.98 GAS UFT CAMCO/MMG-2/1.5/DMY/RW//Comment: STA6 9/24/2003 2.921 5,530 9,959 6,136.9 55.24 GAS UFT -CAMCO/MMG-2/1.5/0V/RK/.25//Comment: STA7 5/14/2009 2.921 10,003 6,163.4 55.48 PBR Baker'80-40r w/10'Stroke PBR 5/3/1990 3.000 10,016 6.170.555.28 PACKER Baker 11B'RETRIEVABLE PACKER 5/3/1990 2.890 GAS LI,062FT, 10,052 6,190.6 54.76 NIPPLE Otis'XN'Nipple NO GO w2.81"POLISHED BORE 5/3/1990 2.750 7 - - . �,. 10,08_3 6,208.4 54.30 SOS Baker 5/3/1990 2.992 10,084 6,209.0 54.29 TTL 5/3/1990 2.992 5.. -r _ 3sy,.gif Perforations&Slots• GAS LIFT,_- Shot ,633 Top(TVD) Btm(TVD) Dns Top(ftKB) B1m(ftKB) (ftKB) (MKB) Zone Date (ell... Type Comment 10,169 10,189 6,259.4 6,271.4 A-4,2K-19 3/1/2010 6.0 APERF 2.5"Millenium HMX charges,60 degree phase 10,210 10,2506,285.3 6,309.1 A-5,2K-19 5/1/1990 4.0 IPERF 180 deg.Phasing;4.5"HLS Casing GAS LIFT, - Guns 6.577 Notes:General&Safety End Date Annotation 10/24/2004 NO 10:WAIVE HEU WELL IA OA COMMUNICATION • "t 9242009 NO 10:Repan SURF CSGot 95/8"hanger;weld 38"sleeve W/10".500 wall API SL-X65 pipe GAS LIFT, 9,296 = GAS LIFT 9,959 yll `` PBR,10,003 -- - -_1 /!!2!!!! - PACKER, 1 -...i 10,016 ' / a NIPPLE,10,052-.. jtr.:, SOS,10,063 TTL,10,084- 10,169-10,189 IPERF, _._ 10,210-10,250 PRODUCTION, 10,557 TO 10,659 --- ORIGINAL � Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing N Lubricator Riser Annular Blind/Shear 2" Pipe/Slip(CT) Pump into Lubricator 0j��J L\/ • above BHA rams ►/\/\ I<>�<_� 1 r ' Choke 1 2-3/8" Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8" Pipe/Slip(BHA) Kill ►>`>< >CI _I L ► 477 1 r Blind/Shear 2" Pipe/Slip (CT) Choke 2 1 Swab Valves ANL Wing Valves I Ogg 441ill Tree Flow Cross Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT C Choke Line: 2-1/16", 5M psi XI Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union ORIGINAL I▪) a O oS o o_ N o J(pm Y OV N P V N H _ D 0 2 O 7 J N T n n co N O l- M Tin O n Y co o C O II o c II Y U co o E (I I\ co o n.Ci n U COCC v w uCL7c i y K Y' I O o -F-2 Ma CC co g II �� k O (V CO O V 0 O a co o Y M U u) g N o w c N m .o aUm o co d° o am_ 11 o n W 1- oo x Z a o _ J N N X} m \\ A `-A3 a U rn ei ci O 2' _U N N N Co N m N i N N yC N -7?0 M (h co O m m M MO`° o U,- -2P- n o / o I i o_ "c5.o ° a mN � O EO ,co o co IrI AA '1'1co o _ NO �i � MI' N L 5- I Vki il (n i i / ~ „hp,- !#1 �P 0 TIV � 5 to. a) :Ito ; !!! it!!!!! 2 I d C 0 C1 d n E o o cVI U Is' U NIt)LO O co Sc N O L N n Q) q 7 CO A S2 r0 2 c O ro "c O N C .I S(('-�-�� gt'L CO NO N� y Y N V C coOC O C O ' V O n N co oo m n a o a o Q Q <oLO Z8�,p� N`2 m V RIGI [IA I.„. ConocdPhilhi Alas-Ka ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2K Pad 2K-19 2K-19A Plan: 2K-19A_wp03 Standard Planning Report 25 February, 2011 r `r. BAKER HUGHES JR1GLNAL �' ConocoPhillips (e' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19A Design: 2K-19A_wp03 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2K Pad Site Position: Northing: 5,938,600.18ft Latitude: 70° 14'36.519 N From: Map Easting: 498,310.178 Longitude: 150°0'49.133 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well 2K-19 Well Position +NI-S 0.00 ft Northing: 5,938,085.20 ft Latitude: 70° 14'31.454 N F +EI-W 0.00 ft Easting: 498,310.27 ft Longitude: 150°0'49.127 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 118 50f Wellbore 2K-19A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 4/15/2011 16.64 79.76 57,334 Design 2K-19A_wp03 II Audit Notes: Version: Phase: PLAN Tie On Depth: 10,160.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction .,-4 (ft) (ft) (ft) (°) -118.50 0.00 0.00 271.00 2/25/2011 11:32:23AM Page 2 COMPASS 2003.16 Build 69 '1 C? IGINAL ,.-- ConocoPhillips r/` ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19A Design: 2K-19A_wp03 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°HOOft) (°) Target 10,160.00 53.58 239.61 6,115.01 -3,560.03 -6,414.38 0.00 0.00 0.00 0.00 10,170.00 53.38 239.74 6,120.96 -3,564.09 -6,421.32 2.26 -2.00 1.30 152.46 10,185.00 55.33 239.74 6,129.70 -3,570.23 -6,431.85 13.00 13.00 0.00 0.00 10,225.00 71.33 239.74 6,147.60 -3,588.18 -6,462.62 40.00 40.00 0.00 0.00 10,279.71 90.50 250.48 6,156.22 -3,610.65 -6,511.38 40.00 35.04 19.63 30.00 10,379.71 90.38 290.48 6,155.42 -3,609.83 -6,609.35 40.00 -0.12 40.00 90.00 10,679.71 90.37 278.48 6,153.43 -3,534.95 -6,899.28 4.00 0.00 -4.00 270.00 10,799.71 86.65 275.46 6,156.55 -3,520.40 -7,018.32 4.00 -3.11 -2.52 219.00 10,979.71 90.04 281.81 6,161.76 -3,493.40 -7,196.09 4.00 1.89 3.53 62.00 11,229.71 97.09 274.70 6,146.20 -3,457.55 -7,442.70 4.00 2.82 -2.84 315.00 11,379.71 91.27 267.82 6,135.25 -3,454.30 -7,592.11 6.00 -3.88 -4.59 230.00 11,529.71 90.01 258.91 6,133.58 -3,471.61 -7,740.94 6.00 -0.84 -5.94 262.00 11,679.71 84.37 256.85 6,140.93 -3,503.06 -7,887.35 4.00 -3.76 -1.37 200.00 11,929.71 90.14 265.03 6,152.91 -3,542.30 -8,133.64 4.00 2.31 3.27 55.00 12,129.71 92.82 253.32 6,147.72 -3,579.77 -8,329.66 6.00 1.34 -5.85 283.00 12,429.71 92.76 265.34 6,133.06 -3,635.14 -8,623.58 4.00 -0.02 4.00 90.00 • 13,200.00 91.76 296.16 6,101.97 • -3,493.26 -9,370.64 4.00 -0.13 4.00 91.20 2/2.5/2011 11:32:23AM Page 3 COMPASS 2003.16 Build 69 I GI NIL • 'iv- ConocoPhillips IC' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19A Design: 2K-19A_wp03 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) C) C) (ft) (ft) (ft) (ft) (°1100ft) (') (ft) (ft) 110,160.00 53.58 239.61 6,115.01 -3,560.03 -6,414.38 6,351.27 0.00 0.00 5,934,526.97 491,895.73 TIP 10,170.00 53.38 239.74 6,120.96 -3,564.09 -6,421.32 6,358.14 2.26 152.46 5,934,522.91 491,888.79 KOP 10,185.00 55.33 239.74 6,129.70 -3,570.23 -6,431.85 6,368.56 13.00 0.00 5,934,516.77 491,878.27 End of DLS 13 10,200.00 61.33 239.74 6,137.57 -3,576.66 -6,442.87 6,379.47 40.00 0.00 5,934,510.34 491,867.24 10,225.00 71.33 239.74 6,147.60 -3,588.18 -6,462.62 6,399.01 40.00 0.00 5,934,498.83 491,847.49 4 10,279.71 90.50 250.48 6,156.22 -3,610.65 -6,511.38 6,447.37 40.00 30.00 5,934,476.37 491,798.73 5 10,300.00 90.49 258.60 6,156.04 -3,616.06 -6,530.92 6,466.82 40.00 90.00 5,934,470.97 491,779.19 i 10,379.71 90.38 290.48 6,155.42 -3,609.83 -6,609.35 6,545.35 40.00 90.07 5,934,477.21 491,700.77 End of DLS 40 10,400.00 90.38 289.67 6,155.28 -3,602.86 -6,628.41 6,564.53 4.00 -90.00 5,934,484.18 491,681.71 10,500.00 90.38 285.67 6,154.61 -3,572.52 -6,723.67 6,660.30 4.00 -90.01 5,934,514.55 491,586.47 10,600.00 90.38 281.67 6,153.95 -3,548.89 -6,820.82 6,757.84 4.00 -90.03 5,934,538.19 491,489.34 10,679.71 90.37 278.48 6,153.43 -3,534.95 -6,899.28 6,836.54 4.00 -90.06 5,934,552.15 491,410.88 Rib-Steer 10,700.00 89.74 277.97 6,153.40 -3,532.05 -6,919.37 6,856.67 4.00 -141.00 5,934,555.06 491,390.80 10,799.71 86.65 275.46 6,156.55 -3,520.40 -7,018.32 6,955.81 4.00 -141.00 5,934,566.73 491,291.86 8 10,800.00 86.65 275.47 6,156.56 -3,520.37 -7,018.62 6,956.11 4.00 62.00 5,934,566.76 491,291.57 10,900.00 88.53 279.00 6,160.76 -3,507.79 -7,117.71 7,055.41 4.00 62.00 5,934,579.36 491,192.48 10,979.71 90.04 281.81 6,161.76 -3,493.40 -7,196.09 7,134.03 4.00 61.85 5,934,593.77 491,114.12 9 11,000.00 90.61 281.24 6,161.64 -3,489.34 -7,215.97 7,153.98 4.00 -45.00 5,934,597.82 491,094.24 11,100.00 93.44 278.40 6,158.10 -3,472.30 -7,314.43 7,252.71 4.00 -45.00 5,934,614.89 490,995.80 11,200.00 96.26 275.55 6,149.65 -3,460.19 -7,413.31 7,351.79 4.00 -45.10 5,934,627.02 490,896.93 11,229.71 97.09 274.70 6,146.20 -3,457.55 -7,442.70 7,381.22 4.00 -45.34 5,934,629.66 490,867.54 10 11,300.00 94.37 271.46 6,139.18 -3,453.79 -7,512.52 7,451.10 6.00 -130.00 5,934,633.44 490,797.73 11,379.71 91.27 267.82 6,135.25 -3,454.30 -7,592.11 7,530.66 6.00 -130.32 5,934,632.95 490,718.15 11 11,400.00 91.10 266.61 6,134.83 -3,455.28 -7,612.37 7,550.91 6.00 -98.00 5,934,631.97 490,697.89 11,500.00 90.26 260.67 6,133.65 -3,466.35 -7,711.70 7,650.03 6.00 -98.02 5,934,620.93 490,598.56 11,529.71 90.01 258.91 6,133.58 -3,471.61 -7,740.94 7,679.17 6.00 -98.10 5,934,615.67 490,569.33 12 11,600.00 87.36 257.94 6,135.19 -3,485.71 -7,809.78 7,747.75 4.00 -160.00 5,934,601.59 490,500.49 11,679.71 84.37 256.85 6,140.93 -3,503.06 -7,887.35 7,825.01 4.00 -159.98 5,934,584.26 490,422.92 13 11,700.00 84.84 257.52 6,142.84 -3,507.54 -7,907.05 7,844.63 4.00 55.00 5,934,579.78 490,403.22 11,800.00 87.14 260.79 6,149.84 -3,526.30 -8,005.01 7,942.24 4.00 54.94 5,934,561.05 490,305.27 11,900.00 89.46 264.06 6,152.81 -3,539.47 -8,104.07 8,041.06 4.00 54.71 5,934,547.90 490,206.22 l 11,929.71 90.14 265.03 6,152.91 -3,542.30 -8,133.64 8,070.58 4.00 54.61 5,934,545.08 490,176.65 I 14 12,000.00 91.09 260.92 6,152.16 -3,550.90 -8,203.39 8,140.16 6.00 -77.00 5,934,536.50 490,106.91 12,100.00 92.43 255.06 6,149.08 -3,571.68 -8,301.11 8,237.51 6.00 -77.04 5,934,515.73 490,009.19 12,129.71 92.82 253.32 6,147.72 -3,579.77 -8,329.66 8,265.91 6.00 -77.22 5,934,507.66 489,980.64 15 12,200.00 92.82 256.14 6,144.26 -3,598.25 -8,397.38 8,333.30 4.00 90.00 5,934,489.19 489,912.92 12,300.00 92.80 260.14 6,139.36 -3,618.78 -8,495.11 8,430.66 4.00 90.14 5,934,468.69 489,815.20 2/25/2011 11:32:23AM Page 4 COMPASS 2003.16 Build 69 ORIGINAL 'Iv' ConocoPhillips re, ConocoPhiIIips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19A Design: 2K-19A_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 12,400.00 92.77 264.15 6,134.50 -3,632.42 -8,594.03 8,529.33 4.00 90.33 5,934,455.07 489,716.28 12,429.71 92.76 265.34 6,133.06 -3,635.14 -8,623.58 8,558.82 4.00 90.53 5,934,452.36 489,686.74 16 12,500.00 92.70 268.15 6,129.72 -3,639.13 -8,693.67 8,628.84 4.00 91.20 5,934,448.39 489,616.65 12,600.00 92.60 272.16 6,125.10 -3,638.86 -8,793.55 8,728.70 4.00 91.33 5,934,448.68 489,516.79 12,700.00 92.49 276.16 6,120.66 -3,631.62 -8,893.17 8,828.43 4.00 91.52 5,934,455.94 489,417.18 12,800.00 92.36 280.16 6,116.43 -3,617.44 -8,992.04 8,927.54 4.00 91.70 5,934,470.13 489,318.31 12,900.00 92.23 284.16 6,112.43 -3,596.40 -9,089.70 9,025.55 4.00 91.87 5,934,491.19 489,220.67 13,000.00 92.08 288.16 6,108.67 -3,568.60 -9,185.66 9,121.99 4.00 92.03 5,934,519.02 489,124.72 13,100.00 91.92 292.16 6,105.18 -3,534.16 -9,279.46 9,216.37 4.00 92.18 5,934,553.47 489,030.94 13,200.00 91.76 296.16 6,101.97 -3,493.26 -9,370.64 9,308.24 4.00 92.32 5,934,594.39 488,939.79 TD ?12.512011 11:32::23AM Page 5 COMPASS 2003.16 Build 69 ..` � ISI L ConocoPhillips 7,4 ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19A Design: 2K-19A_wp03 Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting -Shape (1 (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2K-19A t5 0.00 0.00 6,134.00 -3,466.11 -7,712.29 5,934,621.16 490,597.97 70°13'57.326 N 150°4'33.228 W -plan hits target center -Point 2K-19A Fault#1 0.00 0.00 0.00 -3,159.00 -7,277.30 5,934,928.15 491,032.99 70°14'0.351 N 150°4'20.597 W -plan misses target center by 6150.07ft at 11365.48ft MD(6135.64 TVD,-3453.83 N,-7577.89 E) -Polygon Point 1 0.00 -3,159.00 -7,277.30 5,934,928.15 491,032.99 Point2 0.00 -3,489.02 -7,216.20 5,934,598.15 491,094.01 Point 3 0.00 -3,801.08 -7,329.13 5,934,286.14 490,981.02 Point 4 0.00 -3,489.02 -7,216.20 5,934,598.15 491,094.01 2K-19A t3 0.00 0.00 6,162.00 -3,489.01 -7,216.23 5,934,598.15 491,093.98 70°13'57.105 N 150°4'18.813 W -plan hits target center -Point 2K-19A t8 0.00 0.00 6,102.00 -3,492.46 -9,371.50 5,934,595.19 488,938.93 70°13'57.048 N 150°5'21.439 W -plan misses target center by 1.17ft at 13200.00ft MD(6101.97 TVD,-3493.26 N,-9370.64 E) -Point 2K-19A t4 0.00 0.00 6,153.00 -3,464.04 -7,374.25 5,934,623.16 490,935.98 70°13'57.350 N 150°4'23.405 W -plan hits target center -Point 2K-19A,AL2 Fault#2 0.00 0.00 0.00 -2,377.01 -7,624.51 5,935,710.13 490,685.99 70°14'8.038 N 150°4'30.709 W -plan misses target center by 6228.88ft at 11400.00ft MD(6134.83 TVD,-3455.28 N,-7612.37 E) -Polygon Point 1 0.00 -2,377.01 -7,624.51 5,935,710.13 490,685.99 Point 2 0.00 -3,514.21 -7,946.23 5,934,573.12 490,364.04 Point 3 0.00 -3,853.22 -7,867.13 5,934,234.13 490,443.06 Point 4 0.00 -3,514.21 -7,946.23 5,934,573.12 490,364.04 2K-19A t2 0.00 0.00 6,153.00 -3,531.95 -6,920.18 5,934,555.15 491,389.99 70°13'56.686 N 150°4'10209 W -plan hits target center -Point 2K-19A t1 0.00 0.00 6,156.00 -3,606.87 -6,503.11 5,934,480.14 491,807.00 70°13'55.953 N 150°3'58.088 W -plan hits target center -Point 2K-19A t6 0.00 0.00 6,146.00 -3,514.17 -7,946.31 5,934,573.17 490,363.97 70°13'56.851 N 150°4'40.026 W -plan misses target center by 1.56ft at 11739.94ft MD(6146.12 TVD,-3515.70 N,-7946.01 E) -Point 2K-19A Polygon 0.00 0.00 0.00 -3,476.86 -6,478.13 5,934,610.14 491,832.00 70°13'57.232 N 150°3'57.366 W -plan misses target center by 6115.91ft at 10160.00ft MD(6115.01 TVD,-3560.03 N,-6414.38 E) -Polygon Point 1 0.00 -3,476.86 -6,478.13 5,934,610.14 491,832.00 Point 2 0.00 -3,634.84 -6,350.07 5,934,452.15 491,960.02 Point 3 0.00 -3,727.89 -6,512.06 5,934,359.14 491,798.02 Point4 0.00 -3,668.98 -6,838.11 5,934,418.12 491,472.02 Point 5 0.00 -3,551.16 -7,528.21 5,934,536.08 490,782.01 Point 6 0.00 -3,738.46 -8,559.27 5,934,349.03 489,751.01 Point 7 0.00 -3,743.58 -8,983.31 5,934,344.01 489,327.01 Point 8 0.00 -3,570.71 -9,526.41 5,934,516.98 488,784.01 Point 9 0.00 -3,378.68 -9,482.46 5,934,708.98 488,828.00 Point 10 0.00 -3,526.53 -8,880.36 5,934,561.01 489,430.00 Point 11 0.00 -3,467.33 -8,199.30 5,934,620.06 490,111.01 Point 12 0.00 -3,329.16 -7,632.29 5,934,758.08 490,677.99 Point 13 0.00 -3,476.86 -6,478.13 5,934,610.14 491,832.00 2K-19A t7 0.00 0.00 6,153.00 -3,539.20 -8,104.33 5,934,548.17 490,205.96 70°13'56.603 N 150°4'44.617 W flan hits target center 2I25/2011 11:32:23AM Page 6 COMPASS 2003.16 Build 69 ORIGINAL Iry ConocoPhillips r/l ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19A Design: 2K-19A_wp03 1 Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,789.00 2,758.29 9 5/8" 9-5/8 12-1/4 13,200.00 6,101.97 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EJ-W (ft) (ft) (ft) (ft) Comment 10,160.00 6,115.01 -3,560.03 -6,414.38 TIP 10,170.00 6,120.96 -3,564.09 -6,421.32 KOP 10,185.00 6,129.70 -3,570.23 -6,431.85 End of DLS 13 10,225.00 6,147.60 -3,588.18 -6,462.62 4 10,279.71 6,156.22 -3,610.65 -6,511.38 5 10,379.71 6,155.42 -3,609.83 -6,609.35 End of DLS 40 10,679.71 6,153.43 -3,534.95 -6,899.28 Rib-Steer 10,799.71 6,156.55 -3,520.40 -7,018.32 8 10,979.71 6,161.76 -3,493.40 -7,196.09 9 11,229.71 6,146.20 -3,457.55 -7,442.70 10 11,379.71 6,135.25 -3,454.30 -7,592.11 11 11,529.71 6,133.58 -3,471.61 -7,740.94 12 11,679.71 6,140.93 -3,503.06 -7,887.35 13 11,929.71 6,152.91 -3,542.30 -8,133.64 14 12,129.71 6,147.72 -3,579.77 -8,329.66 15 12,429.71 6,133.06 -3,635.14 -8,623.58 16 13,200.00 6,101.97 -3,493.26 -9,370.64 TD 2/25/2011 11:32:23AM Page 7 COMPASS 2003.16 Build 69 CRIME -- ' 1111 La lamt g ! i Q Ili II O fr , : . .AtY JH 8 ffi NI o a 3 8 1 I i I 1 • g I o a v N -� '16.F r- -f- o 4 ::,=-7...1,4 1. 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" ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2K Pad 2K-19 2K-19A 2K-19A_wp03 Travelling Cylinder Report 28 February, 2011 r''rr BAKER HUGHES ORIGINAL ConocoPhillips ia' ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-19 Project: Kuparuk River Unit TVD Reference: 2K-19 @ 154.00ft(Nordic 1) Reference Site: Kuparuk 2K Pad MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site Error: 0.00ft North Reference: True Reference Well: 2K-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-19A Database: EDM Alaska Prod v16 Reference Design: 2K-19A_wp03 Offset TVD Reference: Offset Datum Reference 2K-19A_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer(WARNING:There is hidden tight data in this project Interpolation Method: MD Interval 25.008 Error Model: ISCWSA Depth Range: 10,160.00 to 13,200.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,516.45ft Error Surface: Elliptical Conic Survey Tool Program Date 2/23/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 40.00 10,160.00 2K-19 GyroData(2K-19) GYD-CT-CMS Gyrodata cont.casing m/s 10,160.00 13,200.00 2K-19A_wp03(2K-19A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name n n 3,789.00 2,912.29 9 5/8" 9-5/8 12-1/4 13,200.00 6,255.97 2 3/8" 2-3/8 3 , Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2K Pad 2K 13 2K 13 2K 13 Out of range 2K-19-2K-19-2K-19 10,175.00 10,175.00 0.03 0.28 -0.24 FAIL-No Errors 2K-19-2K-19AL1 -2K-19AL1_wp02 12,350.00 12,350.00 0.00 0.23 -0.22 FAIL-No Errors 2K-19-2K-19AL2-2K-19AL2_wp02 11,600.00 11,600.00 0.00 0.22 -0.22 FAIL-No Errors 2K-21 -2K-21-2K-21 Out of range 2K-21 -2K-21A-2K-21A Out of range 2K 27 2K 27 2K 27 Out of range 2K-27-2K-27-2K-27(wp02) Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/28/2011 10:39:25AM Page 2 of 6 COMPASS 2003.16 Build 69 ORIGiNAL OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL L LETTER CHECKLIST WELL NAME �'`' C,( PTD# / t `7 V Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: Kt,,Iczt-tt(L POOL: ((I), Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 cn D 0 3 u! 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