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Home My WebLink About196-1361. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7675' feet None feet true vertical 6035' feet None feet Effective Depth measured 7352' feet None feet true vertical 5795' feet feet 7308-7320' 7328-7336' 7348-7368' Perforation depth Measured depth feet 5762-5771' 5777-5783' 7348-7368' True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7217' 5693' Packers and SSSV (type, measured and true vertical depth) None 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: Elliott Tuttle Contact Email:elliott.tuttle@conocophillips.com Authorized Title: RWO/CTD Engineer Contact Phone: 907-263-4742 323-224 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf MD 0 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 1141 1241152 0 00 181 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 282 N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025547 Kuparuk Field/ Kuparuk Oil Pool ConocoPhillips Alaska, Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-136 50-103-20246-00-00 P.O. Box 100360, Anchorage, AK 995103. Address: KRU 3G-25X N/A N/A Length 79' 3758' 121'Conductor Surface Temp Tie Back 16" 7-5/8" Size 121' 5-1/2" 5-1/2" measured TVD Production Liner 7165' 3714' 7637' Casing 5685' 3012' 5-1/2" 7207' 3728' 7667 6029' Plugs Junk measured 3800' 3064' Burst Collapse 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 8:42 am, Aug 02, 2023 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O= Conoco Phillips, CN=Elliott Tuttle, E=elliott.tuttle @conocophillips.com Reason: I am approving this document Location: Date: 2023.08.01 15:33:41-08'00' Foxit PDF Editor Version: 12.1.2 Elliott Tuttle Page 1/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/12/2023 12:00 6/12/2023 14:30 2.50 MIRU, MOVE MOB P Hook up truck to rig office, pull matting boards, pick up stairs and landing on subbase and pits, jack up pits, hook up truck, install jeep Move pits, shop and rig office to 3G-25X 0.0 0.0 6/12/2023 14:30 6/12/2023 16:00 1.50 MIRU, MOVE MOB P PJSM, pull pins for derrick, lay derrick over, pull subbase off 3N-19 Clean up around 3N-19 0.0 0.0 6/12/2023 16:00 6/12/2023 18:00 2.00 MIRU, MOVE MOB P Move sub base from 3N-19 to spine road 0.0 0.0 6/12/2023 18:00 6/12/2023 18:30 0.50 MIRU, MOVE MOB P Crew change out and let traffic get clear of spine road to CPF3 0.0 0.0 6/12/2023 18:30 6/13/2023 00:00 5.50 MIRU, MOVE MOB P Move sub base from spine road 3N intersection to 3G 0.0 0.0 6/13/2023 00:00 6/13/2023 03:30 3.50 MIRU, MOVE MOB P Move sub base to 3G pad 0.0 0.0 6/13/2023 03:30 6/13/2023 04:45 1.25 MIRU, MOVE RURD P Hang tree in cellar, lay herculite and rig mats around 3G-25X, spot wellhead equipment in cellar 0.0 0.0 6/13/2023 04:45 6/13/2023 06:00 1.25 MIRU, MOVE MOB P Shut down spotting sub base due to close proximity of 3G-13 wing valve Contact pad operator about getting wing valve removed 0.0 0.0 6/13/2023 06:00 6/13/2023 12:00 6.00 MIRU, MOVE MOB P Spot sub base over 3G-25X, raise derrick, lay herculite and mats spot pits to sub base, hook up service lines, berm around rig, spot mud lab Hook up interconnect and electrical to pits. Turn on steam and air. Spot cuttings tank. Complete acceptance checklist. Get measurements for riser height from tubing spool height. Begin taking on seawater into pits. 0.0 0.0 6/13/2023 12:00 6/13/2023 19:00 7.00 MIRU, WELCTL COND P Fill Pits with 8.6# seawater. Build 30 BBLS deep clean vis pill. Rig up circ manifold in cellar. Take initial pressures T/IA/OA=100/20/40 Bleed gas off TBG/IA. Kill Well. Test kill tank line to 3500 PSI for 10 min 0.0 0.0 6/13/2023 19:00 6/13/2023 20:45 1.75 MIRU, WELCTL KLWL P PJSM, circulate 8.4 PPG seaswater Pump 30 BBLS deep clean pill Chase with 254 BBLS seawater Had clean 8.4 PPG seawater back at 185 BBLS pumped past pill 2 BPM 400 PSI 4 BPM 1775 PSI ICP 4 BPM 1430 PSI FCP 0.0 0.0 6/13/2023 20:45 6/13/2023 21:00 0.25 MIRU, WELCTL OWFF P Shut down monitor PSI No pressure on TBG and IA Open up to atmosphere, no flow at first but then started to trickle,, shut in montior PSI, no pressure build, open up had diesel at surface 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 2/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/13/2023 21:00 6/14/2023 00:00 3.00 MIRU, WELCTL KLWL P Pump 50 more BBLS at 4 BPM 1430 PSI Shut down flow check, still have no pressure and get diesel back to surface as it migrates up hole Repeat pump 50 BBLS, shut down monitor PSI, check for diesel at surface 4 BPM 1430 PSI While pumping at 5 BPM 2100 PSI, have 180 PSI on IA and 480 PSI on OA When shut down have 0 PSI on TBG/IA and 40 PSI on OA As of midnight have a total of 490 BBLS of 8.4 PPG seawater pumped 0.0 0.0 6/14/2023 00:00 6/14/2023 01:45 1.75 MIRU, WELCTL KLWL P Monitor pressures 0 on TBG, 3 PSI on IA and 40 on OA Get diesel to surface, break circulation have 8.4 PPG at surface in less than 10 BBLS Pump 20 BBLS total, shut in let diesel migrate to surface from 3 1/2" x 5 1/2" and 5 1/2" x 7 5/8" annulus Pump 5 BPM 2100 PSI , 180 PSI on IA and 480 PSI on OA, shut in for 1 HR to let diesel migrate up hole 0.0 0.0 6/14/2023 01:45 6/14/2023 02:30 0.75 MIRU, WELCTL OWFF P Monitor PSI, check fluid at IA IA climb to 13 PSI , OA climb to 50 PSI Diesel at surface 0.0 0.0 6/14/2023 02:30 6/14/2023 03:00 0.50 MIRU, WELCTL KLWL P Circ S/S @ 5 BPM 2100 PSI OA/IA at 490 PSI 8.4 PPG in/out Pump total of 657 BBLS 0.0 0.0 6/14/2023 03:00 6/14/2023 03:30 0.50 MIRU, WELCTL OWFF P Shut down monitor pressure TBG= 0 PSI I/A = 3 PSI OA = 40 PSI 0.0 0.0 6/14/2023 03:30 6/14/2023 04:30 1.00 MIRU, WELCTL KLWL P Pump 30 BBLS @ 5 BPM 2030 PSI OA/IA = 480 PSI Shut down monitor pressures, shut in let diesel migrate to surface from 5 1/2" x 7 5/8" annulus IA = 13 PSI OA = 40 PSI Pump 60 BBLS more @ 5 BPM 2030 PSI Pump total of 747 BBLS 0.0 0.0 6/14/2023 04:30 6/14/2023 05:15 0.75 MIRU, WELCTL OWFF P Shut down monitor pressure TBG= 8 PSI I/A = 13 PSI OA = 40 PSI Bleed pressure cap off OA, IA/TBG go to zero 0.0 0.0 6/14/2023 05:15 6/14/2023 06:00 0.75 MIRU, WELCTL OWFF P Perform no flow test to atmosphere 0.0 0.0 6/14/2023 06:00 6/14/2023 07:30 1.50 MIRU, WELCTL MPSP P Set BPV test unfder BPV to 1000 PSI for 10 minutes (Charted) good test. 0.0 0.0 6/14/2023 07:30 6/14/2023 08:30 1.00 MIRU, WHDBOP NUND P N/D tree and adapter. Set external neck sealing blanking plug. Verify pulling tool will engage blanking plug. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 3/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/14/2023 08:30 6/14/2023 13:00 4.50 MIRU, WHDBOP NUND P NU DSA and BOP's install turnbuckles torque flanges. 0.0 0.0 6/14/2023 13:00 6/14/2023 23:00 10.00 MIRU, WHDBOP SVRG P Perform BWM Finish loading and processing 3 1/2" EUE TBG in shed Load and process 65 Joints of 3.5" PH-6 DP in the shed. Fix glycol leak under draworks Maintance on shakers, changfe out springs and screens 0.0 0.0 6/14/2023 23:00 6/14/2023 23:30 0.50 MIRU, WHDBOP SVRG P Service rig 0.0 0.0 6/14/2023 23:30 6/15/2023 00:00 0.50 MIRU, WHDBOP RURD P Rig up to test BOP, make up PH6 floor valve and dart valve Fill lines, choke manifold and BOP stack with water 0.0 0.0 6/15/2023 00:00 6/15/2023 00:45 0.75 MIRU, WHDBOP RURD P Fill lines, choke manifold and BOP stack with water. Purge air out of system Obtain good shell test 0.0 0.0 6/15/2023 00:45 6/15/2023 11:30 10.75 MIRU, WHDBOP BOPE P BOPE test All test to 250/3500 PSI F/5 min each, Test annular with 3 1/2" test joint, Test UVBR/LVBR w/ 5 1/2" and 3 1/2" test joints, Test blinds rams, Choke valves #1 to #16, upper/lower IBOP valves. Test 3 1/2" HT-38 FOSV/Dart Valve, Test 3 ½ EUE FOSV, Test PH6 FOSV/Dart valve, Test 2" rig floor Demco kill valves, Test manual and HCR kill and choke valves.Test two ea 2 1/16" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3150 PSI, after closure = 1600 PSI, 200 PSI attained = 20 sec, full recovery attained = 115 sec. UVBR = 6 sec, LVBR = 6 sec, Annular = 20 sec, Simulated blinds = 6 sec, HCR choke/kill = 1 sec each, 5 back up nitrogen bottles average = 2000 PSI, Prechare bottles = 11 @ 1100 PSI, Test gas detectors, PVT and flow show. AOGCC Rep. Austin McLeod witness test 0.0 0.0 6/15/2023 11:30 6/15/2023 13:00 1.50 MIRU, WHDBOP RURD P RD testing lines and Eq. L.D. test joints. Break out safety valves and MU X-O's to safety valves to pull tubing. Drain stack and fill W/seawater. RU to pull completion. 0.0 0.0 6/15/2023 13:00 6/15/2023 15:00 2.00 COMPZN, RPCOMP PULL P Pull blanking plug and BPV. PU landing joint and M.U. to tubing hanger lift threads. Set down 10K on landing joint. BOLDS. 0.0 0.0 6/15/2023 15:00 6/15/2023 15:30 0.50 COMPZN, RPCOMP PULL P Pull hanger to floor PUW=155K weight broke back to 95K Blocks=30K. 7,218.0 7,183.0 6/15/2023 15:30 6/15/2023 16:00 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes. 7,183.0 7,183.0 6/15/2023 16:00 6/15/2023 16:30 0.50 COMPZN, RPCOMP CIRC P Circulate BUS sewater at 5 BPM 1600 PSI 7,183.0 7,183.0 6/15/2023 16:30 6/15/2023 17:00 0.50 COMPZN, RPCOMP PULL P LD tubing tubing hanger and pup joints under hanger. 7,183.0 7,165.0 6/15/2023 17:00 6/15/2023 20:15 3.25 COMPZN, RPCOMP PULL P LD tubing F/7,165' T/5,168' 70K UP 70K DN 7,165.0 5,168.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 4/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/15/2023 20:15 6/15/2023 21:30 1.25 COMPZN, RPCOMP BHAH P Bring up little jerks and BHA components to floor M/U 4" G bait sub to tubing. P/U G- spear BHA on 3 1/2" PH6 work string. 5,168.0 5,168.0 6/15/2023 21:30 6/15/2023 22:30 1.00 COMPZN, RPCOMP PULD P Stab G spear onto bait sub RIH F/5,168' T/5,285' Set DN 10K @ 117' P/U pull 30K over, slack off pull 30K over, slack back off retag same spot with 10K, pick up pop free with 15 - 20K over Pull stand up and stand back, pull bait sub and crossovers to floor and inspect, Looks like bait sub and PH6 to 2 7/8" IF are binding 5,168.0 5,168.0 6/15/2023 22:30 6/16/2023 00:00 1.50 COMPZN, RPCOMP OTHR P Call and discuss options for plan forward Locate X/overs and handling equipment for adding a flex joint of 2 7/8" EUE for a flex joint 5,168.0 5,168.0 6/16/2023 00:00 6/16/2023 01:00 1.00 COMPZN, RPCOMP BHAH P Release G spear, L/D cross overs and 1 JT PH6 Bring up 2 7/8" handling equipment and BHA components to rig floor Put 2 7/8" elev on 5,168.0 5,168.0 6/16/2023 01:00 6/16/2023 05:00 4.00 COMPZN, RPCOMP PULD P P/U 1 JT 2 7/8" EUE, make up G spear and 4" bait sub on to 3 1/2" TBG RIH F/5,168' T/7,212' Tag at 7,222' - Set DN 10K P/U T/7,212' 110K UP 60K DN Bait sub depth's take 5-8K at 117', take 10K DN at 155' pick up with 5K over then pull clean, take 5-8K drag from 155' T/210' 5,168.0 7,212.0 6/16/2023 05:00 6/16/2023 05:30 0.50 COMPZN, RPCOMP CIRC P Screw in with top drive S/O and tag seal assy in seal bore set DN 10K - top of 4" bait sub at 2,052.75' Pump at 2 BPM 1940 PSI - slack off set 25K DN P/U release G spear 55K UP 7,212.0 2,037.0 6/16/2023 05:30 6/16/2023 06:00 0.50 COMPZN, RPCOMP CIRC P CBU @ 2 BPM 1950 PSI 2,037.0 2,037.0 6/16/2023 06:00 6/16/2023 06:30 0.50 COMPZN, RPCOMP RURD P Blow down surface lines and top drive after pumping off tubing. 2,037.0 2,037.0 6/16/2023 06:30 6/16/2023 07:00 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes, well static. 2,037.0 2,037.0 6/16/2023 07:00 6/16/2023 09:00 2.00 COMPZN, RPCOMP TRIP P Start TOOH F/2037 T/117' pulled tight at 117' PUW=60K work through and con't TOOH. T/39.28' 2,037.0 39.3 6/16/2023 09:00 6/16/2023 11:00 2.00 COMPZN, RPCOMP BHAH P LD G-spear MU IBP X-O's and IBP. 39.3 52.3 6/16/2023 11:00 6/16/2023 11:30 0.50 COMPZN, RPCOMP SVRG P Service rig 52.3 0.0 6/16/2023 11:30 6/16/2023 12:30 1.00 COMPZN, RPCOMP TRIP P TIH F/52.3 T/117' tag at 4.5" OD 2-3/8" Reg x 3-1/2" PH-6 X-O. unable to pass. POOH L/D BHA. 52.3 117.0 6/16/2023 12:30 6/16/2023 13:00 0.50 COMPZN, RPCOMP BHAH P LD BHA 0.0 0.0 6/16/2023 13:00 6/16/2023 16:00 3.00 COMPZN, RPCOMP WAIT P Wait on E-line. Service rig work on skate. Clean rig 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 5/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/16/2023 16:00 6/16/2023 19:45 3.75 COMPZN, RPCOMP ELOG P RIH with 1 11/16" 24 arm caliper log tool Log 5 1/2" from 2,045' to surface Break logging tools down, leave Eline rig up 0.0 0.0 6/16/2023 19:45 6/17/2023 00:00 4.25 COMPZN, RPCOMP WAIT P Wait on IBP from Baker Service rig work on skate. Clean rig Rig up OA to take returns out of 0.0 0.0 6/17/2023 00:00 6/17/2023 01:15 1.25 COMPZN, RPCOMP RURD P Baker IBP on location Test line connections with Baker computer. M/U tools and 2 1/8" IBP Tool string = 27.59' total CCL to C.O.E. = 23.69' 0.0 0.0 6/17/2023 01:15 6/17/2023 02:45 1.50 COMPZN, RPCOMP ELOG P RIH with 2 1/8" IBP on Eline T/1972' CCL depth P/U to 1,961' CCL, Element 1,983' - 1,987', C.O.E. @ 1,985' 341# UP WT Start pump to inflate IBP 0.0 1,988.0 6/17/2023 02:45 6/17/2023 03:30 0.75 COMPZN, RPCOMP ELNE P POOH R/D Eline 290# UP 1,977.0 0.0 6/17/2023 03:30 6/17/2023 04:30 1.00 COMPZN, RPCOMP TRIP P RIH with PH6 with M/S T/122' Tag up at 117' - L/D single make up top drive - take 3-5K DN, tried another full stand would not go, unable to screw into stands due to thread Pick up clean out of it Decide to dump sand ontop of IBP after growing casing 0.0 0.0 6/17/2023 04:30 6/17/2023 05:30 1.00 COMPZN, RPCOMP MPSP P Rig up to test IBP at 1,983' and 7 5/8" x 5 1/2" OA Test to 1800 PSI F/30 min Pump 1.1 BBLS, bleed back XX BBLS 0.0 0.0 6/17/2023 05:30 6/17/2023 08:00 2.50 COMPZN, RPCOMP OWFF P Bled off OA after pressure test. OWFF for 30 minutes after well static. 0.0 0.0 6/17/2023 08:00 6/17/2023 09:30 1.50 COMPZN, WELLPR NUND P ND BOP's and DSA. rack on the pedestal. 0.0 0.0 6/17/2023 09:30 6/17/2023 10:30 1.00 COMPZN, WELLPR NUND P ND wellhead No growth seen in 5.5" casing at wellhead. 0.0 0.0 6/17/2023 10:30 6/17/2023 10:45 0.25 COMPZN, WELLPR BHAH P Make up 5 1/2" spear to HT38 DP 0.0 6.5 6/17/2023 10:45 6/17/2023 12:00 1.25 COMPZN, WELLPR FISH P RIH to top of 5.5" casing at wellhead engage spear. PU to clear slips from wellhead. PU to 115K casing appears to have parted. Weight broke back to 30K 6.5 115.0 6/17/2023 12:00 6/17/2023 14:00 2.00 COMPZN, WELLPR BHAH P Pull Spear and 5 1/2" to surface, could not get spear to release, cut joint on floor with air powered saw. R/U GBR 115.0 88.0 6/17/2023 14:00 6/17/2023 15:00 1.00 COMPZN, WELLPR PULL P Pull and L/D 116.53' of 5 1/2" casing 116.53' from Nordic 3 RKB 115.38' from 7ES RKB 88.0 0.0 6/17/2023 15:00 6/17/2023 19:30 4.50 COMPZN, WELLPR NUND P N/U BOP with 11" 3K to 11" 5K spool Install riser and turn buckles 0.0 0.0 6/17/2023 19:30 6/17/2023 20:15 0.75 COMPZN, WELLPR BOPE P Set test plug, fill stack with water, R/U test equipment, purge air from lines, test breaks on BOP to 250/3000 PSI 5 min each 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 6/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/17/2023 20:15 6/18/2023 00:00 3.75 COMPZN, WELLPR ELOG P R/U Eline RIH with 1 11/16" 24 arm caliper to log the top of the 5 1/2" RIH to log the top 88' of 7 5/8" casing 0.0 0.0 6/18/2023 00:00 6/18/2023 00:45 0.75 COMPZN, WELLPR ELOG P Log 7 5/8" casing from 108' to surface with 3 1/8" 40 arm caliper tool Caliper log show smallest ID of 6.745" at 108' thats as far down as tool can go before tagging up on 5 1/2" stump POOH 0.0 0.0 6/18/2023 00:45 6/18/2023 02:30 1.75 COMPZN, WELLPR ELOG P M/U 5' of 160 grain string shot, corrrelate CCL at 1,400' , pull up to 1,200',RIH T/1,291' fire shot F/1,292' T/1,297' Eline depth, shoot across collar at 1,294' Eline depth. 1,305' casing tally depth POOH R/D Eline 0.0 0.0 6/18/2023 02:30 6/18/2023 03:30 1.00 COMPZN, WELLPR WAIT P Discuss options for plan forward after seeing 5 1/2" and 7 5/8" caliper logs Decide to get 4 3/4" mills and equipment coming from Baker shop in Deadhorse 0.0 0.0 6/18/2023 03:30 6/18/2023 05:30 2.00 COMPZN, WELLPR RURD P Load and process 24 JTS PH6 in pipe shed Put in wear ring 0.0 0.0 6/18/2023 05:30 6/18/2023 08:00 2.50 COMPZN, WELLPR PULD P PU Mule shoe on 3-1/2" PH-6 work down to 187'. Set down 3-5K at top of 5.5" casing work up and down to get pipe to 187' PUW=10K decision made to stop and dump sand at 187' 0.0 0.0 6/18/2023 08:00 6/18/2023 14:30 6.50 COMPZN, WELLPR OTHR P Dump 18 bags of sand at 1 bag per 20 minutes to allow to fall and not plug off DP. 0.0 187.0 6/18/2023 14:30 6/18/2023 15:00 0.50 COMPZN, WELLPR BHAH P LD DP and mule shoe joint. 187.0 187.0 6/18/2023 15:00 6/18/2023 16:30 1.50 COMPZN, WELLPR BHAH P PU 4.813" Swedge BHA BS jars accelerator 3ea. 4.75" DC's 187.0 105.1 6/18/2023 16:30 6/18/2023 17:30 1.00 COMPZN, WELLPR SWDG P PU single and attempt to swedge. Tag at 114' inside 7-5/8" casing. 105.1 114.0 6/18/2023 17:30 6/18/2023 19:30 2.00 COMPZN, WELLPR BHAH P LD a single , C/O BHA to bigger thread connections on BHA #5 114.0 0.0 6/18/2023 19:30 6/18/2023 20:30 1.00 COMPZN, WELLPR SWDG P RIH with 4.813" swage tag at 114', swage down setting down to 5K on hook and max over pull seen was 15K No progress made 0.0 0.0 6/18/2023 20:30 6/18/2023 21:30 1.00 COMPZN, WELLPR SVRG P Inspect top drive and derrick after swaging while discussing path forward 0.0 114.0 6/18/2023 21:30 6/18/2023 22:30 1.00 COMPZN, WELLPR BHAH P POOH, L/D BHA 114.0 0.0 6/18/2023 22:30 6/18/2023 23:30 1.00 COMPZN, WELLPR PRTS P R/U test 7 5/8" and 5 1/2" to 1600 PSI for 5 min, good test 0.0 0.0 6/18/2023 23:30 6/19/2023 00:00 0.50 COMPZN, WELLPR WAIT P Discuss path forward 0.0 0.0 6/19/2023 00:00 6/19/2023 00:30 0.50 COMPZN, WELLPR WAIT P Discuss path forward 0.0 0.0 6/19/2023 00:30 6/19/2023 01:00 0.50 COMPZN, WELLPR BHAH P Load BHA components into pipe shed and rig floor 0.0 0.0 6/19/2023 01:00 6/19/2023 01:00 COMPZN, WELLPR BHAH P M/U BHA # 6, 3 3/4" bull nose drift run T/65' 0.0 65.0 6/19/2023 01:00 6/19/2023 01:30 0.50 COMPZN, WELLPR TRIP P RIH T/116' Tag up at 116' 65.0 116.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 7/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/19/2023 01:30 6/19/2023 02:15 0.75 COMPZN, WELLPR TRIP P POOH to change out BHA discuss what to run next Bring up tools to rig floor 116.0 0.0 6/19/2023 02:15 6/19/2023 03:15 1.00 COMPZN, WELLPR BHAH P L/D BHA #6 0.0 0.0 6/19/2023 03:15 6/19/2023 03:45 0.50 COMPZN, WELLPR TRIP P M/U PH6 mule shoe to see if 3 1/2" tube will go into 5 1/2" casing 0.0 34.0 6/19/2023 03:45 6/19/2023 04:15 0.50 COMPZN, WELLPR TRIP P RIH on HT38 from pipe shed T/116.41' Pick up 1/4 turn make 6" - rotate pipe by hand and can make it go down POOH L/D mule shoe 34.0 0.0 6/19/2023 04:15 6/19/2023 05:00 0.75 COMPZN, WELLPR BHAH P Pick up 6 3/4" junk mill to drift 7 5/8" with RIH T/109.81' tag up POOH L/D mill 0.0 0.0 6/19/2023 05:00 6/19/2023 05:30 0.50 COMPZN, WELLPR BHAH P Clean and clear rig floor of BHA tools 0.0 0.0 6/19/2023 05:30 6/19/2023 06:00 0.50 COMPZN, WELLPR SVRG P Service rig 0.0 0.0 6/19/2023 06:00 6/19/2023 16:00 10.00 COMPZN, WELLPR WAIT P Discuss plan forward for getting 3 1/2" out of hole and for getting a RBP set deeper in the 5 1/2" casing, Wait on fishing tools and mills from Deadhorse Work on house keeping and perform rig maintenance 0.0 0.0 6/19/2023 16:00 6/19/2023 17:00 1.00 COMPZN, WELLPR BHAH P M/U BHA #7 with a 4 1/2" rough OD string mill and 2 7/8" bull nose on the end RIH tag up at 129' - mill depth = 113' 0.0 129.0 6/19/2023 17:00 6/19/2023 18:00 1.00 COMPZN, WELLPR MILL P Mill F/129' T/141' bull nose depth Mill depth = 113' T/125' Have 1300# TQ with 60 RPM while milling 60 RPM 830 pounds TQ free TQ 5 BPM 100 PSI 129.0 141.0 6/19/2023 18:00 6/19/2023 18:45 0.75 COMPZN, WELLPR TRIP P POOH , L/D BHA # 7 141.0 0.0 6/19/2023 18:45 6/19/2023 19:30 0.75 COMPZN, WELLPR BHAH P M/U BHA # 8 with 4 1/2" rough OD string mill and one rough OD 4 3/4" string mill with 2 7/8" bull nose T/45 RIH T/124' bull nose depth Recover pin end from 5 1/2" collar where pipe pulled into 0.0 124.0 6/19/2023 19:30 6/19/2023 20:30 1.00 COMPZN, WELLPR MILL P Tag up at 124' bull nose depth, 108' 4 1/2" mill depth Mill F/124' T/154' Bullnose depth Mill depth = 108' T/139' with 4 1/2" mill Mill Depth = 93' T/115' with 4 /3" mill 124.0 154.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 8/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/19/2023 20:30 6/19/2023 21:30 1.00 COMPZN, WELLPR CIRC P Pick up and work pipe F/154' T/120' bull nose depth Working mills thru 5 1/2" casing 60 RPM 1100 TQ - 770 pounds free TQ when mills out of 5 1/2" 5 BPM 140 PSI Attempt to dry drift after working mills, tag up at 130' bull nose, 4 1/2" mill at 114' set down 5K Pick up and work mills again twice F/154' T/120' with 60 RPM and 5 BPM - at 154' turn off rotary and pull out with 3- 5K drag up, attempt to slack off again with no success 154.0 120.0 6/19/2023 21:30 6/19/2023 22:00 0.50 COMPZN, WELLPR TRIP P POOH L/D BHA #8 120.0 0.0 6/19/2023 22:00 6/19/2023 22:45 0.75 COMPZN, WELLPR BHAH P M/U BHA #9 to 59' with 1 rough OD 4 1/2" mill , and one rough 4 3/4" OD string mill with a smooth 4 3/4" OD string mill stack on top of one another 10' back from 4 1/2" mill RIH to 118' bull nose depth 0.0 118.0 6/19/2023 22:45 6/20/2023 00:00 1.25 COMPZN, WELLPR MILL P Tag up at 118' slack off to 126' with 3K down drag, bull nose depths, 4 1/2" mill at 110' P/U to 120' bull nose depth Start milling F/120' T/146' bullnose depth 4 1/2" mill at 104' - 130 4 3/4" mill at 91' - 117' 4 3/4" mill at 87' - 113' 60 RPM 500 pound free TQ - have 1200 - 1400 with 4 1/2" mill in 5 1/2" and 1600 - 1800 TQ when milling with 4 3/4" in 5 1/2" 5 BPM 120 PSI Get first 4 3/4" mill to 113' and see mill work TQ from 1400 to 1700 - 1800 pounds 118.0 146.0 6/20/2023 00:00 6/20/2023 00:45 0.75 COMPZN, WELLPR MILL P Mill F/146' T/148' bull nose depth 4 1/2" mill = 130' - 132' 4 3/4" mill = 117' - 119' 4 3/4" mill = 113' - 115' 60 RPM 1700 - 1800 pounds TQ 5 BPM 100 PSI 146.0 148.0 6/20/2023 00:45 6/20/2023 02:00 1.25 COMPZN, WELLPR TRIP P Notice loss of pump PSI fromm 120 to 50 Not decrease in TQ and no TQ spike before POOH to inspect BHA - broke 2 7/8" Pac connection between the two 4 3/4" mills Lost 33.09' of BHA From bottom of smooth OD string mill to bull nose TOF @ 116' L/D BHA 148.0 0.0 6/20/2023 02:00 6/20/2023 03:15 1.25 COMPZN, WELLPR WAIT T Work on house keeping and perform rig maintenance While getting fishing tools from Deadhorse to fish out mills 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 9/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/20/2023 03:15 6/20/2023 03:45 0.50 COMPZN, WELLPR WAIT T Attempt to test 7 5/8" and 5 1/2" casing, pump 4 strokes and get to 90 PSI, pump 11 total strokes and no gain in pressure Total pump = .6 BBLS Flow check static Monitor well on trip tank 0.0 0.0 6/20/2023 03:45 6/20/2023 05:45 2.00 COMPZN, WELLPR WAIT T Work on house keeping and perform rig maintenance While getting fishing tools from Deadhorse to fish out mills 0.0 0.0 6/20/2023 05:45 6/20/2023 06:15 0.50 COMPZN, WELLPR BHAH T Baker tools on location Load tools into pipe shed and rig floor 0.0 0.0 6/20/2023 06:15 6/20/2023 06:45 0.50 COMPZN, WELLPR BHAH T M/U BHA T/46' 0.0 46.0 6/20/2023 06:45 6/20/2023 07:30 0.75 COMPZN, WELLPR FISH T Wash DN F/46' T/111' Tag up at 111' 3 BPM 50 PSI 15 RPM 800 pounds free TQ - 900 - 1200 pounds TQ from 111' to 114' Work down to 114' with rotary and 10 - 25K DN 46.0 114.0 6/20/2023 07:30 6/20/2023 08:15 0.75 COMPZN, WELLPR BHAH T POOH to inspect tools Wear on overshot Change out BHA for something more flex to get thru bad spot in casing 114.0 0.0 6/20/2023 08:15 6/20/2023 09:00 0.75 COMPZN, WELLPR BHAH T M/U BHA #11 T/36' 0.0 36.0 6/20/2023 09:00 6/20/2023 09:15 0.25 COMPZN, WELLPR FISH T Wash down F/36' T/111' 3 BPM 50 PSI Tag up with 2K DN Rotate at 20 RPM 300 pounds free TQ Wash/ream down to 114.89' stall rotary at 1400 pounds P/U clean no drag from fish 36.0 114.0 6/20/2023 09:15 6/20/2023 09:45 0.50 COMPZN, WELLPR TRIP T POOH to change over shot for cut lip guide 114.0 0.0 6/20/2023 09:45 6/20/2023 10:15 0.50 COMPZN, WELLPR BHAH T Make up BHA #12 T/38' 0.0 38.0 6/20/2023 10:15 6/20/2023 10:45 0.50 COMPZN, WELLPR FISH T Wash down F/36' T/114 3 BPM 50 PSI Tag up at 114' Rotate at 15-20 RPM Wash/ream down T/114' Stalled once then unable to get grapple to catch fish with cut lip unable to S/O past 114' 36.0 114.0 6/20/2023 10:45 6/20/2023 11:45 1.00 COMPZN, WELLPR BHAH T Lay down and inspect BHA, cut lip folded over and worn not catching fish, break down and lay down all BHA 114.0 0.0 6/20/2023 11:45 6/20/2023 13:00 1.25 COMPZN, WELLPR BHAH T Strap and pick up milling BHA# 13 // 4.75" junk mill, Bumper sub, Oil jar, accelorator // Total length 101.43' 0.0 102.0 6/20/2023 13:00 6/20/2023 14:30 1.50 COMPZN, WELLPR MILL T Mill down F/111' T/114 5 BPM 300 ROT= 62 rpm TQ= 1700 ft/lbs Clean up top of 5.5" above fish for good access to fish inside of 5.5" Attempt to knock 4-3/4" tandem mills down hole, no movement 102.0 115.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 10/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/20/2023 14:30 6/20/2023 15:30 1.00 COMPZN, WELLPR BHAH T Lay down and inspect BHA# 13 115.0 0.0 6/20/2023 15:30 6/20/2023 16:30 1.00 COMPZN, WELLPR BHAH T Pick up slim BHA# 14 0.0 100.0 6/20/2023 16:30 6/20/2023 17:45 1.25 COMPZN, WELLPR FISH T Attempt to dislodge fish down hole // No movement on fish 100.0 115.0 6/20/2023 17:45 6/20/2023 18:30 0.75 COMPZN, WELLPR BHAH T Lay down BHA# 14 slim assembly 115.0 0.0 6/20/2023 18:30 6/20/2023 19:00 0.50 COMPZN, WELLPR OTHR T Pull and inspect wear ring, re-install and secure 0.0 0.0 6/20/2023 19:00 6/20/2023 19:30 0.50 COMPZN, WELLPR SVRG T Service rig 0.0 0.0 6/20/2023 19:30 6/20/2023 20:30 1.00 COMPZN, WELLPR BHAH T Pick up BHA# 15 6.75" junk mill w/ tandem 6.75" string mills T/107' BHA length = 111.94' 0.0 107.0 6/20/2023 20:30 6/20/2023 21:00 0.50 COMPZN, WELLPR BHAH T Make up single to BHA and top drive Tag up at 109', same spot as previous 6 3/4' junk mill drift run 107.0 109.0 6/20/2023 21:00 6/20/2023 21:30 0.50 COMPZN, WELLPR MILL T Mill F/109' T/110' 35K up and down 5 BPM 125 PSI 80 RPM 500# free TQ 1200 - 1500 -- pounds TQ while milling at 109' T/110' TQ drop down to 1000 - 1100 pounds at 110' 2-3K WT on mills Get to 110.5' gain weight on mills, but wont drill off, pick up clean 109.0 110.0 6/20/2023 21:30 6/20/2023 22:00 0.50 COMPZN, WELLPR BHAH T POOH to inspect BHA make sure everything looked good, all components looked good Lay down single of DP, oil jars, drill collars and accelerator jars and pick back up T/107' 110.0 107.0 6/20/2023 22:00 6/20/2023 22:30 0.50 COMPZN, WELLPR BHAH T Make up single to BHA and top drive Tag up at 109', same spot as previous 6 3/4' junk mill drift run 107.0 109.0 6/20/2023 22:30 6/21/2023 00:00 1.50 COMPZN, WELLPR MILL T Mill F/109' T/114' 35K up and down 5 BPM 125 PSI 80 RPM 500# free TQ 1200 - 1500 -- pounds TQ while milling at 109' - 110.5' 2-3K WT on mills Get to 110.5' TQ drop to 570 pounds, ream down tag at 113.5' start getting TQ and weight on mills Mill to 114.5', TQ increase to 2500 - 3100 pounds, first string mill at 108.23' Start to stall out rotary at 114.5' pick up to 112' clear mills, ease back top bottom and at 114' started milling off slower 109.0 114.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 11/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/21/2023 00:00 6/21/2023 02:45 2.75 COMPZN, WELLPR MILL T Mill F/114' T/115' 35K up and down 5 BPM 125 PSI 80 RPM 500# free TQ 1400 - 1700 pounds TQ 2-5K WT on mills Try various parameters with RPM, working mills up to 111' and back down to 115', still no depth progress no change in TQ and weight wont drill off, not much metal back at shakers 114.0 115.0 6/21/2023 02:45 6/21/2023 03:30 0.75 COMPZN, WELLPR BHAH T PJSM - POOH F/115' to surface Inspect mills 6 3/4" junk mill used up 115.0 0.0 6/21/2023 03:30 6/21/2023 04:15 0.75 COMPZN, WELLPR BHAH T Change out 6 3/4" junk mill M/U BHA #16 T/108' Kelly up on a single of drill pipe Wash DN F/108' T/113.5 5 BPM 120 PSI 70 RPM 570# TQ TQ at 109' - 110' from 560# T/1100 - 1200# From 110' to 113.5' no real TQ and no WT on mills At 113.5' start getting TQ 1300#, 1-3K on mills 0.0 113.5 6/21/2023 04:15 6/21/2023 06:00 1.75 COMPZN, WELLPR MILL T Mill F/113.5 T/115.5' 5 BPM 120 PSI 70 RPM 570# free TQ 1200 - 1300 pounds TQ 2-4K WT on mills 113.5 115.5 6/21/2023 06:00 6/21/2023 07:15 1.25 COMPZN, WELLPR BHAH T Inspect mills and BHA 115.5 0.0 6/21/2023 07:15 6/21/2023 07:45 0.50 COMPZN, WELLPR CLEN T Clean floor for BHA remove tools not being useed 0.0 0.0 6/21/2023 07:45 6/21/2023 08:45 1.00 COMPZN, WELLPR BHAH T Pick up BHA# 16 overshot unable to catch fish stack ate 113.5' 0.0 113.0 6/21/2023 08:45 6/21/2023 09:15 0.50 COMPZN, WELLPR BHAH T Lay down overshot BHA 16 113.0 0.0 6/21/2023 09:15 6/21/2023 09:45 0.50 COMPZN, WELLPR BHAH T Pick up BHA 17 slim assembly with bull nose attemp to move fish down hole 0.0 110.0 6/21/2023 09:45 6/21/2023 10:45 1.00 COMPZN, WELLPR FISH T Tag fish @ 115' , set wt on fish move down hole 8' then fish fell down hole, 110.0 120.0 6/21/2023 10:45 6/21/2023 11:15 0.50 COMPZN, WELLPR WAIT T Discuss plan forward with town 120.0 120.0 6/21/2023 11:15 6/21/2023 12:15 1.00 COMPZN, WELLPR BHAH T Lay down BHA# 17 slim assembly 120.0 0.0 6/21/2023 12:15 6/21/2023 13:30 1.25 COMPZN, WELLPR BHAH T Pick up BHA# 18 packer mill assembly 0.0 110.0 6/21/2023 13:30 6/21/2023 18:00 4.50 COMPZN, WELLPR MILL T Mill down 5.5" F/ 115' T/123' 5 bpm @ 500psi Rot 68 rpm 1300 tq 110.0 123.0 6/21/2023 18:00 6/21/2023 19:00 1.00 COMPZN, WELLPR CIRC T Circ at 8 BPM 130 PSI While crew change out and get next BHA drafted up and mobilized to rig floor 123.0 123.0 6/21/2023 19:00 6/21/2023 20:00 1.00 COMPZN, WELLPR BHAH T POOH L/D BHA # 18 123.0 0.0 6/21/2023 20:00 6/21/2023 21:00 1.00 COMPZN, WELLPR BHAH T Mobilize BHA components to floor M/U BHA #19 to drift 5 1/2" for MSC Drift T/191' with 3.75" OD bull nose POOH L/D BHA Notice lots of metal cuttings packed inside crossover on BHA 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 12/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/21/2023 21:00 6/21/2023 21:15 0.25 COMPZN, WELLPR TRIP T RIH W/PH6 mule shoe RIH T/220' 0.0 220.0 6/21/2023 21:15 6/21/2023 22:00 0.75 COMPZN, WELLPR CIRC T Circ at 8 BPM 100 PSI to remove any metal cuttings that may have fallen down the 5 1/2" so we dont plug off MSC BHA on trip in Flow check, blow down top drive,POOH L/D mule shoe 220.0 0.0 6/21/2023 22:00 6/21/2023 22:30 0.50 COMPZN, WELLPR BHAH T P/U BHA #20 with 3.75" MSC T/131' 0.0 131.0 6/21/2023 22:30 6/21/2023 23:00 0.50 COMPZN, WELLPR CPBO T Locate casing collar @ 3.5 BPM 500 PSI Slack off to 159.41' knife depth tag collar P/U 4' T/155.41' Cut casing at 65 RPM 500# free TQ 3.7 BPM 500 PSI - 580 - 620# TQ while cutting Turn off rotary set down 5K - P/U 2' turn off rotary slack off 1-2K bobbles 131.0 155.0 6/21/2023 23:00 6/21/2023 23:30 0.50 COMPZN, WELLPR BHAH T POOH L/D BHA # 20 One knife have chip, fishing hand not satisfied with wear pattern on knives Change out knives in MSC 155.0 0.0 6/21/2023 23:30 6/22/2023 00:00 0.50 COMPZN, WELLPR SVRG T Service rig 0.0 0.0 6/22/2023 00:00 6/22/2023 00:45 0.75 COMPZN, WELLPR CPBO T M/U BHA #21 MSC RIH T/150' Locate cut at 155' Cut casing at 65 PRM 500# TQ, 3.7 BPM 500 PSI TQ to 700 - 800# - feed knives 4 times TQ increase to 900 - 1100# each time 0.0 155.0 6/22/2023 00:45 6/22/2023 01:15 0.50 COMPZN, WELLPR BHAH T POOH L/D BHA # 20 Knives show good indication of cutting 155.0 0.0 6/22/2023 01:15 6/22/2023 02:30 1.25 COMPZN, WELLPR BHAH T M/U BHA #22 T/103' Spear with 4.961" grapple 0.0 103.0 6/22/2023 02:30 6/22/2023 03:15 0.75 COMPZN, WELLPR FISH T Slack off 19' to 126' engage fish, put spear 7' into fish,see 3-5K drag as spear entered fish P/U 5' and pull 10K over, Slack off spear slide down into fish, P/U pull 40K over to 75K on hook, kelly up pump at 5 BPM 200 PSI, work fish free Max over pull = 60K over to 90K on hook, work fish free see 10 - 15K drag while pulling fish past 119' 103.0 155.0 6/22/2023 03:15 6/22/2023 04:00 0.75 COMPZN, WELLPR BHAH T L/D BHA and fish Fish length = 29.88', total 5 1/2" pulled/milled = 125.55' 155.0 0.0 6/22/2023 04:00 6/22/2023 04:30 0.50 COMPZN, WELLPR SVRG T Service rig 0.0 0.0 6/22/2023 04:30 6/22/2023 06:00 1.50 COMPZN, WELLPR BHAH T Mobilze BHA componets to rig floor for dressing up 7 5/8" CSG M/U BHA #22 - 6 3/4" string mills Tag up at 109' with 5K DN 0.0 110.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 13/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/22/2023 06:00 6/22/2023 09:15 3.25 COMPZN, WELLPR REAM T Ream area between 109' and 155' 5 BPM 75 PSI, 75 RPM 550# free TQ 119' - 127' TQ up to 1200 - 1400# ream 6 times Drift 5K drag up and down 119' - 127' Clean up area re-drift 3K PU through 127' - 119' 110.0 155.0 6/22/2023 09:15 6/22/2023 10:15 1.00 COMPZN, WELLPR BHAH T Lay down BHA 155.0 0.0 6/22/2023 10:15 6/22/2023 10:45 0.50 COMPZN, WELLPR SVRG T Service rig 0.0 0.0 6/22/2023 10:45 6/22/2023 11:45 1.00 COMPZN, WELLPR WAIT T Wait on tools from DH for clean out run 0.0 0.0 6/22/2023 11:45 6/22/2023 14:00 2.25 COMPZN, WELLPR BHAH T Pick up and make up BHA for clean out run of 5.5" Pick stack out 175' rotate BHA able to move down, cross over to drill pipe to circulate down catch any debris 0.0 175.0 6/22/2023 14:00 6/22/2023 14:45 0.75 COMPZN, WELLPR WASH T Wash BHA into hole F/175' T/189 5 BPM 630 PSI and 45 RPM 520# TQ 175.0 189.0 6/22/2023 14:45 6/22/2023 16:30 1.75 COMPZN, WELLPR TRIP T TIH w/ stands PH6 F/189' T/1,877' 189.0 1,877.0 6/22/2023 16:30 6/22/2023 18:15 1.75 COMPZN, WELLPR CIRC T Circ cond brine around, get vis up to 77 5 BPM 800 PSI 1,877.0 1,877.0 6/22/2023 18:15 6/22/2023 19:00 0.75 COMPZN, WELLPR CIRC T Drop 1/2" ball for RCJB pump down at 3 BPM 500 PSI , PSI up to 570 when ball on seat 1,877.0 1,877.0 6/22/2023 19:00 6/22/2023 19:30 0.50 COMPZN, WELLPR FISH T Wash DN F/1,877' T/1,905' 4 BPM 730 PSI Slack off set DN 2K at 1,905' Pick up work pipe to clean up area around top of fish Slack off to 1905' re tag TOF with 2-3K DN, slack off 2' to 1,907', set DN 5K, P/U clean at 48K UP 48K UP 45K DN Pick up to 1,904' 1,877.0 1,904.0 6/22/2023 19:30 6/22/2023 19:45 0.25 COMPZN, WELLPR CIRC T CIrc 3' above fish at 8 BPM 1800 PSI 1,904.0 1,904.0 6/22/2023 19:45 6/22/2023 20:30 0.75 COMPZN, WELLPR TRIP T POOH F/1,904' T/280' 1,904.0 280.0 6/22/2023 20:30 6/22/2023 21:00 0.50 COMPZN, WELLPR BHAH T PJSM L/D BHA Flow check static 280.0 280.0 6/22/2023 21:00 6/22/2023 22:00 1.00 COMPZN, WELLPR BHAH T L/D BHA #23 Clean magnets Boot baskets empty Some gravel and metal in RCJB 280.0 0.0 6/22/2023 22:00 6/22/2023 22:30 0.50 COMPZN, WELLPR BHAH T Clean clear rig floor, bring up BHA #24 components 0.0 0.0 6/22/2023 22:30 6/22/2023 23:15 0.75 COMPZN, WELLPR BHAH T M/U BHA #24 T/180' 0.0 180.0 6/22/2023 23:15 6/23/2023 00:00 0.75 COMPZN, WELLPR TRIP T RIH on PH6 F/180' T/1,310' 45K UP 42K DN 180.0 1,310.0 6/23/2023 00:00 6/23/2023 00:30 0.50 COMPZN, WELLPR TRIP T RIH on PH6 F/1,310' T/1,877' 45K UP 42K DN 1,310.0 1,877.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 14/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/23/2023 00:30 6/23/2023 01:15 0.75 COMPZN, WELLPR FISH T Circulate at 3 BPM 400 PSI Slack off to 1,908' No pump PSI increase Set DN 5K P/U see no increase in up WT Make several attempts to engage fish, with rotary at 15 RPM 800# free TQ - slack off set DN 10 - 15K several times stall rot out at 2K, working down to 1,911' 48K UP 45K DN 1,877.0 1,911.0 6/23/2023 01:15 6/23/2023 02:45 1.50 COMPZN, WELLPR TRIP T POOH F/1,911' T/190' 1,911.0 180.0 6/23/2023 02:45 6/23/2023 03:30 0.75 COMPZN, WELLPR BHAH T L/D BHA #24 Clean magnets, boot baskets empty Inside of over shot show no signs of being over fish neck 180.0 0.0 6/23/2023 03:30 6/23/2023 04:30 1.00 COMPZN, WELLPR BHAH T M/U BHA #25 clean out assemably with RCJB T/180' 0.0 180.0 6/23/2023 04:30 6/23/2023 06:15 1.75 COMPZN, WELLPR TRIP T RIH F/180' T/1,877' 180.0 1,877.0 6/23/2023 06:15 6/23/2023 06:45 0.50 COMPZN, WELLPR FISH T Fish on mills, Tag 1909' work down on fish 1911' 1,877.0 1,911.0 6/23/2023 06:45 6/23/2023 08:15 1.50 COMPZN, WELLPR TRIP T POOH with clean out assembly 1,911.0 150.0 6/23/2023 08:15 6/23/2023 09:15 1.00 COMPZN, WELLPR BHAH T Lay down clean out assemlby and inspect BHA# 25 Top 4.75" reamer recovered in RCJB, break down tools to remove fish 150.0 0.0 6/23/2023 09:15 6/23/2023 09:45 0.50 COMPZN, WELLPR BHAH T Make up clean out assembly to RIH for second fish 0.0 150.0 6/23/2023 09:45 6/23/2023 11:00 1.25 COMPZN, WELLPR TRIP T TIH to top of fish 150.0 1,905.0 6/23/2023 11:00 6/23/2023 11:30 0.50 COMPZN, WELLPR FISH T Work down over fish , indications of retrieving fish 1,905.0 1,912.0 6/23/2023 11:30 6/23/2023 13:00 1.50 COMPZN, WELLPR TRIP T TOOH with clean out ( fishing ) BHA# 26 Fish length = 29.12' All fish recovered 1,912.0 150.0 6/23/2023 13:00 6/23/2023 14:45 1.75 COMPZN, WELLPR BHAH T Lay down and inspect BHA# 26 cleanout ( fishing ) assembly 150.0 0.0 6/23/2023 14:45 6/23/2023 16:30 1.75 COMPZN, WELLPR CLEN P Remove all fishing tools from rig and clean up floor // Prep fish and broken tools for transport to DH Baker shop 0.0 0.0 6/23/2023 16:30 6/23/2023 17:00 0.50 COMPZN, WELLPR SVRG P Service rig // Grease topdrive blocks and crown 0.0 0.0 6/23/2023 17:00 6/23/2023 17:30 0.50 COMPZN, WELLPR TRIP P Make up BHA #27 MSC RIH T/255' 0.0 255.0 6/23/2023 17:30 6/23/2023 18:15 0.75 COMPZN, WELLPR CPBO P Locate casing collar at 1.3 BPM 250 PSI Slack off to 281.41' knife depth set DN 2K, pick 20' to 261.41' Cut casing at 67 RPM 550# free TQ 3 BPM 990 PSI, TQ climb to 1000# and drop to 600# indicating casing cut Turn off rotary, slack off 3K on knifes 255.0 261.0 6/23/2023 18:15 6/23/2023 18:45 0.50 COMPZN, WELLPR TRIP P POOH F/261', L/D BHA 261.0 0.0 6/23/2023 18:45 6/23/2023 19:45 1.00 COMPZN, WELLPR BHAH P Load BHA components in to pipe shed, M/U BHA #28, spear with 4.961" grapple T/95' 0.0 95.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 15/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/23/2023 19:45 6/23/2023 20:30 0.75 COMPZN, WELLPR FISH P RIH F/95' T/156' 35K UP and DN Pump 3 BPM 100 PSI; slack off engage fish with spear, set DN 5K , see 40 PSI pump increase, P/U gain 4K in up WT 95.0 157.0 6/23/2023 20:30 6/23/2023 21:45 1.25 COMPZN, WELLPR BHAH P L/D 2 singles DP, L/D BHA to 23' Set slips on 5 1/2" release spear and L/D BHA R/U GBR, L/D 5 1/2" CSG = 107' and one bow spring centralizer R/D GBR 157.0 0.0 6/23/2023 21:45 6/23/2023 23:00 1.25 COMPZN, WELLPR BHAH P M/U BHA #29, 6 1/8" Packer mill with 6 3/4" string mills T/95' 0.0 95.0 6/23/2023 23:00 6/23/2023 23:15 0.25 COMPZN, WELLPR TRIP P RIH F/95' T/127' Tag at 127' bullnose depth, 120' and 114' 6 3/4" string mill depth Set 5K DN 95.0 127.0 6/23/2023 23:15 6/24/2023 00:00 0.75 COMPZN, WELLPR REAM P Work mills F/120' T/114' 5 BPM 100 PSI 70 RPM 730 free TQ See 3-5K drag at 114' See 1900 - 2800 pounds TQ while working mills thru area 120' - 114' Work DN to 160', turn off rotary pick up thru and see 8 - 12K over pull and 8 - 12K DN to push thru at 120' , several times 127.0 127.0 6/24/2023 00:00 6/24/2023 00:30 0.50 COMPZN, WELLPR REAM P Work mills F/120' T/114' 5 BPM 100 PSI 70 RPM 730 free TQ See 3-5K drag at 114' See 1900 - 2800 pounds TQ while working mills thru area 120' - 114' See 8 - 10K over to pull thru, take 8 - 10K DN with no rotary Drift down to 190' clean from 127' to 190' 127.0 190.0 6/24/2023 00:30 6/24/2023 01:00 0.50 COMPZN, WELLPR REAM P RIH F/190' T/257' Wash DN @ 5 BPM 100 PSI Tag at 261' top of cut JT P/U rotate 65 RPM 750# free TQ TQ to 900# while working mill inside 5 1/2" 190.0 261.0 6/24/2023 01:00 6/24/2023 01:15 0.25 COMPZN, WELLPR TRIP P POOH F/261' T/90' See 8 - 10K over at 120' - 114' with string mills 261.0 95.0 6/24/2023 01:15 6/24/2023 01:30 0.25 COMPZN, WELLPR BHAH P L/D one drill collar, break off string mills and packer mill 95.0 0.0 6/24/2023 01:30 6/24/2023 01:45 0.25 COMPZN, WELLPR BHAH P M/U 6 5/8" burn shoe BHA #30 T/85' 0.0 85.0 6/24/2023 01:45 6/24/2023 02:45 1.00 COMPZN, WELLPR MILL P RIH F/85' T/259' Wash DN at 5 BPM 100 PSI Tag at 259' P/U rotate at 60 RPM 1000 - 1400# TQ Dress off 5 1/2" casing stump See 6K bobble down at 120' 85.0 259.0 6/24/2023 02:45 6/24/2023 03:30 0.75 COMPZN, WELLPR BHAH P POOH F/259' to surface L/D BHA, clean clear rig floor 259.0 0.0 6/24/2023 03:30 6/24/2023 04:15 0.75 COMPZN, WELLPR RURD P Bring up BHA tools Break out X/Over from 3 1/2" EUE to PH6 Change out DP elevators 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 16/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/24/2023 04:15 6/24/2023 04:45 0.50 COMPZN, WELLPR BHAH P M/U EA test packer BHA T/48' 0.0 48.0 6/24/2023 04:45 6/24/2023 05:00 0.25 COMPZN, WELLPR TRIP P RIH F/48' T/261' Tag up at 261' Set DN 5K, P/U pump at 3 BPM 80 PSI, put 2 turns to the right in string, attempt to get into the 5 1/2" no success, set DN 5-6K 48.0 261.0 6/24/2023 05:00 6/24/2023 06:00 1.00 COMPZN, WELLPR TRIP P POOH - inspect test packer 261.0 0.0 6/24/2023 06:00 6/24/2023 06:30 0.50 COMPZN, WELLPR BHAH P Reconfigure BHA to centrilize in pipe 0.0 0.0 6/24/2023 06:30 6/24/2023 07:30 1.00 COMPZN, WELLPR TRIP P RIH w/ test packer with GS spear to test 5.5" casing 0.0 261.0 6/24/2023 07:30 6/24/2023 08:15 0.75 COMPZN, WELLPR PRTS P Pressure test IBP and 5.5" to IBP // 1500 psi 30min 261.0 280.0 6/24/2023 08:15 6/24/2023 09:15 1.00 COMPZN, WELLPR TRIP P TOOH lay down packer 280.0 0.0 6/24/2023 09:15 6/24/2023 10:00 0.75 COMPZN, WELLPR OTHR P Pull wear ring 0.0 0.0 6/24/2023 10:00 6/24/2023 11:00 1.00 COMPZN, WELLPR RURD P Rig up to run 5.5" casing tie in with casing patch 0.0 0.0 6/24/2023 11:00 6/24/2023 13:00 2.00 COMPZN, WELLPR PUTB P P/U and run 5.5" casing patch, 10' pup, 6 - Jts 5.5" 15.5# HYD563 Casing // Unable to pass 114' with rotation or pushing 4k down with TD // Discuss with town engineer decision made to POOH and run string reamers 0.0 114.0 6/24/2023 13:00 6/24/2023 14:00 1.00 COMPZN, WELLPR PULL P Lay down casing and casing patch // Rig down casing crew 114.0 0.0 6/24/2023 14:00 6/24/2023 14:30 0.50 COMPZN, WELLPR OTHR P Install wear ring 0.0 0.0 6/24/2023 14:30 6/24/2023 15:30 1.00 COMPZN, WELLPR BHAH P Pick up 3 - 6.75" string mills in tandem to dress 114' area // 0.0 105.0 6/24/2023 15:30 6/24/2023 17:30 2.00 COMPZN, WELLPR REAM P Dressing hole with 3 - 6.75" string mills 70 RPM 1300 - 2400 TQ 8 BPM 75 PSI After reaming area see 5K DN at 114' - 120' area 105.0 125.0 6/24/2023 17:30 6/24/2023 19:00 1.50 COMPZN, WELLPR TRIP P POOH for drift run M/U casing patch on DP and RIH T/205' See 2-3K DN and up at 114' - to 120' POOH L/D casing patch Clean clear rig floor 125.0 0.0 6/24/2023 19:00 6/24/2023 19:30 0.50 COMPZN, WELLPR SVRG P Service rig 0.0 0.0 6/24/2023 19:30 6/24/2023 20:30 1.00 COMPZN, WELLPR RURD P Pull wear ring, R/U GBR to run casing 0.0 0.0 6/24/2023 20:30 6/24/2023 21:45 1.25 COMPZN, WELLPR PUTB P PJSM RIH with 5 1/2" HYD 563 with Logan External casing patch T/263.93' over shot depth, top of 5 1/2" stump at 261' M/U TQ = 6200 FT/LBS S/O set DN 5K, Pull 10K over, slack off 5K, pull 20K over, pull 50K over to 80K on hook 0.0 264.0 6/24/2023 21:45 6/24/2023 22:15 0.50 COMPZN, WELLPR MPSP P Test 5 1/2" casing to 1500 PSI F/30 m in, good test 264.0 264.0 6/24/2023 22:15 6/24/2023 22:45 0.50 COMPZN, WELLPR OWFF P Bleed off pressure, Flow check 264.0 264.0 6/24/2023 22:45 6/24/2023 23:30 0.75 COMPZN, WELLPR RURD P Drain BOP stack, suck out 5 1/2" joint for cutting at well head 264.0 264.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 17/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/24/2023 23:30 6/25/2023 00:00 0.50 COMPZN, WHDBOP NUND P Break BOP apart, P/U T/120K = 90K over 264.0 0.0 6/25/2023 00:00 6/25/2023 02:30 2.50 COMPZN, WHDBOP NUND P P/U T/120K = 90K over Set 5 1/2" slips Make cut on 5 1/2" L/D cut JT = 28.59' Set pack off 0.0 0.0 6/25/2023 02:30 6/25/2023 11:00 8.50 COMPZN, WHDBOP NUND P N/U TBG head, cut seals in reducer bushing while installing TBG head Cut riser to length, polish up top of 5 1/2" casing with emery cloth, load pipe shed with BHA while waiting to get more seals // different seal design needed to rig up old tubing head due to seal availability // Re-dress old tubing head to install on weall head with valves Test pack off and void T/3000 PSI F/15 Min and N/U BOP 0.0 0.0 6/25/2023 11:00 6/25/2023 11:30 0.50 COMPZN, WHDBOP BOPE P Set test plug Fill stack with water, set breaks to 250/3500 PSI 5 min each R/D test equipment, blow down lines 0.0 0.0 6/25/2023 11:30 6/25/2023 12:00 0.50 COMPZN, WHDBOP OTHR P Install wear ring 0.0 0.0 6/25/2023 12:00 6/25/2023 12:30 0.50 COMPZN, WELLPR CLEN P Clean and prep floor for picking up BHA 0.0 0.0 6/25/2023 12:30 6/25/2023 13:30 1.00 COMPZN, WELLPR BHAH P Pick up bha for cleaning out sand on top of IBP, RCJB 0.0 150.0 6/25/2023 13:30 6/25/2023 15:00 1.50 COMPZN, WELLPR TRIP P Trip in hole on stands PH6 clean out on top of IBP 150.0 1,900.0 6/25/2023 15:00 6/25/2023 16:00 1.00 COMPZN, WELLPR WASH P Wash/ream sand and junk off of IBP, Tag sand 1940' wash down 1950' 5 BPM 1300 PSI 50 RPM 800 - 900# TQ Circulate at 5 BPM 1300 PSI until returns clean at surface 1,900.0 1,950.0 6/25/2023 16:00 6/25/2023 17:00 1.00 COMPZN, WELLPR TRIP P POOH F/1,950' T/155' 1,950.0 155.0 6/25/2023 17:00 6/25/2023 18:00 1.00 COMPZN, WELLPR BHAH P L/D BHA , clean out RCJB RCJB have rocks and metal in it Decide to make another RCJB run 155.0 0.0 6/25/2023 18:00 6/25/2023 18:30 0.50 COMPZN, WELLPR SVRG P Service rig Clean clear rig floor 0.0 0.0 6/25/2023 18:30 6/25/2023 18:45 0.25 COMPZN, WELLPR BHAH P M/U BHA #34 RCJB T/155' 0.0 155.0 6/25/2023 18:45 6/25/2023 20:00 1.25 COMPZN, WELLPR TRIP P RIH F/155' T/1,952' 155.0 1,952.0 6/25/2023 20:00 6/25/2023 20:30 0.50 COMPZN, WELLPR CIRC P Wash/ream down F/1,940' T/1,962' 5 BPM 1330 PSI 600 RPM 740 free TQ - 800 - 1100 # TQ while ream down Circ until clean at 5 BPM 1300 PSI 1,940.0 1,962.0 6/25/2023 20:30 6/25/2023 21:30 1.00 COMPZN, WELLPR TRIP P POOH F/1,962' T/155' 1,962.0 155.0 6/25/2023 21:30 6/25/2023 22:00 0.50 COMPZN, WELLPR BHAH P Lay down BHA # 34 clean out RCJB 155.0 0.0 6/25/2023 22:00 6/25/2023 22:30 0.50 COMPZN, WELLPR BHAH P M/U BHA # 35 4 3/4" wash pipe T/160' 0.0 160.0 6/25/2023 22:30 6/25/2023 23:30 1.00 COMPZN, WELLPR TRIP P RIH F/160' T/1,946' 50K UP 45K DN 160.0 1,946.0 6/25/2023 23:30 6/26/2023 00:00 0.50 COMPZN, WELLPR WASH P Wash down @ 5 BPM 450 PSI S/O tag @ 1,965' with 5K DN P/U rotate at 25 RPM 750 - 800# TQ 1,946.0 1,965.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 18/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/26/2023 00:00 6/26/2023 01:00 1.00 COMPZN, WELLPR WASH P Wash down @ 5 BPM 450 PSI P/U rotate at 25 RPM 750 - 800# TQ S/O T/1,966' stall rotatry out at 1200# P/U T/1,964' Pump at 8 BPM 900 PSI S/O T/1,973' set DN 5K P/U 3' S/O tag same spot at 1,973' P/U 4' rotate 20 RPM 700 - 740# TQ S/O to 1,980' set DN 3K confirm tag, Pick up 3' to 1,978' 1,965.0 1,978.0 6/26/2023 01:00 6/26/2023 01:30 0.50 COMPZN, WELLPR CIRC P Circulate until shakers clean Roll hole to thin seawater, dump milling fluid 8 BPM 900 PSI, slow to 6 BPM 550 PSI Circulate until shakers clean 1,978.0 1,978.0 6/26/2023 01:30 6/26/2023 02:30 1.00 COMPZN, WELLPR TRIP P POOH F/1,978' T/160' 1,978.0 160.0 6/26/2023 02:30 6/26/2023 03:15 0.75 COMPZN, WELLPR BHAH P L/D BHA #35 Clean clear rig floor 160.0 0.0 6/26/2023 03:15 6/26/2023 03:45 0.50 COMPZN, WELLPR BHAH P M/U BHA #36 Retrieve IBP 0.0 0.0 6/26/2023 03:45 6/26/2023 05:30 1.75 COMPZN, WELLPR FISH P RIH T/1,949' Wash DN at 2 BPM 100 PSI 50K UP, 49K DN S/O T/2,001', set DN 2K, see snap in, slack off to 3K P/U see over pull at 5K, pull 8K release IBP 0.0 2,001.0 6/26/2023 05:30 6/26/2023 06:00 0.50 COMPZN, WELLPR OWFF P Flow check while IBP elements relax - static Monitor well on trip tank No flow noted at surface 2,001.0 2,001.0 6/26/2023 06:00 6/26/2023 07:00 1.00 COMPZN, WELLPR CIRC P Circulate B/U @ 3 bbls/min 370 psi // 2,001.0 2,001.0 6/26/2023 07:00 6/26/2023 08:30 1.50 COMPZN, WELLPR TRIP P TOOH with IBP 2,001.0 150.0 6/26/2023 08:30 6/26/2023 09:00 0.50 COMPZN, WELLPR BHAH P Lay down IBP // Install GS spear for liner retrieval 150.0 0.0 6/26/2023 09:00 6/26/2023 10:15 1.25 COMPZN, WELLPR TRIP P TIH to retrieve 3.5" completion 0.0 2,005.0 6/26/2023 10:15 6/26/2023 11:45 1.50 COMPZN, WELLPR SLPC P Cut and slip drill line 2,005.0 2,005.0 6/26/2023 11:45 6/26/2023 12:15 0.50 COMPZN, WELLPR SVRG P Service rig set crown saver grease blocks and TD 2,005.0 2,005.0 6/26/2023 12:15 6/26/2023 12:30 0.25 COMPZN, WELLPR FISH P Pu wt 53K So wt 50K // Tag Fish @ 2053' Pu 55K SO 44K // Pu 95K fish latched // OWFF no flow open ended pipe no trapped pressure 2,005.0 2,053.0 6/26/2023 12:30 6/26/2023 14:00 1.50 COMPZN, WELLPR TRIP P TOOH with 3.5" TBG on GS // PU wt from bottom 95K 2,053.0 85.0 6/26/2023 14:00 6/26/2023 14:30 0.50 COMPZN, WELLPR BHAH P Lay down fishing bha // pipe at surface 85.0 0.0 6/26/2023 14:30 6/26/2023 15:30 1.00 COMPZN, WELLPR CIRC P Circulate hole with good fluid while rigging up tubing tongs for laying down 3.5" completion // Shut down pump hole out of balance circulate B/U OWFF no flow proceed with laying down 3.5" completion 5,168.0 5,168.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 19/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/26/2023 15:30 6/26/2023 17:00 1.50 COMPZN, WELLPR PULL P Lay down 3.5" completion F/5,168' T/4,250' Note: Shut down have a saftey meeting about pipe shed, rig floor saftey when laying down pipe 5,168.0 4,250.0 6/26/2023 17:00 6/26/2023 17:30 0.50 COMPZN, WELLPR SFTY P Shut down, have a safety stand down about pipe shed safety, rig floor safety Discussed why we have red zones on floor and pipe shed. New guys to the rig and operations 4,250.0 4,250.0 6/26/2023 17:30 6/26/2023 22:00 4.50 COMPZN, WELLPR PULL P POOH F/4,250' Laying down 3 1/2" TBG to pipe shed 4,250.0 0.0 6/26/2023 22:00 6/26/2023 23:30 1.50 COMPZN, WELLPR RURD P Clear rig floor, R/D power tongs, change elevators, load 63 JTS PH6 in pipe shed and process, load BHA #38 in shed 0.0 0.0 6/26/2023 23:30 6/27/2023 00:00 0.50 COMPZN, WELLPR BHAH P M/U BHA T/22' 0.0 22.0 6/27/2023 00:00 6/27/2023 04:00 4.00 COMPZN, WELLPR TRIP P RIH F/22' T/3,900' 22.0 3,900.0 6/27/2023 04:00 6/27/2023 04:15 0.25 COMPZN, WELLPR MPSP P Set G lock as per baker 70K UP 60K DN Set DN T40K on hook = 20K DN Pick up T/90K over = 20K Set at 3,930' end of tool C.O.E. = 3,924.81' Top of fish neck @ 3920.36' P/U to 3,900' 3,900.0 3,900.0 6/27/2023 04:15 6/27/2023 05:15 1.00 COMPZN, WELLPR MPSP P Break circ down drill pipe R/U to test G lock to 2500 PSI F/30 Min Pump 1.8 BBLS OA PSI at start = 0 OA PSI with 2500 PSI on plug = 20 Bleed off pressure, flow check open rams, R/D test equipment 3,900.0 3,900.0 6/27/2023 05:15 6/27/2023 06:00 0.75 COMPZN, WELLPR TRIP P POOH F/3,900' T/3,489' Drain stack, rig up sand hopper, dump 18 sacks of sand 3,900.0 3,489.0 6/27/2023 06:00 6/27/2023 12:00 6.00 COMPZN, WELLPR OTHR P Dump 18 sacks of sand on top of G plug // 20 min per sack 3,489.0 3,489.0 6/27/2023 12:00 6/27/2023 12:30 0.50 COMPZN, WELLPR TRIP P TOOH 290' above sand 3,489.0 3,100.0 6/27/2023 12:30 6/27/2023 13:00 0.50 COMPZN, WELLPR CIRC P Circulate ensure pipe clean 3,100.0 3,100.0 6/27/2023 13:00 6/27/2023 15:00 2.00 COMPZN, WELLPR TRIP P TOOH for e-line work 3,100.0 100.0 6/27/2023 15:00 6/27/2023 15:30 0.50 COMPZN, WELLPR BHAH P Lay down BHA 100.0 0.0 6/27/2023 15:30 6/27/2023 17:45 2.25 COMPZN, WELLPR ELNE P Rig up E-line RIH // CBL 3800' to 2500' 0.0 0.0 6/27/2023 17:45 6/27/2023 18:30 0.75 COMPZN, WELLPR ELNE P RD e-line 0.0 0.0 6/27/2023 18:30 6/27/2023 21:30 3.00 COMPZN, WELLPR OTHR P Prep RF for testing BOP's, pull WR, MU 3.5" test joint with FOSV, continue greasing surface equipment. Fill stack, obtain shell test *** Note: Pull Wear Ring 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 20/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/27/2023 21:30 6/28/2023 00:00 2.50 COMPZN, WHDBOP BOPE P Begin testing BOP's, 250/3,500/2,500 Annular, chance to witness waived by state Brian Bixby MU 3.5" Test Joint Test #1 Annular, TD HYD IBOP, HT-38 Dart Valve, Kill Demco, Choke Manifold- #1, #2, #3, #15, & #16, Outer Test Spool Test #2 Upper Pipe Rams, TD HYD IBOP, HT-38 Dart Valve, Kill Demco, Choke Manifold - #1, #2, #3, #15, & #16, Outer Test Spool Test #3 Upper Pipe Rams, TD Lower Manual, Kill HCR, Choke Manifold- #4, #6, #7, & #9 & OuterTest Spool Test #4 Upper Pipe Rams, HT-38 TIW, Kill Inside Manual, Choke Manifold - #5, #10, & #11 Test #5 Upper Pipe Rams, HT-38 TIW, Kill Inside Manual, Choke Manifold - #14 Test #6 Lower Pipe Rams 0.0 0.0 6/28/2023 00:00 6/28/2023 03:00 3.00 COMPZN, WHDBOP BOPE P Finish Test #6, Lower Pipe Rams *** Perform accumulator test. Initial pressure = 3150 PSI, after closure = 1600 PSI, 200 PSI attained = 14.6 sec, full recovery attained = 95 sec. UVBR = 6 sec, LVBR = 6 sec, Annular = 18.3 sec, Simulated blinds = 6 sec, HCR choke/kill = 1 sec each, 5 back up nitrogen bottles average = 1,990 PSI, Prechare bottles = 11 @ 1100 PSI, Test gas detectors, PVT and flow show Test #7 Blind Rams, Choke Manifold - #8, #12, & #13 Test #8 Super Choke and Manual Choke Function test ** MU 5.5" Test Joint Test #10 Upper Pipe Rams, Choke HCR, 3.5" EUE FOSV TIW Test #11 Upper Pipe Rams, Choke Inside Manual, 3.5" EUE FOSV TIW Test #12 Lower Pipe Rams, 3.5" EUE FOSV TIW 0.0 0.0 6/28/2023 03:00 6/28/2023 03:30 0.50 COMPZN, RPCOMP OTHR P RD testing equipment *** Install Wear Ring 0.0 0.0 6/28/2023 03:30 6/28/2023 04:00 0.50 COMPZN, RPCOMP BHAH P MU MSC w/2.25" knives and crossover 0.0 4.5 6/28/2023 04:00 6/28/2023 06:30 2.50 COMPZN, RPCOMP TRIP P TIH with DP PH6 out of derrick 4.5 3,728.0 6/28/2023 06:30 6/28/2023 07:30 1.00 COMPZN, RPCOMP CPBO P Locate collar @ 3755' pick up to 3735' perform cut // pump 35 spm @ 450 psi Rot 68 rpm @ 1200 - 1500 tq // good indications of cut pressure drop 3,755.0 3,735.0 6/28/2023 07:30 6/28/2023 08:30 1.00 COMPZN, RPCOMP CIRC P Circulate OA clean // 4 bbls per min 900 psi // 3,735.0 3,735.0 6/28/2023 08:30 6/28/2023 10:00 1.50 COMPZN, RPCOMP OWFF P OWFF pump out bop's // Tubing and IA dead // watch OA with diminishing returns ( U-tubing well ) // Pull 1 stand well stop flowing // Continue OWFF 20 min no flow // 3,735.0 3,700.0 6/28/2023 10:00 6/28/2023 12:00 2.00 COMPZN, RPCOMP TRIP P TOOH lay down cutter 3,700.0 150.0 6/28/2023 12:00 6/28/2023 12:30 0.50 COMPZN, RPCOMP BHAH P Lay down bha 150.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 21/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/28/2023 12:30 6/28/2023 16:30 4.00 COMPZN, RPCOMP NUND P Pump out stack // OWFF // Nipple down tubing head configure stack for pulling 5.5" casing // Install 11" 3K adapter // Position stack for spear of 5.5" 0.0 0.0 6/28/2023 16:30 6/28/2023 17:15 0.75 COMPZN, RPCOMP THGR P Spear 5.5" pull out of slips in well head // Recover slips pull tubing to rig floor // Remove cut jt lay down spear // Pull casing from slips @ 85 K w/blocks 3,735.0 3,715.0 6/28/2023 17:15 6/28/2023 18:30 1.25 COMPZN, RPCOMP NUND P Set Stack back down and MU to spool Crew Change 3,715.0 3,715.0 6/28/2023 18:30 6/28/2023 19:15 0.75 COMPZN, RPCOMP PULL P Pull 5.5" to the floor, relase spear/grapple cleanup and re-engage. Pull first joint, brake down and LD spear 3,715.0 3,673.0 6/28/2023 19:15 6/29/2023 00:00 4.75 COMPZN, RPCOMP PULL P LD 5.5" HYD 563 to pipe shed 3,673.0 420.0 6/29/2023 00:00 6/29/2023 00:45 0.75 COMPZN, RPCOMP PULL P Continue L/D 5.5" 563 to pipe shed 420.0 0.0 6/29/2023 00:45 6/29/2023 01:45 1.00 COMPZN, RPCOMP OTHR P OOH w/88 jts and cut off, length 20.19', Swap elevators, P/U joint of DP 0.0 0.0 6/29/2023 01:45 6/29/2023 03:00 1.25 COMPZN, RPCOMP PRTS P Set 11" test plug, failed test #1, pull plug and clean, pressure up, discover leak on flange in cellar, tighten, and retest, good test, L/D test plug 0.0 0.0 6/29/2023 03:00 6/29/2023 04:00 1.00 COMPZN, RPCOMP BHAH P P/U, M/U BHA #41 with 6-1/4" Pilot Mill, bit sub, 6-3/4" sting mills x 3, bumper sub, oil jars, 4-3/4" DC x 2, and XO sub 0.0 105.3 6/29/2023 04:00 6/29/2023 04:30 0.50 COMPZN, RPCOMP TRIP P TIH with Drift BHA #41 on HT-38 DP Unable to drift 121' Bring pump online 65 SPM @ 300 psi, ROT=60 rpm, Torque= 2027 ft/lbs Work all three mills past rough spot Recep pipe through area x 3 Shut pump down and dry run, better drift w/max 4 k drag through area 105.3 183.0 6/29/2023 04:30 6/29/2023 04:45 0.25 COMPZN, RPCOMP TRIP P TOOH, standing back HT-38 DP stand 183.0 105.0 6/29/2023 04:45 6/29/2023 05:15 0.50 COMPZN, RPCOMP BHAH P L/D drift assembly 105.0 0.0 6/29/2023 05:15 6/29/2023 05:45 0.50 COMPZN, RPCOMP BHAH P Pick up dress off / drift assembly 0.0 105.0 6/29/2023 05:45 6/29/2023 07:00 1.25 COMPZN, RPCOMP TRIP P Trip in hole on stands to dress off and drift casing 105.0 848.0 6/29/2023 07:00 6/29/2023 07:45 0.75 COMPZN, RPCOMP TRIP P TOOH for mill assembly clean up 848 area 848.0 105.0 6/29/2023 07:45 6/29/2023 08:15 0.50 COMPZN, RPCOMP BHAH P Lay down dress off assembly 105.0 0.0 6/29/2023 08:15 6/29/2023 08:45 0.50 COMPZN, RPCOMP BHAH P Pick up string mill assembly 0.0 105.0 6/29/2023 08:45 6/29/2023 09:45 1.00 COMPZN, RPCOMP TRIP P TIH to trouble area to clean up 7-5/8" casing 105.0 848.0 6/29/2023 09:45 6/29/2023 11:00 1.25 COMPZN, RPCOMP MILL P Clean up and drift area 848.0 890.0 6/29/2023 11:00 6/29/2023 12:00 1.00 COMPZN, RPCOMP TRIP P TOOH to take of string mills so assembly not so stiff 890.0 105.0 6/29/2023 12:00 6/29/2023 12:30 0.50 COMPZN, RPCOMP BHAH P Reconfigure BHA for milling ops 150.0 0.0 6/29/2023 12:30 6/29/2023 14:00 1.50 COMPZN, RPCOMP OTHR P Process 120 jts HT38 for milling ops 0.0 0.0 6/29/2023 14:00 6/29/2023 15:30 1.50 COMPZN, RPCOMP PULD P Trip in hole on singles HT38 drill pipe 0.0 848.0 6/29/2023 15:30 6/29/2023 16:00 0.50 COMPZN, RPCOMP MILL P Mill through tight spot // 2500 ft/lbs torque // 3 bpm 848.0 875.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 22/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/29/2023 16:00 6/29/2023 18:45 2.75 COMPZN, RPCOMP TRIP P RIH on singles to top of cut jt drifing casing to 6.75 SOW=42k, PUW=85k 875.0 3,726.0 6/29/2023 18:45 6/29/2023 19:30 0.75 COMPZN, RPCOMP TRIP P KBU, bring pump online 138 spm/8 bpm/1,000 psi ROT=70 rpm, Torque=2,000 ft/lbs, Locate top of stub @ 3,726' Recep pipe clean, circ BU 3,726.0 3,726.0 6/29/2023 19:30 6/29/2023 21:30 2.00 COMPZN, RPCOMP TRIP P TOOH 3,726.0 154.0 6/29/2023 21:30 6/29/2023 21:45 0.25 COMPZN, RPCOMP BHAH P LD BHA #44 154.0 0.0 6/29/2023 21:45 6/29/2023 21:45 COMPZN, RPCOMP BHAH P P/U BHA #45 w/4 Drill Collars 0.0 161.0 6/29/2023 21:45 6/29/2023 22:30 0.75 COMPZN, RPCOMP TRIP P TIH w/4-3/4" DC x 4, tandum 6-3/4" string mills and 6-1/4" pilot mill 161.0 848.0 6/29/2023 22:30 6/29/2023 23:30 1.00 COMPZN, RPCOMP REAM P KBU on stand #8, stack out @ 855', set down 8k PUH, bring pump online 138 spm/8 bpm/450 psi ROT=80 rpm, Torque=1,500 ft/lbs Ream area, dry drift is 15k to push through 848.0 860.0 6/29/2023 23:30 6/30/2023 00:00 0.50 COMPZN, RPCOMP REAM P Continue reaming area Pump online 138 spm/8 bpm/450 psi ROT=80 rpm, Torque=1,500 ft/lbs 860.0 848.0 6/30/2023 00:00 6/30/2023 01:00 1.00 COMPZN, RPCOMP REAM P Pump online 138 spm/8 bpm/450 psi ROT=80 rpm, Torque=1,500 ft/lbs *** Note: Dry drift area 4k up and down 848.0 860.0 6/30/2023 01:00 6/30/2023 01:30 0.50 COMPZN, RPCOMP TRIP P TOOH w/BHA #45 860.0 161.0 6/30/2023 01:30 6/30/2023 01:45 0.25 COMPZN, RPCOMP BHAH P L/D milling BHA 161.0 0.0 6/30/2023 01:45 6/30/2023 02:00 0.25 COMPZN, RPCOMP BHAH P P/U, BHA #46 w/special clearance 6- 3/4" OD dress off shoe, bushing top dress, drive sub, bumper sub, jars, 4- 3/4" DC x 4, and crossover. 0.0 150.0 6/30/2023 02:00 6/30/2023 04:15 2.25 COMPZN, RPCOMP TRIP P TIH w/BHA #46k, dress off shoe PUW=80 k, SOW=72 k *** Note: Tag stub @ 3,725' 150.0 3,725.0 6/30/2023 04:15 6/30/2023 04:45 0.50 COMPZN, RPCOMP MILL P KBU, Pump 69 spm/4 bpm/260 psi Rot=60 rpm/TQ=1,800 ft/lbs Mill ahead from 3,725'-3,728' 3,725.0 3,728.0 6/30/2023 04:45 6/30/2023 05:45 1.00 COMPZN, RPCOMP CIRC P Pull above stub, launch 25 bbl sweep, increase pump rate 69 spm/4 bpm/214 psi, circ BU 3,728.0 3,722.0 6/30/2023 05:45 6/30/2023 06:15 0.50 COMPZN, RPCOMP TRIP P TOOH 10 stands 3,722.0 2,700.0 6/30/2023 06:15 6/30/2023 08:30 2.25 COMPZN, RPCOMP PULD P Trip out of hole sideways 2,700.0 105.0 6/30/2023 08:30 6/30/2023 09:00 0.50 COMPZN, RPCOMP BHAH P Lay down dress off bha 105.0 0.0 6/30/2023 09:00 6/30/2023 09:30 0.50 COMPZN, RPCOMP CLEN P Clean floor for picking up BHA 0.0 0.0 6/30/2023 09:30 6/30/2023 10:00 0.50 COMPZN, RPCOMP BHAH P Pick up test packer BHA# 47 // 7-5/8" test packer 0.0 18.0 6/30/2023 10:00 6/30/2023 10:30 0.50 COMPZN, RPCOMP TRIP P TIH w/ test packer to pressure test casing shoe for cement ops 18.0 300.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 23/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/30/2023 10:30 6/30/2023 10:45 0.25 COMPZN, RPCOMP PRTS P Set test packer @ 291' COE Pressure up under packer T/ 115 psi 4 bbls pumped .25 bbls/min = 100 psi .5 bbls/min = 100psi .75 bbls/min = 115psi 1 bbl/min = 115psi Shut down pumps consult well engineer Release packer to lay down dp 290.0 290.0 6/30/2023 10:45 6/30/2023 12:45 2.00 COMPZN, RPCOMP PULD P Lay down drill pipe 290.0 0.0 6/30/2023 12:45 6/30/2023 13:15 0.50 COMPZN, RPCOMP OTHR P Pull wear ring 0.0 0.0 6/30/2023 13:15 6/30/2023 13:45 0.50 COMPZN, RPCOMP SVRG P Perform rig service // Grease crown and blocks // Grease drawworks and TD 0.0 0.0 6/30/2023 13:45 6/30/2023 14:45 1.00 COMPZN, RPCOMP RURD P Rig up to run 5.5" casing // Load shed with tools and casing 0.0 0.0 6/30/2023 14:45 6/30/2023 21:45 7.00 COMPZN, RPCOMP PUTB P Pick up casing 87 jts 5.5" 15.5# Hyd 563 casing // GBR torque turn monitor pipe torque // Centralizers every jt first 24 every other after that to below hanger Crew change @ 2100. *** Note: returns going south, getting no displacement 0.0 3,725.0 6/30/2023 21:45 6/30/2023 22:15 0.50 COMPZN, RPCOMP PUTB P Land 5.5" casing, confirm landing, Work pipe 100k, 110k, and 150k, confirm patch set R/U to P/T bowen patch to 2,500 psi, good test 3,725.0 3,725.0 6/30/2023 22:15 6/30/2023 22:45 0.50 COMPZN, RPCOMP PRTS P Bleed pressure, RD testing equipment, blow down top drive and surface lines, vac out stack and 5.5" joints, pull casing in tention 180 k, 80 over PUW. set in slips 3,725.0 3,725.0 6/30/2023 22:45 7/1/2023 00:00 1.25 COMPZN, RPCOMP NUND P PJSM, begin splitting stack 3,725.0 7/1/2023 00:00 7/1/2023 07:30 7.50 COMPZN, RPCOMP NUND P Remove DSA's, install casing spool, nipple up stack, install riser, obtain RKB's 0.0 0.0 7/1/2023 07:30 7/1/2023 09:30 2.00 COMPZN, RPCOMP PRTS P Install test plug, test BOP brakes *** Note: Install Wear Ring 0.0 0.0 7/1/2023 09:30 7/1/2023 10:30 1.00 COMPZN, RPCOMP BHAH P P/U NCS Cement Tool 0.0 0.0 7/1/2023 10:30 7/1/2023 12:00 1.50 COMPZN, RPCOMP TRIP P TIH on PH6 DP 0.0 3,680.0 7/1/2023 12:00 7/1/2023 13:00 1.00 COMPZN, RPCOMP WAIT P Rig up for cement job // wait on cement trucks 3,680.0 3,680.0 7/1/2023 13:00 7/1/2023 15:00 2.00 COMPZN, RPCOMP CIRC P Circulate 290 bbls 85° water down drill pipe and up OA // NCS frac sleave shifted open // 60% returns out temp on mud 58° 3,680.0 3,680.0 7/1/2023 15:00 7/1/2023 16:30 1.50 COMPZN, RPCOMP OTHR T Attempt to close NCS Sleeve 3,680.0 3,680.0 7/1/2023 16:30 7/1/2023 18:00 1.50 COMPZN, RPCOMP TRIP T TOOH stand back DP to inspect BHA 3,680.0 21.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 24/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/1/2023 18:00 7/1/2023 19:30 1.50 COMPZN, RPCOMP BHAH T At surface, LD and inspect NCS tools, found cone had sheared. Continue to fill hole 35 bbl every 30 mins *** Note: Lost rate 69 bph 21.0 0.0 7/1/2023 19:30 7/1/2023 20:15 0.75 COMPZN, RPCOMP BHAH T M/U new NCS cementing tool with steel shear pins in cone. 0.0 21.0 7/1/2023 20:15 7/1/2023 22:15 2.00 COMPZN, RPCOMP TRIP T TIH, w/NCS Cementing BHA take #2 on PH6 DP Test run tool @ 2,364', good function test of the NCS tool 21.0 3,680.0 7/1/2023 22:15 7/1/2023 23:00 0.75 COMPZN, RPCOMP RURD T R/U surface lines, cellar lines, and Haliburton equipment Close pipe rams, 3,680.0 3,680.0 7/1/2023 23:00 7/2/2023 00:00 1.00 COMPZN, RPCOMP PRTS T Attempt to close sleeve, P/T NCS packer to 500 psi, sleeve not closed, bleed pressure off, attempt to close NCS tool. Good indication packer is set, Obtain 500 psi test on NCS packer element. Bleed pressure off. 3,680.0 3,680.0 7/2/2023 00:00 7/2/2023 00:30 0.50 COMPZN, RPCOMP SFTY P RD testing equipment, PJSM with Rig Team and Cement crew 3,680.0 3,680.0 7/2/2023 00:30 7/2/2023 01:00 0.50 COMPZN, RPCOMP PRTS P P/T cement & tiger tanks lines, Cement batching up 3,680.0 3,680.0 7/2/2023 01:00 7/2/2023 01:30 0.50 COMPZN, RPCOMP CIRC P Perform Injectivity test 2 bpm @ 40 psi, 4 bpm @ 122 psi Shut down @ 42 bbls away, with no pressure increase 3,680.0 3,680.0 7/2/2023 01:30 7/2/2023 03:00 1.50 COMPZN, RPCOMP CMNT P Cementing the OA 5.5" x 7.625" Send spacer 10 ppg with LCM 2 bpm @ 80 psi, followed by cement 15.3 ppg 2 bpm @ 130 psi Pump online to 1.0 bpm @ 36 psi Shut down pump 15 mins // 45 bbls cement away, 15 bbl spacer Pump online 1.0 bpm @ 43 psi Shutdown pump 15 mins // 56 bbls cement away, 15 bbl spacer Pump online 1.0 bpm @ 37 psi Shutdown pump 30 mins // 63 cementt away, 15 bbl spacer 3,680.0 3,680.0 7/2/2023 03:00 7/2/2023 08:00 5.00 COMPZN, RPCOMP CMNT P Pump online 1 bpm @ 56 psi Shutdown pump 30 mins // 67 cement away, 15 bbl spacer Pump online 1.0 bpm @ 45 psi Shutdown pump 30 mins // 77 cement away, 15 bbl spacer Pump online 1.0 bpm @ 70 psi Shut down 45min Pump online 1.0 bpm @ 75 psi Shut Down 1HR Pump online 1.0bpm @ 80 3,680.0 3,680.0 7/2/2023 08:00 7/2/2023 09:00 1.00 COMPZN, RPCOMP RURD P Wash up and rig down cement crew and equipment 3,680.0 3,680.0 7/2/2023 09:00 7/2/2023 16:45 7.75 COMPZN, RPCOMP WOC P Waiting on cement // cement flowing out of OA due to thermal exp. // close valve 30 min open no flow // wash out valve and wait for cement to cure 3,680.0 3,680.0 7/2/2023 16:45 7/2/2023 19:30 2.75 COMPZN, RPCOMP TRIP P TOOH for RCJB 3,680.0 105.0 7/2/2023 19:30 7/2/2023 20:00 0.50 COMPZN, RPCOMP BHAH P At sureface, brake down NCS Cementer BHA assembly and inspect 105.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 25/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/2/2023 20:00 7/2/2023 22:30 2.50 COMPZN, RPCOMP BHAH P P/U BHA #48 RCJB 0.0 159.5 7/2/2023 22:30 7/3/2023 00:00 1.50 COMPZN, RPCOMP TRIP P TIH, w/RCJB, XO, Bit Sub, Bumper Sub, Jar, 3-1/2" DC x 4, accelorator, and XO. 159.5 3,763.3 7/3/2023 00:00 7/3/2023 00:15 0.25 COMPZN, RPCOMP CIRC P KBU, Brake Circulation, 2.0 bpm/310 psi, 4.0 bpm/1,050 psi KBD 3,763.3 3,829.0 7/3/2023 00:15 7/3/2023 01:00 0.75 COMPZN, RPCOMP TRIP P TIH on singles, dry tag top of debris/sand @ 3,829' KBU, 5 bpm/1,600 psi Rot=60 rpm/TQ=1,345 ft/lbs 3,829.0 3,843.0 7/3/2023 01:00 7/3/2023 02:00 1.00 COMPZN, RPCOMP TRIP P Continue IH, getting back formation sand/pariffin balls at shaker, continue IH to known top of sand 5 bpm/1,600 psi Rot=60 rpm/TQ=1,345 ft/lbs 3,843', 1,345 ft/lbs up to 1,900 ft/lbs 3,843.0 3,856.0 7/3/2023 02:00 7/3/2023 02:45 0.75 COMPZN, RPCOMP TRIP P P/U another single KBU, 5 bpm/1,600 psi Rot=60 rpm/TQ=1,345 ft/lbs 3,843', 1,345 ft/lbs up to 1,900 ft/lbs Work down to 3,880' 3,856.0 3,880.0 7/3/2023 02:45 7/3/2023 03:15 0.50 COMPZN, RPCOMP CIRC P Circulate S/S w/10 bbl sweep 3,880.0 3,880.0 7/3/2023 03:15 7/3/2023 05:30 2.25 COMPZN, RPCOMP TRIP P TOOH, at surface, brake down tools, inspect JB 3,880.0 159.0 7/3/2023 05:30 7/3/2023 06:00 0.50 COMPZN, RPCOMP BHAH P At surface, brake down tools, inspect JB 159.0 0.0 7/3/2023 06:00 7/3/2023 06:30 0.50 COMPZN, RPCOMP BHAH P M/U RCJB BHA #49 0.0 159.0 7/3/2023 06:30 7/3/2023 08:45 2.25 COMPZN, RPCOMP TRIP P TIH, w/cleanout BHA #49 RCJB 159.0 3,880.0 7/3/2023 08:45 7/3/2023 09:15 0.50 COMPZN, RPCOMP WASH P Wash down to top of plug w/ RCJB KBU, 5 bpm/1,700 psi Rot=60 rpm/TQ=2,045 ft/lbs Work down to 3,887' Tq up to 2400 ft/lbs Continue to clean out to 3895' 3,880.0 3,920.0 7/3/2023 09:15 7/3/2023 10:00 0.75 COMPZN, RPCOMP CIRC P Circulate 10 bbl sweep w/ S x S 3,895.0 3,895.0 7/3/2023 10:00 7/3/2023 11:30 1.50 COMPZN, RPCOMP TRIP P TOOH, at surface, brake down tools, inspect JB // Found large rocks in junk basket // 3,880.0 159.0 7/3/2023 11:30 7/3/2023 12:00 0.50 COMPZN, RPCOMP BHAH P At surface, brake down tools, inspect JB // Found large rocks in junk basket // 159.0 0.0 7/3/2023 12:00 7/3/2023 12:30 0.50 COMPZN, RPCOMP BHAH P M/U RCJB BHA #50 0.0 159.0 7/3/2023 12:30 7/3/2023 14:00 1.50 COMPZN, RPCOMP TRIP P TIH, w/cleanout BHA #50 RCJB 159.0 3,880.0 7/3/2023 14:00 7/3/2023 14:30 0.50 COMPZN, RPCOMP WASH P Wash down to top of plug w/ RCJB KBU, 5 bpm/1,700 psi Rot=60 rpm/TQ=2,045 ft/lbs Work down to 3,887' Tq up to 2400 ft/lbs Continue to clean out to 3910' 3,880.0 3,910.0 7/3/2023 14:30 7/3/2023 15:00 0.50 COMPZN, RPCOMP CIRC P Circulate 10 bbl sweep w/ S x S 3,910.0 3,910.0 7/3/2023 15:00 7/3/2023 16:45 1.75 COMPZN, RPCOMP TRIP P TOOH, at surface, brake down tools, inspect JB 3,910.0 159.0 7/3/2023 16:45 7/3/2023 17:30 0.75 COMPZN, RPCOMP BHAH P At surface, brake down tools, inspect JB 159.0 0.0 7/3/2023 17:30 7/3/2023 18:15 0.75 COMPZN, RPCOMP BHAH P Make up BHA# 50 G-plug retrieval tool 0.0 105.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 26/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/3/2023 18:15 7/3/2023 21:00 2.75 COMPZN, RPCOMP TRIP P TIH to retrieve G-plug 105.0 3,920.0 7/3/2023 21:00 7/3/2023 22:00 1.00 COMPZN, RPCOMP MPSP P Circulate sand off top of plug // Tag plug @ 3923 // Release plug w/ 5 turns right pick up let elements relax while performing flow check 3,920.0 3,920.0 7/3/2023 22:00 7/3/2023 23:15 1.25 COMPZN, RPCOMP CIRC P Circulate S xS pump 10 bbls sweep 3,920.0 3,920.0 7/3/2023 23:15 7/4/2023 00:00 0.75 COMPZN, RPCOMP PULD P TOOH Sideways laying down PH6 string 3,920.0 3,325.0 7/4/2023 00:00 7/4/2023 02:45 2.75 COMPZN, RPCOMP TRIP P TOOH Sideways laying down PH6 string 3,325.0 160.0 7/4/2023 02:45 7/4/2023 03:45 1.00 COMPZN, RPCOMP BHAH P Lay down G-plug BHA 160.0 0.0 7/4/2023 03:45 7/4/2023 04:45 1.00 COMPZN, RPCOMP PUTB P Prep RF for running completion, load jewelry, check pipe tallies and jewelry. 0.0 0.0 7/4/2023 04:45 7/4/2023 05:00 0.25 COMPZN, RPCOMP PUTB P PJSM, with Rig Crew and Baker Completion 0.0 0.0 7/4/2023 05:00 7/4/2023 12:00 7.00 COMPZN, RPCOMP PUTB P P/U, 3.5" 563, L-80, 9.3#, completion with 4.0" Seal Assembly, Locator, 2.75" D nipple w/RHC plug installed, 3 GLM's lower one with SOV (2,000 psi), others with dummy's, and a X nipple 2.813" *** Note: Detained @ 3,884' 0.0 3,884.0 7/4/2023 12:00 7/4/2023 14:45 2.75 COMPZN, RPCOMP PUTB T Brake out, LD joint #123, pump online, work pipe 40k-105k, pipe moving freely, up to 3,835', detained again, work pipe free, check for stretch, 2-3', seems the problem is down hole not at surface. continue OOH on singles until joint #114 3,884.0 3,638.0 7/4/2023 14:45 7/4/2023 19:45 5.00 COMPZN, RPCOMP PUTB T Continue L/D 3.5" tubing Replace seal rings on joints in derrick 3,638.0 0.0 7/4/2023 19:45 7/4/2023 21:45 2.00 COMPZN, RPCOMP SLPC T Cut and slip drill line // Start Processing PH6 drill pipe for clean out 0.0 0.0 7/4/2023 21:45 7/4/2023 22:15 0.50 COMPZN, RPCOMP SVRG T Service rig // set crown saver // grease blocks and DW 0.0 0.0 7/4/2023 22:15 7/5/2023 00:00 1.75 COMPZN, RPCOMP OTHR T Process PH6 DP 0.0 0.0 7/5/2023 00:00 7/5/2023 01:30 1.50 COMPZN, RPCOMP OTHR T Process PH6 DP 0.0 0.0 7/5/2023 01:30 7/5/2023 02:30 1.00 COMPZN, RPCOMP BHAH T Pick up drift/clean out BHA 0.0 105.0 7/5/2023 02:30 7/5/2023 08:30 6.00 COMPZN, RPCOMP TRIP T RIH picking up singles drift 5.5" and clean out SBE 105.0 3,880.0 7/5/2023 08:30 7/5/2023 11:15 2.75 COMPZN, RPCOMP TRIP T Pass through previous tight spot w/4.70" String mill and stinger. Continue TIH on singles, on bottom 3,880.0 7,218.0 7/5/2023 11:15 7/5/2023 12:15 1.00 COMPZN, RPCOMP CIRC T SOW=65k, PUW=115k Pump online 3 bpm/60 spm/1,023 psi Increase pump rate 7 bpm/121 spm/2,900 psi Launch 30 bbl sweep circulate surface to surface (2364 stks) 7,218.0 7,218.0 7/5/2023 12:15 7/5/2023 16:00 3.75 COMPZN, RPCOMP TRIP T TOOH sideways LD DP 7,218.0 3,009.0 7/5/2023 16:00 7/5/2023 16:30 0.50 COMPZN, RPCOMP SVRG P Service rig, top drive, tongs, slips, skate, etc 3,009.0 3,009.0 7/5/2023 16:30 7/5/2023 19:30 3.00 COMPZN, RPCOMP TRIP T TOOH sideways LD DP 3,009.0 105.0 7/5/2023 19:30 7/5/2023 20:45 1.25 COMPZN, RPCOMP BHAH T Lay down BHA 105.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 27/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/5/2023 20:45 7/5/2023 21:45 1.00 COMPZN, RPCOMP OTHR T Change out elevators, remove tools from small BHA, blow down TD and stand pipe 0.0 0.0 7/5/2023 21:45 7/5/2023 22:00 0.25 COMPZN, RPCOMP OTHR T Pull wear ring 0.0 0.0 7/5/2023 22:00 7/5/2023 22:30 0.50 COMPZN, RPCOMP RURD T Rig up to run liner 0.0 0.0 7/5/2023 22:30 7/5/2023 23:00 0.50 COMPZN, RPCOMP PUTB P Run 3.5" completion // Pick up seal assembly not configured correctly with 2 sets of seals on bottom 0.0 0.0 7/5/2023 23:00 7/6/2023 00:00 1.00 COMPZN, RPCOMP WAIT T Wait for seal assembly to go to Baker to get reconfigured and shipped back 0.0 0.0 7/6/2023 00:00 7/6/2023 06:30 6.50 COMPZN, RPCOMP WAIT T Wait for seal assembly to go to Baker to get reconfigured and shipped back 0.0 0.0 7/6/2023 06:30 7/6/2023 16:00 9.50 COMPZN, RPCOMP PUTB P Run 3.5" completion. Small 5K bobble at 3765' then a couple more collars hitting here and there at random. At 13:00 we are 5,000' in the hole and continuing to run completion. Starting Generators at 13:45, came off high line power at 14:10. Back to running in hole with completion at 14:30. Encountered tight spot @ 6930', worked pipe free 145K up wt, multiple orientations unable to pass through tight spot. 0.0 6,930.0 7/6/2023 16:00 7/6/2023 17:30 1.50 COMPZN, RPCOMP CIRC P Circulate 2% 776 , spot in well lower sting went through tight spot @ 6930'. 6,930.0 6,930.0 7/6/2023 17:30 7/6/2023 19:30 2.00 COMPZN, RPCOMP PUTB P Continue to pick up and run 3.5" tubing // Tag SBE @ 7,202' ( 3' high ) , Pump, work pipe, re-tag @ 7,205', become detained then worked free. 6,930.0 7,505.0 7/6/2023 19:30 7/6/2023 20:30 1.00 COMPZN, RPCOMP CIRC P Circulate S x S ensure clean fluid. 7,505.0 7,500.0 7/6/2023 20:30 7/6/2023 21:30 1.00 COMPZN, RPCOMP HOSO P Attempt to fully locate for hang off space out // unable to get past 7212' seals not holding pressure. 7,500.0 7,512.0 7/6/2023 21:30 7/6/2023 23:00 1.50 COMPZN, RPCOMP CIRC T Circulate S x S // Lots of black sand gunk in returns // pump 80 vis sweep. 7,512.0 7,505.0 7/6/2023 23:00 7/7/2023 00:00 1.00 COMPZN, RPCOMP TRIP T Flow check, lay down 3 singles, rack stands in derrick. 7,505.0 6,800.0 7/7/2023 00:00 7/7/2023 09:30 9.50 COMPZN, RPCOMP TRIP T Continue POOH standing back completion in the derrick from 6800' to surface. Off the critical path processed 230 jts of drillpipe. The 3.5" EUE collars continued to hang up randomly until above 3765'. 6,800.0 0.0 7/7/2023 09:30 7/7/2023 12:00 2.50 COMPZN, RPCOMP BHAH T RD tubing tongs and clean floor. Install wear bushing. PU clean out BHA #53 (A 21' 2-7/8" stinger to get inside SBE and circ out sand, 4.75" string reamer to clean up area at 3765', two magnets/ two junk baskets to pick up junk in the hole and jars). 0.0 192.0 7/7/2023 12:00 7/7/2023 22:00 10.00 COMPZN, RPCOMP PULD T RIH with BHA #53. Picking up drill pipe in singles since we had preveously laid it all down. // NG on jt 226 192.0 7,250.0 7/7/2023 22:00 7/8/2023 00:00 2.00 COMPZN, RPCOMP CIRC T Circulate old mud out of well circulate sweeps and new mud with vis // Black sand and gravel at the shakers// pump 3 - 20 bbl sweeps still getting black sand and gunk back // Circulate well 8 bbls/min 7,250.0 7,250.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Page 28/28 3G-25X Report Printed: 7/24/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/8/2023 00:00 7/8/2023 02:00 2.00 COMPZN, RPCOMP CIRC T Circulate 8 bpm // clean out possumbelly of sand and debris // Pump sweep // vis up mud to help clean hole// pump additional 20 bbl sweep 7,250.0 7,250.0 7/8/2023 02:00 7/8/2023 09:30 7.50 COMPZN, RPCOMP PULD T TOOH lay down PH6 drill string. Recovered about two 5 gallon buckets of black tary sand, small rocks and metal particles. 7,250.0 192.0 7/8/2023 09:30 7/8/2023 12:00 2.50 COMPZN, RPCOMP BHAH T LD BHA #53 (A 21' 2-7/8" stinger, 4.75" string reamer, two magnets, two junk baskets and jars) 192.0 0.0 7/8/2023 12:00 7/8/2023 20:00 8.00 COMPZN, RPCOMP TRIP T RIH with completion from stands in derrick // NG @ 7219' // calc space out // 0.0 7,219.0 7/8/2023 20:00 7/8/2023 20:30 0.50 COMPZN, RPCOMP CIRC P Circulate 4.5 bbls/min while locating space out pups 7,219.0 7,219.0 7/8/2023 20:30 7/8/2023 21:00 0.50 COMPZN, RPCOMP HOSO P Lay down 228,227,226 , pick up 23.56' of pups // Pick up 226, hanger and landing jt 7,219.0 7,219.0 7/8/2023 21:00 7/8/2023 22:30 1.50 COMPZN, RPCOMP DISP P Displace well to 8.6 CI 7,219.0 7,219.0 7/8/2023 22:30 7/8/2023 23:00 0.50 COMPZN, RPCOMP HOSO P Land Hanger and RILDS 7,219.0 7,219.0 7/8/2023 23:00 7/9/2023 00:00 1.00 COMPZN, RPCOMP PRTS P Perform tubing 3000 7,219.0 7,912.0 7/9/2023 00:00 7/9/2023 01:00 1.00 COMPZN, RPCOMP OTHR T Trouble shoot test pressure problems, purge hose of bad fluid 7,219.0 7,219.0 7/9/2023 01:00 7/9/2023 02:00 1.00 COMPZN, RPCOMP PRTS P Test IA 2500 psi // Shear SOV ( may have partial shear) 7,219.0 0.0 7/9/2023 02:00 7/9/2023 03:00 1.00 COMPZN, WHDBOP MPSP P Set BPV and test 1000 psi 0.0 0.0 7/9/2023 03:00 7/9/2023 04:00 1.00 COMPZN, WHDBOP OTHR P Flush surface lines and stack for nipple down 0.0 0.0 7/9/2023 04:00 7/9/2023 10:00 6.00 COMPZN, WHDBOP NUND P Nipple down stack and nipple up tree. Pressure test tree 250/5000. FP with 50 bbls diesel, pumping down IA taking returns up tubing. Jumper IA to tubing and let it U-tube. 0.0 0.0 7/9/2023 10:00 7/9/2023 12:00 2.00 DEMOB, MOVE MOB P RDMO and Ceanup wellsite. Release rig at 12:00. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/9/2023 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,352.0 3G-25X 7/22/2023 scolem Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set GLV's and pulled Hex plug/ Post Rig 3G-25X 7/22/2023 scolem Notes: General & Safety Annotation End Date Last Mod By NOTE: MANDREL ORIENTATION: #1 2:00, #2 7:30, #3 8:30, #4 12:00, #5 10:00, #6 8:00 10/14/2013 osborl 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 42.0 121.0 121.0 62.50 H-40 WELDED SURFACE 7 5/8 6.87 41.5 3,799.8 3,063.7 29.70 L-80 BTC-MOD Temp tie back of 5 1/2" casing to surface 6-24-23 5 1/2 4.95 -458.8 7,207.0 5,684.9 15.50 L-80 LTC-MOD Production 5 1/2" Casing Tie Back to surface 5 1/2 4.95 13.5 3,728.0 3,011.5 15.50 L-80 Hyd563 4.5" Liner 5 1/2 4.95 29.9 7,667.0 6,028.7 15.50 L-80 LTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 0.0 Set Depth 7,217.0 Set Depth 5,692.6 String Ma 3 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd ID (in) 2.92 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.8 26.8 0.17 Casing Hanger 6.980 FMC Gen IV 3 1/2" EUE TBG hanger FMC Gen 4 2.920 29.9 29.9 0.19 Liner 3.500 3 1/2" 9.3# L-80 EUE TBG N/A N/A 2.920 82.9 82.9 0.53 Liner 3.500 3 1/2" 9.3# L-80 EUE TBG N/A N/A 2.920 498.4 497.5 8.53 Nipple 4.109 3 1/2" X nipple with 2.813" profile - SS#4277509-05 HES HES 2.813 510.0 509.0 8.71 Liner 3.500 3 1/2" 9.3# L-80 EUE TBG N/A N/A 2.920 3,130.5 2,580.8 44.41 Mandrel GAS LIFT 4.757 3 1/2" x 1" KBG 2-9 GLM SS#23681 -05 KBG SLB 2.818 3,147.2 2,592.8 44.33 Liner 3.500 3 1/2" 9.3# L-80 EUE TBG N/A N/A 2.920 5,169.5 4,105.4 39.08 Mandrel GAS LIFT 4.757 3 1/2" x 1" KBG 2-9 GLM SS#23681- 06 KBG SLB 2.818 5,186.2 4,118.4 39.16 Liner 3.500 3 1/2" 9.3# L-80 EUE TBG N/A N/A 2.920 7,158.1 5,647.1 39.05 Mandrel GAS LIFT 4.757 3 1/2" x 1" KBG 2-9 GLM SS#23681- 07 KBG SLB 2.818 7,185.0 5,668.0 39.40 Nipple 3.500 3 1/2" D nipple with 2.75" profile N/A N/A 2.750 7,206.6 5,684.6 39.64 Locator 3.500 Tri-Point locater N/A N/A 2.920 7,207.1 5,685.0 39.64 Seal Assembly 3.500 Tri-Point 4.0" Seal Assembly with 10' of seals (2' Spaceout) HES HES 2.984 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) 3,130.5 2,580.8 44.41 1 GAS LIFT GLV BTM 1 1,296.0 7/20/2023 SLB KBG 2-9 0.188 5,169.5 4,105.4 39.08 2 GAS LIFT GLV BTM 1 1,233.0 7/20/2023 SLB KBG 2-9 0.188 7,158.1 5,647.1 39.05 3 GAS LIFT OV BTM 1 0.0 7/20/2023 SLB KBG 2-9 0.188 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) 29.9 29.9 0.19 CUT OFF JT 5.500 4.950 7,446.3 5,866.1 41.82 MARKER JT 4.500 3.795 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,308.0 7,320.0 5,762.1 5,771.2 C-4, 3G-25X 9/12/2000 6.0 APERF 2-1/8" EJ, 180 Deg Ph; +/- 90 oriented from high side 7,328.0 7,336.0 5,777.3 5,783.3 A-3, 3G-25X 6/7/1998 4.0 IPERF 2.5" HC-BH,180 Phasing, 90 orient 7,348.0 7,368.0 5,792.4 5,807.4 A-2, 3G-25X 6/7/1998 4.0 IPERF 2.5" HC-BH,180 Phasing, 90 orient 3G-25X, 7/24/2023 12:48:09 PM Vertical schematic (actual) 4.5" Liner; 29.9-7,667.0 IPERF; 7,348.0-7,368.0 IPERF; 7,328.0-7,336.0 APERF; 7,308.0-7,320.0 Seal Assembly; 7,207.1 Temp tie back of 5 1/2" casing to surface 6-24-23; 3,725.0-7,207.0 Mandrel GAS LIFT; 7,158.1 Mandrel GAS LIFT; 5,169.5 SURFACE; 41.5-3,799.8 Production 5 1/2" Casing Tie Back to surface; 13.5-3,728.0 Mandrel GAS LIFT; 3,130.5 CONDUCTOR; 42.0-121.0 Casing Hanger; 26.8 KUP PROD KB-Grd (ft) 37.85 RR Date 6/2/1998 Other Elev 3G-25X ... TD Act Btm (ftKB) 7,675.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032024600 Wellbore Status PROD Max Angle & MD Incl (°) 46.81 MD (ftKB) 2,668.90 WELLNAME WELLBORE3G-25X Annotation Last WO: End Date 7/9/2023 H2S (ppm) 110 Date 12/20/2012 Comment SSSV: NIPPLE STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 3G-25X JBR 07/27/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 3-1/2" & 5-1/2" joints. Annular cycled for a pass. Test Results TEST DATA Rig Rep:Morales/YearoutOperator:ConocoPhillips Alaska, Inc.Operator Rep:Adams/Pickworth Rig Owner/Rig No.:Nabors 7ES PTD#:1961360 DATE:6/15/2023 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopSAM230617124430 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 11.5 MASP: 3258 Sundry No: 323-224 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 3 P Inside BOP 2 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"FP #1 Rams 1 3-1/2"x5-1/2"P #2 Rams 1 Blinds P #3 Rams 1 3-1/2"x5-1/2"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"P Kill Line Valves 2 2"&3-1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3150 Pressure After Closure P1600 200 PSI Attained P20 Full Pressure Attained P115 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P5@2000 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P20 #1 Rams P6 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9 9999 9 9FP Annular cycled for a pass. C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-04-28_KRU_3G-25X_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22538 KRU 3G-25X 50-103-20246-00 Coil Flag 28-Apr-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 196-136 T37622 Kayla Junke Digitally signed by Kayla Junke Date: 2023.05.02 13:24:58 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7675'None Casing Collapse Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7308-7320', 7328-7336', 7348-7368' 7637' 5762-5771', 5777-5783, 5792-5807'3-1/2" 5-1/2" 16" 7-5/8" 79' 3758' Perforation Depth MD (ft): MD 121' 3064' 121' 3800' 6029'7667' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6035' 7344' 5789' 3258 7135' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025547 196-136 P.O. Box 100360, Anchorage, AK 99510 50-103-20246-00-00 ConocoPhillips Alaska, Inc. KRU 3G-25X Kuparuk River Oil PoolKuparuk Oil PoolKuparuk River Field N/A Tubing Grade: Tubing MD (ft): Packer: N/A SSSV: 502' MD/501'TVD Perforation Depth TVD (ft): Tubing Size: L-80 7218' 5/1/2023 Packer: N/A SSSV: CAMCO DS NIPPLE NO GO 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742 Senior RWO/CTD Engineer Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Elliott Tuttle DN: C=US, OU=CTD/ RWO Drilling Engineer, O="Conoco Phillips, Inc", CN=Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am the author this document Location: Date: 2023.04.13 13:21:59-08'00' Foxit PDF Editor Version: 12.0.1 Elliott Tuttle 323-224 By Kayla Junke at 1:41 pm, Apr 13, 2023 BOP test to 3500 psig Annular preventer test to 2500 psig MDG 4/17/2023 X 10-404 VTL 4/24/2023 X DSR-4/13/23GCW 04/24/23 JLC 4/24/2023 04/24/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.24 14:20:34 -08'00' RBDMS JSB 042523 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 12, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 3G-25X (PTD# 196-136). Well 3G-25X was drilled and completed in December of 1998 as a an A-sand producer. C-sands were added in 2000. The 3.5" tubing has multiples leaks, and one patch already in the well. The 5.5" casing has also begun to leak and the 3.5" x 5.5" IA is communicating with the 5.5" x 7.625" OA. OA has an open shoe. The well became a RWO with the multiple failures. If you have any questions or require any further information, please contact me at +1 907-252-3347. The scope of the workover is to pull the 3.5" tubing all the way down to seals. The required barriers will then be established to work the 5.5" Production Casing (PC). The 5.5" PC will then be backed off below the known leak and new 5.5"will be threaded back in as primary plan. If unsuccessful with obtaining PC integrity or drift of 7 5/8" casing forces work to be performed, the PC will be cut lower and tied back with a casing patch and annulus cementing tool. The 5.5" x 7.625" OA will then be cemented up to surface. Regardless, 5.5" will be terminated at surface. Then the new 3.5" will finally be run and stung back into seals. 3G-25X RWO Procedure Kuparuk Producer PTD #196-136 Page 1 of 3 Completed Pre-Rig Work 1. T-PPPOT, T-POT, IC POT, IC PPPOT (PASS) – 1/8/23 2. Combo TxIAxOA to 1800psi, confirm OA shoe can hold a column of cement (Passed)– 3/29/23 3. Fish plug @ 7135’ RKB – 3/30/23 4. Obtain SBHP – 3/30/23 5. Fish Patch set @ 7140’ RKB – Completed 4/4/23 Remaining Pre-Rig Work 6. Set High Expansion Mechanical Plug in Liner below 7220’ RKB 7. CDDT TxIAxOA 8. Prepare well for rig arrival within 48-72 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3G-25X. (No BPV will be set due to internal risk assessment for N7ES MIRU/RDMO.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500psi. Test annular 250/3,500 psi. Retrieve Tubing and Seals 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the seals, if unsuccessful, RU Eline and cut below lowest GLM. a. Perform Drift with mill down prior to 1st GLM pulled across last 500’, If drift is unsuccessful, drop tubing off, run plug and set above tubing (obtain needed barriers), dump sand and move to “Pull and Run New 5.5” Casing”. b. If needed, RIH on DP and pull seals and remaining tubing from seal bore. 6. Obtain needed barriers: RU Eline: a. Evaluate casing to determine good base in OA (5.5” x 7.625”) and casing condition. b. Set 5.5” plug below base of fill/ casing shoe. Dump sand on plug. Pull and Run New 5.5” Casing 7. ND BOPE. ND Tubing Spool, allow growth and remove PC Packoffs. 8. NU BOPE to Casing Spool. (The flange break of the BOPE is unable to be tested at this point in the program due to the PC packoffs being removed) 9. MU Casing Back off tool, trip in below damaged casing and pull into collar to back off LTC Mod connection, TOOH with BHA 10. Spear 5 ½” casing and lay down same. Inspect 11. Install Casing Spool test plug and test Flange Break to 3,000psi. (Casing Spool Rated to 3K) 12. Drift 7 5/8” casing with mills in preparation for triple connect bushing, if milling occurs, move to “Subsidence Management”. 13. Run new 5 ½” 15.5lb/ft H563 Casing, thread into stump. Test casing to 2500psi. 14. ND BOP, terminate 5.5” and NU new Tubing Spool. NU BOPE and test to 3500psi. 15. On DP, RIH and circulate out sand then pull 5.5” Plug – Move to “Install New 3 ½” Tubing” Subsidence Management 16. RIH and cut 5.5” casing above plug and sand. Circulate out OA fluids. Perform 30 minute NFT. 17. Spear 5.5” casing and LD down old 5.5” casing. 18. RIH and dress off 5.5” casing stub and/or mill 7.625” casing as needed to create drift for new casing. 19. MU and RIH with new 5.5” casing, annular cement tool, and 5.5” sealing overshot. 3G-25X RWO Procedure Kuparuk Producer PTD #196-136 Page 2 of 3 20. PT new 5.5” casing and overshot to 2500 psig against plug. 21. Perform 5.5” x 7.625” OA cement job through annular cement tool. Wait on cement. 22. Once cement reaches adequate compressive strength, ND BOP, terminate 5.5” and NU new Tubing Spool. NU BOPE and test to 3500psi. 23. RIH and mill up any residual cement. Grind up debris as necessary on sand. 24. RIH and circulate out sand. Then pull 5.5” plug. Install New 3-½” Tubing 25. MU 3 ½” completion with Nipples, GLMs, and seals. RIH and sting into PBR. 26. Once on depth, and space out as needed. Circulate in Corrosion Inhibited brine at opportune time. 27. Land tubing. RILDS. 28. Pressure test tubing to 3000 psi for 30 minutes. 29. Pressure test inner annulus to 2500 psi while holding tubing pressure @ 500 psi for 30 minutes on chart. ND BOP, NU Tree 30. Confirm pressure tests, then shear out SOV with pressure differential. 31. Install BPV. 32. ND BOPE. NU tubing head adapter and tree. PT packoffs. 33. Pull BPV, freeze protect well. (No BPV will be set due to internal risk assessment for N7ES MIRU/RDMO.) 34. RDMO. Post-Rig Work 35. Retrieve plug in liner below 7220’ RKB 36. Complete GLD 37. Pull ball and rod if necessary 38. Return to production General Well info: Wellhead type/pressure rating: FMC Gen 4, 3M psi top flange Production Engineer: Brian Lewis Reservoir Development Engineer: Lynn Aleshire Estimated Start Date: 5/1/2023 Workover Engineer: Elliott Tuttle (263-4742/ elliott.tuttle@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to seals. Attempt to back off connection below PC leak and rethread to gain PC integrity; if not successful, cut and pull old 5.5” casing down to near surface casing shoe. Run new 5.5” casing and cement up 5.5” x 7.625” OA. Run new 3.5” completion. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram 3G-25X RWO Procedure Kuparuk Producer PTD #196-136 Page 3 of 3 Following subject to change/be updated with pre-rig work: MIT results: MIT-T N/A CMIT-TxIAxOA to 1800psi Passed 3/29/23 MIT-OA N/A IC POT &PPPOT PASSED – 1/8/23 TBG POT &PPPOT PASSED – 1/8/23 MPSP: 3258 psi using 0.1 psi/ft gradient Static BHP: 3818 psi / 5602’ TVD measured on 3/30/23 (13.1 EMW) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 36' Of Open Perf's 7,344.0 3G-25X 8/13/2019 jhansen8 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Annotate Tbg Leaks 3G-25X 12/6/2022 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: MANDREL ORIENTATION: #1 2:00, #2 7:30, #3 8:30, #4 12:00, #5 10:00, #6 8:00 10/14/2013 osborl 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 42.0 121.0 121.0 62.50 H-40 WELDED SURFACE 7 5/8 6.87 41.5 3,799.8 3,063.7 29.70 L-80 BTC-MOD PRODUCTION 5.5"x4.5" @ 7207' 5 1/2 4.95 29.9 7,667.0 6,028.7 15.50 L-80 LTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 26.8 Set Depth … 7,218.2 Set Depth … 5,693.5 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.8 26.8 0.17 HANGER 8.000 FMC GEN IV HANGER 3.500 501.7 500.7 8.58 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO PROFILE 2.812 3,330.0 2,724.2 43.99 GAS LIFT 4.750 WTF AXT 2.900 4,534.9 3,616.1 40.59 GAS LIFT 4.750 WTF AXT 2.900 5,519.4 4,373.4 40.74 GAS LIFT 4.750 WTF AXT 2.900 6,217.9 4,913.0 38.95 GAS LIFT 4.750 WTF AXT 2.900 6,760.3 5,340.3 38.93 GAS LIFT 4.750 WTF AXT 2.900 7,145.3 5,637.2 38.88 GAS LIFT 4.750 WTF AXT 2.900 7,198.3 5,678.2 39.55 NIPPLE 4.520 CAMCO D NIPPLE w/ 2.75 NO GO 2.750 7,205.5 5,683.8 39.63 LOCATOR 3.980 BAKER LOCATOR 3.000 7,206.7 5,684.7 39.64 SEAL ASSY 3.980 BAKER GBH-22 SEAL ASSEMBLY 2.970 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) 5,520.0 4,373.9 40.74 LEAK LEAK IDENTIFIED AT 5520' RKB BY EL LDL 12/6/2022 2.992 6,891.0 5,440.3 40.70 LEAK LEAK IDENTIFIED AT 6891' RKB BY EL LDL 12/6/2022 2.992 7,135.0 5,629.1 38.75 PLUG Set 2.60" (ME) RBP( 5.34' OAL) Note: no junk tube due to difficulty getting past tight spot at 91' SLM. CPME 35001 /CPE Q2801 2SC 11/24/2022 0.000 7,140.0 5,633.0 38.81 PATCH SET TWO PIECE PATCH ASSEMBLY W/ LOWER SECTION ( SLICK STICK TIE BACK RECEPTACLE, SPACER PIPE, AND D- NIPPLE SEAL ASSEMBLY -- 33.34' OAL W/ MIN. ID OF 1.70" ) STUNG INTO D- NIPPLE @ 7198' RKB. SET UPPER SECTION ( ER PACKER, SPACER PIPE, AND SLICK STICK STINGER- -25.9' OAL W/ MIN. ID OF 1.75 ) IN TIE BACK RECPTACLE @ 7166' RKB. 10/31/2008 1.700 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) 3,330.0 2,724.2 43.99 1 GAS LIFT GLV T1 1 1,367.0 10/7/2013 0.156 4,534.9 3,616.1 40.59 2 GAS LIFT GLV T1 1 1,338.0 10/7/2013 0.156 5,519.4 4,373.4 40.74 3 GAS LIFT GLV T1 1 1,312.0 10/7/2013 0.156 6,217.9 4,913.0 38.95 4 GAS LIFT GLV T1 1 1,290.0 10/7/2013 0.156 6,760.3 5,340.3 38.93 5 GAS LIFT OV T1 1 0.0 8/23/2019 0.250 7,145.3 5,637.2 38.88 6 GAS LIFT PATCH T1 1 0.0 11/1/2008 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,308.0 7,320.0 5,762.1 5,771.2 C-4, 3G-25X 9/12/2000 6.0 APERF 2-1/8" EJ, 180 Deg Ph; +/- 90 oriented from high side 7,328.0 7,336.0 5,777.3 5,783.3 A-3, 3G-25X 6/7/1998 4.0 IPERF 2.5" HC-BH,180 Phasing, 90 orient 7,348.0 7,368.0 5,792.4 5,807.4 A-2, 3G-25X 6/7/1998 4.0 IPERF 2.5" HC-BH,180 Phasing, 90 orient 3G-25X, 12/10/2022 4:01:10 PM Vertical schematic (actual) PRODUCTION 5.5"x4.5" @ 7207'; 29.9-7,667.0 FLOAT SHOE; 7,665.6-7,667.0 IPERF; 7,348.0-7,368.0 IPERF; 7,328.0-7,336.0 APERF; 7,308.0-7,320.0 SBEw/XO; 7,206.8-7,220.1 SEAL ASSY; 7,206.7 LOCATOR; 7,205.5 NIPPLE; 7,198.3 PATCH; 7,140.0 GAS LIFT; 7,145.3 PLUG; 7,135.0 LEAK; 6,891.0 GAS LIFT; 6,760.3 GAS LIFT; 6,217.9 GAS LIFT; 5,519.4 LEAK; 5,520.0 GAS LIFT; 4,534.9 SURFACE; 41.5-3,799.8 FLOAT SHOE; 3,798.2-3,799.8 GAS LIFT; 3,330.0 NIPPLE; 501.7 CONDUCTOR; 42.0-121.0 HANGER; 41.5-43.1 HANGER; 26.8 KUP PROD KB-Grd (ft) 37.85 RR Date 6/2/1998 Other Elev… 3G-25X ... TD Act Btm (ftKB) 7,675.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032024600 Wellbore Status PROD Max Angle & MD Incl (°) 46.81 MD (ftKB) 2,668.90 WELLNAME WELLBORE3G-25X Annotation Last WO: End DateH2S (ppm) 110 Date 12/20/2012 Comment SSSV: NIPPLE 3G-25X 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 121 121 16 15.06 62.5 H-40 Welded Welded Surface 3799.8 3063.7 7 5/8 6.875 29.7 L-80 BTC-MOD BTC-MOD Production 5.5" x 4.5"7207 5685 5.5 4.95 15.5 L-80 LTC-MOD LTC-MOD 7667 6028.7 4.5 3.958 12.6 L-80 Tubing 7218.2 5693.5 3.5 2.992 9.3 L-80 EUE-M 8rd EUE-M 8rd Last Tag: 36' of Open Perf's Date: 8/13/2019 Depth: 7344' RKB PROPOSED CASING COMPLETION 5 1/2" 15.5lb/ft Hydril 563 Casing Crossover w/ Bell Guide (5 1/2" Hyd563 to 5 1/2" LCT Mod) Casing cut ~500' RKB PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Camco KBG29-1R gas lift mandrels @ -3140' RKB -5163' RKB -7150' RKB 3-½" D nipple at xxxx' RKB (2.75" min ID) 3 1/2" Baker GBH-22 Seal Assembly REMAINING COMPLETION LEFT IN HOLE Sealbore @ 7206.8' to 7220.1' RKB 7 5/8" Surface Production Casing 5 1/2" x 4 1/2" 16" Conductor A/C-sand perfs 7308' - 7368' RKB 3G-25X 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 121 121 16 15.06 62.5 H-40 Welded Welded Surface 3799.8 3063.7 7 5/8 6.875 29.7 L-80 BTC-MOD BTC-MOD Production 5.5" x 4.5"7207 5685 5.5 4.95 15.5 L-80 LTC-MOD LTC-MOD 7667 6028.7 4.5 3.958 12.6 L-80 Tubing 7218.2 5693.5 3.5 2.992 9.3 L-80 EUE-M 8rd EUE-M 8rd PROPOSED CASING COMPLETION 5 1/2" 15.5lb/ft Hydril 563 Casing 5 1/2" Cementer 5 1/2" Casing Patch 5K Casing cut ~3700' RKB PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Camco MMG gas lift mandrels @ TBD 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3 1/2" Baker GBH-22 Seal Assembly REMAINING COMPLETION LEFT IN HOLE Sealbore @ 7206.8' to 7220.1' RKB 7 5/8" Surface Production Casing 5 1/2" x 4 1/2" 16" Conductor A/C-sand perfs 7308' - 7368' RKB C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\LCF4WGUY\2022-12-06_21114_KRU_3G-25X_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 21114 KRU 3G-25X 50-103-20246-00 LeakPoint Survey 06-Dec-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM By Meredith Guhl at 1:33 pm, Jan 03, 2023 196-136 T37411 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.03 13:34:01 -09'00' ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 12, 2009 .` ~~, ~ ~`'s~ ;~~~ ~ ~~~ ~' i. s. ;.. ,~i ~- Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~ q (~- ~~, ~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kupanxlc field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped February 15th 2009. The corrosion inhibitor/sealant was pumped March 10th and 11th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, r i~ M.J. Loveland i~ ~' ^~~,,. f~J ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/12/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3G-02 190-137 SF NA 16" NA 1.7 3/11/2009 3G-03 196-122 SF NA 16" NA 1.7 3/11/2009 3G-05 190-075 12'6" 1.80 19" 2/15/2009 4.25 3/10/2009 3G-06 190-069 8'4" 1.20 18" 2/15/2009 3.5 3/10/2009 3G-07A 190-085 25'6" 3.40 18" 2/15/2009 3.4 3/10/2009 3G-11 190-076 22" NA 22" NA 4.25 3/10/2009 3G-14A 197-251 SF NA 17" NA 3.4 3/10/2009 3G-17 190-122 5' 0.80 16" 2/15/2009 2.55 3/10/2009 3G-18 190-125 18" NA 18" NA 4.25 3/10/2009 3G-19A 201-106 18" NA 18" NA 2.55 3/10/2009 3G-21A 198-052 21' 2.80 2'10" 2/15/2009 12.75 3/10/2009 3G-25X 196-136 SF NA 7" NA 2.55 3/10/2009 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA~'tONS 1. operations Performed: Abandon ^ Repair Well 0 ~ Plug Perforations ^ Stimulate ^ Other.. ~ ~b~~~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ ~~ ~~ g pp og ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ Chan e A roved Pr ram 2.Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 196-136 . 3. Address: Stratigraphic ^ service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20246-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 85' 3G-25X 8. Property Designation: 10. Field/Poal(s}; ADL 0025547 Kuparuk River Field / Kuparuk Oil Pool 11. Present Weil Condition Summary: Total Depth measured 7675 feet true vertical 6032 feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse CONDUCTOR 16" 80' 80' SURFACE 7 5/8 3800' 3064' PRODUCTION 51/2" 7197' 5677' LINER 4-1 /2" 7667' 6029' x~~E~ ~ ~: ~ ~ 2QD~ Pertoration depth: Measured depth: 7308-7320, 7328-7336, 7348-7368 true vertical depth: 5762-5771, 5777-5783, 5792-5807 Tubing (size, grade, and measured depth) 3 1/2", L-80, 7218' MD, 5693 TVD 3-1 /2" WFT Patch from 7100' - 7198' MD ' Packers &SSSV (type & measured depth) Pkr= Baker 80-40 SBE, 7207' MD SSSV= Camco DS Nipple, 501' 12. Stimulation or cement squeeze summary: Intervals treated (measured) -~/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ • Service ^ Daily Report of Well Operations _X 16. Well Status after work: C^ ~ Gas^ WAG^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my Imowledge. Sundry Number or NIA ff C.O. Exempt: contact Brent Rogers/Martin Walters Printed Name Martin Walters Signature ~~ ~,~l~ ~~~,~ Title Problem Wells Supervisor Phone: 659-7224 Date 11 /15/2008 ~~ -- .~ n. ~`f`.°$ /~ ~ . l~~ r ~~Submit Original Onli Form 10-404 Revised 04/2006 } ~ / . , -~. i f '~: J~ If'~: ~~ lac r° ~~ Q znnu • • 3G-25X DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 9/21 /2008 RAN SPINNER/TEMPERATURE LDL. RESULTS: LEAK DETECTED AT 7154' IN TOP OF F GLM .DOES NOT APPEAR TO BE A PROBLEM WITH VALVE SEATING OR PACKING. LEAK RATE NOT CONSISTENT AND VARYING BETWEEN PRESSURING UP THE TUBING TO 2700 PSI AT 0.35 BBL/MINUTE AND PUMPING AWAY AT 0.9 BBL/MINUTE AT 2000 PSI. 9/28!2008 LOG TBG WITH PDS CALIPER FROM 7250' SLM TO SURFACE SET 2.75 CAT STANDING VALVE @ 7198' RKB. PULLED DGLV @ 7145' RKB. DRIFTED 10/30/2008 TBG. W/ 23' BARBELL DRIFT. CIRCULATED 165 BBLS OF DIESEL AND CMIT TBG X IA TO 2500 PSI (PASSED ). PULLED CAT Cad 7198' RKB. 10/31/2008 11/1/2008 11/9/2008 SET TWO PIECE PATCH ASSEMBLY W/ LOWER SECTION (SLICK STICK TIEBACK RECEPTICLE, SPACER PIPE, AND D-NIPPLE SEAL ASSEMBLY --33.34' OAL W/ MIN. ID OF 1")STUNG INTO D-NIPPLE @ 7198' RKB. SET UPPPER SECTION (ER PACKER, SPACER PIPE, AND SLICK STICK STINGER--25.9' OAL W/MIN. ID OF 1.75) IN TIE BACK RECPTICLE @ 7166' RKB. DROPPED AVA CATCHER SUB ONTOP OF ER PACKER @ 7140' RKB. PULLED DGLV @ 6760' RKB. PULLED 2.81" CA-2 PLUG FROM 499' RKB. SET BAITED 2 1/2" RB ON 2.75" CA-2 PLUG @ 6978' RKB(OAL=33") REPLACED DV'S IN STA#2,3 AND #5 W/ VALVES PER DESIGN. PULLED DV STA #'I.**OPEN POCKET**VERIFIED VLV'S SET BY BLEEDING IA Post Patch TIFL -passed, Initial T/I/0= 200/825/250. Shut in the WH and GL upon arrival. Shot the initial IA FL @ 6760' sta. #5 OV. Stacked out the TBG with LG. Bled down the IA and shot the 2nd IA FL @ the same location. Final T/I/O = 740/220/0 RAN LEAK DETECTION LOG AND CALIPER TO DETERMINE LEAK LOCATION. Summary PERFORMED CMIT. SET WEATHERFORD PATCH FROM'7140' - 7198' MD. INSTALLED NEW GASLIFT DESIGN AND WELL PASSED TIFL. ~~rL~~~r-r~~ NO.4914 1 .'"'`7 _`~`;' '~._1 i, ~~.I Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 r ,,~.~ ~ ~ ~ ~- ;- i ~~ ~., ~, ~ ~~~, ATTN: Beth ~ iY. i,dn. .. ._: ,:.~r~rc: Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/14/08 1L-23 - 12097405 SBHP SURVEY 07!17/08 1 1 2A-17 11975793 PRODUCTION PROFILE 9 - /C. © p L 09/10/08 1 1 3G-25X 12080437 LDL ( - 3 L/{o 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE C.- C / ~ 09/14/08 1 1 3M-13 12096541 LDL - (~C( ( (~ 09/10/08 1 1 2Z-13A 12100446 LDL o7b(o- l'~O '~U 3 09/15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - 5~ 09/22/08 1 1 iC-111 12100451 INJECTION PROFILE ~ U 09/20/08 1 1 30-15 12f00452 LDL - ~ 5Q 09/21/08 1 1 1C-117 12100453 INJECTION PROFILE o r 09/23/08 1 1 1R-11 11966277 SBHP SURVEY S - ~ (~ 09/25/08 1 1 1 R-35 11966279 SBHP SURVEY ~ 09/25/08 1 1 1 R-14 11966286 LDL ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE 09/30/08 1 1 iR-34 12080444 _ GLS ~ .- 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .= L ~C/ 10/02/08 1 1 iD-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ~'-~ '~- ( 10/06/08 1 1 1 H-19 12096548 INJECTION PROFILE L~ 10/03/08 1 1 1B-16 12097426 GLS ~ - =' 10/07/08 1 1 36-09 12100442 PRODUCTION PROFILE 09/12/08 1 1 3K-103 12096550 USIT 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE - ~~ 10/07/08 1 1 1 B-04 12096552 INJECTION PROFILE -- 10/08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 1 i B-16 12096554 PRODUCTION PROFILE q C' .. G 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE ,I'~G , 10/11/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • • To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 • RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, (nc. Attn: Robert A. Richey 130 West International Airport Road (~!~G SUrte Ci ,> :.:5,~i~~~~~;a } \~ ~i i,; i ri ~ l.i s1(;~ Anchorage, AK 99518 Fax: (907) 245-8952 1] 2) Signed Caliper Report 27Sep-08 1 A-05 1 Report /EDE 50-029-20627-00 Caliper Report 28,Sep-08 3G25X 1 Report /EDE 50.103-2024Fr00 Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAf3E, AK 99518 PHONE: (907)245-8951 FAX: (907j245~8952 E-MAIL: ~'aS?iDC'3vf8~~~(~ai32~,'ffiS?t°.^.yt.~C^'s?l WE85RE: ~'~~'1'atl,i"i';+V~f7~JP'•)~Dv.~'ia`t~ ' /^ C:\Doc~anen6 and Settings\Owner\Desktop\Transmit_Conoco.doc 1 • • Memory MuttNFinger Caliper Log Results Summary Company: ConocoPhiRips Alaska, Inc. Well: 3G-25X Log Date: September 28, 2008 Field: Kuparuk Log No.: 7269 State: Alaska Run No_: 1 API No.: 50-103-20246-00 Pipet Desc.: 3.5" 9.3 fb. L-80 EUE 8RD Top log intvf: Surtace Pipet Use: Tubing Bot. Log Intvl: 7,232 Ft. (MD) Inspection Type : Corsosive & Mechanical Damage /nspectlon COMMENTS This caliper data is tied into the D Nipple ~ 7,198' RKB. This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical ' damage. The caliper recordings indicate the 3.5" tubing is in good condition with respect to corrosive damage, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded throughout the tubing logged. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetratians {> 17°~) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 9%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS No sign cant I.D. restrictions are recorded throughout the tubing logged. ja:1~~J W~Wii {+SI ~J ~`•i y l' a. l' [... tJ 1F ti Field Engineer: Wm. McCrossan Analyst: M. Lawrence Witness: S. Ferguson j ~ ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888} 565-9085 Fax: (281) 565-1369 E-mail: PDS,a~memorylog.com Prudhoe bay Field Office Phone: {907) 659-2307 Fax: (907) 659-2314 ~~ ~9l0-~3~ ~ • Correlation of Recorded Daman ~i Pipe 1 3.5 in (16.4' - 7214.5') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 3G-25X Kuparuk ConocoPhillips Alaska, Inc. USA September 28, 2008 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 47 809 1599 2393 3185 p GLM 1 c 4015 s a. v GLM 2 4843 GLM 3 5672 GLM 4 6500 GLM 5 GLM 6 218.7 7214 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 218.7 1 25 .- 50 75 100 a~ E Z 125 'o 150 175 200 • • PDS Report Overview ~, ~,. Body Region Analysis Well: 3G-25X Survey Date: September 28, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: M. Lawrence Tubing: Norn.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°,6 wall) ~ penetration body ~ metal loss body 150 100 50 0 0 l0 1 l0 10 to 20 to 40 to over 1% 10%~ 20% 40% 85% 85% Number of ~oints anal sed total = 236 gene. 0 128 108 0 0 0 loss 132 104 0 0 0 0 Damage Configuration (body ) 40 30 20 10 U isolated general line nng hole/pons pitting contusion corrosion corrosion ible hole Number of 'oints dama ed total = 50 31 19 0 0 0 Damage Profile (°~ wall) tiw penetration body s?r.: metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 Bottom of Survey = 218.7 Analysis Overview page 2 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ELATION SHEET 3G25X Kuparuk ConocoPhillips Alaska, Inc USA Septernber 28, 2008 Joint No. Jt. Depth (Ft.) I'~~n. (ll,.~~t (In,.) Pen. Body (Ins.) Pen. °lo ~1~~i.il I utiti <~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 16 ~~ 0.02 ~~ ~) 2.89 PUP .2 20 O 0.03 1(1 I 2.93 PUP .3 29 I) 0.03 12 I .93 PUP .4 38 U 0.01 i .89 PUP 1 47 ~? 0.01 4 u .93 2 78 ~) 0.03 I O 1 2.93 3 110 U 0.03 l U I 2.93 4 142 ~) 0.02 9 I 2.94 5 174 O 0.01 4 I 2.93 6 205 U 0.02 9 I 2.92 7 237 O 0.03 12 ~' 2.91 8 269 O 0.01 i U 2.94 9 3 0 ~) 0.04 14 2.93 Shallow corrosion. 10 332 O 0.03 IO I 2.93 11 364 ~ ~ 0.01 5 I 2.94 12 396 ~) 0.03 1 i ~ 2.93 Shallo ittin . 13 428 a 0.03 1 U I 2. 3 14 459 a 0.03 1l) ~ 2.93 14.1 491 O 0 O ~) 2.81 amco DS Ni le w No Go Profile 15 492 I~ 0.02 '~ I 2. 3 16 524 O 0.03 1 1 1 2.91 17 555 O 0.04 16 I 2.91 Shallow ittin . 18 587 O 0.02 ti I 2.94 19 618 U 0.03 11 2.94 20 6 0 O 0.03 1O 1 2.93 21 682 U 0.03 11 I 2.94 2 714 U 0.03 1 U 2.93 23 745 O 0.03 12 2.93 24 777 U 0.03 13 _' 2.93 Shallow ittin . 25 809 ~ ~ 0.01 4 1 2.95 26 841 !) 0.02 ~~ 1 2.91 27 872 ~~ 0.03 13 1 2.94 Shallow ittin . 28 904 U 0.03 13 I 2.93 Shallow ittin . 29 936 a 0.02 ~> s 2.94 30 968 U 0.01 ~ I 2.93 31 998 (1 0.01 (; I 2.93 3 1030 O 0.02 ~) 1 2.93 33 1062 !) 0.03 1 I 1 2.94 34 1093 ~) 0.01 ~ 2.93 35 1125 ~? 0.03 1:3 _' 2.93 Shallow ittin . 36 1157 a 0.02 ti ~~ 2.93 37 1188 U 0.03 12 2.93 38 1220 U 0.02 ~) I 2.94 39 1252 O 0.04 I i I 2.94 Shallow ittin . 40 1284 U 0.03 1 ~' 2.93 Shallow corr Sion. 41 1316 ~ ? 0.02 ~) I 2.93 42 1347 ~ ~ 0.03 1 i _' 2.94 Shallow ittin . 43 1379 ~ ~ 0.02 ~) 1 2.93 44 1411 ~ ~ 0.03 I ~ 1 2.93 45 1441 ~.~ 0.03 i~! I 2.93 _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 3G25X Kuparuk ConocoPhillips Alaska, Inc. USA September 28, 2008 Joint No. Jt. Depth (Ft.) I'c~n. Ul~tiet (In..l Pen. Body (Ins.) Pen. `%~ Metal I uss ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 46 1473 l) 0.01 z I 2.93 47 1505 a 0.03 11 ' 2. 3 48 1535 a 0.01 4 2.93 49 1567 ~! 0.02 ~? I 2.94 50 1599 a .02 ~) I 2.92 51 1631 i ! 0.03 1 ' I 2.9 52 1662 i ! .02 t3 _' 2.93 53 1694 t) 0.02 ~~ 2.94 54 172 6 t 1 0.03 11 I 2.94 55 1758 t! 0.04 I i 2.94 Shallow c rrosion 56 1789 U 0.0 tt I 2.94 57 1821 U 0.02 ~) 2.93 58 1853 t ! 0.01 -1 I 2.93 59 1885 ~ ! 0.02 ~ ~ I 2.93 60 1916 t ! 0.02 ~ ~ I 2.92 61 1948 t! 0.02 t~ I 2.93 62 1980 U 0.02 ~! I 2. 1 63 2012 t! .02 ~) I 2.93 64 2044 t! 0.04 I G ~ 2.93 Shallow corrosio . 65 2076 i! 0.03 1 ~' I 2.92 66 2107 i! 0.03 11 I 2.92 67 2139 i ~ 0.02 ti 2.93 68 2171 t~ 0.01 5 > 2.93 69 2202 t t 0.04 14 I 2.93 Shallow ittin . 70 2234 t! 0. 3 13 _' 2.93 Shallow ittin . 71 2266 ~! 0.03 11 2.92 72 2298 t! 0.02 ~) I 2.92 73 2330 i! 0.03 13 _' 2.92 Shallow corrosion. 74 2362 i! 0.03 11 I 3 75 2393 i i 0.02 7 I 2.91 76 2425 a 0.03 11 I .93 77 2457 ~ i 0.02 7 1 2.93 78 2489 t! 0.03 11 I 2. 79 2520 i! 0.02 9 I 2.93 80 2552 t! 0.03 11 1 2.93 81 2583 t! 0.02 f3 I 2.93 82 2615 l! 0.04 14 I 2.92 Shallow corrosion. 83 2647 a 0.03 12 ' 2.94 84 2678 U 0.03 11 t) 2.93 85 2710 t) 0.03 t 3 I 2.91 Shallow ittin . Lt. De sits. 86 2742 a 0.03 12 ~ 2.93 87 2774 t! 0.03 11 1 2.93 88 2805 n 0.04 15 I 2.92 Shallow ittin . 89 2837 t! 0.04 17 ~ 2.94 Shallow ittin Lt. De osits. 90 2869 ~! 0.03 11 I 2.92 91 2900 t! 0.04 I t, 2.93 Shallow ittin . 92 2932 U 0.04 15 ! 2.93 hallow corrosion. 93 2964 (! 0.03 11 I 2.94 94 2996 i! 0.02 ~? I .93 95 3026 ~! 0.03 1 _' I 2.93 _ Penetration Body Metal Loss Body Page 2 PDS REPORT JOINTTABI, Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 3G25X Kuparuk ConocoPhillips Alaska, Inc USA September 28, 2008 Joint No. Jt. Depth (Ft.) I'~~n. t!I,~~•t IIm.J Pen. Body (Ins.) I'e~n. % ~~tc~t,~l loss "~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 3058 t~ 0.02 y I 2.93 97 3090 a 0.03 2 1 2.93 98 3121 t) 0.03 13 ~' 2.92 Shall w ittin . 99 3153 U 0.02 9 _' 2 91 100 3185 t ~ 0.03 12 2. 3 101 3216 i i 0.01 (~ I .92 102 3248 t! 0.02 ~~ 2.93 103 3280 U 0.03 1 Z I 2.93 103.1 3312 tt 0.02 8 I 2.95 PU 103.2 3327 U 0 l) U N A G M 1 Latch ~ 2:00 103.3 3 34 t~ 0.02 8 ~' 9 PUP 104 3349 i? 0.04 1 7 2.93 Shallow corrosion. 105 3380 t~ 0.04 14 I .93 Shallow corrosion. 106 3412 c~ 0.02 ~~ I 2.94 107 3443 t I 0.02 9 I .93 108 3475 t ~ 0.01 5 t 2.93 109 3507 t ~ 0.03 1 U 1 2.93 110 3539 t~ 0.04 I6 I 2.93 Shallow corrosi n. Lt De osits. 111 3570 i ~ 0.0 I 1 1 .92 112 3601 ! ~ 0.02 £3 2.92 113 3633 i ~ 0.04 1 ~ 2.92 Shallow ittin . 114 3665 ~ ~ 0.03 I I I 2.93 115 3696 t~ 0.03 10 1 2.92 116 3728 t) 0.03 11 0 2.93 117 376 a 0.03 1 U 2.93 118 3792 t~ 0.03 I _' 2.91 Shallow corrosion. 119 3824 U 0.03 1O I 2.92 120 3855 ~ ~ 0.03 13 I 2.92 Shallow ittin . 121 3887 t? 0.03 t 1 n 2.92 122 3919 (~ 0.04 1-1 I 2.92 Shallow corrosion. 123 3951 c~ 0.03 I I 2.93 Shallow co rosion. 124 3983 U 0.02 ~~ I 2.92 125 4015 cl 0.02 ~~ t 2.91 126 4046 U 0.03 I2 ~' 2.92 127 4078 t) 0.03 10 ~ 2.92 Lt. osits. 128 4108 t) 0.02 9 ~ 2.92 129 4139 U 0.04 l i 3 2.91 Shall w corrosion. 130 4171 i } 0.01 ~ I 2.92 131 4203 i i 0.03 I t I 2.92 132 4235 i~ 0.01 4 I 2.93 133 4266 t ~ 0.03 1 U 2.91 134 4298 i I 0.02 f3 ~' 2.91 135 4329 U 0.01 4 _' 2.92 136 4361 U 0.01 5 t 2.92 7 4393 ti 0.03 12 ~ 2. 4 138 4425 t> 0.03 t 1 I 2.92 139 4456 i ~ 0.01 (~ _' 2.91 140 4488 ! ~ 0.02 ~3 I 2.93 140.1 4520 0.03 t U _' .92 PUP 140.2 4536 0 t~ !' N A GLM 2 Latch ~ 7:30 _ Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: iLATION SHEEP 3G-25X Kuparuk ConocoPhillips Alaska, Inc. USA September 28, 2008 Joint No. Jt. Depth (Ft.) P~~n. Ul~sc~t (lnti.) Pen. Body (Ins.) Pen. % :Metal I o~~ °~<~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 140.3 4542 t) 0.01 5 -1 2.95 PUP 141 4558 t) 0.03 12 _' 2.93 142 4589 a 0.02 ~) 1 2.92 143 4621 !) 0.03 1 1 2.92 144 4652 !) 0.01 +~ I 2.93 145 4684 ~) 0.01 ~ I 2.92 146 4715 l l 0.01 i ~ } 2.92 147 4747 U 0.03 1.t ? 2.93 Shallow ittin . 148 4779 U 0.02 i (1 .92 149 4811 t) 0.03 1 1 2.92 150 4843 (~ 0.03 I1 ! 2.93 151 4874 a 0.01 5 1 2.93 152 4906 ~) 0.03 I ~ t 2.93 153 4938 ! ~ 0.0 I I I 2.92 154 4969 !) 0.02 i 2.92 155 5001 a 0.03 11 I 2.91 156 5033 t) 0.03 12 .92 157 5065 t) .03 13 1 2.93 Shallow ittin . 158 5096 c) 0.03 1O 1 2.92 159 5128 a 0.03 1 Z .95 160 515 !) 0.04 1-t 2.92 Shallow ittin . 161 5191 t) 0.03 I ~ I 2.93 Shallow ittin . 162 5223 t) 0.02 ~! I 2.91 163 5255 !) 0.03 13 2.89 Shallow itti 164 286 t) 0.02 ~) 1 2.92 165 5318 U 0.03 13 _' 2.90 Shallow ittin . 166 5349 t) 0.03 12 2 2.92 167 5381 a 0.02 9 1 2.92 68 5413 ~ 1 0.02 9 Z 2.91 169 5444 ~ ~ 0.02 7 I 2.91 170 5476 ~) 0.03 I Z I 2.92 170.1 5508 !~ 0.02 £3 2.93 PUP 170.2 5523 t) 0 [) t! N A G M 3 Latch ~ 830 170.3 5529 U 0.03 1 Z ~ 2.91 PUP 171 5545 U 0.04 14 2.91 Shallow ittin . 172 5576 t) 0.03 I ~) I 2.92 173 5608 t) 0.03 1 ~ I 2.91 174 5640 ~) 0.02 ~) I 2.91 175 5672 !! 0.03 II ~ 2.9 176 5703 U 0.02 ~) ! 2.92 177 5735 ~! 0.03 1t) ~' 2.90 178 5766 n 0.04 15 I 2.92 Shallow ittin . 179 5798 U 0.04 14 2.91 Shallow it6n . 180 5830 !) 0.04 la ) 2.91 Shallow ittin . 181 5861 U 0.03 1 Z 1 2.91 Shallow ittin . 182 5893 a 0.02 £i _' 2.93 183 5924 a .02 ~) ? 2.88 Lt De o its. 184 5956 t) 0.04 14 2.91 Shallow corrosion. 185 5987 ~) 0.03 Il) 2.91 186 6019 ~! 0.03 13 - 2.91 Shall<~w ~ittin Lt. De sits. _ Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 3G25X Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: September 28, 2008 Joint No. Jt. Depth (Ft.) I'~•n. Illnet (lrn.) Pen. Body (Ins.) Pen. `i~> ~tc~t,il loss 44, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 187 6050 ~) 0.03 10 1 .91 188 6082 ~) 0.01 b I 2.92 189 6114 ~) 0.02 ti 2.92 190 614 I) 0.02 ') I 2.91 191 6177 0 0.03 1 _' ? 2.92 191.1 6209 0 0.02 ti _' 2.95 PUP 191.2 6222 I) 0 ~) ~) N A GLM 4 Latch ~ 12:00 191.3 6231 ~) 0.01 <' I 2.94 PUP 192 6246 ~ ? 0.02 ~) I 2.93 193 6278 ~) 0.03 I I _' 2.91 194 6310 a 0.03 1I 2.90 195 6341 n 0.03 I ~) 1 2.92 196 6373 ~) 0.03 1 < ~ 2.92 Shallow corrosion. 197 6405 0 0.01 6 I 2.91 198 6437 0 0.02 ') _' 2.92 199 6468 ~) 0.02 ti 2.92 200 6500 i) 0.04 I l 2.93 Shallow corrosion. 201 6532 ~! 0.02 ') 2.91 02 6564 0 0.03 1 2.93 Shallow corrosion. 2 6595 l) 0.0 I z I 2.9 204 6627 U 0.03 1 _> I 2.89 Shallow ittin . 205 6659 l) 0.03 10 1 .92 206 6689 U 0.02 ~) _' 2.91 207 6720 0 0.03 lI I 2.91 207.1 6751 0 0 02 £3 ! 2 94 P P 207.2 6767 0 0 0 u N A GLM 5 Latch ~ 10:00 207.3 6774 i) 0.02 ~) I 2.91 PUP 208 6790 ~) 0.03 I 0 2.91 209 6821 i 1 0.03 1 U I 2.88 210 6853 0 0.02 ~) I 2.93 211 6885 0 0.02 8 ~' 2.90 212 6916 0 0.01 ~ 2.92 213 6948 U 0.03 11 _' 2.90 214 6979 ~) 0.03 11 2.92 215 7011 0 0.02 ~) 2.92 216 7043 c) 0.02 ~) 2.92 217 7074 U 0.03 1 _i ') 2.91 Shallow corr sion. 218 7106 0 0.03 12 ~ 2.91 218.1 7137 ~) 0.02 ri ~' 2.93 P P 218.2 7153 ~> 0 U i) N A CLM 6 Latch @ 8:00 218.3 7162 ~~ 0.01 _' 2.95 PUP 218.4 7175 a 0.02 - I 2.95 PUP 218.5 7198 i ~ 0 i? ! ~ 2.75 D Ni le w No Go Zlfl.h 7201 (104 2 9 SFi:~~l iftinR. ~ _'1 I _ ~I1 ! - ~ ~~ _ __ _ , f ~ l ~11~I ~til \I ~ I ~ _i ~ ~ _ Penetration Body Metal Loss Body Page 5 ConacoPhillips Alaska, Inc. KRU 3G-25X `i' 3G-25X API: 501032024600 Well T : PROD An le TS: 41 d 7307 TUBING (a72ts, OD 3 500 SSSV Type: Nipple Orig COm letion: 62/1998 Angle @ TD: 43 deg @ 7675 : . , ID:2.992) Annular Fluid: Last W/O: Rev Reason: TAG FILL Reference L Ref L Date: Last U ate: 8/7/2006 Last T : 7360 TD: 7675 ftKB Last Ta Date: 7/31/2006 Max Hole An le: 47 d 2669 Casin Strin -ALL STRING S Descri lion Size To Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 80 80 62.50 H~0 WELDED SURF CASING 7.625 0 3800 3064 29.70 L-80 BTCM PRODUCTION 5.500 0 7197 5677 15.50 L-80 LTC LINER 4.500 7197 7667 6029 12.70 L-80 EUE-8RD Tu in Stri -TUBING Size To Bottom ND Wt Grade Thread ~ 3.500 0 7218 5693 9.30 L-80 EUE 8RD ROOUCT1oN (a7t97 Perforations Summa , oD:s.soo, . I Interval ND Zone Status Ft SPF Date T Comment wt:ts.so) ~ 7308 - 7320 5762 - 5771 C-4 12 6 9/12/2000 APERF 2-1/8" EJ, 180 Deg Ph; +/- 90 oriented from hi h side ( 7328 - 7336 5777 - 5783 A-3 8 4 6/1/1998 IPERF 2.5" HC-BH,180 Phasing, 90 orient Gas Lift MandrelNalee 3 ~~ _ © 734g _ 7368 5792 - 5807 A-2 20 4 6!7/1998 IPERF 2.5" HC-BH,180 Phasing, 90 Oflent (5579-5520, _ _- G Lift Me ndrels /Vahles St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3330 2724 BST AXT GLV 1.0 T1 0.188 1318 2/26/2006 2 4535 3616 BST AXT DMY 1.0 T1 0.000 0 6/1/1998 3 5519 4373 BST AXT GLV 1.0 T1 0.250 1389 2/26/2006 4 6218 4913 BST AXT DMY 1.0 T1 0.000 0 6/1/1998 5 6760 5340 BST AXT DMY 1.0 T1 0.000 0 3/18/2006 I 6 7145 5637 BST AXT OV 1.0 T1 0250 0 3/9/2006 Other lu s u i .etc. -JEWELRY ' - De th TVD T e Descri lion ID ~ . 501 500 NIP CAMCO DS NIPPLE W2.812" NO GO PROFILE 2.812 7198 5678 NIP D NIPPLE W2.75" NO GO 2.750 7207 5685 SEAL 3.5" BAKER GBH-22 SEAL ASSEMBLY OD 4.0 3.500 7207 5685 SBE BAKER 80-40 4.000 cas Lirt 7633 6004 FLOAT COLLAR 4.5" WEATHER GEMCO FLOAT COLLAR 3.958 MandrelNaNe s 7665 6027 SHOE WEATHERFORD GEMCO SHOE 3.958 (71457146, LINER (7197-7667, OD:4.500, I Wt 12.70) I Pert (730&7320) Pert (732&7336) Pert (7348-7368) FLOAT COLLAR (76337634, OD:4.500) - - - - - - 3G-25X (PTD 1961360) Report o~ SCP ~ Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, August 30, 2008 4:23 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 3G-25X (PTD 1961360) Report of IA SCP Attachments: 3G-25X schematic.pdf; 3G-25X 90 day TIO plot.jpg Tom & Jim, Kuparuk gas lifted roducer 3G-25X (PTD 1961360) has suspect IA sustainedcasing pressure while SI and has been added to the weekly CP report. The current TIO is 320/210~Ib. A leakin GLV use so slickline will troubleshoot the leak and repair if possible. The production casing is 5. ' 15.5# L-80 with an internal yield pressure of 7000 psi. The well is currently Sl and will remain so until repaired. Attached is a 90 day TIO plot and schematic. «3G-25X schematic.pdf» «3G-25X 90 day TIO plot.jpg» '~ Please let me know if you have any questions. _._ _... Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 ~ ~~~~.• ~~~~ ,y' ~~ ~~ ~` Pager (907) 659-7000 pgr. 909 '~`° `'" 12/10/2009 KRU 3G-25X PTD 1961360 8/30/2008 TIO Pressures • f~ Conoc+~Philiips Alaska, Ins. KRU 3G-25X 3G-25X API: 501032024600 Well T e: PROD An le TS: 41 de 7307 TueiNG - { SSSV Type: Nipple Orig 6/2/1998 Angle @ TD: 43 deg @ 7675 (o-721a, I Com letion: OD:3.500, ss2) iD:z Annular Fluid: Last W/O: Rev Reason: TAG FILL . Reference Lo Ref Lo Date: Last U date: 8/7/2006 Last Ta : 7360 TD: 7675 ftK6 Last Ta Date: 7/31/2006 Max Hole An le: 47 de 2669 Casin Strin -ALL STRINGS Descri lion Size To Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 80 80 62.50 H-40 WELDED " " ` ~~ SURF CASING 7.625 0 3800 3064 29.70 L-80 BTCM - ~ ~°_ ~' PRODUCTION 5.500 0 7197 5677 15.50 L-80 LTC . ~ ~-I LINER 4.500 7197 7667 6029 12.70 L-80 EUE-8RD Tubin Strin -TUBING - Size To Bottom ND Wt Grade Thread 3.500 0 7218 5693 9.30 L-80 EUE 8RD PRODUCTION ~ Pertorations. Summa - - Oo a aoo, . Interval ND Zone Status Ft SPF Date T e Comment wt:15.5a) 7308 - 7320 5762 - 5771 C-4 12 6 9/12/2000 APERF 2-1/8" EJ, 180 Deg Ph; +/- ~ 90 oriented from hi h side 7328 - 7336 5777 - 5783 A-3 8 4 6/7/1998 IPERF 2.5" HC-BH,180 Phasing, 90 orient Gas Lift e M d lN l ~c ~ , '~ 7348 - 7368 5792 - 5807 A-2 20 4 6/7/1998 IPERF 2.5" HC-BH,180 Phasing, an re a v 3 s ~: ~ 90 orient (5519-5520, ~s~ _. ` - _+ Gas.:: Lift MandrelslValves ~ St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 3330 2724 BST AXT GLV 1.0 T1 0.188 1318 2/26/2006 2 4535 3616 BST AXT DMY 1.0 T1 0.000 0 6/1/1998 t~ ' 3 5519 4373 BST AXT GLV 1.0 T1 0.250 1389 2/26/2006 _ 4 6218 4913 BST AXT DMY 1.0 T1 0.000 0 6/1/1998 5 6760 5340 BST AXT DMY 1.0 T1 0.000 0 3/18/2006 6 7145 5637 BST AXT OV 1.0 T1 0.250 0 3/9/2006 Other lu s e ui ..etc. - JEWELRY - De th ND T e Descri lion ID 501 500 NIP CAMCO DS NIPPLE W/2.812" NO GO PROFILE 2.812 ~~ 7198 5678 NIP D NIPPLE W/2.75" NO GO 2.750 ' "" ~ ~ 7207 5685 SEAL 3.5" BAKER GBH-22 SEAL ASSEMBLY OD 4.0 3.500 7207 5685 SBE BAKER 80-40 4.000 7633 6004 FLOAT 4.5" WEATHER GEMCO FLOAT COLLAR 3.958 Gas Lift ~ is COLLAR MandrelNalve s ~ 7665 6027 SHOE WEATHERFORD GEMCO SHOE 3.958 (7145-7146, _ LINER --- ~ (7197-7667, - OD:4.500, Wt:12.70) Pert -......_ (7308-7320) ----- Pert - (7328-7336) .._..... i ~ Perf - (7348-7368) - __ _,_ i i i FLOAT _..__ COLLAR (7633-7634, OD:4.500) I i RECEI\/ED A.Ul; () ð 2006 08/01/06 Scblumbepgep ~ Oii & Gas Cons. COIf.rr.~ AnchcrdQe NO. 3899 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ¡Cj(o-J3b Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well ")f'\rV fl.\)b 1 4. ,-uJO (.'f· hN'NE.D .' w \¡J.f's Log Description Date Color CD Field: Kuparuk Job # BL 1J-101 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 1D-125A (REDO) 11213778 INJECTION PROFILE 07/17/06 1 2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1 1 G-05 11249932 INJECTION PROFILE 07/28/06 1 3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1 1 D-117 11216305 INJECTION PROFILE 07/08/06 1 3F-18 11235384 SBHP SURVEY 07/25/06 1 3F-17 11235383 BHP SURVEY 07/25/06 1 1Y-32 11213707 SBHP LOG 07/25/06 1 3G-25X 11216313 PROD PROFILE W/DEFT 07/31/06 1 1Y-24A 11216315 GLS/FBHP SURVEY 08/01/06 1 1 R-36 11249931 LDL 07/27/06 1 2V-10 11216311 SBHP SURVEY 07/28/06 1 1 D-1 07 11216309 INJECTION PROFILE 07/12/06 1 1 D-130 11249928 INJECTION PROFILE 07/09/06 1 31-03 11213788 PROD PROFILE W/DEFT 07/26/06 1 1Y-05 11216310 LDL 07/27/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Schlumberger NO. 3604 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth EGEtVED /' C\ ¿ 1 ~2GG:5 i\J:;ìi \c0 .':;';::~'/èl cn "i Gas Cçns. C~}ffiW:5B;or :L\{~{:hOf~g8 h.. ~~\ 0\1 2. 9 LD05 Field: S(;ANNE~ N c Kuparuk Well Job # Log Description Date BL 2C-05 11072930 INJECTION PROFILE 11/02/05 1 2Z-09 11057062 INJECTION PROFILE 11/03/05 1 20-09 11141218 LEAK DETECTION LOG 11/04/05 1 3F-03 11141219 INJECTION PROFILE 11/05/05 1 3F-01 11057064 PRODUCTION PROFILE 11/05/05 1 3F-15 11057065 INJECTION PROFILE 11/07/05 1 1 F-03A 11141222 LEAK DETECTION LOG 11/08/05 1 1G-17 11141221 PRODUCTION PROFILE 11/07/05 1 1J-164 N/A USIT 11/12/05 3G-25X 11141229 SBHP SURVEY "1. (.-/~tA 11/16/05 1 1 Q-20A 11144038 SBHP SURVEY 11/17/05 1 Color 1 tf\ ~ ì¡I¡.".tII¡o·¡::; SIGNED: ('~C~(1ri:r'0., 1.-- DATE: I (7 .- ~- rT J Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 11/18/05 CD -/ ì53-0CP¡ U¡· ¡Ó5-- \3G L'lC ;~A- \ò3 j ú3 -,;ì.;ìl U'1 r: ÌSS-2J5 '55 -c~'1¿' Uì C Iq~~ 090 i <1 C¡ -Of,¡;:J.. ~D5- 14+- ¡ C¡ (..p - i '60 /Cj5-15/¿. .~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 85 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 2538' FNL, 8' FEL, Sec. 23, T12N, R8E, UM (asp's 498370, 5988562) 3G-25X At top of productive interval 9. Permit number / approval number 1327' FSL, 1692' FEL, Sec. 14, T12N, R8E, UM (asp'$ 496684, 5992427) 196-136 At effective depth 10. APl number 50-103-20246 At total depth 11. Field / Pool 1573' FSL, 1785' FEL, Sec. 14, T12N, R8E, UM (asp's 496592, 5992673) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7675 feet Plugs (measured) Tagged PBTD (9/12/00) @ 7355' MD. true vertical 6035 feet Effective depth: measured 7355 feet Junk (measured) true vertical 5798 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 123 Sx AS I 121' 121' SURFACE 3715' 7-5/8" 910 Sx AS III, 360 Sx G 3800' 3064' PRODUCTION 7112' 5-1/2" 179 Sx Class G 7197' 5677' PRODUCTION 470' 4-1/2 ............ 7667' 6029' RF_.CE VED Perforation depth: measured 7308 - 7320'; 7328 - 7336'; 7348 - 7368' D, qAR 2, ? 200I true vertical 5762 - 5771'; 5777 - 5783'; 5792 - 5807' Alaska Oil & Gas Cons. Commission Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80, Tubing @ 7218' MD. Anchorage Packers & SSSV (type&measured depth) No Packer.~,}(~'"" F-,~ i ~,::., i' Camco DS Nipple w/2.812" No Go Profile @ 501' MD. .-.~'~ i [ ~ i ~ '~! ,,_'Lti 13. Stimulation or cement squeeze summary ' ~ "" "'''~ Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 541 385 219 - 167 Subsequent to operation 500 257 186 - 188 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ___X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. TiIle: Date -- -- ·// Signed ~.~4%_ Prepared by Jol~n Pelrce 265-6471 ~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 3G-25X PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 9/10/00: RIH & tagged PBTD at 7318' MD. 9/12/00: MIRU & PT equipment. RIH w/perforating guns & shot 12' of perforations in the 'C4' sand as follows: Added perforations: 7308 - 7320' MD Used 2-1/8" Enerjet carrier & shot the perfs at 6 spf at 180 degree phasing. POOH w/guns. RD. Returned the well to production & obtained a valid well test. ON OR BEFORE Well Compliance Report File on Left side of folder 196-136-0 KUPA~IJK RIV UNIT 3G-25X 50- 103-20246-00 ARCO MD 07675 TVD 06032 C~ompletion Date: -6/1/98 Completed Status: 1-OIL Current: Name Interval Sent Received T/C/D D 8476 ~ SPERRY M?T/GR/EWR4 OH 7/22/98 7/22/98 L CBT ~FINAL 1410-3524 ~,~-*~ ¢',-5 ch 5 10/3/96 10/7/96 L CMT ADVISOR II~" BL(C) 50-3350 ~/'~4/~' CH 5 2/4/98 2/4/98 L DGR/EWR4-MD qel~qAL 3547-7675 OH 7/22/98 7/22/98 L DGR/EWR4-TVD L STAT PRES SRVY L USIT R SRVY CALC R SRVY CALC ~_,F.}NAL 2878-6032 ~[~' 7200-7617 ~/~//g ~ ~ - _~L(, ,~~ '-Fllq~AL BL(C)0-3340 t/~/~ 3722.27-7675. R SRVY ~T /~Y 3731.27-7675. Daily Well Ops ~fi' f/~}" &~/~ Was the well co~w ..... OH 7/22/98 7/22/98 CH 5 8/3/98 8/6/98 CH 5 5/6/99 5/19/99 OH 6/30/98 7/1/98 OH 6/30/98 7/1/98 OH 6/26/98 7/1/98 Are Dry Ditch Samples Required? yes d'n~0~ And Received? yes._._no Analysis.De~_c_rJption~Received? yes no --.~aengl~et4t--~ Comments: Tuesday, May 30, 2000 Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate X Pull tubing _ Alter casing _ Plugging _ Perforate _ Repair well _ Other _ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 2538' FNL, 8' FEL, Sec 23, T12N, R8E, UM At top of productive interval: 1327' FSL, 1692' FEL, Sec 14, T18N, R8E, UM At effective depth: 1546' FSL, 1775' FEL, Sec 14, T18N, R8E, UM At total depth: 1573' FSL, 1785' FEL, Sec 14, T12N, R8E, UM 5. Type of Well: Development X_. Exploratory Stratagrapic Serv ce 6. Datum of elavation (DF or KB feet): 85' RKE 7. Unit or Property: Kuparuk River Unit 8. Well number: 3G-25X 9. Permit number/approval number: 96-136 & 398-017 10. APl number: 50-103-20246-00 11. Field/Pool: Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured true vertical 7675 feet Plugs (measured) None 6035 feet Effective Deptl measured true vertical 7633 feet Junk (measured) None 6004 feet Casing Conductor Surface Production Production Liner Length Size Cemented 80' 16" 123 Sx AS I 3773' 7-5/8" 860 Sx AS Ill & 360 Sx Class G & 50 Sx AS III Top Job 7170' 5-1/2" 179 Sx Class G 470' 4-1/2" (included above) Measured depth 121' 3800' 7197' 7197 '-7667 True vertical depth 121' 3064' 5677' 5677'-6029 Perforation Depth measured 7328'-7336';7348'-7368 true vertical 5777'-5783';5792'-5807' Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, L-80 @ 7218' Packers and SSSV (type and measured depth) Packer: None; SSSV: None - Camco DS Nipple @ 501' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 6/8/98. Intervals treated (measured) 7328 '-7336'; 7348'-7368 Treatment description including volumes used and final pressure Pumped 146,054 lbs of 16/20 & 12/18 ceramic proppant into formation, fp was 5589 psi, 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 750 Subsequent to operation 1614 2051 271 1400 188 15. Attachments MITform Copies of Logs and Surveys run _ Dally Report of Well Operations _~X 16. Status of well classification as: Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~1~,~]~1 ]~'-~ ~1 Title'. Production Engineering Supervisor Date "" " l/l /t/d Form10-404 Re~6~1~/88 SUBMIT IN DUPLICATE Alaska, Inc. '(UPARUK RIVER UNIT ~, ~LL SERVICE REPORT 3G-25X(4-1)) WELL JOB SCOPE JOB NUMBER 3G-25X FRAC, FRAC SUPPORT 0605981834.1 UNIT NUMBER DATE 06/08/98 DAY 2 FIELD ESTIMATE DALLY WORK FRACTURE STIMULATE A SAND OPERATION COMPLETE I SUCCESSFUL I KEY PERSON ~ Yes O No ~_~ Yes O No DS-YOKUM AFC# ICC# I DAILY COST AOCUM COST AK8589 230DS36G G $112,714 $125,353 InitialTbg IFinalTbg IlnitiallA IFinallA IlnitialOA IFinalOA ITTLSize 880PSII 500PSII 0PSI 500PSI 570PSII 570PSll 0.000 " SUPERVISOR JORDAN Signed Min ID I Depth 0.000" I 0 FT DALLY SUMMARY A SAND FRACTURE SCREENED OUT EARLY WITH 10 PPA PROPPANT AT THE PERFS. MAX TREATING PRESSURE 7566 PSI. 146,054 LBS PROPPANT PLACED IN FORMATION WITH 18,955 LBS PROP LEFT IN TUBING. [Frac-Refrac] TIME LOG ENTRY 06:00 MIRU DS FRAC UNIT - YOAKUM; LRS; APC. TGSM, 15 ON LOCATION. PT TO 10,020 PSI OK. 08:00 PUMP BREAKDOWN / CONDITIONING STAGES ACCORDING TO PROCEDURE. MAX PRESSURE 5589 PSI. STEPDOWN TEST AT SHUTDOWN. OBTAIN ISIP 1886 PSI. PULSES DURING PRESSURE DECLINE. 09:20 PUMP DATAFRAC AND SHUTDOWN. MAX PRESSURE 4843 PSI. OBTAIN ISIP 2019 PSI. ADJUST PAD. 10:30 PUMP FRAC ACCORDING TO PROCEDURE TO 10 PPA FLAT STAGE. A SAND FRAC SCREENED OUT EARLY WI 9.7 PPA AT PERFS. 146,054 LBS PROPPANT PLACED IN FORMATION WITH 18,955 LBS LEFT IN PIPE. MAX TREATING PRESSURE 7566 PSI. 13:30 RDMO DS FRAC UNIT. SERVICE COMPANY- SERVICE DAILY COST ACCUM TOTAL $o.oo $o.oo APC $5,000.00 $5,350.00 CAMCO $0.00 $0.00 DOWELL $104,714.00 $104,714.00 HALLIBURTON $0.00 $446.00 LITTLE RED $3,000.00 i $3,000.00 SCHLUMBERGER $0.00 $11,843.00 TOTAL FIELD ESTIMATE $112,714.00 $125,353.00 5/6/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 12557 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia Color CD-R Print 1D-10 3~- c~-~' 98193 REPROCESSEDDSl 980410 1 i 1 1D-111 CBL 990415 1 1 1D-114 CBL 990421 I 1 1 D-132 WFL W/RST 990416 1 1 2B-02 i PROD. PROFILE 990423 1 1 3N-18 I PROD. PROFILE 990425 1 1 3G-25X 99200 USIT 980107 1 3H-11 99201 USIT 990428 1 SIGNED.(~~~'J~ RECEIVED Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ~A~/ '1 r,.'~ i999 Alaska Oil & Gas Cons. (:;ommi~sio~ Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 25, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3G-25X (Permit No. 96-136 & 398-017) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3G-25X. If there are any questions, please call 265-1319. Sincerely, Mark A. Chambers Drilling Engineer Kupamk Drill Site Development MAC/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-136 & 398-017 ~.! 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20246 4 Location of well at surface i'~ ,, ¥--';~---:"~/,-:~.':"~ 9 Unit or Lease Name . ~.~;,~ ~i! ~.,'~'-' 2538' FNL, 8' FEL, Sec. 23, T12N, R8E, UM ;,, ~/;.'~[~ ~O~o '~ ~ Kuparuk River Unit At Top Producing Interval ......I;~i-!,1~~ ~~ ~ .. 10 Well Number 1327' FSL, 1692' FEL, Sec 14, T12N, R8E, UM i~ ~1~ ~ ~:?~,_~~~_ ~ 3G-25X ................. ~!' 11 Field and Pool At Total Depth ?~:.: ~ ....... ..--~- 1573' FSL, 1785' FEL, Sec. 14, T12N, R8E, UM ' ~ ........ ~....f~'ii.~ ~..~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Kuparuk River Oil Pool Ri9 RKB 85', Pad 53' ADL 25547 ALK 2561 12 Date06.Aug.96Spudded 13 29-May-98Date T.D. Reached 14 01Date-Jun-98Comp', Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 NO.lOf Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set I 21 Thickness of permafrost I 7675' MD & 6032' TVD 7633' MD & 6002' TVD YES xL~ NO U NA feet MD 1650' APPROX 22 Type Electdc or Other Logs Run GR/CCL/CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 151.53# X-65 SURF. 121' 24' 123 sx AS I 7.625' 29.7# L-80 SURF. 3800' 9.875' 860 sx AS III, 360 sx Class G 50 sx AS III top job 5.5' 15.5# L-80 SURF. 7197' 6.75" 179 sx Class G 4.5" 12.7# L-80 7197' 7667' 6.75' (included above) 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5' 7218' 7328'-7336' MD 5775'-5781' TVD 7348'-7368' MD 5790'-5805' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7328'-7336', 7348'-7368' 146,054# proppant in formation; 18955# proppant in tubing Date First Production JMethod of Operation (Flowing, gas lift, etc.) ~,/ ~ \ I ~ i I "~ i % L-._ 6/11/98I Gas Lift Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBl. CHQKE SIZE I GAS-OIL RATIO 6/16/9E 18 TEST PERIOI: 2383 2454 147 136I 1202 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 228 '1397 24-HOUR RATE: 290] 3487 196 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-'1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7307' 5761' Bottom Kuparuk C 7321' 5772' Top KuparukA II 7321' 5772' Bottom Kuparuk A 7321' 5772' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Surveys 32. I hereby cen'ify that the foregoing is true and correct to the best of my knowledge. '""' " Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: if no cores taken, indicate "none". Form 10-407 Date: 6/18/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3G-25X RIG:NORDIC WELL_ID: AK8589 TYPE: AFC: AK8589 AFC EST/UL:$ 1175M/ 1410M STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:08/06/96 START COMP: FINAL: WI: 55% SECURITY:0 API NUMBER: 50-103-20244-00 07/19/96 (D1) TD: 121' (121) SUPV:DCL 07/20/96 (D2) TD: 121'( SUPV:DCL o) 07/21/96 (D3) TD: 121'( SUPV:DCL o) 07/22/96 (D4) TD: 121'( 0) SUPV:DCL 07/23/96 (D5) TD: 1190'(1069) SUPV:GR 07/24/96 (D6) TD: 3725' (2535) SUPV:GR 07/25/96 (D7) TD: 3725'( SUPV:GR o) 07/26/96 (DS) TD: 3725' ( 0) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVE RIG MATS Move drill and utility modules. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVE RIG Continue to move rig modules. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PREP TO MOVE BALL MILL Move mats around drill module w/rollagons while moving ahead w/module. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 LOAD PIPE SHED Move CPM from 3F pad to 3G. Move drill module over hole. MW: 9.2 VISC: 58 PV/YP: 18/20 APIWL: 10.6 DRILLING 9-7/8" HOLE 8 2549' Nipple up diverter. Pre-tour safety meeting. Function test diverter and accumulator. Drill 9-7/8" hole w/MWD from 121' to 1190' MW: 10.1 VISC: 52 PV/YP: 18/22 APIWL: 8.8 MONITOR FLOW Finished drilling surface hole. Trip out. Run casing. Lost circulation at 2500' Run to bottom. Circ for cement job. MW: 10.0 VISC: 42 PV/YP: 8/15 APIWL: 12.4 RUN CBT Cement surface casing. Monitor annular flowback. Annular flow stopped. Ran cement bond log. MW: 10.0 VISC: 46 PV/YP: 8/17 APIWL: 8.8 CIRC THRU PERFS @ 3065' SUPV:GR/RLM 07/27/96 (Dg) TD: 3725'( SUPV:GR/RLM o) 07/28/96 (D10) TD: 3725'( 0) SUPV:GR/RLM 07/29/96 (Dll) TD: 3725' ( 0) SUPV: 08/06/96 (D12) TD: 930'( 0) SUPV: 08/07/96 (D13) TD: 3812' (2882) SUPV:DCL 08/08/96 (D14) TD: 3812' ( 0) SUPV:DCL 08/09/96 (D15) TD: 3812'( 0) SUPV:DCL Monitor well. RIH w/bit and HWDP and drill pipe to 3495' Circulate and change out water to mud. MW: 10.0 VISC: 43 PV/YP: 18/16 NIPPLE UP 13-5/8" BOPE APIWL: 8.4 Held safety meeting. Run in with drillable bridge plug and set at 3070'. Test 7-5/8" casing to 2000 psi for 10 minutes. No bleed off. RIH with perf gun. Shot 9 holes from 3067-3065' Circulate through perfs. Had 59 bbls heavily contaminated returns to surface. Monitor well. Returned all fluid loss. RIH with drillable cement retainer and set at 3008'. Cement casing and squeeze perfs. MW: 10.0 VISC: 42 PV/YP: 15/15 WAIT ON RETAINER APIWL: 9.0 Perform top job on 16" x 7-5/8" annulus. Test BOPE to 300/3000 psi. Drill out cement retainer at 3008' Drill hard cement from 3008 to 3070' MW: 10.0 VISC: 42 PV/YP: 15/15 RIG RELEASED APIWL: 9.0 Attempt to obtain test on squeeze perfs from 3065' to 3067'. RIH with cement retainer and set at 3040' Pressure test casing and retainer to 2000 psi for 10 minutes. No bleed off. ND BOPE. Make up tubing head adaptor and master valve. Rig released at 1930 hrs. 7/29/96. MW: 9.4 VISC: 68 PV/YP: 21/19 DRILLING AT 2350' APIWL: 8.8 Move rig from 3G-03 to 3G-25X. Accept rig at 13:00 hrs. 8/6/96. Nipple up diverter. Function test. Drilling from 121' to 930' MW: 10.0 VISC: 57 PV/YP: 25/24 RIH W/7-5/8" CSG APIWL: 5.8 Drilling from 930' to 3812' Hole tight at 3116' while POOH. Hole packing off. POH. Hole tight at 3029' Unable to rotate pipe or work pipe down hole. Pump out of hole to 1646' Pump out to HWDP. RIH to TD. No problems. No fill. Circ hi vis sweep. Pump pill. STAND BY MW: 0.0 VISC: 52 PV/YP: 22/18 APIWL: 5.6 Run 7-5/8" casing. Land casing. Pump cement. Lost circ. when switch to tail cement. 1 hr. after cement in place well started flowing out annulus. Well is static. MW: 0.0 VISC: 0 PV/YP: 0/ 0 STAND BY - RIG MAINTENANCE APIWL: 0.0 08/10/96 (D16) TD: 3812' ( 0) SUPV: DCL 08/11/96 (D17) TD: 3812'( 0) SUPV:DCL 08/12/96 (D18) TD: 3812'( 0) SUPV:DCL 08/13/96 (D19) TD: 3812' ( 0) SUPV:DCL 05/24/98 (D20) TD: 3812'( 0) SUPV:MCH 05/25/98 (D21) TD: 3980'(168) SUPV:MCH 05/26/98 (D22) TD: 5301' (1321) SUPV:DLW 05/27/98 (D23) TD: 6374'(1073) SUPV:DLW 05/28/98 (D24) TD: 7196' (822) SUPV:DLW Run CBL from 3540' to 600'. Rerun CBL log. Log indicated top of lead cement at 1676' Performed top job. NU BOPE. RIH to open ended to 2000' Circ to prevent freezing. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 STAND BY - RIG MAINTENANCE Stand by. Rig maintenance. Break circ every 4 hrs. to prevent freeze up. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 STAND BY - RIG MAINTENANCE Stand by. Rig maintenance. Break circ every 4 hrs. to prevent freeze up. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 REMOVE CSG F/PIPE SHED Stand by. Rig maintenance. Break circ every 4 hrs. to prevent freeze up. Displace well at 2000' w/diesel. ND BOPE. NU well head and master valve. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Held pre-job safety meeting. Release rig at 0700 hrs. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 POH Move rig from 3G-21A to 3G-25X. Accept rig @ 1300 hrs. 5/24/98. MWD malfunction, work on. MW: 9.3 VISC: 42 PV/YP: 10/10 APIWL: 7.6 Drilling & surveys Set storm packer. Test BOPE 250/3000#. Drill out cement from 3547'-3659' Perform LOT = 12.0#. Drilling and surveys from 3823' to 3980' MW: 9.5 VISC: 42 PV/YP: 11/12 APIWL: 6.0 Drilling ahead @ 5710' Directional drill 6.75" hole from 3980' to 4828' Ream and wash to bottom @ 4828' no fill. Drill from 4828' to 5301' MW: 9.5 VISC: 44 PV/YP: 16/ 8 APIWL: 6.2 Drilling ahead @ 6690' Directional drill 6.75" hole from 5301' to 6374' MW: 11.5 VISC: 48 PV/YP: 19/21 APIWL: 4.2 Drill @ 7324' Continue drilling 6.75" hole from 6374' to 7000'. Started adding 10 ppb barofiber and raise mud weight to 10 ppg 05/29/98 (D25) TD: 7675' (479) SUPV:DLW 05/30/98 (D26) TD: 7675' ( 0) SUPV:DLW 05/31/98 (D27) TD: 7675'( 0) SUPV:DLW 06/01/98 (D28) TD: 7675' ( 0) SUPV:DLW 06/02/98 (D29) TD: 7675' ( 0) SUPV:DLW while drilling to 7164' Perform FIT to 11.5 ppg EMW. Continue drilling ahead from 7164' to 7196' MW: 11.7 VISC: 56 PV/YP: 22/23 R/U T/5.5" X 4.5" PRODUCTION CSG. APIWL: 4.0 DRILL F/7196 T/7675' TD. CIRC AND COND HOLE FOR 5.5" X 4.5" TAPERED PRODUCTION CSG. DROP SINGLE SHOT SURVEY. MW: 11.7 VISC: 50 PV/YP: 22/20 APIWL: 4.1 CEMENTED CSG, NO RETURNS. N/D BOPs TO SET PIPE SLIPS. CONTINUE RUNNING 5.5" CSG T/6590' BROKE POWER TONGS UNABLE TO REPAIR. 170 JOINTS IN HOLE. MW: 8.5 VISC: 0 PV/YP: 0/ 0 SPACE OUT 4.5" PRODUCTION TBG. APIWL: 0o0 CASING AND CEMENTING. INSTALL PACK OFF AND TBG SPOOL TEST PACK OFF TO 3000 PSI. N/U BOPE TEST FLANGE TO 3500 PSI. OK. BEGIN TO RUN COMPLETION. MW: 0.0 VISC: 0 PV/YP: 0/ 0 Rig released @ 0430 hrs. 6/2/98 APIWL: 0.0 Finish running 3.5" completion. Test 7-5/8" casing to 3500 psi for 30 min, OK. N/D BOPE. N/U tree. MW: 0.0 VISC: 0 PV/YP: 0/ 0 Released rig @ 0430 6/2/98 APIWL: 0.0 Move to 3K-31 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ,, K1(3G-25X(W4-6)) WELL JOB SCOPE JOB NU'MBER " 3G-25X FRAC, FRAC SUPPORT 0605981834.1 DATE DAILY WORK UNIT NUMBER 06/07/98 FRAC SUPPORT - PERFORATE A3 & A2 SANDS 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I NOI YES SWS-BARTZ JONES AFC# CC# Signed AK8589 230DS36GG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 0 PSI 750 PSI 0 PSI 0 PSII 20 PSI 20 PSI DALLY SUMMARY SWS RAN GR/CCL LOG, PERFED 7328' TO 7336' & 7348' TO 7368'. RAN A SBHP SURVEY PRESS = 3321 PSI @ 7348'. TAGGED FILL @ 7617' RKB. TIME LOG ENTRY 10:00 SWS MIRU, HELD TGSM. MU TOOLS & PT LUB TO 3000#. 11:00 MIH W/1 11/16" CPLT, GR, CCL. LOGGED FROM 7617' TO 7030' & CORR TO SPERRY-SUN 5-30-98. TAGGED FILL @ 7617' RKB. 11:45 POH & LD TOOLS. SECURED RADIO SILENCE. 12:45 MU 2.5" HC, 4 SPF, BH, 180 DEG PHASED, 90 DEG ORIENT. PT LUB TO 3000#. 13:30 MIH W/PERF GUN, CORR TO SWS LOG 6-7-98. PRESS LINER TO 1800 PSI & PERF FROM 7348' TO 7368'. 14:45 POH & LD GUNS. ALL SHOTS FIRED. 16:00 MU 10' 2.5" HC GUN AS ABOVE W/TOP 2' BLANK. PT LUB TO 3000#. 16:30 MIH W/GUN, CORR TO ABOVE LOG & PERF FROM 7328' TO 7336'. 17:20 POH & LD GUN, ALL SHOTS FIRED. 18:15 MU CPLT, PT LUB TO 3000#. MIH TO 7348' & LOG SBHP FOR 30 MIN, PRESS - 3321 PSI. 20:00 POH & LD TOOLS. 21:00 RIG DOWN. 21:45 RELEASE SWS. I ARCO Alaska. Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~, K1(3G-25X(W4-6)) WELL JOB SCOPE JOB NL~MBER " 3G-25X FRAC, FRAC SUPPORT 0605981834.1 DATE DAILY WORK UNIT NUMBER 06/08/98 FRACTURE STIMULATE A SAND DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 YESI YES DS-YO KU M JO R DAN FIELD AFC# Signed ESTIMATE Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann J Final Outer Ann 880 PSI 500 PSI 0 PSI 500 PSI 570 PSII 570 PSI DAILY SUMMARY A SAND FRACTURE SCREENED OUT EARLY WITH 10 PPA PROPPANT AT THE PERFS. MAX TREATING PRESSURE 7566 PSI. I 146,054 LBS PROPPANT PLACED IN FORMATION WITH 18,955 LBS PROP LEFT IN TUBING. I TIME LOG ENTRY 06:00 MIRU DS FRAC UNIT- YOAKUM; LRS; APC. TGSM, 15 ON LOCATION.PT TO 10,020 PSI OK. 08:00 PUMP BREAKDOWN / CONDITIONING STAGES ACCORDING TO PROCEDURE. MAX PRESSURE 5589 PSI. STEPDOWN TEST AT SHUTDOWN. OBTAIN ISIP 1886 PSI. PULSES DURING PRESSURE DECLINE. 09:20 PUMP DATAFRAC AND SHUTDOWN. MAX PRESSURE 4843 PSI. OBTAIN ISIP 2019 PSI. ADJUST PAD. 10:30 PUMP FRAC ACCORDING TO PROCEDURE TO 10 PPA FLAT STAGE. A SAND FRAC SCREENED OUT EARLY WITH 9.7 PPA AT PERFS. 146,054 LBS PROPPANT PLACED IN FORMATION WITH 18,955 LBS LEFT IN PIPE. MAX TREATING PRESSURE 7566 PSI. 13:30 RDMO DS FRAC UNIT. I SURVEY CALCULATION AND FIELD WORKSHEET Jo~ No. 0450-97232 Sidetrack No.~ Page 1 of 2 · '-[ll~5-' I =[-.-! Company ARCO ALASKA, INC. Rig Contractor & No. NORDIC/2 Field KUPARUK RIVER UNIT Well Name & No. PAD 3G/25X Survey Section Name 6 3/4 DRILL OUT BHI Rep. A.J. HARSTAD WELL D~TA Target TVD 5765.00 {ft) Target Coord. N/S 3871.53 Slot Coord. N/S -2537.71 Grid Correction 0.000 .Depth~ Measured From:RKi~ MSL~ SS[- Target Description 150' Radius Target Coord. E/W -1678.83 Slot Coord. E/W -5.84 Magn. Declination 27.420 Calculation MethodMinimum Curvature Target Direction 338.78 (dd) Build\Walk\DL p{ll[10£t[~ 30mi-'] 10mi--1 Yert. Sec. Azim. 336.56 Magn. to Map Corr. 27.420 Map North to:TRUE NORTH SURVEY DATA ~_ Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical Date Tool Build (+) Right (+) Comment Type D~t~h Angle Direction Length TVD Section m(+0ft~ S(-) E(+tf/)W(" (pc?L100 't)Drop (-) Left (-) .__ (rid) (dd) (fi) (fL) __ MWD 3722.27 43.28 336.52 3004.85 1930.71 1738.22 -844.51 Tie In Point 25-MAY-91 MWDI 3874.40 43.00 339.08 152.13 3115.87 2034.70 1834.51 -883.81 1.17 -0.18 1.68 26-MAY-91 MWD 3970.52 42.82 339.85 96.12 3186.27 2100.05 1895.79 -.906.77 0.58 -0.19 0.80 26-MAY-91 MWD 4065.44 40.72 337.65 94.92 3257.06 2163.22 1954.72 -929.66 2.70 -2.21 -2.32 26~MAY-9',g MWD 4160.04 40.60 337.63 94.60 3328.83 2224.85 2011.72 -953.11 0.13 -0.13 -0.02 26-MAY-9:g MWD 4255.50 40.24 336.82 95.46 3401.50 2286.74 2068.79 -977.07 0.67 -0.38 -0.85 26-MAY-9 MWD 4351.65 40.42 335.61 96.15 3474.80 2348.96 2125.73 -1002.16 0.84 0.19 -1.26 26-MAY-9 MWD 4446.70 40.79 334.48 95.05 3546.96 2410.80 2181.81 -1028.27 0.87 0.39 -1.19 /m~ I'~ I 26-MAY-9 MWD 4540.53 40.58 333.97 93.83 3618.12 2471.91 2236.90 - 1054.86 0.42 -0.22 -0.54 26-MAY-91 MWD 4634.05 39.93 336.83 93.52 3689.49 2532.32 2291.83 - 1080.02 2.09 -0.70 3.06 26-MAY-9',t MWD 4727.92 40.24 335.85 93.87 3761.31 2592.76 2347.19 -1104.28 0.75 0.33 -1.04 26-MAY-9:I MWD 4822.75 38.91 338.87 94.83 3834.41 2653.16 2402.93 -1127.55 2.47 -1.40 3.18 26-MAY-9 MWD 4916.56 39.08 339.68 93.81 3907.32 2712.12 2458.14 -1148.44 0.57 0.18 0.86 26-MAY-91 MWD~ 5011.94 39.83 338.85 95.38 3980.97 2772.67 2514.82 -1169.90 0.96 0.79 -0.87 26-MAY-91~ MWD 5106.15 38.79 340.55 94.21 4053.86 2832.25 2570.79 -1190.61 1.59 -1.10 1.80 26-MAY-9',~ MWD 5201.08 39.23 340.26 94.93 4127.62 2891.87 2627.08 -1210.65 0.50 0.46 -0.31 27-MAY-9:5 MWD 5295.48 39.76 340.38 94.40 4200.47 2951.78 2683.61 - 1230.87 0.57 0.56 0.13 27-MAY-9: MWD 5389.70 40.43 340.82 94.22 4272.55 3012.31 2740.85 -1251.03 0.77 : 0.71 0.47 27-MAY-9 MWD 5485.21 40.60 340.83 95.51 4345.16 3074.19 2799.46 - 1271.41 0.18 0.18 0.01 27-MAY-9 MWD 5579.21 40.98 340.82 94.00 4416.33 3135.43 2857.46 - 1291.58 0.40 0.40 -0.01 27-MAY-9 MWD 5672.78 41.29 339.94 93.57 4486.80 3196.85 2915.44 -1312.25 0.70 0.33 -0.94 27-MAY-911 MWD 5768.24 38.72 338.19 95.46 4559.92 3258.14 2972.75 -1334.15 2.94 -2.69 -1.83 27-MAY-9:i MWD 5863.29 38.63 338.68 95.05 4634.13 3317.50 3027.99 -1355.98 0.34 -0.09 0.52 27-MAY-9'~ MWD 5957.19 38.73 338.83 93.90 4707.43 3376.15 3082.69 - 1377.24 0.15 0.11 0.16 I I ' '" SURVEY CALCULATION AND FIELD WORKSHEET No. 0450-97232 Sidetrack No. Page I-'|~[~-1~:~ Company ARCO ALASKA, INC. Rig Contractor & No. NORDIC/ 2 Field KUPARUK RIVER UNIT Well Name & No. PAD 3G/25X Survey Section Name 6 3/4 DRILL OUT BHI Rep. A.J. HARSTAD I~ WELL DATA Target TVD 5765.00 (ft) Target Coord. N/S 3871.53 Slot Coord. N/S -2537.71 Grid Correction 0.000 Depths Measured From:RKl~ MSL~ SS~ Target Description 150' Radius Target Coord. E/W -1678.83 Slot Coord. E/W -5.84 Magn. Declination 27.420 Calculation McthodMinimum Curvature Target Direction 338.78 (dd) Build\Walk\DL pel~0ft[~ 30m[-] 10m~ Vert. Sec. Azim. 336.56 Magn. to Map Corr. 27.420 Map North to:TRUE NORTH SURVEY DATA , Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Depth (dd) (ft) Left Type (ft) /~lgdl~ Direction L¢~l~lh TVD Section N(+/ft~ $(-) E(+~ft/)W(- (pc?L100 :t)Drop (_) (_) 27-MAY-91 MWD 6054.14 38.73 338.34 96.95 4783.06 3436.77 3139.16 - 1399.39 0.32 0.00 -0.51 r 27--MAY'91 MWD' 6149.74 38.80 339.08 95.60 4857.60 3496.58 3194.93 '1421.12 0.49 0.07 0.77 27--MAY'91 MWD 6243.42 39.00 337.84 93.68 4930.51 3555.37 3249.65 '1442.72 0.86 0.21 '1.32 28--MAY--91 MWD 6337.28 38.72 338.56 93.86 5003.60 3614.24 3304.33 '1464.59 0.57 --0.30 0.77 28--MAY'9: MWD 6432.97 38.16 338.40 95.69 5078.55 3673.70 3359.67 '1486.41 0.59 '0.59 '0.17 28--MAY--9:~ MWD 6527.89 37.54 338.40 94.92 5153.50 3731.91 3413.82 '1507.85 0.65 '0.65 0.00 28--MAY'9 MWD 6622.58 36.73 337.33 94.69 5228.99 3789.06 3466.77 '1529.39 1.09 --0.86 '1.13 28--MAY'9 MWD 6718.76 37.93 337.43 96.18 5305.47 3847.37 3520.61 '1551.82 1.25 1.25 0.10 28--MAY'9 MWD 6812.52 40.18 337.99 93.76 5378.27 3906.43 3575.27 --1574.22 2.43 2.40 0.60 28--MAY'91 MWD 6906.72 40.80 337.68 94.20 5449.91 3967.59 3631.91 '1597.30 0.69 0.66 '0.33 28--MAY--9"~ MWD 7002.55 39.13 339.81 95.83 5523.36 4029.08 3689.26 --1619.63 2.25 --1.74 2.22 ,. 28-MAY-9:~ MWD 7097.27 38.26 340.53 94.72 5597.29 4088.18 3744.96 -1639.72 1.03 -0.92 0.76 28-MAY-9 ~ MWD 7192.99 39.50 339.09 95.72 5671.80 4148.16 3801.34 - 1660.46 1.60 1.30 - 1.50 28-MAY-9 MWD 7288.11 40.45 339.30 95.12 5744.69 4209.20 3858.46 -1682.16 1.01 1.00 0.22 28-MAY-91~ MWD 7383.08 41.38 338.60 94.97 5816.46 4271.34 3916.51 - 1704.50 1.09 0.98 -0.74 28-MAY-91~ MWD 7478.08 42.04 338.77 95.00 5887.38 4334.50 3975.40 -1727.48 0.70 0.69 0.18 28-MAY-91~ MWD 7608.39 42.91 339.90 130.31 5983.49 4422.40 4057.73 -1758.53 0.89 0.67 0.87 28-MAY-9',] MWD 7675.00 42.91 339.90 66.61 6032.28 4467.67 4100.32 -1774.12 0.00 0.00 0.00 PROJECTION-NO SURVEY , INTIK;t SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-79206 Company ARCO ALASKA, INC, Rig Contractor & No. PARKER DRILMNG,CO - ~245. Well Name & No. PAD 3G/3G#25X Survey Section Name ANADRILL .... '" '"' ' ' "'""'~EL'LoATA "'" ' .... Sidetrack No. Page 1 Field KUPARUK RIVER UNIT BHI Pep, RO~¥ . Target TVD Target Description Date 06-AUG-96 06-AUG-96 06-AUG-96 06-AUG-96 06-AUG-96 06-AUG-96 06-AUG-96 06-AU0-98 07-AUG-96 07-AUG-98 07-AUG-96 07-AUG-96 07-AUG-98 07-AUG-96 07-AUG-98 07-AUG-98 07-AUG-98 ' 07-AUG-96 07-AUG-98 07-AUG-S6 07-AUG-96 07-AUG-96 Survey Depth 0.00 121.00 272.00 465.57 558.97 651.55 743.89 927.74 1020,18 i111.92 1202.15 1292.40 1383.78 1473.47 1,565.24 1654.09 1 ?49.64 1933.07 2116.53 2395.50 2668.91 2945.61 Target Coord. N/S Slot Cc)ord. N/S ~" ~,1 .I '~r' ' iiI I.J~ ~ BuiI~WalK\DL per: lO01tl~ 3Om[-} 10mE] Vert. Se~. Azim. SURVEY DATA Hole Course Vertical Direction Length 'i'VD Section (DD) p'r) (Fr) 0.00 0.08 0.00 0.00 121.00 121.00 0.00 309.00 151.00 271.98 2.09 327.00 91,00 362.92 5.13 345.63 102.57 465.04 14.15 326.36 93.40 557.37 26.14 337.89 92.58 648.44 44.75 335.61 92.44 828.65 85.47 332,03 91.41 916.43 110.89 332.12 92.44 1003.40 142.17 333.40 91.74 1087.58 178,59 333.35 90.23 1168.65 218.19 333.05 90.25 1248.65 259.97 332.43 91.38 1327.92' 305.39 332.24 89.59 1403,33 353.90 33.1.70 9'1,77 1477.76 407,55 331.88 68.85 1546.88 463.31 331.79 95.55 1618.06 527.00 3;34.~') 133.43 1747.87 656.54 3,34,51 183.46 1875.22 788,59 336.07 278.97 2069.57 988.65 332.64 273.41 2257.79 1186.93 331.79 276.70 2449.77 1386.09 -2538.00 Grid Correction 0,000 333,87 Magn. to Map .Corr. 27.630 Total Coordinate Build Rate Walk Rate N(+) / S(-) E(+) / W(-) Build (+) Right (+) (F-r) Ow) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 1.45 -1,79 1.16 3.82 -3.84 0,55 12.46 -6.72 5.64 18.16 25.17 -12.59 1.52 -20.63 39.92 -20,22 2.03 12.45 57.59 -27.69 1.43 -1.62 77.31 -36.48 1.85 43,84 100,08 -47.77 3.93 -3,92 127.73 -62.42 3.98 0.10 160.14 ' -79.07 3.87 1.40 195.53 -96.62 1.68 43.08 232.33 -115,66 1.55 43.33 ' 273.21 -136.48 '3.37 ' 43.68 316.19 -159.01 3.12 43.21 363.56 -184.25 3.57 43.59 412.74 -210.62 3.31 0.20 468.92 -240.70 3.06 -0.09 584.39 -299.44 1.80 1.32 703.45 -356.57 43.61 0.16 885.25 -440.21 0.26 0.56 1063.99 .-526.06 0.22 -1.25 1240.27 -618.92 43.54 -0.31 ~mculatlon Method MINIMUM CURVATURE Map North to: OTHER Comment TIE IN POINT 8'MACH 1 C-AKO-1.4deg. ****GYRO ****GYRO S/S**** ~' · -' ' SURVEY CALC,ULATION AND 'FIELD WORKSHE~ET Job.o. o~.~?~ S,d~track No. ,age · '. ti [,fl · I =(~1 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO. #245~ . .' Field KUPARUK RIVER UNIT .. Well Name & No. PAD 3G/3Gf25X Survey Section Name ANADRILL BHI Rep. ROBBY BARNARD. INTI~ ' ' ' L~ ' ' WEL ATA Target TVD (FT) Target Coord..N/S Slot Coord. N/S -2538.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W -8.00 Magn. DeclinatiOn 27.630 Calculation Method MINIMUM CURVATURE Target Direction (oo) Build\Walk~DL per: 100ff[~ 30m~ 10m0 Vert. Sec. Azim. 333.87 Magn. to Map Corr. 27.630 Map North to: OTHER I SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) i S(-i ..... E(+)/w(.) EX. Build (+) Right (+) 'Comment Type (Fr) (Do) (oo). (Fr) (FT) (Fr) 0=T) (Per 100 Fr) Drop (-) Left (-) , 07-AUG-96 MWD 3219.14 43.97 336.16 273.53 2644.42 1578121 1412.87 -703.29 1.23 -0.49 1.60 8'MACH lC-AKO-1.4deg. , ,. 07-AUG-96 IMWD 349~.~ 44.01 336.75 279.55 2845'55 1772.17 1590.86 -780.85 0.15 0.01 0.21 07-AUG-96 MWD 3731.27 43.28 336.52 232.58 3013~85 i932.50 1738.22 -844.51 0.32 -0.31 -0.10 , , , 07-AUG-96 MWD 3812.00 43.28 336.52 80.73 3072.62 1987.79 1798.99 -866.56 0.00 0.00 0.00 PROJ. TD*BHC= 1987.81 (~3,.q4.16deg.. , , , , , i ~mpany ARCO A~8~, INC. ,, Rig ~.tra~or & No. PARER ~R!~U~G.CO - ~. , Field Well Name & No PAD ~/3G~2~ Su.w, S~ion Name A.~DRILL ~HI Target 'rVD Target Description I Date 06-AUG-96 06-AUG-96 06-AUG-96 06-AUG-96 06-AUG-96 06-AUG-96 06-AUG.96 06-AUG-98 07-AUG-96 07-AUG-96 DT-AUG-96 37-AUG-96 37-AUG-98 )7.RUG-96 )7-AU<3-98 )7-AUG-98 )7-AUG-98 ~7-AUG-98 17-AUG-96 7-AUG-96 7-AUG-96 7-AUG-96 7-AUG-96 Survey Depth 0.00 121.00 272.00 465,57 558.97 651.55 743,89 927.74 1020.18 1111.92 1202.15 1292.40 1383.78. 1473.47 1565.24 1654.09 1749,64 1933.07 2116,53 23~5,50 2668.91 2945.61 Target Ooord. N/S Slot Coord. N/S :1.111.._1".' , , .. IiJL .1 ~ BMild~WalK\DL per: 103ft[~ 30mO lOmE] vert, Sec. Azim. " '" 'J ' " 'SURVEY' ' DATA Hole Course Vertical Oire~ion Length TVO Section 0,00 0,00 0.00 121.00 121.00 0.00 2.09 5.13 309.00 151.03 271.98 327.00 91.00 362.92 345.63 102.57 465.04 14.15 326.36 93.40 557.37 28.14 337.89 92.58 648.44 44.75 3,36.39 92.34 738.77 65.90 I Total Coordinate N(+) i S(-) E(+) / W(-) 0,00 0,00 0.00 0,00 1.45 -1,79 3.82 -3.84 12.46 -6.72 25.17 -12.59 335,61 92.44 828.65 85.47 77,31 332,03 91.41 916.43 110.89 100.08 3,32.12 92,44 1003.40 142.17 127.73 333.40 91.74 1087.58 178.59 160.14 333.~ g0.23 1168.65 218.19 195.53 333.05 90~5 1246.65 259.97 232.83 332.43 91.38 ' 1327.92' 305,39 ' 273.21 332,24 89.69 1403.33 353.90 316.19 a31.70 91.77 1477.76 407.55 363.56 331.68 68.85 1546.38 463.31 412.74 331 95.55 1616.06 527.00 468.92 334.22 165.3,3 1747.87 656.54 584.39 334.51 183,46 1875.22 788.59 703.45 336.07 278.97 206g.57 988,65 885,25 332.64 273.41 2257.79 1186.93 1063.99 276.70 2449.77 1386.09 1240.27 -36,48 -47,77 -62.42 · -7g.07 -96.82 -115.68 -136.46 -159.01 -184~5 -210.62 -240.70 -299.44 -356.57 -440.21 · -526.06 -618,92 Gdd Correction 0,000 Magn. to Map Corr. 27.630 I I Oal~ula~lon Method 'MINIMUM CURVATURE Map North to: OTHER Build Rate Build (+) Orap (-) 0.00 1.16 0;55 Walk Rate Right (+) Left (-) Comment TIEINPOINT 8'MACH 1G-AKCL1.4deg. ****GYROS/S**** ****GYROS/S**** 5,64 18,16 1.52 -20.63 2.03 12,45 1.43 -1,62 1,85 -0.64 3.93 -3,92 3,98 0,10 3,87 1.40 1.88 -0.06 1.55 -0.33 '3.37 · -0.68 3.12 -0.21 3.57 -0.59 3.31 0.20 3.06 -0,09 1.80 1.32 · 0.61 0,16 0.26 0.56 0.22 -1.25 -0.54 -0.31 SURVEY ,CALCULATION AND "FI.EL:D WO RKSH.EET JobNo. 0450.79206 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO - #245. '. .i ·, Well Name & No. PAD' 3C-.d3O~X Survey Section Name ANADRILL ' ' ' ' ' ' W L'ELDATA' ' Sidetrack No. ~ Page 2 of Field KUPARUK R~R UNil BHI Rep. ROBBY BARNARD. 2 Target TVD Target Description Target Direction Date 07.AUG.96 07-AUG-96 07-AUG-96 Survey 3219,14 3731.27 3812.00 · Target Coord..N/$ Slot Coord. N/S Target Coord. E/W Slot Coord. E/W Build~Walk~DL per: 100ft{~ 30m[:] 10m[::l Vert, Sec. Azim, SURVEY DATA Hole Course Vertical Direction Length TVD Section 3.36.16 273.53 2644.42 1578.21 336.75 279.55 2845.55 177Z.17 232.58. 3013~85 1932.50 336.52 80.73 3072.62 1987.79 -2538.00 Grid Correction 0,000 -8.00 Magn. Declination 27.630 333.87 Magn. to Map Corr. 27.630 Total Coordinate Build Rate Walk Rate N(+) / 81 E(+) / W(-) Build (+) Right (+) Drop (-) Left (-) 1412.87 -703.29 -0.49 1.60 1590.86 -780.85 0.01 0.21 1738.22 -844.51 -0.31 -0.10 1798.99 -866.56 0.00 0.00 Depths MeasuredFrom: RKBI~ MSLr'! SSI"! Caloulatien Method MINIMUM CURVATURE Map North to: OTHER ~Comment 8"MACH lC-AKO-1.4deg. ' PROJ. TD*BHC= 1987.81 (~kq34.16deg.. Kuparuk Unit Kuparuk 3G 3G-25X SURVEY REPORT 26 June, 1998 Your Ref: API-501032024600 Last Day of Survey 29-May-98 Job# AKMMS0236 KBE- 85.16' DRILLING C;ERVICEc; 'D RECEIVE- ,JUL 0 1 !9~8 /~Jaska Oil,& Gas Cons. Conmission Anchorage Survey Ref: svy28 Sperry-Sun Drilling Services Survey Report for 3G-25X Your Ref: AP1-501032024600 Kuparuk Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 3731.27 43.280 336.520 2922.12 3007.28 3791.00 43.280 336.520 2965.60 3050.76 3874.40 43.000 339.080 3026.46 3111.62 3970.52 42.820 339.850 3096.87 3182.03 4065.44 40.720 337.650 3167.66 3252.82 4160.04 40.600 337.630 3239.42 3324.58 4255.50 40.240 336.820 3312.10 3397.26 4351.65 40.420 335.610 3385.40 3470.56 4446.70 40.790 334.480 3457.56 3542.72 4540.53 40.580 333.970 3528.71 3613.87 4634.05 39.930 336.830 3600.09 3685.25 4727.92 40.240 335.850 3671.91 3757,07 4822.75 38.910 338.870 3745.01 3830.17 4916.56 39.080 339.680 3817.92 3903.08 5011.94 39.830 338.850 3891,56 3976.72 5106.15 38.790 340.550 3964.46 4049.62 5201.08 39.230 340.260 4038.22 4123.38 5295.48 39.760 340.380 4111.07 4196.23 5389.70 40.430 340.820 4183.14 4268.30 5485.21 40.600 340.830 4255.75 4340.91 5579.21 40.980 340.820 4326.92 4412.08 5672.78 41.290 339.940 4397.40 4482.56 5768.25 38.720 338.190 4470.52 4555.68 5863.29 38.630 338.680 4544.72 4629.88 5957,19 38.730 338.830 4618,02 4703.18 6054.14 38.730 338.340 4693.65 4778.81 6149.74 38.800 339,080 4768.20 4853.36 6243.42 39.000 337,840 4841,10 4926.26 6337.28 38.720 338.560 4914.19 4999.35 6432.97 38.160 338.400 4989.14 5074.30 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 1733.73 N 843.48W 5990294.16 N 497529.29 E 1926.18 1771.29 N 859.80W 5990331.73 N 497512.98 E 0.000 1967.13 1824,08 N 881.34W 5990384.52 N 497491.45 E 2.125 2024.14 1885.36 N 904.30W 5990445.81 N 497468.50 E 0.577 2089.50 1944.29 N 927.19W 5990504.74 N 497445.63 E 2.698 2152.67 2001.29 N 950.64W 5990561.75 N 497422.19 E 0.128 2214.29 2058.36 N 974.60W 5990618.83 N 497398.24 E 0.667 2276.18 2115.30 N 999.69W 5990675.77 N 497373.16 E 0.836 2338.41 2171.39 N 1025.79W 5990731.86 N 497347.07 E 0.866 2400.25 2226.47 N 1052.39W 5990786.95 N 497320.48 E 0.419 2461.36 2281.40 N 1077.55W 5990841.88 N 497295.34 E 2.095 2521.77 2336.76 N 1101.81W 5990897.25 N 497271.09 E 0.749 2582.21 2392.50 N 1125.08W 5990952.99 N 497247.83 E 2.466 2642.60 2447.71N 1145.97W 5991008.20 N 497226.96 E 0.573 2701.57 2504.39 N 1167.43W 5991064.89 N 497205.51 E 0.961 2762.11 2560.36 N 1188.14W 5991120.86 N 497184.80 E 1.589 2821.70 2616.65 N 1208.18W 5991177.16 N 497164.78 E 0.502 2881.32 2673.18 N 1228.40W 5991233.70 N 497144.57 E 0.567 2941.23 2730.42 N 1248.56W 5991290.94 N 497124.43 E 0.772 3001.76 2789.02 N 1268.94W 5991349.55 N 497104.06 E 0.178 3063.63 2847.03 N 1289.11W 5991407.56 N 497083.90 E 0.404 3124.87 2905.00 N 1309.78W 5991465.54 N 497063.25 E 0.702 3186.29 2962.33 N 1331.68W 5991522.86 N 497041.36 E 2.938 3247.59 3017.56 N 1353.51W 5991578.10 N 497019.54 E 0.336 3306.95 3072.25 N 1374.77W 5991632.80 N 496998.29 E 0.146 3365.59 3128.72 N 1396.92W 5991689.28 N 496976.15 E 0.316 3426.21 3184.50 N 1418.65W 5991745.05 N 496954.43 E 0.490 3486.03 3239.21 N 1440.25W 5991799.77 N 496932.84 E 0.858 3544.82 3293.89 N 1462.12W 5991854.46 N 496910.98 E 0.566 3603.68 3349.23 N 1483.94W 5991909.80 N 496889.17 E 0.594 3663.14 Comment Tie-on Survey Kuparuk 3G Continued... 26 June, 1998 - 4:04 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3G-25X Your Ref: AP1-501032024600 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 6527.89 37.540 338.400 5064.09 5149.25 6622.58 36.730 337.330 5139.58 5224.74 6718.76 37.930 337.430 5216.06 5301.22 6812.52 40.180 337.990 5288.86 5374.02 6906.72 40.800 337.680 5360.50 5445.66 7002.55 39.130 339.810 5433.95 5519.11 7097.27 38.260 340.530 5507.88 5593.04 7192.99 39.500 339.090 5582.39 5667.55 7288.11 40.450 339.300 5655.28 5740.44 7383.08 41.380 338.600 5727.05 5812.21 7478.08 42.040 338.770 5797.97 5883.13 7608.39 42.910 339.900 5894.08 5979.24 7675.00 42.910 339.900 5942.87 6028.03 3403.38 N 1505.38W 5991963.96 N 496867.75 E 0.653 3721.35 3456.33 N 1526.92W 5992016.92 N 496846.22 E 1.094 3778.50 3510.17 N 1549.35W 5992070.76 N 496823.80 E 1.249 3836.81 3564.83 N 1571.75W 5992125.42 N 496801.42 E 2.429 3895.87 3621.47 N 1594.82W 5992182.07 N 496778.35 E 0.692 3957.02 3678.82 N 1617.15W 5992239.43 N 496756.04 E 2.253 4018.52 3734.53 N 1637.24W 5992295.13 N 496735.96 E 1.034 4077.62 3790.91N 1657.99W 5992351.52 N 496715.23 E 1.603 4137.60 3848.04 N 1679.69W 5992408.65 N 496693.53 E 1.009 4198.65 3906.08 N 1702.04W 5992466.70 N 496671.20 E 1.092 4260.79 3964.97 N 1725.01W 5992525.59 N 496648.24 E 0.705 4323.96 4047.30 N 1756.06W 5992607.93 N 496617.21 E 0.888 4411.84 4089.89 N 1771.64W 5992650.52 N 496601.64 E 0.000 4457.12 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 336.560° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7675.00ft., The Bottom Hole Displacement is 4457.12ft., in the Direction of 336.579° (True). Comment Projected Survey Kuparuk 3G Continued... 26 June, 1998 - 4:04 o 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3G-25X Yo ur Ref: A PI-501032024 600 Kuparuk Unit Kuparuk 3G Comments Measured Depth (ft) 3731.27 7675.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3007.28 1733.73 N 843.48 W 6028.03 4089.89 N 1771.64 W Comment Tie-on Survey Projected Survey 26 June, 1998 - 4:04 - 4 - DrillQuest GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11392 Company: Alaska Oil & Gas Cons Comm Attn: ~Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 8/3/98 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia US Tape ,1A-23 TDTP/WFL 980308 I 1 ; 1 L- 13 PRODUCTION PROFILE 980701 I 1 !1L-17 ~k.t C.,, INJECTION PROFILE 980630 I 1 1R-16 GAS LIFT SURVEY 980602 I 1 1Y-08 L,LI C.._ WATER INJECTION PROFILE 980602 1 1 2A-24 PRODUCTION PRORLE 980619 I 1 2F-10 GAS LIFT SURVEY 980720 I 1 2T-36 11~ ~ C.. INJECTION PROFILE 980629 I 1 2 X- 14 PRODUCTION PROFILE 980601 1 1 2 X- 15 PRODUCTION PROFILE 980611 I 1 3 F- 15 INJECTION PROFILE 980720 I 1 3F-18 GAS LIFT SURVEY 980703 1 1 3G-25X STATIC PRESSURE SURVEY 980607 1 1 , 3K-14 GAS LIFT SURVEY 980604 I 1 3K-25 i~%.[ ~ CEMENT MAPPING TOOL 980606 I 1 3 K-31 CEMENT BOND LOG 980701 I 1 3K-31 STATIC BOI'I'OM HOLE 980715 I 1 3K-34 ~J~,l ~ CEMENT BOND LOG 980623 I 1 3 K-34 STATIC PRESSUREfi'EMP 980624 I 1 3 O- 04 GAS LIFT SURVEY 980612 1 I q~- oq~ O'4O, o%1 SIGNED: Please sign and return one copy of this transmittal to Sherrle at the above address. Thank you. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. 'Anchorage, Alaska 99501 c~ (.o ~ (~--~ (D July 22. 1998 Formation Evaluation Logs 3G-25X, AK-MM-80241 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: .~Ui Turker. Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3G-25X: MD Resistivity & Gamma Ray Logs: 50-103-20246-00 511 .' TVD Resistivity & Gamma Ray Logs: 50-103-20246-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia .~' ,!/ 5631 Siiverado Way, Suite G · Anchorage, Alaska 99518 · ~907) 563-3256 · Fax 907) 563-7252 A Division of Dresser Industries. Inc. D I=! I I_1_ I I~ [~ S I~ I=! U'I I" BI~ 26-Jun-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3G-25X Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 3,731.27' MD 'MD 7,675.OO' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) R. ECE VEB ' ,JUL 0 1 1998 AJaska 0ii & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska _&laska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. 'Anchorage, Alaska 99501 July ,:.,~, 1998 RE: MWD Formation Evaluation Logs 3G-25X, AK-~MM-80241 1 LDWG formatted Disc with verification listing. API#: 50-103-20246-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING TIlE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. .Anchorage, Alaska ~9518 5631 Siiverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. 2/24/98 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11863 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive 'Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1 D-07 --1~ · il "')-- WATER INJECTION PROFILE 9 8 01 3 0 I 1 2X-05 ~. l[31~ INJECTION PROFILE 980201 I 1 3B-4 ~'~. ~L~ ' PRODUCTION PROFILE 9801 1 5 I 1 3F-02 ~'~ '~L~ · PRODUCTION PROFILE LOG 98021 5 I 1 3G-25X °tL~. t~ · '-- CEMENT BOND LOG 9801 07 I 1 3K-22 c{~. Ob>Lo --- INJECTION PROFILE (CTE) 980211 1 I ,, SIGNED' DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ~"~ ~ L~ i ~i1,~:.] ~ £:.]~.--~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10728 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 1/23/97 Well Job # Log Description Date BL RF Sepia LIS Tape MPC-25A JEWELRY LOG-GR/CCL 961 22 2 1 1 MPC-25A INJECTION PROFILE 9 61 2 2 2 I 1 MPC-25A WATER FLOW LOG-TDTP-GR/CCL 9 61 22 3 I 1 MPE-16 PERFORATING RECORD 9 61 22 9 1 1 MPE-16 PACKER DEPTH DETERMINATION 9 61 23 0 I 1 MPE-16 DEPTH CONTROL LOG-GR/CCI. 9 61 22 2 1 1 MPE-16 CEMENT BOND LOG 961 222 I 1 MPU F-77 TUBING PUNCHING RECORD 9 61 21 0 I 1 MPU F-77 GRAVEL PACK LOG 961 21 7 I 1 MPU K-13 GR/CCL CORRELATION LOG 961 208 1 1 MPU K-13 PERFORATING RECORD 961 208 I 1 MPU K-13 STATIC PRESSURE/TEMP LOG 9 61 2 0 9 I 1 MPU K-13 PACKER SEttING RECORD 9 61 20 9 I 1 MPU K-17 SUMP PACKER SE'i-rING RECORD 961 21 3 I 1 MPU K-17 PERFORATION RECORD 9 61 21 3 1 1 MPK-38 PERFORATION RECORD 9 61 201 1 1 M P K-38 ! PACKER SET RECORD 9 61 2 01 1 1 MPK-38 PERF RECORD 961 204 1 1 c~ f...:,, OBo PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by~'~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend _ Alter casing _ Repair well _ Change approved program _ Operation Shutdown __ Re-enter suspended well X Plugging __ Time extension _ Stimulate _ Pull tubing_ Variance_ Perforate_ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _~X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 8' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1334' FSU 1685' FEL, Sec. 14, T12N, R8E, UM (projected) At effective depth At total depth 1544' FSL, 1765' FEL, Sec. 14, T12N, R8E, UM (projected) 6. Datum elevation (DF or KB) Ri.q RKB 41', Pad 53' 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-25X 9. Permit number 96-136 10. APl number 50-103-20246 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: (approx) 3812 3073 measured 3711 true vertical 3000 Length Size 80' 16" 3759' 7-5/8" Casing Structural Conductor Surface Intermediate Production Liner feet feet feet feet Plugs (measured) None Junk (measured) Cemented Measured depth 123 sx AS I 121' 860 sx AS III 3800' & 360 sx Class G 50 sx ASIII top job to 121' True vertical depth 121' 3063' Perforation depth: measured Tubin~ (size, ~rad~, and m~asured depth) Non~ RECEIVED , ORIGINAL Alaska 0il & Gas Cons. Commi,~sion Anchorage Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal X Contact William Isaacson at 263-4622 with any questions_. Detailed operation program __ BOP sketch __ 14. Estimated date for commencing operation March 1, 1998 Oil X 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify t~at th~,dor~going is true and correct to the best of my knowledge. · Signed .,./{ //c:~/ Title DrillingSuperintendant - CI '~ FOR COMMISSION USE ONLY Conditions of approval: Not4~Commission so representative may witness 15. Status of well classification as: Gas _ Suspended_~_X Date Plug integrity_ Mechanical Integrity Test _ BOP Test Location clearance __ i~'( ~',.-~~::~¢'~'~' '~ . ,Approval No~(~-- 0/) Subsequent-form require 10- /-t'O .7' I~-~r'c'~ 7~e~,'/''') I Approved by' the order of the Commission Form 10-403 Rev 06/15/88 ~pprove~ OoP¥ p~e~r"ed commissioner Date c~l'/q~ SUBMIT INITRII~LICATE APPLICATION FOR SUNDRY APPROVAL Well 3G-25X 3G-25X History: - Spud August 6, 1996 - Drilled 9-7/8" surface hole to 3812' MD - Ran 7-5/8" casing to 3800' MD - While cementing 7-5/8" casing, encountered lost circulation prior to obtaining cement returns to surface - Run CBT: Results show good cement with top at approximately 1675' MD (base permafrost -1680' MD) - Top of 15.8 ppg tail estimated at 3280' MD (520' MD above shoe) - Top of 12.1 ppg lead estimated at 1675' MD (2125' MD above shoe) - Performed 'Top Job' down to base of conductor at 121' MD - Freeze protected 7-5/8" casing with diesel down to 2000' MD and installed tubing head / tree - Operations suspended August 12, 1996, due to denied request for approval to drill ahead Discussion: Additional cement evaluation logs have been run in the 7-5/8" surface casing of 3G-25X in order to verify the actual top of cement behind pipe. At the time the original cement evaluation logs were run, only 18 hours had passed between mixing the cement and obtaining the Icg. Listed below are results from compressive strength tests performed on the actual 12.1 ppg lead cement pumped in the well. The test was performed at 40° F, which is assumed to be representative of (or higher than) the temperatures experienced in the wellbore adjacent to the permafrost as the cement was allowed to set. Time Since Mixing Compressive Strength 16 hrs No Strength 24 hrs 40 psi 72 hrs 95 psi 7 days 200 psi (Ultimate Strength) Based upon this information, any cement across the permafrost at the time the original cement evaluation logs were run, would have just began building compressive strength and may have not been seen by the 'Cement Bond Tool'. The base of permafrost in well 3G-25X is estimated at approximately 1680' MD, and the top of lead cement was estimated at approximately 1675' MD, as based upon the August 9, 1996 'CBT' Icg results. On January 7, 1998, logs consisting of the 'Ultrasonic Imager' (USl) and 'Cement Bond Tool' (CBT) were run. Results of the logs are as follows: Interval Depth (MD) Surface to -120' -120' to -450' -450 to -1150' - 1150' to - 1675' -1675' to 3280' -3280 to Csg Shoe Interpretation of Logs ~ Good cement bond -'Top Job' cement p,,__o Free pipe - No cement, liquids behind pipe (not frozen) ~'~¢- /¢¢zj' o ~- Excellent bo._~~nd - Assumed to be frozen liquids (mud) & permafrost behind pipe o~- Intermittent fair & very good bond - Lead cement with a few frozen mud channels Ot~ Very good cement bond - Lead cement o~ Intermittent very good & excellent cement bond - Tail cement Page 1 Based upon these logging results, the actual top of cement is being estimated'at -1150' MD. This cement top is adequate to provide isolation of all hydrocarbon zones within the surface hole interval, eliminating the need for remedial cement action. In addition, the current hydraulic integrity of the 7-5/8" casing is vital for isolating the surface hole interval from any pressure encountered while completing drilling operations and / or while the well is in production mode. After a thorough review, it has been determined that remedial cement operations to fill the remaining annular space are not needed and will only jeopardize the integrity of the 7-5/8" casing string. After your review of the details stated above, ARCO Alaska, Inc. respectfully requests approval to re-enter and complete drilling operations on 3G-25X. The well will be drilled to the proposed target and completed as a producer, as per the original 'Permit to Drill'. Drilling and completion operations will be performed using Nordic Rig 2, with an expected March 1~', 1998 commencement date. If you have any questions or require additional information, please contact Mike Zanghi at 263-6206 or the Drilling Engineer, William Isaacson at 263-4622. Page 2 Memo' ARCO' Well KRU 3G-25X Kick: 8AUG96 To: David Johnston 9AUG96 rev 8/14/96 Tuckerman Babcock Jack Hartz Bob Crandail Fm: Blair Wondzell c:\aogccgen\kr3g-25x,kic) 8/8/96 5:45 pm: arrived home and received a message that Mike Winfree, ARCO had called and left the following message. KRU 3G-25X cement job. Faxed a memo at 5 pm. Office 263-4603 till 6 pm, home 274-4437. I called the office number about 5:58 pm and got Mike's recorder. I called his home about 6:20 pm and talked to Mike who relayed the following information: lost circulation after pumping about 120 bbls of lead cement; final pump pressure 650 psi indicating that tail slurry would be well above the top of the West Sak. Annulus now flowing, will watch it for a while. He requested they be allowed to do a top job, an LOT and proceed as indicated by the LOT. I said I didn't believe that I had the authority to void the regs regarding annular fill. He said that he didn't want to shoot and squeeze after what happened last time. I said maybe they should run a "DV" collar. I suggested he run a CQL e , and we would discuss it with the Commissioners in the morning ~sa~d it would not show lead cement and I pointed out I had told them about using tracers). I also told Mike that while I was sensitive to his predicament, I was not sympathetic because they designed and carried out the program - it was their program, and they should modify it so that it works. 6:30 pm: I called Lou at the North Slope and filled him in on the situation, and the game plan. I asked Lou to go to 3G-25X in the morning and get a copy of the CQL and give me a call. ;~/9/96 -- 8:30 am; typed an incident data sheet and briefed David and Jack. -- 9:30 am: talked to Lou. He reported that they had finished running a CQL with temperature log; the CQL showed top of tail cement at about 3300' top of lead about 1700' and free pipe to surface. They plan to rerun the CQL because the first one appeared to have technical difficulties. -- 10:00 am: talked to Fred Johnson and he reported that the annulus had trickled about 26bblsin 5 hours - 5 pm to 10 pm - but since that time was dead. They had run a bond log with temperature log - were now rerunning the CBT with Temperature log. The 7&5/8' shoe at 3800', TD at 3812' TVD, top of tail cement at 3280', top of lead at 1675', then free pipe to surface. Top of West Sak was at 2900'. He wanted to do a top job and go forward. I suggested he bring his copy of the CBT over and we would discuss the options - I mentioned the three options listed below. ~- 10:30 am: updated David, Tuckerman, Jack, and Charles. A good discussion ensured. The out come was that the Commission decided to insist on compliance with the regs. The operator was to fill the annulus with cement. -~ 11:30 am: I met with Fred Johnson and told him the Commission position was that they were to fill the annulus to the surface. We looked at the log. I agreed with the approx, picks - did note that for the lead cement the variable density log looked peculiar in that the initial 2 waves were muted, the next -~4 were sharp, the next -~3 were muted, the last 2 were sharp. Fred was very unhappy with the decision and tried to argue about it - declined to participate. He said we were making them abandon the well. Fred stated that there was no reason to cement casing thru the permafrost. Jack and I pointed that they could present data at a conservation hearing. - 1:30 pm: Fred called back to arrange a meeting with the Commissioners. David said he could see no reason to meet - they had made a decision and were not about to change. Fred said Mike Zanghi wanted the meeting. I asked that Mike call David so David could tell him there was no purpose for a meeting and David could explain that changes could be made with a conservation order. pm: I updated Lou and told him he need not stick around the rig. -6 pm' Fred Johnson ca~.d me at home and stated that in discussion with Mike Zanghi, David Johnston ~ said that the Commission on Monday, in response to arguments to be presented by ARCO, would reconsider the "fill annulus" decision. He then said that they would like to secure the well pending a decision to move the rig to another location or to proceed with this well; either way they would need to do a top job. Since the top job would not preclude shooting and squeezing or circulating cement behind pipe, I told him that would be OK, but they need to contact Lou Grimaldi on the Slope. He said he would have their people do that. 8/12/96, -8:30 am: I contacted Lou. He said the Parker 245 had done a top job, installed the BOPs and was waiting on orders. -~ 10:30 am: We received a letter from ARCO's Mike Zanghi in which he made these points: * The top job satisfies the requirement of cement to surface as provided for in 20 AAC 25.030(d)(2)(B). * There is no operational requirement for, or benefit obtained by filling the remaining annular space with cement.. * "After a thorough review of the possible options we have determined that remedial cement operations to satisfy the Commission's requirement to completely fill the annular space on this well are not available." 11:30 am: Commission meeting with David, Jack, Bob, Chuck, Bobby, and Blair. Recognized that most of the states and most countries in the world required the surface casing be fully cemented. Discussed the need for cement opposite the permafrost and determined that we didn't know that answer. Recognized that the operation on 3G-25 blatantly ignored attempting to circulate cement. Acknowledged that relative to our Friday discussion and decision, no new data was presented. Decided to reaffirm our Friday decision - surface casing is to be cemented to the surface. --3:30 pm: David sent a letter to Mike Zanghi commenting on some specific points made by Mike in his letter of 8/11/96 and reaffirming our Friday decision. 8/12/96: Mike Winfree called and asked if I would meet with him and Mike Zanghi - we agreed on 11 am. am: Scott Sigurdson called and asked for a meeting - we agreed on 10 am. 10 am: Bobby, John, Chuck and I met with Scott. To questions, we explained that fully cementing surface casing was required in most states and thru-out most of the world. That if the Com..was guilty of any thing, it was for not assuring industry compliance with that part of the Com. regs at an earlier date. 11 am: Bobby, Chuck, and I met with Mike Zanghi and Mike Winfree. The questions and answers were pretty much the same as with Scott. --3;30 pm: Mike Winfree called and asked this question: If they do not get cement to the surface and they shoot and squeeze and still do not get cement to the surface, what then? Answer: If it appears probable that the annulus is not filled, they would have to repeat the process. Some Factors Affectinq Cement Jobs - Especially Surface Casing Depth of casing Holes size vs casing size Jewelry - centralizers, scratchers, turbolizers, etc. Hole condition Mud properties Cement type and properties, weight, viscosity, setting time, etc. Cement placement technique; e.g. pump rate, spacers, etc. Reciprocation Stab-in Possible Improvements Shorten surface casing Add a short string of surface casing The factors listed above DV collars Tracers Possibilities for Current Situation Do nothing - allow them to proceed after doing a Top Job with assurances of specific changes on future jobs: e.g. DV collars, tracers, etc. Require them to finish filling the annulus (as in shoot & circulate or squeeze). Down squeeze the annulus. Other ? Policy Requirements Data on all casing cement jobs be faxed to the Commission within 12 hours after job completion. Data is to include time and date spudded, time and date when TD reached, MD & TVD; hole size, casing size, weight, grade, and couplings, and specific data on the jewelry used; hole problems while drilling such as flows, sticking, and lost circulation (amount, type of fluid, and where occurred); short trips completed after TD is reached; circulations during running of the casing and while on bottom prior to cementing; spacers used including amount and type; cementing details to include stab-in, reciprocation, rotation, plugs, pumping rates and pressures,; cement type and lab data concerning weight, pumping time, LCM, viscosity, etc.; and cement to surface, amount, and time pumping was completed. 0/3/96 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle .. NO. 10437 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk (Reservoir Analysis Logs) RF Sepia Floppy Disk 1Q-2A ~'--IClH CBT 960806 I 1 , , 1Y-13 ~- ~- INJECTION PROFILE 960820 I 1 ....... 1Y-25 ~.,<~ -©<~ PRODUCTION PROFILE W/DEFT 960821 I 1 2X-12A ~- l'-IL~ GAS LIFT SURVEY 960810 I 1 2 X- 17 c~ ~-- - I -~ t PRODUCTION PROFILE 9 6081 0 1 1 3A-18 c~G_ ~)--z~ 'USIT 960907 I 1 3A-18 xS- CBT 960907 1 1 ,,3,,G-,25X q~ - I:~(~ CBT 960809 I I SIGNED: ~~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ,', Alaska 0ii ~ Gas Cu~, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend Alter casing _ Repair well Change approved program _ X Operation Shutdown__ Re-enter suspended well_ _ Plugging __ Time extension Stimulate Pull tubing __ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL,'8' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1334' FSL, 1685' FEL, Sec 14, T12N, R8E, UM At effective depth At total depth 1544' FSL, 1765' FEL, Sec. 14, T12N, R8E, UM 3812 3073 12. Present well condition summary Total Depth: measured (approx) true vertical 3711 3000 Effective depth: measured (approx) true vertical 5. Type of Well' Development __X Exploratory _ Stratigraphic _ Service (projected) (projected) 6. Datum elevation (DF or KB) Rig RKB 41', Pad 53' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3G-25X 9. Permit number 96-136 10. APl number 50-1 Q3-20246 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool feet feet feet feet Plugs (measured) Junk (measured) None ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 3759' measured None Size 16" 7-5/8" Cemented 123 Sx AS I 860 sx ASIII 360 sx Class G Measured depth True vertical depth 121' 121' 3800' 3063' 50 sx ASIII top job to 121' RECEIVED true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) AIJG 2_ 2 199G Alaska 0il & 6as Cons. Commission Anch0F~'.ge 13. Attachments Description summary of proposal _ Detailed operation program __ BOP sketch _ 14. Estimated date for commencing operation 8/13/96 Oil 16. If proposal was verbally approved Name of ~Vondzell y¢¢ approver Blair Date approved 8/12/96 17. I hereby c~y~/t th)¢ foregoing is true and correct to the best of my knowledge. Signed f~Ak ~~~ - _'. Title /,,~ FOR COMMISSION USE ONLY 15. Status of well classification as: Gas _ Suspended , Service Drill Site Development Supervisor Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test _ Location clearance__ Mechanical Integrity Test _ Subsequent form require 10- ¢¢42~ IApproval No4~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 Original Signed By TI! ¢ [¢'~:~ ~' ~,'¢~ ,.~ f-I Commissioner Date ~- ~).--'~ "?') ~D SUBMIT IN TRIPLICATE ALASKA OIL AND GAS CONSERVATION COMMISSION August12,1996 TONY KNOWLE$, (~OVEF~NOF~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mike Zanghi Kuparuk Drillsite Development ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re~ ARCO KRU 3G-25X Permit No. 96-136 Dear Mr. Zanghi: The Commission denies your August 11, 1996 request for a variance to the cementing requirements of 20 AAC 25.030 for the above reference well. Log information obtained by ARCO for the well indicates an.open annulus from 1700 feet md to the surface. Essentially, the well has n_9_o cement behind casing almost its entire length through the permafrost. Contrary to your claim, a "top job" or "well stability program" does not satisfy the requirement of 20 AAC 25.030(d)(2)(B). Failure to cement the annulus through the permafrost also violates general provisions under 20 AAC 25.030(a) which requires a casing program to protect, among other things, against thaw subsidence and freezeback effects within permafrost. If you have questions about this denial, please call me or Blair Wondzell, Senior Petroleum Engineer, at the above number. Chairman .. ARCO Alaska, Inc. Post Office Bo× 100360 Anchorage, Alaska 99510-0360 Telephone 907 275 1215 August 11, 1996 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Surface Casing Cementing ARCO KRU 3G-25X Permit No. 96-136 Dear Commissioner Johnston, You have requested ARCO Alaska, Inc. to submit in writing its reasons why remedial cementing operations on KRU 3G-25X to fill the entire annular space between the surface casing and the open hole are neither necessary nor possible. Under a separate cover, correspondence entitled 3G-25X Surface Cementing Discussion, 8 August 1996 was faxed to the Commission describing the events of the surface casing cementing of this well. Subsequently we were requested by the Commission to confirm the top of the cement using a "cement evaluation" tool. A bond log was run and evaluated, indicating the top of cement at 1675'. Following a discussion with Blair Wondzell of our plans for this well and with his approval, a conventional top job has been done to cement the open annulus. The well as it is presently cemented conforms to all of the general requirements of 20 AAC 25.030 (a) and all of the specific requirements of 20 AAC (d) (2) (A) through (D). The top of cement is clearly above any "significant hydrocarbon zones" as required by 20 AAC 25.030 (b) (4) and all "producible hydrocarbon zones" as set out in the July 31, 1996 Memorandum: State of Alaska provided to us by the Commission. The cement job at the casing shoe will provide adequate integrity to safely drill the well to total depth. This integrity will be shown by the formation integrity test or leak off test to be performed. The "top job" or "wellhead stability cement job" satisfies the requirement of cement to surface as provided for in 20 AAC 25.030 (d) (2) (B) "If cement does not circulate to surface, the open annulus must be cemented- to the su_.rface before d,-4Jling ahead". There is no operational requirement for, or benefit obtained by filling the remaining annular space with cement. A completely filled annular space is not required to meet any objectives of well control and containment, structural integrity, or freshwater aquifer protection. The present condition of the surface casing cement job will allow for the well to be safely drilled and produced. In addition we have reviewed the 'offset data again and conclude that the West Sak interval in the area around 3-G is neither "significant" nor "producible" using any reasonable assumptions as to the advancements of recovery techniques of thinly bedded sands containing higher gravity oils at low temperature. REC£1VED AUG 1 ?. 1996 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Naska 011 & Gas Cons. ¢omrnissio~ Anchorage After a thorough review of the possible options we have determined that remedial cement operations to satisfy the Commission's requirement to completely fill the annular space on this well are not available. Perforating the surface casing above the existing top of cement in order to circulate or squeeze cement will result in lowering the kick tolerance of the well such that the surface casing is rendered useless for well control and containment purposes. Down squeezing cement between the conductor and the surface casing is not operationally feasible, is not likely to fill the entire annular space, and has a high risk of a spill due to broaching around the conductor. Running slim tubing between the conductor and surface casing down to the existing top of cement is not operationally possible. After your review of the details stated above we respectfully request that the Commission grant permission to drill ahead upon demonstration of a valid leak off test. Your earliest attention to this matter would be greatly appreciated. We presently have the drilling rig standing by on the well pending resolution of this matter. The rig has been idled since August 9 and we are incurring daily costs of $60,000 in this standby mode. If you have questions or require additional information, please contact me at 265- 6206 in our Anchorage office. Sincerely, Kupamk Drillsite Development ALASKA OIL ~D CONSERVATION COMMISSION August 12, 1996 TONY KNOWLE$, GOVEF~NOFI 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mike Zanghi Kuparuk Drillsite Development ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: ARCO KRU 3G-25X Permit No. 96-136 Dear Mr. Zanghi: The Commission denies your August 11, 1996 request for a variance to the cementing requirements of 20 AAC 25.030 for the above reference well. Log information obtained by ARCO for the well indicates an.open annulus from 1700 feet md to the surface. Essentially, the well has no cement behind casing almost its entire length through the permafrost. Contrary to your claim, a "top job" or "well stability program" does not satisfy the requirement of 20 AAC 25.030(d)(2)(B). Failure to cement the annulus through the permafrost also violates general provisions under 20 AAC 25.030(a) which requires a casing program to protect, among other things, against thaw subsidence and freezeback effects within permafrost. If you haVe questions about this denial, please call me or Blair Wondzell, Senior Petroleum Engineer, at the above number. Chairman MEMORANDUMS- State of- laska TO: David J~ Chairma~ Alaska Oil and Gas £ ~aservation Commission DATE: August 6, 1996 Blair Wondzell, (~ P. !. Supervisor ~//~, FROM: Chuck Scheve, ~ SUBJECT: Petroleum Inspector. FILE NO: ecxkhfdd.doc Diverter Test - Parker 245 ARCO Kuparuk River Unit KRU 3G-25X PTD # 96-136 Tuesday August 6,1996: t traveled to ARCO's Kuparuk River Unit to witness a diverter function test on Parker Rig 245 drilling the 3G-25X Well. The Diverter Test Report is attached for reference. The diverter function test went smoothly. Parker 245 is utilizing a straight 16" line and the setup is a good one. The equipment appeared to be in good condition and the location was well organized. Summary: ! witnessed a diverter function test on Parker 245 drilling ARCO's KRU 3G-25X Well. Attachment: ecxkhfdd.xls X- Unclassified " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIt~ION Diverter Systems Inspection Report Operation: Development Drlg Contractor. Parker Drilling Rig No. 245 PTD Cf Operator: Arco KRU Oper. Rep.: Well Name: 3G-25X Rig Rep.: Location: Sec. 23 T. 12N R. 8E Merdian Umiat Date: 8/6/96 X Exploratory: 96-136 Rig Ph. # 659 - 7670 Donnie Lutrik John Crisp MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign: OK Systems Pressure: 3000 , psig Housekeeping: OK (Gen.) Drlg. Rig: OK Pressure After Closure: 1500 psig Reserve Pit: N / A Flare Pit: N / A 200 psi Attained After Closure: 0 min. 25 sec. Systems Pressure Attained: 2 min. 45 sec. Nitrogen Bottles: Six Bottles 2300 Ave. DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES Vent Line(s) Size: 16 Vent Line(s) Length: 90 'Line(s) Bifurcated: NO Line(s) Down Wind: YES Line(s) Anchored: YES Turns Targeted / Long Radius: N/A in. psig MUD SYSTEM INSPECTION: Light Alarm in. Trip Tank: N/A OK ft. Mud Pits: N/A OK Flow Monitor: N/A OK GAS DETECTORS: Light Alarm Methane OK OK Hydrogen Sulfide: OK OK NORTH Prevailing Winds 20" Annular Preventer With 16" FO Hydraulic Knife Valve I I Mounted on 2Z' Dual Wheels Mud System ~ Pipe Shed & Motor Module-~ i I I I Non Compliance Items 0 Repair Items Withir Remarks: 0 Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - OpeflRep c - Database C - Trip Rpt File c- Inspector AOGCC REP.: FI-022 (Rev. 7/93 ECXKHFDD.XLS TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 2, 1996 Mike Zanghi Drill Site Develop Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3G-25X ARCO Alaska, Inc. Permit No.96-136 Sur. Loc. 2538'FNL, 8'FEL, Sec. 23, T12N, R8E, UM Btmnhole Loc. 1544'FSL, 1765'FEL, Sec. 14, T12N, R8E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman '~~ BY ORDER OF TItE COMMISSION dlffEnclosures Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. A! ~-- V-.A OIL AND GAS CONSERVATION COMMISSIr PERMIT TO DRILL 20 AAC 25.005 '11. Type et Week Drill [] Redrill X lb TYPe e1 V~etl ExploralOr~ [] $lraligml~hic TeSl O ~vel~mN ~ X 2, Na~ ~ O~raor ' ~'. D$um Ebvallon (DF or ~) 10. AR~ Alaska~ Inc. Rig RKB 41' ~d 53' leer Kuparuk River Reid 3. Addmaa 6. Prepay ~Uon Kuparuk River Oil Pool P, O. Box 100360, Anchorage, AK 99510-0360 ADL 25547~ ALK 2561 4. LotiOn ot well al ~fla~ ' 7. U~ or ~y Name "' 11. Ty~ 2538' FNL, 8' FEL, Sec. 23, T12N, RBE, UM Kupsruk River Unit Storewide Al top ~ pmd~lve Intew~ (~ TARGET) ~. Well n~b~ Number 13~' FSL 1685' FE~ Sec. 14, T12N, RBE, UM 3G-25X fU-630610 Al [~al dash g. Appmx~ale ~ dale Am~ 15~' FS~ 1765' FE~ Sec. 14, T12N, RBE. UM 8/5/96 $200,000 12. ~n~ lo ~al 13. Disl~ !o ~am~ well 14, N~ber of ~ In pm~ny 15. Pro~ ~h _. prwe~ ~im 3G-14 7701' MD 3515 ~ TD fee~ 11.9' ~ 550' ~eel 2650 6044' TVD feat 16, To ~ ~mpleted f~ ~aled ~lla 17. An~ic~le~ ~m (~ ~ AAC 2s.o3s(e)(3D " ~ckoff depth 400' feet M~i~m~ ~ 39.8~ ~m~ 1808 p~ At ~ot~ 18. ~g pr~ff~m ~ -- Seai~ Oeplh e~e Spedfi~tions ~" So~om Qua~ of ~nt ~b _ Caen_ We~hl Gm~ C~p~ Le~h ~ ~ ~ ~ {indu~ ~age d~a~ , ~4' 16' 62.5~ H-40 Weld 80' 41' 41' 121' 121' ~00 CF 9.875' 7.625' 2g.7~ L-80 LTC 3636' 41' 41' 3677' 3054' 860 Sx Arcticset ~11 & _ ~ , HF~ 350 Sx Class G .. 6.75, '~.5~- '15-.~' L~80 LTCMOD 7239' 41' 41' 7280' 5720; 8.75' 4.5' 12.8~ L-80 EUEBrdM 421' 7280' 5720' .~01' 6044' Top 500' above. Kuparu~' lg. To ~ ~~ for Re~, Re-en~, ~d ~egen Opeml~. P~nl weR ~i~ Tolal~plh: ~umd 3725 ~eel P~¢(~asumd) Baker K-1 c~ retainer set ~ 3040' line vs~lcal 3069 [est Baker N-1 drillable BP set ~ 3070' ~e~e depth= ~d 3040 [eel ~k I~ v~l 2560 C~ LeeCh S~ C~e~ ~umd ~plh T~ Veni~ Sl~ural ~tor 80' 1 6' 250 sx Arcticset III 1 21' 121' suff~e 3674' 7-5/8' 770 sx AS III, 300 ax Class G 3715' 3063' I~e~la~e Squeeze: 260 sx AS 111, 240 sx AS I P~lon Top Job: 40 sx AS Iit U~r Peff~ion deDIh: ~d 306~-3067' I~ veniml 2679-2680' 20, Allachmenls RI~ fee D Pro~ pla~ ~ .... ~S~ X D~e~er Skat~ X D~i~ p~m X D~ I~ program X ~ vs ~plh pin ~ Rel~lion a~s ~ Se~ ~on ~ 20 AAC 25.050 m~lm~nls X - ~ Co~ U~ On~ [ ! I ~wn~m~ me~s ~ Yes ~ No DE~lio~ su~y required ~ Yes ~ No Original Signed By David W. Johnston ~p~ed by Com~en~ t~ ~mm~lon Form 10.4OI Rev. 7.24.89 Subm~l kl ldpllcate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3G-25X 5. 6. 7. 8. 9, 10. 11, 12. 13. 14. Move in and rig up Parker #245, Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (3,790')according to directional plan. Run and cement 7-5/8' casing, Install and test BOPE to ,3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole, Perform leak off test~. Drill 6-3/4" hole to total depth (7,701') according to directional plan, Run open hole evalua~on logs or LWD tools as needed. Run and cement 5-1/2' x 4-1/2" tapered casing string with polished seal bore as part of XO, (if significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed,) Pressure test 5-1/2" x 4-1/2' casing to 3500 psi. Run completion assembly. Sting into poJished seal bore with seal assembly and pressure test tubing and annulus, ND BOPE. NU tubinghead & master valve and upper tree assembly. Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job, Shut in and secure well. Clean location and release rig in preparation for pedorating, DRILLING FLUID PROGRAM Well KRU 3G.25X Spud to 9.5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9,0-10,0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 ±10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.9 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes: Drilling fluid-practices will be in accordance with the appropriate regulations stated in"20 AAC 25.033. Maximum anticipated surface pressure is calculated using a shallow formation leak-off of 13.5 ppg EMW and a gas gradient of 0,11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,808 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BQP equipment to 3000 psi, The nearest existing well to 3G-25X is 3G-14. As designed, the minimum distance between the two wells would be 11.9' @ 550'. Drillin~l Area Risks: Risks in the 3G-25X drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed, 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10,9 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be taken .to leak-off or to an_ e_~uivalent mud weight of 16~0 ppg upon drilling out of the surface casing, whichever comes first. *Spud mud should be adjusted to a F'V between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 3G-25X Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. !Note that cement rinseate wjlJ noLb~ iniected down the dedicated disposal well but will be recycled or held for a_n__open annulus.1 The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3G-25X surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. 3G-25X will not be permitted for annular pumping due to its being the last well in this drilling program. ALASKAt AR , ~~1~ J r~ld : Kupamk ~;ver Unit Lo=atlon : No~h Slope, Al~ska~ ""~'~=~ I <- West (feet) 21~ ~7~ ~400 1050 7~ ~ O . I I ___1 ' I i m i , I __L-- L t L I "~ . I 133&' ~O 7350 D~-~215 6.0~ 2.00 1S.Oa 21,00 ~ 27.00 . 30.~0 ~ . 7 5/8 Ca=,ng ~ ~9.00 B/ PERMA~O~ ~D-159¢ mO-l~O ~P-419 8aS~ ~ 7 5/8" ~IN~ ~Ds~O=305~=319~TuO=~TgOT~o=3987~P=I92~O~=2966 ~2.70 ~850 I e,O.g5 2535' mL, 8' EL J 3500 3~50 4goo 5~00 6500 Z 21~0 "t 1750 1400 1050 700 3,90 350 TARGET ANGLE 39.82, DEG N Z6.13 DEG W 421. O'(TO TABGET) , ,Plane of Proposal,*= T,,~GET - T/ UNITS D/C ~'h'~b: 9z~O I ' r ' ' J ' F J i i ; ! , i , i , , , , , , , , ' s - 350 0 350 700 1050 1400 1750 2100 2450 2800 3150 ,3501= 3~50 4:~Oo ,550 Vertical Section (feet) -> Azimuth 333.87 with reference 0,00 N, 0.00 E from $1ot #25X AR,~ 0 ALAS KA, I ne.. 2000 720 ~ .- 540 d~GO. 1BO0 480 $~ructute : P~d 3G Well : 25X Field : Kuparuk River UnTt Location :NoHh Slope, Aleeka <- west (feet) 350 320 280 240 200 1~o 120 Igo ~o o ~o 8o 360 2~o 240 1~o0 I I I I I ! 1 ~00 ~ IEO0 [ Ill I 22C0 1 ~00 2OO0 720 ~80 ~0 5GO I 320 260 2~ o 150 - 1000 GOO BOC 1200 1600 IOOO 8C0 600 0(3O 200 <-- West (feet) ~oo 42{xl ~o ~,~00 ' 3600 )OOO -e-- ~ 2400 ~- 2200 O 2000 1800 160~ 12G0 6O0 ARC O ALASKA, Inc. Slrucfur. : Pad 3G Well : 25X Field : Kuparuk River Unff Locotlon f North Slope, Aloaka <- West 2~0fl 2200 2OOO 1800 1BO0 14430 12OO 1000 BOO 500 400 700 0 200 4~~ .- 6000 5600 · 5B00 5600 · 3~Co~,~ 5600 5400 3400 5~00 360[ 52~0 50~0 5~00 ~0( ~00 ZBO0 &600 ~00 ~00 ~o00 ~ZO0 ~O00 ~000 3BO0 ~800 · 0~00 2G0O 3200 ~000 2200 2600 30CO ~800 2800 200 t ~4OO ¢0 ~0oo <- Wesf (feel), 4200 4000 5500 3400 3200 ~co 28Co 26C0 O ~00 '"' v 1GC0 ~200 10O0 BO0 6OO 400 -UPARUK RIVER UNIT 20" DIVERTER SCHEMATIC 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. .MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFYTHAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELl_BORE FLUIDS OR GAS IS DETECTED, OPEN APPF~PRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 15' CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16'- 2000 PSI BALL VALVE 20' - 20o0 PSI DRILLING SPOOL WITH TWO 10' OUTLETS. .5. 10' HCR BALL VALVES WITH 10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNUI.~R PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20'- 2000 PSI ANNULAR PREVENTER EDF 3/1~ i t I ' 1 3 2 1. 16' - 20130 PSi STARTING HEAD 11' - 31;XlO P~I CASING HEAD 11"- 3CO0 PSt X 13~a~- ~ P~ SPACE]:! SPOOL 4. 13,5/B'. 5~00 ~ PIPE RAM~ 5. 13.6/6. - 5(X~ PSi O RLG SPOOL W/ ~ AND KILL UNES a. 13,,G~, 5(X~ PS1DOUeLE RAM W/ PIPE RAM~ ON TOP, BLIND RNvI$ ON I~'M 7. 13.,5/8" - 500o PSI ANN ULAR 13 5/8" 5000 PS! B 'P STACK _ACCUMULATOR CAPACITY TEST 1. CHEGK AND FlU_ ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID, ~_ ASSURETHAT ACCUMULATOR PRESSURE IS 3000 PSi WITH 15OO PSI DOWNSTREAM OF THE REGULATOR. 3~ OI~ERVETIME. THEN CLOSE N_L UNITS $1MUL.TANEO~Y AND RECORD THE TIME AND PRESSURE REMAINING AFTER AU. UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4, RECORD ONTHE IAOC REPORT. THE ACCEPTABLE LOWER UMIT IS 4~ SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 1. FILL BOP STACK AND MANIFOLD WITH WATEFL CHEC3( THAT ALL HCLD,OOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT ANO SEAT IN WELLI-IE~O, RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES (2iq THE MANIFOLD. ALL OTHERS OPEN. 4, TEST ALL CCNPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO ~ P~ AND HOLD FOR 3 MINUTES. BLEED TO ZERO 5. OPEN ANNULAR PREVEN1'OR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7, TEST TO 250 PSI AND 3000 PSI AS IN STEP 4, CONTINUE TEST1NG ALL VALVES, LINES, AND CHOK]5$ WiTH A ~ P~I LOW AND 3~:)0 PSI HIGH. TEST AS IN STEP 4. DO NOT PRE&SURE TE~T ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKF_ OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEEr BOTTOM RAMS TO 2SO PS! AND 30a3 PSI FOR :3 MINUTES. g. OPEN PIPE RAMS. BAC~OFF RUNNING ,IT AND PULL OUT OF HOLE. CLOSE BUND RAM~ AND TEST TO ~ PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10, OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD ANO UNES ARE FULL OF ARCTIC DIESEL AND ALL VN_VES ARE SET IN THE DRILLING PoSFrK3N. 11, TEST STANDPIPE VN_VES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCF~ AN[;) INSIOE BOP TO 3000 PSi WITH KOOMEY PtJMP. 13 RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FOR~. 61GN AND SEND TO DRILLING SUPERVISOR. 14, PERFORM COMPLETE BOPE TEST ONCE A WEE]< AND FUNCTIONALLY OPERATE BOPE DAILY, NOTE PRIOR TO DFIILUNG OUT OF THE INTERMEDIATE CASING SHOE THE BOP STACK TEST WILL BE CONDUCTED AS DESCRIBED ABOVE, BUT WILL BE TESTED TO ~330 PSI HIGH. ALL FLANGES AND SEN,S BROKEN BETWEEN THES TEST AND THE PRIOR ONE WiLL ALSO BE TEb-TED TO 250 PSi LOW. ARCO Alaska, inc. Eumber of Pages (Cover __ Phone: ~3- Kuparuk Drill Site Development P. O, BOX 1003~ ANCHO~GE, AK 99510-0360 II _ i · WELL PERMIT CHECKLIST COMPANY -. PROGRAM:expE3 edrllE3 servE3 wellboresegr-lann, disposai~req~ FIELD&POOL dT/?/'~ }~.,.--~ INITCLASS./~ ,,~--.,~:>,~/ GEOLAREA UNIT# / ' }?/.~0 ON/OFFSHORE 1. 2. 3. 4. 5. ADMiNIS:i-RATiON ........... ' AT ENGINEERING GEOLOGY 6o 7. 8. 9. 10. 11. 12. 13. ,,, Permit fee attached ....................... ~ Lease number appropriate ................... ~ Unique well name and number ................. Well located in a defined pcol .................. Well located proper distance from drlg unit boundary .... Well located proper distance from other wells ......... Sufficient acreage available in drilling unit. .......... If deviated, is wellbore plat included ............. Operator only affected party .................. Operator has appropriate bond in force ............ Permit can be issued without conservation order ...... Permit can be issued without administrative approval .... Can permit be approved before 15-day wait. ........ ................. REMARKS 14. Conductor string provided ................... (~ N 15. Surface casing protects all known USDWs ......... ~NN 16. CMT vol adequate to circulate on conductor & surf csg . . . 17. CMT vol adequate to tie-in long string to surf csg ...... .Y.~ 18. CMT will cover ail known productive hodzons ......... ~,,N 19. Casing designs adequate for C, T, B & permafrost. ..... ~.N. 20. Adequate tankage or reserve pit ................ 21. If a re-drill, has a 10-403 for abndnmnt been approved .... 22. Adequate wellbore separation proposed ........... :~) N ."~ 23. If diverter required, is it adequate ............... N ~- 24. Ddiling fluid program schematic & equip list adequate .... ~,N 25. BOPEs adequate ........................ '~''~z,'N 26. BOPE press rating adequate; test to "~:~ psig.,~N 27. Choke manifold complies w/APl RP-53 (May 84) ....... LY_~N ~ ~-'~'? - ---'- 28. Work will occur without operation shutdown .......... ,~ N 29. Is presence of H2S gas probable .............. ~ N 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potentiai overpressure zones ....... Y N/ ,/~,,/¥ ~'-/ ,,~ 32. Seismic anaiysis of shailow gas zones ............. .Y_,,,~.. 33. Seabed condil~on survey (if off-shore) ............ /Y' N 34. Contact name/phone for weekly procjres~, repo~......~J. Y N lexpwrawry onn/j GEOLOGY: ENGINEERING: COMMISS~i: RP~_~___. BEC,f2-- DWJ~ JDH ~ JDN TAB Comments/Instructions: HOW/I~ - A%COR~list rev 4/96 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Wed Jul 15 11:52:10 1998 Reel Header Service name ............. LISTPE Date ..................... 98/07/15 .Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 98/07/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services ~% WELL NAME: 3G-25X API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 AK-MM- 80241 K. ALLEN D. HELMS Scientific RECEIVED . · JUN ? ?. 1990 AJaska Oil & Gas Cons. Commission Anchorage 85.20 23 12N 8E 2538 501032024600 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 15-JUL-98 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 83.70 53.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.625 3791.0 6.750 7675.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL DEPTHS ARE DRILLER'S DEPTHS. DEPTH SHIFTING OF MWD DATA IS WAIVED AS PER THE CONVERSATION BETWEEN STEVE MOOTHART AND ALI TURKER ON -- 07/07/98. MWD IS PDC. 3. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE REISTIVITY PHASE-4 (EWR4). 4. MWD RUN 1 REPRESENTS WELL 3G-25X WITH API#: 50-103-20246-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7675'MD, 6032'TVD. SROP= SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC= SMOOTHED GAMMA RAY COMBINED. SEXP= SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP= SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP= SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP= SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE= SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3493.0 7620.0 ROP 3548 5 FET 3805 5 RPD 3805 5 RPX 3805 5 RPS 380~ 5 RPM 3805 5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: 7674.5 7627.0 7627.0 7627.0 7627.0 7627.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 3547.0 7675.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPS MWD OHMM 4 1 68 4 2 RPD MWD OHMM 4 1 68 8 3 ROP MWD FT/H 4 1 68 12 4 GR MWD API 4 1 68 16 5 RPX MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Min Max Mean DEPT 3493 7674.5 5583.75 RPS 0.8381 601.686 3.92191 RPD 0.8293 155.095 3.90749 ROP 7.1447 1956.66 138.979 GR 20.6619 560.562 121.679 RPX 0.7956 205.622 3.7841 RPM 0.8072 288.656 3.8444 FET 0.3393 8.6135 1.10677 Ns am 8364 7644 7644 8253 8255 7644 7644 7644 First Reading 3493 3805.5 3805.5 3548.5 3493 3805.5 3805.5 3805.5 Last Reading 7674.5 7627 7627 7674.5 7620 7627 7627 7627 First Reading For Entire File .......... 3493 Last Reading For Entire File ........... 7674.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/15 Maximum Physical Record..65535 File Type ................ LO .Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3493.0 7620.0 ROP 3548.5 7674.5 FET 3805.5 7627.0 RPD 3805.5 7627.0 RPM 3805.5 7627.0 RPS 3805.5 7627.0 RPX 3805.5 7627.0 $ LOG HEADER DATA DATE LOGGED: 29 - MAY- 98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWN-HOLE SOFTWARE VERSION: DEPII 2.22A / SP4 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 7675.0 TOP LOG INTERVAL (FT) : 3547.0 BOTTOM LOG INTERVAL (FT) : 7675.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 36.7 42.9 TOOL NI/MBER P0997SP4 P0997SP4 6.750 6.8 11.50 48.0 9.1 -- 1000 4.2 2.400 1.230 2.100 1.350 56.1 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 1 FT/H 4 1 68 4 2 GR MWD 1 API 4 1 68 8 3 RPX MWD 1 OHMM 4 1 68 12 4 RPS MWD 1 OHMM 4 1 68 16 5 RPM MWD 1 OHMM 4 1 68 20 6 RPD MWD 1 0HMM 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD Min 3493 ? 144V 20 6619 0 7956 0 8381 0 8072 0 8293 0 3393 Max Mean Nsam 7674.5 5583.75 8364 1956.66 138.979 8253 560.562 121.679 8255 205.622 3.7841 7644 601.686 3.92191 7644 288.656 3.8444 7644 155.095 3.90749 7644 8.6135 1.10677 7644 First Reading 3493 3548.5 3493 3805.5 3805.5 3805.5 3805.5 3805.5 Last Reading 7674.5 7674.5 7620 7627 7627 7627 7627 7627 First Reading For Entire File .......... 3493 Last Reading For Entire File ........... 7674.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/07/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/07/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File