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Home My WebLink About197-0461. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10456'feet 7973'feet true vertical 6979'feet None feet Effective Depth measured 7973'feet 7920', 9910'feet true vertical 5076'feet 5046', 6478'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" 3-1/2" 3-1/2" 3-1/2" L-80 L-80 L-80 L-80 7934' 9910' 9950' 10034' 5055' 6478' 6515' 6591' Packers and SSSV (type, measured and true vertical depth)9973' 10105' 6426 6493' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 6190'4102' Burst Collapse 10484' Casing 6966'10442' 5896' 121'Conductor Surface Production 16" 7-5/8" 70' measured TVD 5-1/2"" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-046 50-029-22751-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025519 Kuparuk River Field/ Kuparuk Oil Pool KRU 3K-27 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 121' Well Shut-In 325-001 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: ZXP Liner Top Packer: Baker FAB1 SSSV: None Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742 RWO/CTD Engineer 10152-10167' 6699-6713' Fra O s 6. A PG , g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:21 am, Jan 29, 2025 Digitally signed by Elliott Tuttle Reason: I am approving this document Location: Anchorage Tower, CoP Date: 2025.01.29 07:14:32-09'00' Elliott Tuttle A.Dewhurst 13FEB25 RBDMS JSB 013025 DSR-1/31/25JJL 2/27/25 Page 1/9 3K-27 Report Printed: 1/28/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/22/2024 00:00 12/22/2024 02:30 2.50 MIRU, MOVE MOB P Mobilization function test sub module moving system. Build 3K-27 dance floor. Continue to prep pit module for move. 0.0 0.0 12/22/2024 02:30 12/22/2024 08:00 5.50 MIRU, MOVE MOB P Suck out cuttings box. Pick up landings, and stair ways on the sub. Break bolts on mud cross on BOP. 0.0 0.0 12/22/2024 08:00 12/22/2024 09:00 1.00 MIRU, MOVE MOB P Pull out cuttings box, and pull Mud module away from sub. 0.0 0.0 12/22/2024 09:00 12/22/2024 10:45 1.75 MIRU, MOVE MOB P Raise cellar doors. Jack up sub, and pull mats from front. Check all walkways/ landings/etc. on sub secured. Pull sub off of 3K-24, and spot on pad. 0.0 0.0 12/22/2024 10:45 12/22/2024 15:15 4.50 MIRU, MOVE MOB P Change out mud cross on BOP. Pull rig mats and herculite off of 3K-24, clean up area around well. Lay Herculite over 3K -27, and place ply wood. 0.0 0.0 12/22/2024 15:15 12/22/2024 16:00 0.75 MIRU, MOVE MOB P Spot rig over 3K-27. Place herculite under the front of the sub. Slide in mats. Level and shim sub. 0.0 0.0 12/22/2024 16:00 12/22/2024 22:00 6.00 MIRU, MOVE MOB P Spot in pits. Hook up interconnects. Work on rig acceptance check list. Rig Accept and Take on fluids at 22:00. 0.0 0.0 12/22/2024 22:00 12/23/2024 00:00 2.00 MIRU, MOVE MOB P Build NaCl/NaBr brine volume. Take on 11.3 ppg and wt back to 11.0 ppg. 0.0 0.0 12/23/2024 00:00 12/23/2024 02:00 2.00 MIRU, MOVE MOB P Build NaCl/NaBr brine volume. Take on 11.3 ppg and wt back to 11.0 ppg. 0.0 0.0 12/23/2024 02:00 12/23/2024 04:30 2.50 MIRU, WELCTL KLWL P PJSM. Pressure test lines to 2500 PSI for 5 MIN: GOOD test. Initial wellhead pressures: T= 1050 PSI, IA= 820 PSI, OA= 750 PSI. LIne up and pump 11.0 PPG NaCL/NaBr brine down the tubing taking returns out the IA @ 3 BBLS/ MIN @ 500 PSI. Pump 132 BBLS. Line up and bullhead 11.0 PPG brine down the tubing @ 4 BBLS/Min. 0.0 0.0 12/23/2024 04:30 12/23/2024 05:00 0.50 MIRU, WELCTL OWFF P Flow check well, observe flow out of the tubing. 0.0 0.0 12/23/2024 05:00 12/23/2024 07:00 2.00 MIRU, WELCTL KLWL P Line up and pump down the tubing taking returns out the IA @ 3 BBLS/ Min @ 430 PSI. Pump 200 BBLS until clean fluid back to surface. 0.0 0.0 12/23/2024 07:00 12/23/2024 07:30 0.50 MIRU, WELCTL OWFF P Observe well for flow 30 Min: GOOD. 0.0 0.0 12/23/2024 07:30 12/23/2024 08:00 0.50 MIRU, WELCTL MPSP P FMC rep install BPV in tubing hanger. 0.0 0.0 12/23/2024 08:00 12/23/2024 08:30 0.50 MIRU, WELCTL MPSP P Line up and pump down IA. Perform rolling test of BPV. Pump 2 BBL/Min @ 500 PSI for 10 min: GOOD test. 0.0 0.0 12/23/2024 08:30 12/23/2024 09:00 0.50 MIRU, WELCTL RURD P Blow down and rig down lines in the cellar. 0.0 0.0 12/23/2024 09:00 12/23/2024 09:30 0.50 MIRU, WHDBOP NUND P N/D Tree and adaptor flange. Inspect hanger neck threads. 0.0 0.0 12/23/2024 09:30 12/23/2024 12:00 2.50 MIRU, WHDBOP NUND P Set 7 1/16"x 13 5/8" DSA on tubing spool. P/U and set stack on DSA, and N/U bolts. tighten bolts on new mud cross. Install Choke and kill lines on mud cross. 0.0 0.0 12/23/2024 12:00 12/23/2024 20:00 8.00 MIRU, WHDBOP NUND P NU BOPs Install choke and kill hoses onto mud cross. Torque flanges. Hook up Koomey hoses to BOP. Change rams F/3.5" x 5.5" T/2-7/8" x 5" 0.0 0.0 12/23/2024 20:00 12/23/2024 22:00 2.00 MIRU, WHDBOP RURD P PU test tools and MU 2-7/8" test tools to test joint 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/5/2025 Page 2/9 3K-27 Report Printed: 1/28/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/23/2024 22:00 12/24/2024 00:00 2.00 MIRU, WHDBOP BOPE P Shell Test BOPE 0.0 0.0 12/24/2024 00:00 12/24/2024 00:30 0.50 MIRU, WHDBOP BOPE P Fill and purge lines for testing BOP. 12/24/2024 00:30 12/24/2024 01:00 0.50 MIRU, WHDBOP SVRG P Rig service grease and function BOP compontents 0.0 0.0 12/24/2024 01:00 12/24/2024 02:30 1.50 MIRU, WHDBOP BOPE T Shell test BOP. Leak observed from weep hole on blind ram bonnet. Water leaking out of weep hole indicating well bore seal failure on Blind ram piston. 0.0 12/24/2024 02:30 12/24/2024 07:30 5.00 MIRU, WHDBOP NUND T Blow down lines, and rig down BOP test equipment. Remove riser from BOP. Remove VBR, and Blind rams from double gate. 12/24/2024 07:30 12/24/2024 11:30 4.00 MIRU, WHDBOP NUND T N/D BOP, N/U BOP. 12/24/2024 11:30 12/24/2024 13:00 1.50 MIRU, WHDBOP NUND T N/U Tree, and FMC set tree test plug in tubing hanger. Test hanger neck void to 5000 PSI for 10 min: GOOD TEST. 12/24/2024 13:00 12/24/2024 14:30 1.50 MIRU, WHDBOP SEQP T Fill tree and attempt to test. Failed test. Observe fluid level falling in tree. Pull test plug, and inspect. External seals looked good. Shear pin did not shear relasing the check valve. Rebuild tree test plug, and re set. 12/24/2024 14:30 12/24/2024 15:00 0.50 MIRU, WHDBOP BOPE T Fill tree with diesel and test to 5000 PSI: GOOD test. 12/24/2024 15:00 12/24/2024 15:45 0.75 MIRU, WHDBOP CIRC T R/U Circulating lines in the cellar. PT lines. Line up and pump down IA until returns at surface. 12/24/2024 15:45 12/24/2024 16:15 0.50 MIRU, WHDBOP FRZP T Line up LRS on IA and pump 15 BBLS Diesel, Taking returns out of the tubing. 12/24/2024 16:15 12/24/2024 17:45 1.50 MIRU, WHDBOP FRZP T U-tube diesel for one hour. Blow down, and rig down lines. Empty pits. Secure rig to pull off of the well. 12/24/2024 17:45 12/24/2024 21:00 3.25 MIRU, WHDBOP DMOB T RD to move off well. Pull pits away from sub at 2000. Notified operator to pull off the well. Pulled off at 2100. 12/24/2024 21:00 12/25/2024 00:00 3.00 MIRU, WHDBOP RGRP T Stage rig mats in cellar. Start to ND BOP double gate. 12/25/2024 00:00 12/25/2024 08:00 8.00 MIRU, WHDBOP RGRP T ND BOP double gate. Replace double gate install 2-7/8" x 5" rams. Function test tdouble gates. Rack back BOPs on pedastool. 12/25/2024 08:00 12/25/2024 09:00 1.00 MIRU, WHDBOP MOB T Spot rig over 3K-27. Shim sub, and set mats. 12/25/2024 09:00 12/25/2024 10:00 1.00 MIRU, WHDBOP MOB T Spot in pit module. Set mats, and shim module. 12/25/2024 10:00 12/25/2024 16:00 6.00 MIRU, WHDBOP RURD T Place containment under rig. Rig up lines and interconnects. Work on rig acceptance check list. load pits with brine 12/25/2024 16:00 12/25/2024 17:30 1.50 MIRU, WHDBOP CIRC T PJSM. Test lines in cellar. Line up on IA and take returns out of the tubing until clean 12/25/2024 17:30 12/25/2024 18:00 0.50 MIRU, WHDBOP OWFF T Flow check well for 30 minutes. 12/25/2024 18:00 12/25/2024 19:30 1.50 MIRU, WHDBOP MPSP T Set BPV. Perform rolling test to 480 PSI at 2 BPM 16 BBL's pumped 12/25/2024 19:30 12/25/2024 20:00 0.50 MIRU, WHDBOP NUND T ND tree and adapter. Rig: NABORS 7ES RIG RELEASE DATE 1/5/2025 Page 3/9 3K-27 Report Printed: 1/28/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/25/2024 20:00 12/25/2024 20:30 0.50 MIRU, WHDBOP NUND T Record RKB measurements, Inspect hanger threads, function fit blanking plug in hanger lift threads. Install overshot blanking plug. Function test blanking plug R&R tool on retrieval threads. function LDS. record in and out measurments. 12/25/2024 20:30 12/26/2024 00:00 3.50 MIRU, WHDBOP NUND T NU DSA to wellhead, install BOP's on DSA. Install turnbuckles. Torque flanges on BOP's. 12/26/2024 00:00 12/26/2024 03:30 3.50 MIRU, WHDBOP NUND T Installl 2 7/8"X 5" VBRS, and blind rams in double gates. Attempt to close bonnets on double gate, unable to close. Increase Koomey pressure, and close bonnets on double gates. 12/26/2024 03:30 12/26/2024 04:30 1.00 MIRU, WHDBOP NUND T Install riser on BOPS, RIH and RIH and Mark test joints. Lay test joints down test joints. P/U tools in the cellar. 12/26/2024 04:30 12/26/2024 05:00 0.50 MIRU, WHDBOP CIRC T Line up and fill IA. 7.2 BBLS pumped. 12/26/2024 05:00 12/26/2024 06:00 1.00 MIRU, WHDBOP BOPE T Run in test joint, R/U test equipment, fill stack and lines, and purge out air. 12/26/2024 06:00 12/26/2024 07:30 1.50 MIRU, WHDBOP BOPE T Attempt to shell test BOP. Leak observed from swivel on choke hose. Tighten lock screws on swivel, and test again. Still leaking. 12/26/2024 07:30 12/26/2024 10:00 2.50 MIRU, WHDBOP NUND T R/D test equipment, Pull riser, and rig down turn buckles. N/D BOPs and rack back. 12/26/2024 10:00 12/26/2024 13:00 3.00 MIRU, WHDBOP NUND T N/D Choke hose, and remove from cellar. 12/26/2024 13:00 12/26/2024 15:00 2.00 MIRU, WHDBOP NUND T Prep cellar for install of new choke hose. Inspect kill line swivel. 12/26/2024 15:00 12/26/2024 21:30 6.50 MIRU, WHDBOP NUND T Prep new choke hose for installation and install new. Install turnbuckels and riser. 12/26/2024 21:30 12/27/2024 00:00 2.50 MIRU, WHDBOP RURD T RU to test. Fill stack with freshwater. Purge air out of system. Tested to 250 PSI low. Attempt to test to 5000 PSI, small leak on choke hose. Tightend choke hose flange, attempted shell test to 5000 PSI, kill line developed small leaked. Tightened flange on kill line. Tested to 5000 PSI for 5 minutes Notified AOGCC rep Kam StJohn as per request. Was informed to continue testing, tests that were acomplished in the interim of his arrival would be reviewed when he got to location. Rig: NABORS 7ES RIG RELEASE DATE 1/5/2025 Page 4/9 3K-27 Report Printed: 1/28/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/27/2024 00:00 12/27/2024 08:00 8.00 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular to 3500 on 2-7/8" and 3-1/2" test joint, UVBR's to 5000 PSI on 2-7/8" and 3500 on 3-1/2", LVBR's w/2-7/8" and 3-1/2" test joint. Tested blinds rams to 5000 PSI. Tested new choke hose to 5000 PSI. Tested choke valves #1 to #16, upper IBOP and lower top drive well control valves. Tested 2-7/8" HT- PAC safety valve, and IBOP. Tested 3- 1/2" EUE FOSV Test 2" rig floor Demco kill valves. Tested manual and HCR kill valves & manual and HCR choke valves. Tested two ea. 2 1/6" gate auxiliary valves below LPR. Tested hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Performed accumulator test. Initial pressure=3000 PSI, after closure=1500 PSI, 200 PSI attained =17 sec, full recovery attained = 126 sec. UVBR's= 5 sec, Annular= 21 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test Witnessed by AOGCC rep Kam StJohn. 12/27/2024 08:00 12/27/2024 09:00 1.00 MIRU, WHDBOP RURD P R/D test equipment and blow down lines. 12/27/2024 09:00 12/27/2024 09:30 0.50 MIRU, WHDBOP MPSP P Pull slip on blanking plug and BPV. FMC hand dropped BPV on top of tubing spool. 12/27/2024 09:30 12/27/2024 11:00 1.50 MIRU, WHDBOP MPSP T Call out slick line magnets and retrieve BPV from BOPs 12/27/2024 11:00 12/27/2024 11:30 0.50 COMPZN, RPCOMP OTHR P R/U landing joint, and BOLDS. 12/27/2024 11:30 12/27/2024 12:00 0.50 COMPZN, RPCOMP PULL P P/U and unseat hanger @ 80K, continue to P/U to 120K observe breakover to 110K, once seals out of seal bore weight broke over to 90K. 7,919.0 7,900.0 12/27/2024 12:00 12/27/2024 12:45 0.75 COMPZN, RPCOMP RURD P R/U power tongs. B/O L/D tubing hanger, and landing joint. R/U circulating equipment. 7,900.0 7,900.0 12/27/2024 12:45 12/27/2024 13:30 0.75 COMPZN, RPCOMP CIRC P Circulate bottoms up X2. At 4 BBL/Min @ 450 PSI. 7,900.0 7,900.0 12/27/2024 13:30 12/27/2024 13:45 0.25 COMPZN, RPCOMP OWFF P Flow check well for 10 MIN. 7,900.0 7,900.0 12/27/2024 13:45 12/27/2024 15:00 1.25 COMPZN, RPCOMP TRIP P POOH racking back 3 1/2" tubing from 7900' to 6700' 7,900.0 6,700.0 12/27/2024 15:00 12/27/2024 22:30 7.50 COMPZN, RPCOMP PULL P POOH F/ 6700' to 2218' laying down tubing. 6,700.0 2,218.0 12/27/2024 22:30 12/27/2024 23:15 0.75 COMPZN, RPCOMP CIRC P Tubing wouldn't drain MU Safety joint to top of tubing screw into joint with top drive. Lower safety joint below floor. Circulate SxS 1.5 BPM at 95 PSI. 2,218.0 2,218.0 12/27/2024 23:15 12/27/2024 23:30 0.25 COMPZN, RPCOMP OWFF P Blow down top drive and surface lines. OWFF 2,218.0 2,218.0 12/27/2024 23:30 12/28/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service hand;ling equipment and power tongs. 2,218.0 2,047.0 12/28/2024 00:00 12/28/2024 01:00 1.00 COMPZN, RPCOMP CIRC P Circulate SXS 3 BPM at 960 PSI. Blowdown 2,047.0 2,047.0 Rig: NABORS 7ES RIG RELEASE DATE 1/5/2025 Page 5/9 3K-27 Report Printed: 1/28/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/28/2024 01:00 12/28/2024 06:30 5.50 COMPZN, RPCOMP PULL P Continue to LD TBG F/2047' T/ surface 2,047.0 0.0 12/28/2024 06:30 12/28/2024 07:30 1.00 COMPZN, RPCOMP CLEN P Clean, and clear rig floor. 0.0 0.0 12/28/2024 07:30 12/28/2024 08:00 0.50 COMPZN, RPCOMP SVRG P Service rig floor equipment. 0.0 0.0 12/28/2024 08:00 12/28/2024 08:30 0.50 COMPZN, RPCOMP OTHR P Set wear bushing, and RILDS 0.0 0.0 12/28/2024 08:30 12/28/2024 12:00 3.50 COMPZN, RPCOMP BHAH P P/U 2 7/8" Clean out BHA F/ surface to 139' 0.0 139.0 12/28/2024 12:00 12/28/2024 23:30 11.50 COMPZN, RPCOMP PULD P Single in the hole F/139' T/7609' PUW=100K SOW=60K 139.0 7,609.0 12/28/2024 23:30 12/29/2024 00:00 0.50 COMPZN, RPCOMP SFTY P Stripping drill and after action review. Discussed kick causes, kick indicators, kick prevention and stripping operations following drill. 7,609.0 7,609.0 12/29/2024 00:00 12/29/2024 02:30 2.50 COMPZN, RPCOMP REAM P Ream down F/7549' T/7706' PUW=100K SOW=60K Establish parameters. Rot 20 RPM ROT WT=75K 3.8K-4.2K Free Tq. Torque dropped back to 2.8K 7,609.0 7,706.0 12/29/2024 02:30 12/29/2024 07:00 4.50 COMPZN, RPCOMP PULD P RIH F/7706' T/7921.18' PUW= 105K SOW=60K Set down 5K PU off tag. Kelly up. Wash down Rot 20 RPM 3600 Tq. PR=2 BPM 1150 PSI Wash down to 7921 tag. Set down 5K. Pressure increased to 1500 PSI Wash and ream from tag one stand. Pump 20 BBL 160 Vis. sweep. Chase sweep out of hole. 7,706.0 7,921.0 12/29/2024 07:00 12/29/2024 09:00 2.00 COMPZN, RPCOMP REAM P Rack back 2 stands F/ 7921 to 7733'. Ream back to bottom @ 40 RPM 3 K TQ. Pumping 3.5 BBL/Min @ 3200 PSI. Pump 20 BBLS 120 vis sweep, and chase out of the hole. 7,921.0 7,921.0 12/29/2024 09:00 12/29/2024 09:15 0.25 COMPZN, RPCOMP OWFF P Flow check well: Losses ~ 3-5 BBL/hr. 7,921.0 7,921.0 12/29/2024 09:15 12/29/2024 13:00 3.75 COMPZN, RPCOMP TRIP P POOH F/ 7921' to 139' 7,921.0 139.0 12/29/2024 13:00 12/29/2024 14:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA F/ 139' to surface. 139.0 0.0 12/29/2024 14:00 12/29/2024 15:00 1.00 COMPZN, RPCOMP CLEN P clean and clear rig floor. Build 3.5". 0.0 0.0 12/29/2024 15:00 12/29/2024 15:30 0.50 COMPZN, RPCOMP SVRG P Service rig floor equipment. 0.0 0.0 12/29/2024 15:30 12/29/2024 18:00 2.50 COMPZN, RPCOMP BHAH P P/U G-plug BHA. 0.0 55.0 12/29/2024 18:00 12/30/2024 00:00 6.00 COMPZN, RPCOMP TRIP P TIH W/G-lock F/55' to 6537' PUW=75K SOW=55K 55.0 6,537.0 12/30/2024 00:00 12/30/2024 01:45 1.75 COMPZN, RPCOMP TRIP P TIH W/G-Lock on DP F/6537' T/7794' PUW= 100K SOW= 60K 6,537.0 7,794.0 12/30/2024 01:45 12/30/2024 03:15 1.50 COMPZN, RPCOMP CIRC P Well out of balance Circulated BUS balanced out well PR=3 PBM 1800 PSI. 11# in and out Break out blow down 7,794.0 7,794.0 12/30/2024 03:15 12/30/2024 04:00 0.75 COMPZN, RPCOMP TRIP P TIH F/7794' T/7895' Change elevators PU working single. KU on 3-1/2" HT-38 single PUW=100K SOW=60K 7,794.0 7,895.0 Rig: NABORS 7ES RIG RELEASE DATE 1/5/2025 Page 6/9 3K-27 Report Printed: 1/28/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/30/2024 04:00 12/30/2024 04:15 0.25 COMPZN, RPCOMP MPSP P Set RBP (7901' COE 7895' bottom of plug 7ES RKB) (7911.86' COE, 7917.86' bottom of RBP ORKB) 7,895.0 7,895.0 12/30/2024 04:15 12/30/2024 05:00 0.75 COMPZN, RPCOMP TRIP P TOOH 3 Stands F/7895' T/7580' 7,895.0 7,895.0 12/30/2024 05:00 12/30/2024 07:00 2.00 COMPZN, RPCOMP BHAH P P/U and M/U running tool, and storm packer. 7,895.0 7,895.0 12/30/2024 07:00 12/30/2024 08:00 1.00 COMPZN, RPCOMP MPSP P Set storm packer @ 42'. R/U test equipment. 7,895.0 7,895.0 12/30/2024 08:00 12/30/2024 11:00 3.00 COMPZN, RPCOMP PRTS P Attempt to pressure test 5.5" casing to 2000 PSI. Pressure up to 2000 PSI observe IA pressure drop to 1000 PSI immediately after turning off pumps. Observe OA pressure climb to 400 PSI, Pressures equalize ~350-400 PSI in IA and OA. Attempt test again, with similar results. Shut in and verify no leaks on surface equipment. Line up and attempt test again with same results. 7,895.0 7,895.0 12/30/2024 11:00 12/30/2024 12:15 1.25 COMPZN, RPCOMP MPSP P Release storm packer, pull to surface. Install safety valve and lay down. 7,895.0 7,895.0 12/30/2024 12:15 12/30/2024 13:00 0.75 COMPZN, RPCOMP MPSP P Rig up test equipment to string and attempt to test 5.5" casing, and IC pack offs from above to 2000 PSI. Pressure dropped to 500 PSI once pumps off. IA, and OA equalized to 300 PSI with in 5 min of test. 7,895.0 7,895.0 12/30/2024 13:00 12/30/2024 13:30 0.50 COMPZN, RPCOMP RURD P R/D test equipment on the rig floor. Blow down lines. 7,895.0 7,895.0 12/30/2024 13:30 12/30/2024 16:30 3.00 COMPZN, RPCOMP TRIP P POOH F/ 7895' to surface. 7,895.0 0.0 12/30/2024 16:30 12/30/2024 18:15 1.75 COMPZN, RPCOMP BHAH P P/U Storm packer, M/U to G-lock running tool. 0.0 54.0 12/30/2024 18:15 12/30/2024 23:15 5.00 COMPZN, RPCOMP TRIP P TIH F/54' T/7871' 54.0 7,871.0 12/30/2024 23:15 12/30/2024 23:45 0.50 COMPZN, RPCOMP MPSP P Set test packer. 7857.02' COE 7ES RKB 7,871.0 7,871.0 12/30/2024 23:45 12/31/2024 00:00 0.25 COMPZN, RPCOMP RURD P RU to test RBP. 7,871.0 12/31/2024 00:00 12/31/2024 01:45 1.75 COMPZN, RPCOMP MPSP P Sim Ops Attempted to pressure test IC pack off to 2900 PSI. 15 min = 2850 30 min = 2800 PSI. Failed PT. Attempt to pressure test Between G-lock at 7895' and test packer set at 7857' (7ES RKB) Pressure up to 2000 PSI down DP. Return at flow line. Pack off test packer and attempt to test. Pressure up to 2000 PSI. pressure bled off down flow line. Attempted to pressure test above test packer. Pumped 15 BBL's 1 BPM 360 PSI. Shut in monitored pressure. DP=250 PSI IA=250PSI OA=250 PSI Pumped additional 10 BBL's Shut in monitored pressure DP=250 PSI IA=250 PSI OA=250 PSI. Bled off pressure Rig: NABORS 7ES RIG RELEASE DATE 1/5/2025 Page 7/9 3K-27 Report Printed: 1/28/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/31/2024 01:45 12/31/2024 02:45 1.00 COMPZN, RPCOMP MPSP P Release test packer. PUW=100K SOW=60K L/D test joint. Change elevators. Attempt to Retrieve G-Lock plug F/ 7895' PU T/107K Total 77K hookload. Parted pipe PUW=39K 12/31/2024 02:45 12/31/2024 05:00 2.25 COMPZN, RPCOMP TRIP P TOOH to stand 77 tool joint backed off at connection. Replaced joint, TIH to top of string. 12/31/2024 05:00 12/31/2024 05:15 0.25 COMPZN, RPCOMP FISH P Screw into string. 25 RPM 1.5K TQ stalled increased Tq to 3.2K released Tq. PU to 105K. 12/31/2024 05:15 12/31/2024 05:30 0.25 COMPZN, RPCOMP MPSP P Release G-lock, 10 RPM 4.2K Tq. RTW=80K. RPB moving freely. 12/31/2024 05:30 12/31/2024 06:00 0.50 COMPZN, RPCOMP OWFF P OWFF fluid fell in stack. 12/31/2024 06:00 12/31/2024 07:30 1.50 COMPZN, RPCOMP TRIP P TOOH replaced both joints at part between stands 7 & 8 from surface. TIH T/7898' (7ES RKB) PUW=100K SOW=60K 12/31/2024 07:30 12/31/2024 09:00 1.50 COMPZN, RPCOMP MPSP P Set G-Lock at 7883' COE. Rot 8 RH rotations PUW-115K Pack off plug, Attempted to walk off plug. Unable to release j-lug from plug. Called Baker office recommended POOH to inspect plug and R&R tool 12/31/2024 09:00 12/31/2024 10:00 1.00 COMPZN, RPCOMP SVRG P Service rig 12/31/2024 10:00 12/31/2024 12:00 2.00 COMPZN, RPCOMP OWFF P OWFF and monitor and establish loss rate. 2 bph loss rate 7,920.0 7,920.0 12/31/2024 12:00 12/31/2024 18:00 6.00 COMPZN, RPCOMP TRIP P TOOH sideways L/D 2-7/8" drill pipe 7,920.0 1,500.0 12/31/2024 18:00 12/31/2024 18:45 0.75 COMPZN, RPCOMP TRIP P Contiinue TOOH sideways L/D drill pipe 1,500.0 60.6 12/31/2024 18:45 12/31/2024 20:15 1.50 COMPZN, RPCOMP BHAH P LD BHA #3, brake out cross-overs and label, *** AK E-line (Shaphan) on location @ 1900 hr Reed cased hole (Corey) on location @ 1940 hr Spot in E-line unit 60.6 0.0 12/31/2024 20:15 12/31/2024 21:45 1.50 COMPZN, RPCOMP ELOG P RU E-line, bring wire to RF, Bring sheave, and metal straps, shackles, etc, to RF via beavorlator MU Caliper tools in cellar. 0.0 0.0 12/31/2024 21:45 12/31/2024 22:00 0.25 COMPZN, RPCOMP ELNE P Function test Caliper 0.0 0.0 12/31/2024 22:00 1/1/2025 00:00 2.00 COMPZN, RPCOMP ELNE P RIH w/Reed Cased Hole 40 arm Caliper on AK E-line wire 2.75" Max OD, 0.0 0.0 1/1/2025 00:00 1/1/2025 02:30 2.50 COMPZN, RPCOMP ELOG P Continue logging F/6,420' T/2,900', close caliper arms, continue OOH F/2,900' T/surface, LD caliper and inspect 0.0 0.0 1/1/2025 02:30 1/1/2025 03:30 1.00 COMPZN, RPCOMP ELOG P MU and test CBL tools 0.0 0.0 1/1/2025 03:30 1/1/2025 17:00 13.50 COMPZN, RPCOMP ELOG P RIH w/2.75" CBL. max OD 3.125" upper Hoist caliper F/7912' to top of cement at 4,353'. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/5/2025 Page 8/9 3K-27 Report Printed: 1/28/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/1/2025 17:00 1/1/2025 20:30 3.50 COMPZN, RPCOMP ELOG P RIH w/2.72" OD P2P drift 7.0', set down, work wire, unable to get past top of liner @ 7,936' uncorrected. Confer with TT, decision POOH, LD E- line, 0.0 0.0 1/1/2025 20:30 1/1/2025 21:00 0.50 COMPZN, RPCOMP ELOG P RD Eline and spot unit out of way. 0.0 0.0 1/1/2025 21:00 1/1/2025 21:30 0.50 COMPZN, RPCOMP SVRG P Service Rig 0.0 0.0 1/1/2025 21:30 1/2/2025 00:00 2.50 COMPZN, RPCOMP TRIP P Prep RF for tripping operations TIH w/2-7/8" work sting out of derrick 0.0 4,240.0 1/2/2025 00:00 1/2/2025 05:00 5.00 COMPZN, RPCOMP TRIP P POOH sideways LD/DP F/4,240' T/surface 4,240.0 0.0 1/2/2025 05:00 1/2/2025 05:30 0.50 COMPZN, RPCOMP RURD P RU to Run and LD 3.5" tubing. 0.0 0.0 1/2/2025 05:30 1/2/2025 06:30 1.00 COMPZN, RPCOMP SVRG P Service blocks and Black jack on top drive. 0.0 0.0 1/2/2025 06:30 1/2/2025 07:00 0.50 COMPZN, RPCOMP TRIP P TIH W/3.5" Tubing out of the derrick. 0.0 0.0 1/2/2025 07:00 1/2/2025 08:00 1.00 COMPZN, RPCOMP PULD P Single out of the well LD 3.5" tubing. 0.0 0.0 1/2/2025 08:00 1/2/2025 10:00 2.00 COMPZN, RPCOMP RURD P Pull wear ring. Remove all 2-7/8" Handling equipment, X-O's and from the rig floor 0.0 0.0 1/2/2025 10:00 1/2/2025 17:00 7.00 COMPZN, RPCOMP PUTB P Run 3.5" EUE L-80 tubing per tally T/surface T/7,939' PUW=82k SOW=52k 0.0 7,939.0 1/2/2025 17:00 1/2/2025 18:00 1.00 COMPZN, RPCOMP HOSO P Obtain parameters. bring pump online 1.0 bpm/62 pump pressure, continue to slackoff, observe seals enter SBE. pump pressure increase to 250 psi, shut down pump, set down 5k, no-go @ 7,939', PU 2' off tag, 7,937', LD 1 joint and 10' pup, calulate spaceout, PU 4.09' MU Tubing Hanger and landing joint 7,939.0 7,937.0 1/2/2025 18:00 1/2/2025 18:30 0.50 COMPZN, RPCOMP THGR P Land tubing hanger RILDS Torque to spec 7,937.0 7,937.0 1/2/2025 18:30 1/2/2025 19:30 1.00 COMPZN, RPCOMP CLEN P Clean RF and Prep for slickline operations 7,937.0 7,937.0 1/2/2025 19:30 1/2/2025 20:30 1.00 COMPZN, RPCOMP SLKL P Spot in SL, bring sheave and wire to RF 0.0 0.0 1/2/2025 20:30 1/3/2025 00:00 3.50 COMPZN, RPCOMP SLKL P MU 2.5" pump bailer, RIH start bailing 7,929' SLMD T/7,932' SLMD, POOH, debris recovered, add another 10' bailer extension, RIH, T/7,948' SLMD, POOH, recovered more of the same debris TIH 0.0 0.0 1/3/2025 00:00 1/3/2025 10:00 10.00 COMPZN, RPCOMP SLKL P Bailing debris F/7,948' T/7,989' MU Brush, RIH T/7987' MU 2.5" bailer RIH to 7990' MU 2.72" RBP Drift RIH T/7988' 7ES RKB. RD S/L 0.0 0.0 1/3/2025 10:00 1/3/2025 17:00 7.00 COMPZN, RPCOMP ELNE P MIRU E-Line MU TS to 2.72" PIIP RIH T/7980' 7ES RKB Set PIIP at 7975' COE 7ES RKB. POOH W/E-Line and RD. 0.0 0.0 1/3/2025 17:00 1/3/2025 17:30 0.50 COMPZN, RPCOMP RURD P RU to test tubing. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/5/2025 Page 9/9 3K-27 Report Printed: 1/28/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/3/2025 17:30 1/3/2025 20:00 2.50 COMPZN, RPCOMP PRTS P Test P2P down the tubing, 1,500 psi, bled off quickly, no pressure IA or OA , confirm fluid packed on tubing and IA, bring pressure back up to 1,500 psi, bled down again quickly. 200 psi on the IA and 220 OA, bled pressure off, confirm no flow at IA, line up to bucket and cellar suction pump, come online 0.25 bpm/570 psi, pumping 1x1 through the IA, increase pump rate to 1.0 bpm/1,500 psi, pumping 1x1 through the IA. Shut down, blow down cement line. 0.0 0.0 1/3/2025 20:00 1/3/2025 21:30 1.50 COMPZN, RPCOMP WAIT P Call town for plan forward Call out SL, with D&D hole finder tool SL on location at 2130 pm. 0.0 0.0 1/3/2025 21:30 1/3/2025 22:30 1.00 COMPZN, RPCOMP SLKL P Spot in and RU SL to rig floor Bring D&D hole finder to the rig floor, MU to wire. 0.0 0.0 1/3/2025 22:30 1/4/2025 00:00 1.50 COMPZN, RPCOMP SLKL P RIH w/SL D&D, set down @ 7,929', PU RBIH T/7,963' 0.0 0.0 1/4/2025 00:00 1/4/2025 03:30 3.50 COMPZN, RPCOMP SLKL P Walk pressure up down the tubing, IA open to bucket, 0.5 bpm/850 psi, 3 bbls away start getting returns up the IA. Shutdown pump, blow down lines do to - 30°F ambient temp SL release plug and pull up hole T/7,850', Walk pressure up down the tubing T/1,000 psi, no flow at the IA, good test, chart 1,000 psi 30 mins Bleed pressure, blow down cement line POOH w/SL, LD hole finder, set catcher, pull SOV, pull catcher POOH, RD SL 0.0 0.0 1/4/2025 03:30 1/4/2025 04:30 1.00 COMPZN, RPCOMP MPSP P Jet stack and prep to set BPV Blow down choke and kill lines. 0.0 0.0 1/4/2025 04:30 1/4/2025 05:00 0.50 COMPZN, RPCOMP MPSP P FMC on location via 2W-3B ice road, Willow Convoy on spine road between CPF3-1Q-pad. Bring setting tools and plug to the rig floor Set HP-BPV 0.0 0.0 1/4/2025 05:00 1/4/2025 05:30 0.50 COMPZN, RPCOMP MPSP P Test HP-BPV in the direction of flow, unable to obtain test, perform rolling test of 750 psi. 0.0 0.0 1/4/2025 05:30 1/4/2025 06:00 0.50 COMPZN, RPCOMP RURD P Blow down surface lines. 0.0 0.0 1/4/2025 06:00 1/4/2025 12:00 6.00 COMPZN, RPCOMP SVRG P Clean under rotary table and pits. prep to RDMO. 0.0 0.0 1/4/2025 12:00 1/4/2025 15:30 3.50 COMPZN, RPCOMP NUND P ND BOP's NU adapter and tree test adapter to 5000 PSI for 10 minutes. Pull BPV and install TTP. RU to test tree and Test tree to 5000 PSI 0.0 0.0 1/4/2025 15:30 1/4/2025 19:30 4.00 COMPZN, RPCOMP FRZP P RU LRS and surface lines to F/P verified lines to tankwas clear. Attempt to FP OA pressure up to 1000 PSI pressure leaks off continue to FP. Swap to IA pump 47 BBLS diesel down IA. allow to U-tube for 1 hour. 0.0 0.0 1/4/2025 19:30 1/4/2025 20:30 1.00 COMPZN, RPCOMP FRZP P Flow check tubing and IA, No Flow Blow down and RD hoses 0.0 0.0 1/4/2025 20:30 1/5/2025 00:00 3.50 COMPZN, RPCOMP RURD P Prep sub/pits for move. RD berming, equipment, etc. *** Note: Release rig at mdnight. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/5/2025 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 10,213.0 3K-27 11/29/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post RWO upate 3K-27 1/6/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE:lehallf 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 6.88 41.0 6,190.4 4,101.5 29.70 L-80 BTC PRODUCTION 5.5x4.5"@10053' 5 1/2 4.90 39.2 10,442.0 6,966.1 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 7,937.0 String Max No… 3 1/2 Set Depth … 5,054.9 Tubing Description Tubing - Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.8 36.8 0.14 Hanger 7.000 FMC GEN 4A TUBING HANGER FMC Gen 4 2.900 2,013.5 1,803.4 49.33 Mandrel – GAS LIFT 4.730 3.5" KBG2-9 GLM W/TBG to IA SOV installed 2000 PSI Shear SLB KGB2-9 2.992 7,916.6 5,043.3 56.05 Locator 4.500 LOCATOR Reduced OD Baker 2.992 7,917.7 5,044.0 56.00 Seal - Packoff 4.100 4.12" SEAL ASSEMBLY Spaced out 2' off tag. Baker 2.992 Top (ftKB) 7,920.4 Set Depth … 9,910.0 String Max No… 3 1/2 Set Depth … 6,478.0 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 7,920.4 5,045.5 55.89 PACKER 4.670 ZXP Liner Top Packer (7944.21 COE') 3.000 7,949.9 5,062.2 54.66 HANGER 4.460 Flexlock Liner Hanger 2.980 9,908.3 6,476.4 23.69 ANCHOR 3.990 KBH-22 Baker Anchor Assembly 3.010 Top (ftKB) 9,816.7 Set Depth … 10,034.2 String Max No… 3 1/2 Set Depth … 6,591.3 Tubing Description Tubing – Production 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) 9,974.1 6,536.5 24.18 XO Reducing 2.875 2.441 10,012.1 6,571.2 24.23 GAS LIFT 4.507 CAMCO KBMM 2.347 10,024.5 6,582.4 24.16 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 10,032.3 6,589.6 24.11 SEAL ASSY 4.500 BAKER GBH-22 LOCATOR /SEAL ASSEMBLY w/SBE 3.000 Top (ftKB) 9,910.1 Set Depth … 9,950.0 String Max No… 3 1/2 Set Depth … 6,514.5 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection 3.5 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) 9,910.1 6,478.0 23.71 PACKER 4.260 Baker FAB1 Packer 3.000 9,927.3 6,493.8 23.86 NIPPLE 4.500 Camco 2.75" D-Nipple 2.750 9,945.0 6,510.0 24.02 SHOE 4.500 4.75 Poor Boy OverShot Baker ( 4.31' of Swallow ) 3.910 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) 42.5 42.5 0.17 PATCH - SURFACE CASING SURFACE CASING PATCH: OAL= 79", welded sleeve w/.500 wall X65, 10" pipe 11/7/2009 6.875 7,968.0 5,072.7 54.68 PC LEAK DOYON 142 ISOLATED LEAK IN THE 5-1/2" PC BETWEEN 7968' AND 8017', WITH TEST PACKER ON 3.5" PH6 DP. 6/1/2016 4.900 7,973.0 5,075.6 54.68 TUBING PLUG 2.72" PIIP set at 7975' COE paragon 1/3/2025 0.000 9,947.0 6,511.8 24.03 TUBING CUT CHEMICAL CUT TUBING ON- RIG AT 9947' RKB 5/28/2016 2.440 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,013.5 1,803.4 49.33 1 SOV Botto m latch 1 1/2/2025 SLB BK Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,152.0 10,167.0 6,699.2 6,713.0 A-3, 3K-27 5/8/1997 4.0 IPERF 180 deg. phasing; Oriented (+/-) 90 deg. F/ Lowside, 2 1/8" EnerJet 3K-27, 1/28/2025 1:59:05 PM Vertical schematic (actual) PRODUCTION 5.5x4.5"@10053'; 39.2-10,442.0 IPERF; 10,152.0-10,167.0 GAS LIFT; 10,012.1 TUBING CUT; 9,947.0 NIPPLE; 9,927.3 PACKER; 9,910.1 PC LEAK; 7,968.0 TUBING PLUG; 7,973.0 HANGER; 7,949.9 PACKER; 7,920.4 Seal - Packoff; 7,917.7 SURFACE; 41.0-6,190.4 Mandrel – GAS LIFT; 2,013.5 CONDUCTOR; 42.0-121.0 PATCH - SURFACE CASING; 42.5 Hanger; 36.8 KUP PROD KB-Grd (ft) 41.02 RR Date 4/19/1997 Other Elev… 3K-27 ... TD Act Btm (ftKB) 10,456.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292275100 Wellbore Status PROD Max Angle & MD Incl (°) 59.55 MD (ftKB) 3,200.00 WELLNAME WELLBORE3K-27 Annotation Last WO: End Date 6/4/2016 H2S (ppm) 180 Date 10/29/2015 Comment SSSV: NONE ORIGINATED TRANSMITTAL DATE: 1/27/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5233 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5233 3K-27 50029227510000 Plug Setting Record 2-Jan-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 197-046 T40016 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.28 09:44:13 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-12-31_22205_KRU_3K-27_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22205 KRU 3K-27 50-029-22751-00 Caliper Survey w/ Log Data 31-Dec-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 197-046 T39941 1/9/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.09 08:07:30 -09'00' ORIGINATED TRANSMITTAL DATE: 1/7/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5230 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5230 3K-27 50029227510000 Cement Bond Log 31-Dec-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 197-046 T39938 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.08 08:14:28 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 1 Gluyas, Gavin R (OGC) From:Lau, Jack J (OGC) Sent:Monday, January 6, 2025 9:28 AM To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]Re: 3K-27 Sundry 324-639 Attachments:3K-27 Daily RWO Report 1.5.25.pdf From: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent: Monday, January 6, 2025 9:26 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Jack, I had misunderstood the steps taken the morning of the 4th. The DDT had not yet been completed but a no flow was performed to set the BPV. The DDT as outlined below was completed from 15:30 to 19:30 and passed as shown in the report attached. Thank you, Elliott Tuttle C: 907.252.3347 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Saturday, January 4, 2025 11:36 AM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Elliott – You are approved to RDMO off 3K-27, there is sufficient evidence fluid flow between indigenous strata will not occur. Please keep me informed on the P&A plan. Jack 2 From: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent: Saturday, January 4, 2025 11:21 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Jack, thank you for the call, as we discussed these were the steps taken yesterday/ last night: 1. S/L: Bailed debris down to 7990’ MD a. MU RBP drift, drift to 7988’ MD b. RD S/L 2. MIRU E/L: MU P2P WRBP a. RIH to 7980’ PU and set plug at 7975’ MD b. RD E/L 3. RU and test tubing to 1500psi, bled off quickly. RU and fluid pack IA, OA, T 4. Pressure up on tubing and bleed off quickly TxIA 220psi/ 200psi a. Come online pump .25BPM @ 570psi, 1x1 returns through the IA b. Increase pumps to 1BPM @ 1500psi, 1x1 returns through the IA 5. RU S/L with D&D Hole Finder a. Set Packer at 7963’ MD, pump down tubing .5BPM @ 850psi 3 bbls away start getting returns up the IA b. PUH to 7850’ MD, walk pressure up to 1000psi, no flow up IA. Good test c. Set Catcher and pull SOV 6. Jet Stack and set BPV, perform rolling test down IA to 750psi. BPV holding. 7. Roll in 47Bbls of diesel, RU jumper and let U-tube. OWFF, passed 8. Await orders. Please provide verbal to RDMO as discussed or let me know if you have any questions, thank you! Elliott Tuttle C: 907.252.3347 From: Tuttle, Elliott Sent: Friday, January 3, 2025 10:14 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; victoria.loepp@alaska.gov Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Jack, I submitted the CAP today based on the plan below, but we are running into additional issues. 3 We are currently struggling to get the tubing test as outline below, but we feel that the plug is holding as we are getting one for one returns. We will rig up SL and use a hold finder to determine if the leak is the SOV or seal assembly, but could we verify the plug set in the straddle below the seal assembly in the direction of flow? If it is the SOV, it will be changed out and a tubing test will be retried. If continued failing tubing test, steps as follows:  Pull T>IA SOV from side pocket mandrel at ~2000’  Set BPV in tubing hanger, confirm with rolling test, not to exceed 750psi pump pressure down IA(surface casing FIT of 16ppg @ 4101’ TVD)  ND BOPE, NU Tree/ adapter, and test against BPV to 250/5000psi.  Pull BPV and circulate in freeze protect, 47 bbls of diesel, down IA and rig up jumper to let u-tube.  Observe well for flow for 30 minutes Pressure TVD ppg 3741 6699 10.74 PPG TVD Pressure 6.9 2000 718 11 4699 2688 3405 Drawdown: 336 Psi o  RDMO For reference, the SBHP was taken 11/14/24 as noted on the original sundry. Let me know if you have any questions or concerns. Since no changes will be made to the completion, we will progress with these steps but will not RDMO until verbal has been received. Thank you, Elliott Tuttle C: 907.252.3347 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, December 31, 2024 4:46 PM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Thanks Elliott – Your plan outlined below is approved. Jack From: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent: Tuesday, December 31, 2024 4:22 PM 4 To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Jack, Thank you for being available and willing to talk through this on NYE. Please see attached proposed schematic as we discussed. I pulled the PDC and added the top of the Kuparuk detail as well. Plan forward would be as follows: 1. TOOH with the Test Packer and RBP, laying down DP 2. RU Eline and pull CBL/ MFC from 7900’ to 3000’ RKB a. Attempt to set plug in tubing at 7975’ RKB, below current LT 3. PU 3 ½” Tubing string with 4.12” Seal Assembly and single side pocket mandrel 4. Space out, MU Tubing hanger, Land tubing, RI LD’s test void a. If previously unable RU eline and set WRBP at 7975’ RKB 5. Pressure up tubing and test to 1500psi for 30minutes, chart. Continue to pressure up and shear T>IA SOV @ 2000psi 6. OWFF, ND BOPE, NU Tree and adapter 7. Circ in Diesel FP down tubing and up IA, fill OA with diesel as able. 8. RDMO Thank you, Elliott Tuttle C: 907.252.3347 From: Tuttle, Elliott Sent: Tuesday, December 31, 2024 2:36 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Jack, Please see attached proposed suspend schematic. We would like to seek variance and set primary plug at 7900’ ORKB, and cement through leaving cement on top we can tag. Plan forward: 1. TOOH with Test Packer and RBP 2. RU Eline and pull CBL/ MFC Log 3. TIH with 5.5” Cast Iron Cement Retainer, Set at 7900’ (pending caliper log results) a. Attempt to place 48+ Bbls 15.8ppg Cement below retainer, leaving 1Bbls above retainer, Circulate out excess b. WOC, Tag c. POOH without filling pipe voidage 4. Fill Casing with Diesel as FP to 1280’ RKB 5. RU Dry hole (Dual 7 1/16 Swab Valves) 5 6. RDMO We do not know the condition of the straddle below the ZXP Liner packer at 7920’ RKB so we plan to have adequate cement volume to account for it. Please call when available to discuss. Elliott Tuttle C: 907.252.3347 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, December 31, 2024 9:58 AM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: [EXTERNAL]Re: 3K-27 Sundry 324-639 Elliott - Please send me the daily workover reports and any other information learned implicit to well condition Jack From: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent: Tuesday, December 31, 2024 8:18:36 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: 3K-27 Sundry 324-639 Jack, 3K-27 does have a PC leak. We are still taking steps to identify where the leak is. Can you give me a call today to discuss? Thank you, Elliott Tuttle C: 907.252.3347 From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Sent: Friday, November 22, 2024 9:05 AM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: Fw: [EXTERNAL]Completed Sundry 324-639 Get Outlook for iOS CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 6 From: Christianson, Grace K (OGC) <grace.christianson@alaska.gov> Sent: Friday, November 22, 2024 8:57:10 AM To: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: [EXTERNAL]Completed Sundry 324-639 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello, Attached is the completed Sundry for KRU 3K-27. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska, and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use, or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it without first saving or forwarding it, and so that the AOGCC is aware of the mistake in sending it to you, contact Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). Daily Workover Report 3K-27 SECURITY TYPE: AK Development 491 WBS/AFE: GKA.00546.E.WOOI.DR.RE NETWORK #: 10461031 REPORT #: 14 CorwcoPhillips Rig: NABORS 7ES Active Reference Datum: KB75.30ft REPORT START DATE: 1/4/2025 Objective P&R Tubing with IC -PO repair Start Date Original Spud Date 12/22/2024 00:00 4/9/1997 0000 Well Type WeIISub Type I Field Name Project Desc Estimator AFEaSupp Amt(Cosh Total FH Est (Cost) Development Production KUPARUK P&R Single Completion Elliott Tuttle 2,141,017.94 1,513,783.52 RIVER UNIT Job Phases Phase Op Cotle Actual Start Data Actual End Date Summary P10 End Date Rigs Rig Supervisor Rig Accept Date RR Date Rig Type Seth Burson,Drilling supervisor 12/22/2024 10:00 1/5/2025 00:00 DRILLING Daily Mud Field Est (Cost) Cumulative Mud Cost (Cost) Daily Cost Total (Cost) Cumulative Cost (Cost) 90,556.50 1,513,783.52 AFE Duration Total (days) Days on Location (days) Phase %Complete (ML) (%) Projected Phase End Date (ML) 9.10 14.0 94.5 1/12/2025 Field / AFE % I%) Job Days Ahead (ML) (days) Job % Complete (ML) (%) Projected Job End Date (ML) 70.7 -5.90 93.3 1/6/2025 Head Count Personnel Regular Hours (hr) Cum Problem Time Days (days) Cum Percent Problem Time (%) 22.0 ,264.00 13.021 121.58 Ops and Depth Q Morning Report Days LTI (days) Days RI (days) Days Since Last Spill Waiting to move sub base to I 1,051.00 1051 169 Last 24hr Summary Tested tubing above seal assembly to 1000 PSI. OWFF for 30 minutes, set BPV and performed rolling test. Cleaned and performed general housekeeping on rig. NO BOP's NU tree and adapter. tested both to 5000 PSI. FP TBG and IA to 2000'. Sque22ed 2 BBL's diesel into OA. No flow TxIA, 24hr Forecast RDMO Pits office complex and shop Move sub off well. General Remarks No AIS Weather Temperature (°F) Road Condition Wind Ice/Snow Observation Cards Obsen Type #Rpts Com Company STOP INTERVENTIONS 18 JSA/ GO CARD DISCUSSION 1 16 LIFESAVING RULES VERIFICATION 12 Time Log r me Start End Activity P-T Start Depth End Depth Time Time Dur (hr) Phase Cotle -% Trbl Cotle Trbl Class (flKB) (flKB) Operation Wellbore 00:00 03:30 3.50 COMPZN, RPCOMP SLKL P 0.0 0.0 Walk pressure up down the tubing, IA qr open to bucket, 0.5 bpm/850 psi, 3 this away start getting returns up the IA. Shutdown pump, blow down lines do to - 30°F ambient temp SL release plug and pull up hole T/7,850', Walk pressure up down the tubing T/1,000 psi, no flow at the IA, good test, chart 1,000 psi 30 mins Bleed pressure, blow down cement line POOH w/SL, LID hole finder, set catcher, pull SOV, pull catcher POOH, RD SL 03:30 04:30 1.00 COMPZN, RPCOMP MPSP P 0.0 0.0 Jet stack and prep to set BPV Blow down 3K-27 choke and kill lines. 04:30 05:00 0.50 COMPZN, RPCOMP MPSP P 0.0 0.0 FMC on location via 2W-3B ice road, 3K-27 Willow Convoy on spine road between CPF3-1 Q-pad. Bring setting tools and plug to the rig floor Set HP-BPV 05:00 05:30 0.50 COMPZN, RPCOMP MPSP P 0.0 0.0 Test HP-BPV in the direction of flow, unable to obtain test, perform rolling test of 750 psi. Page 113 Report Printed: 1/6/2025 Daily Workover Report 3K-27 SECURITY TYPE: AK Development WBS/AFE: GKA.00546.E.W001.DR.RE NETWORK #: 10461031 491 REPORT #: 14 CorwcoPhillips Rig: NABORS 7ES Active Reference Datum: KB75.30ft REPORT START DATE: 1/4/2025 Time Log Stan Time End Time our (hr) Phase Activity Code Ti me P-T -x TM Code Trbl Class Start Depth (flKB) End Depth (flKB) Operation Wellbore 05:30 06:00 0.50 COMPZN, RPCOMP RURD P 0.0 0.0 Blow down surface lines. 3K-27 06:00 12:00 6.00 COMPZN, RPCOMP SVRG P 0.0 0.0 Clean under rotary table and pits. prep to RDMO. 3K-27 12:00 15:30 3.50 COMPZN, RPCOMP NUND P 0.0 0.0 ND BOP's NU adapter and tree test adapter to 5000 PSI for 10 minutes. Pull BPV and install TTP. RU to test tree and Test tree to 5000 PSI 3K-27 15:30 19:30 4.00 COMPZN, RPCOMP FRZP P 0.0 0.0 RU LRS and surface lines to F/P verified lines to tankwas clear. Attempt to FP CA pressure up to 1000 PSI pressure leaks off continue to FP. Swap to IA pump 47 BBLS diesel down IA. allow to U-tube for 1 hour. 3K-27 19:30 20:30 1.00 COMPZN, RPCOMP FRZP P 0.0 0.0 Flow check tubing and IA, No Flow Blow down and RD hoses K-27 20:30 00:00 3.50 COMPZN, RPCOMP RURD P 0.0 0.0 Prep sub/pits for move. RD berming, equipment, etc. *** Note: Release rig at mdnight. 3K-27 Supervisor Phone Work Scott Kiser,Wells Supervisor CTD 907-670-6130 Elliott Tuttle,Drilling Engineer ADAMS, MARK,Wells Supervisor 670-6130 Mud Volumes Wellbore Type Volume(bbl) Tank/Additionli-oss Daily Pressures Des i String P(psi) Type Subtype PRODUCTION 5.5x4.5" @10053', 10,442.0ftKB 0.0 SURFACE, 6,190.4ftKB 0.0 FINAL FINAL IIA JUA Tubing -Production set at 7,937.0ffKB on 1/2/2025 10:00 0.0 1 FINAL IT Head Count / Manhours Company Function Personnel Type Name Note Count Time (hr) Totwork Time (hr) ConocoPhillips Company RIG SUPERVISOR 2 12.00 24.00 Nabors Alaska Drilling TOOL PUSHER 2 12.00 24.00 Nabors Alaska Drilling RIG CREW 12 12.00 144.00 Nabors Alaska Drilling SUPPORT CREW 3 12.00 36.00 MI Swaco MUD ENGINEER 2 12.00 24.00 YellowJacket OiKeld SVC FISHING 1 12.00 12.00 Safety Meetings / Operational Checks Date Type Tour Inspected By Des Result Days to Next Check (days) Com 1/4/2025 02:00 Emergency Drill Night S.Kiser Fire Drill Acceptable CRT 75 sec 1/4/2025 14:00 Emergency Drill Day M.Adams Accumlator Drill Acceptable CRT 77 sec Interval Problems Stan Stan Data Depth (flKB) Trouble Code Wellbere Vendor(NPT) Action Taken 12/24/2024 0.0 Well Control System 3K-27 Nabors Alaska Drilling N/D BOP, Pull off of well 12/24/2024 0.0 Wellhead/Tree 3K-27 FMC Corporation Wellhead Equipment Pull Tree test plug. redress and re run. 12/26/2024 0.0 Well Control System 3K-27 Nabors Alaska Drilling N/D stack, rack back, and Change out Choke hose. 12/27/2024 0.0 Wellhead/free 3K-27 FMC Technologies Inc Call out slick line magnet, and retrieve BPV. Fluid I Mud Additive Amounts Des Activity Code Data Rec Consumed Returned Note Daily Cost (Cost) Tubing Strings Tubing - Production set at 9,950.0ftKB on 5/31 /2016 00:00 String Max Nomi.. 31/2 Wt (Ib/ft) 9.30 Grade L-80 Run Job RECOMPLETION-<jobsubtyp> 5/24/201616:00 Wellbore 3K-27 Page 213 Report Printed: 1/612025 Daily Workover Report 3K-27 49, SECURITY TYPE: AK Development WBS/AFE: GKA.00546.E.W001.DR.RE NETWORK #: 10461031 REPORT #: 14 CorwcoPhillips Rig: NABORS 7ES Active Reference Datum: KB75.30ft REPORT START DATE: 1/4/2025 Tubing Strings Tubing — Production set at 9,910.OftKB on 612/2016 00:00 String Max Nomi.. Wt (lb/tt) Grade Run Job Wellbore 3 1/2 9.30 L-80 RECOMPLETION-<jobsubtyp> 5/24/2016 16:00 3K-27 Tubing - Production set at 7,937.OftKB on 1/212025 10:00 String Max Nomi.. Wt)Ib/ft) Grade Run Job Wellbore 31/2 9.30 L-80 RECOMPLETION-<jobsubtyp> 12/22/202400:00Elff 3K-27 Mandrel Inserts Station No/SP Valve I I I M Type Make Wdel W(in) Port Size(in) Run Date TRORun(psi) Latch Type Top(ftKB) Bun(flKB) 1 ISOV I SLB jBK 111 111212025 1 1 Bottom latch 1 2,013.51 2,020.4 Other in Hole - Pull date NULL and sorted by TOP depth ASCD Des Icon OD (in) ID (in) Top (flKB) BM (flKB) Type Run Date Run Job Wellbore PATCH- 7.625 6.875 42.5 52.5 11/7/2009 3K-27 SURFACE CASING PC LEAK N 5.500 4.900 7,968.0 8,017.0 6/1/2016 3K-27 TUBING PLUG + 2.720 0.000 7,973.0 7,980.0 Other 1/3/2025 ECOMPLETION-<jobsubtyp> 12/22/2024 00:00 3K-27 TUBING CUT ® 2.875 2.440 9,947.0 9,948.0 5/28/2016 3K-27 SSSV 3K-27 Page 313 Report Printed: 1/612025 1 Gluyas, Gavin R (OGC) From:Lau, Jack J (OGC) Sent:Monday, January 6, 2025 9:28 AM To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]Re: 3K-27 Sundry 324-639 From: Lau, Jack J (OGC) Sent: Saturday, January 4, 2025 11:36 AM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Elliott – You are approved to RDMO off 3K-27, there is sufficient evidence fluid flow between indigenous strata will not occur. Please keep me informed on the P&A plan. Jack From: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent: Saturday, January 4, 2025 11:21 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Jack, thank you for the call, as we discussed these were the steps taken yesterday/ last night: 1. S/L: Bailed debris down to 7990’ MD a. MU RBP drift, drift to 7988’ MD b. RD S/L 2. MIRU E/L: MU P2P WRBP a. RIH to 7980’ PU and set plug at 7975’ MD b. RD E/L 3. RU and test tubing to 1500psi, bled off quickly. RU and fluid pack IA, OA, T 4. Pressure up on tubing and bleed off quickly TxIA 220psi/ 200psi a. Come online pump .25BPM @ 570psi, 1x1 returns through the IA b. Increase pumps to 1BPM @ 1500psi, 1x1 returns through the IA 5. RU S/L with D&D Hole Finder 2 a. Set Packer at 7963’ MD, pump down tubing .5BPM @ 850psi 3 bbls away start getting returns up the IA b. PUH to 7850’ MD, walk pressure up to 1000psi, no flow up IA. Good test c. Set Catcher and pull SOV 6. Jet Stack and set BPV, perform rolling test down IA to 750psi. BPV holding. 7. Roll in 47Bbls of diesel, RU jumper and let U-tube. OWFF, passed 8. Await orders. Please provide verbal to RDMO as discussed or let me know if you have any questions, thank you! Elliott Tuttle C: 907.252.3347 From: Tuttle, Elliott Sent: Friday, January 3, 2025 10:14 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; victoria.loepp@alaska.gov Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Jack, I submitted the CAP today based on the plan below, but we are running into additional issues. We are currently struggling to get the tubing test as outline below, but we feel that the plug is holding as we are getting one for one returns. We will rig up SL and use a hold finder to determine if the leak is the SOV or seal assembly, but could we verify the plug set in the straddle below the seal assembly in the direction of flow? If it is the SOV, it will be changed out and a tubing test will be retried. If continued failing tubing test, steps as follows:  Pull T>IA SOV from side pocket mandrel at ~2000’  Set BPV in tubing hanger, confirm with rolling test, not to exceed 750psi pump pressure down IA(surface casing FIT of 16ppg @ 4101’ TVD)  ND BOPE, NU Tree/ adapter, and test against BPV to 250/5000psi.  Pull BPV and circulate in freeze protect, 47 bbls of diesel, down IA and rig up jumper to let u-tube.  Observe well for flow for 30 minutes Pressure TVD ppg 3741 6699 10.74 PPG TVD Pressure 6.9 2000 718 11 4699 2688 3405 Drawdown: 336 Psi o  RDMO 3 For reference, the SBHP was taken 11/14/24 as noted on the original sundry. Let me know if you have any questions or concerns. Since no changes will be made to the completion, we will progress with these steps but will not RDMO until verbal has been received. Thank you, Elliott Tuttle C: 907.252.3347 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, December 31, 2024 4:46 PM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Thanks Elliott – Your plan outlined below is approved. Jack From: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent: Tuesday, December 31, 2024 4:22 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Jack, Thank you for being available and willing to talk through this on NYE. Please see attached proposed schematic as we discussed. I pulled the PDC and added the top of the Kuparuk detail as well. Plan forward would be as follows: 1. TOOH with the Test Packer and RBP, laying down DP 2. RU Eline and pull CBL/ MFC from 7900’ to 3000’ RKB a. Attempt to set plug in tubing at 7975’ RKB, below current LT 3. PU 3 ½” Tubing string with 4.12” Seal Assembly and single side pocket mandrel 4. Space out, MU Tubing hanger, Land tubing, RI LD’s test void a. If previously unable RU eline and set WRBP at 7975’ RKB 5. Pressure up tubing and test to 1500psi for 30minutes, chart. Continue to pressure up and shear T>IA SOV @ 2000psi 6. OWFF, ND BOPE, NU Tree and adapter 7. Circ in Diesel FP down tubing and up IA, fill OA with diesel as able. 8. RDMO 4 Thank you, Elliott Tuttle C: 907.252.3347 From: Tuttle, Elliott Sent: Tuesday, December 31, 2024 2:36 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Jack, Please see attached proposed suspend schematic. We would like to seek variance and set primary plug at 7900’ ORKB, and cement through leaving cement on top we can tag. Plan forward: 1. TOOH with Test Packer and RBP 2. RU Eline and pull CBL/ MFC Log 3. TIH with 5.5” Cast Iron Cement Retainer, Set at 7900’ (pending caliper log results) a. Attempt to place 48+ Bbls 15.8ppg Cement below retainer, leaving 1Bbls above retainer, Circulate out excess b. WOC, Tag c. POOH without filling pipe voidage 4. Fill Casing with Diesel as FP to 1280’ RKB 5. RU Dry hole (Dual 7 1/16 Swab Valves) 6. RDMO We do not know the condition of the straddle below the ZXP Liner packer at 7920’ RKB so we plan to have adequate cement volume to account for it. Please call when available to discuss. Elliott Tuttle C: 907.252.3347 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, December 31, 2024 9:58 AM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: [EXTERNAL]Re: 3K-27 Sundry 324-639 Elliott - Please send me the daily workover reports and any other information learned implicit to well condition Jack From: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent: Tuesday, December 31, 2024 8:18:36 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> 5 Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: 3K-27 Sundry 324-639 Jack, 3K-27 does have a PC leak. We are still taking steps to identify where the leak is. Can you give me a call today to discuss? Thank you, Elliott Tuttle C: 907.252.3347 From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Sent: Friday, November 22, 2024 9:05 AM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: Fw: [EXTERNAL]Completed Sundry 324-639 Get Outlook for iOS From: Christianson, Grace K (OGC) <grace.christianson@alaska.gov> Sent: Friday, November 22, 2024 8:57:10 AM To: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: [EXTERNAL]Completed Sundry 324-639 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello, Attached is the completed Sundry for KRU 3K-27. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska, and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use, or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it without first CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 6 saving or forwarding it, and so that the AOGCC is aware of the mistake in sending it to you, contact Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10456 3071 5926' Casing Collapse Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. W ell Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4742 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 121' None 7-5/8" 79' 121' Upper Patch Packer P2P Lower Patch Packer P2P Baker ZXP Liner Top Packer Baker FAB1 SSSV: None 6979' 5926' 3965' 5-1/2" 16" 3-1/2" 3-1/2" 3-1/2" 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025519 197-046 P.O. Box 100360, Anchorage, AK 99510 50-029-22751-00-00 ConocoPhillips Alaska, Inc KRU 3K-27 Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5930'MD/3968'TVD 5950'MD/3978'TVD 7920'MD/5046'TVD 9910'MD6478'TVD Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 4101' Burst 6190' Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size 7934' 9910' 9950' 10034' 10152-10167' 10383' 6699-6713' Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6966' Elliott Tuttle 11/18/2024 6149' 10442' Perforation Depth MD (ft): elliott.tuttle@conocophillips.com RWO/CTD Engineer Subsequent Form Required: Suspension Expiration Date: L-80 L-80 L-80 L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov -DQ By Grace Christianson at 2:50 pm, Jan 03, 2025 325-001 11/18/2024 DSR-1/8/25SFD 1/3/2025 10-404 JJL 1/9/24&': &':IRU-/& Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.01.09 13:45:41 -09'00'01/09/25 RBDMS JSB 011025 3K-27 CAP RWO PTD# 197-046 1. TOOH with the Test Packer and RBP, laying down DP 2. RU Eline and pull CBL/ MFC from 7900’ to 3000’ RKB - holes found at 4184’ and 7607’ a. Attempt to set plug in tubing at 7975’ RKB, below current LT – Unable to. 3. PU 3 ½” Tubing string with 4.12” Seal Assembly and single side pocket mandrel 4. Space out, MU Tubing hanger, Land tubing, RI LD’s test void a. If previously unable RU eline and set WRBP at 7975’ RKB 5. Pressure up tubing and test to 1500psi for 30minutes, chart. Continue to pressure up and shear T>IA SOV @ 2000psi 6. OWFF, ND BOPE, NU Tree and adapter 7. Circ in Diesel FP down tubing and up IA, ?ll OA with diesel as able. 8. RDMO 3K-27 Proposed Suspend Schematic - 12.31.24 - V2.0 COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 121 121 16 15.06 62.5 H-40 Welded Surface 6190.4 4101.5 7 5/8 6.875 29.7 L-80 BTC Production 5.5"10020.7 6578.9 5 1/2 4.95 15.5 L-80 LTC-MOD Production 4.5"10442 6966 4 1/2 3.958 12.7 L-80 EUE-M 8rd Tubing 7918 5040 3 1/2 2.992 9.3 L-80 EUE-M 8rd Wall Loss Depth (ft) 100.0%4184 98.5%7607 88.4%7258 87.6%5266 86.2%7242 Surface Casing: Repair made near surface, externally welded collars 11/6/2009 IC POs Leaking, can currently hold 3000psi in void and lose 100psi over 30minutes 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco KBG-2-9 gas lift mandrels @ ~2000' RKB w/ T>IA SOV @ 2000psi 3 1/2" Baker Bullet Seal Stack (4 1/8" OD) Assembly @ 7918' ORKB Eline Set 3 1/2" plug @ 7975' RKB Existing Completion 3-1/2" x 5-1/2" Baker ZXP Packer @ 7920' RKB Baker KBH-22 Anchor Assembly @ 9908' RKB 3-1/2" x 5-1/2" Baker FAB-1 Packer @ 9910' RKB 3-1/2" Non-Sealing Overshot @ 9945' RKB 2-7/8" x 1" Camco KBMM GLM @ 10012' RKB Camco D Nipple @ 10024' RKB (2.25" min ID) B Baker GBH-22 Seal Assembly & SBE @ 10032' RKB PBTD @ 10376' RKB 7 5/8" Surface Casing 6190' RKB Production Casing 5 1/2" x 4 1/2" 16" Conductor A-sand perfs 10152' - 10167' RKB ϳͬϮϳͬϬϳ͗K^ŚŽĞWƵŵƉĞĚ͕ϮϱďůƐϭϱ͘ϴ ƉƉŐůĂƐƐ'͕ŶŽƋƵŽƚĞĚĚŝĞƐĞů&W sŽůƵŵĞ͕ĞƐƚŝŵĂƚĞĚdKΛϰϵϯϬΖZ< ϰϮďůƐƉƵŵƉĞĚ͕ϭϱ͘ϴůĂƐƐ '͘ƐƐƵŵŝŶŐ'ĂƵŐĞ,ŽůĞ͕ dKƐƚ͗ϴϴϮϵΖZ< dŽƉKĨ<ƵƉĂƌƵŬZĞƐĞƌǀŽŝƌϵϴϴϬΖZ< 1 Christianson, Grace K (OGC) From:Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent:Friday, January 3, 2025 11:50 AM To:Taylor, Jenna Subject:FW: [EXTERNAL]Re: 3K-27 Sundry 324-639 Jenna, Here is the email with the verbal approval, please include or send CAP with this email chain below. Thank you, Elliott Tuttle C: 907.252.3347 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, December 31, 2024 4:46 PM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Thanks Elliott – Your plan outlined below is approved. Jack From: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com > Sent: Tuesday, December 31, 2024 4:22 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com >; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com >; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com >; NSK RWO CM <NSKRWO.CM@conocophillips.com > Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Jack, Thank you for being available and willing to talk through this on NYE. Please see attached proposed schematic as we discussed. I pulled the PDC and added the top of the Kuparuk detail as well. Plan forward would be as follows: 1. TOOH with the Test Packer and RBP, laying down DP 2. RU Eline and pull CBL/ MFC from 7900’ to 3000’ RKB a. Attempt to set plug in tubing at 7975’ RKB, below current LT 3. PU 3 ½” Tubing string with 4.12” Seal Assembly and single side pocket mandrel 4. Space out, MU Tubing hanger, Land tubing, RI LD’s test void 2 a. If previously unable RU eline and set WRBP at 7975’ RKB 5. Pressure up tubing and test to 1500psi for 30minutes, chart. Continue to pressure up and shear T>IA SOV @ 2000psi 6. OWFF, ND BOPE, NU Tree and adapter 7. Circ in Diesel FP down tubing and up IA, fill OA with diesel as able. 8. RDMO Thank you, EElliott Tuttle C: 907.252.3347 From: Tuttle, Elliott Sent: Tuesday, December 31, 2024 2:36 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com >; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com > Subject: RE: [EXTERNAL]Re: 3K-27 Sundry 324-639 Jack, Please see attached proposed suspend schematic. We would like to seek variance and set primary plug at 7900’ ORKB, and cement through leaving cement on top we can tag. Plan forward: 1. TOOH with Test Packer and RBP 2. RU Eline and pull CBL/ MFC Log 3. TIH with 5.5” Cast Iron Cement Retainer, Set at 7900’ (pending caliper log results) a. Attempt to place 48+ Bbls 15.8ppg Cement below retainer, leaving 1Bbls above retainer, Circulate out excess b. WOC, Tag c. POOH without filling pipe voidage 4. Fill Casing with Diesel as FP to 1280’ RKB 5. RU Dry hole (Dual 7 1/16 Swab Valves) 6. RDMO We do not know the condition of the straddle below the ZXP Liner packer at 7920’ RKB so we plan to have adequate cement volume to account for it. Please call when available to discuss. Elliott Tuttle C: 907.252.3347 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, December 31, 2024 9:58 AM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com > Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com >; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com > Subject: [EXTERNAL]Re: 3K-27 Sundry 324-639 Elliott - 3 Please send me the daily workover reports and any other information learned implicit to well condition Jack From: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com > Sent: Tuesday, December 31, 2024 8:18:36 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com >; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com > Subject: 3K-27 Sundry 324-639 Jack, 3K-27 does have a PC leak. We are still taking steps to identify where the leak is. Can you give me a call today to discuss? Thank you, EElliott Tuttle C: 907.252.3347 From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Sent: Friday, November 22, 2024 9:05 AM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com > Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com >; Conklin, Amy A <Amy.A.Conklin@conocophillips.com > Subject: Fw: [EXTERNAL]Completed Sundry 324-639 Get Outlook for iOS From: Christianson, Grace K (OGC) <grace.christianson@alaska.gov> Sent: Friday, November 22, 2024 8:57:10 AM To: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: [EXTERNAL]Completed Sundry 324-639 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello, Attached is the completed Sundry for KRU 3K-27. Thank you, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 4 GGrace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907)793-1230 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska, and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use, or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it without first saving or forwarding it, and so that the AOGCC is aware of the mistake in sending it to you, contact Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 3K-27 JBR 02/03/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 TJ used 2-7/8" and 3-1/2" Accumulator bottles 11 @ 1020 psi Precharge. Blind and Upper rams tested to 5000psi due to changing out of double gate. Test Results TEST DATA Rig Rep:Kelly Coxby/Ralph LanOperator:ConocoPhillips Alaska, Inc.Operator Rep:Seth Burson/Mark Adams Rig Owner/Rig No.:Nabors 7ES PTD#:1970460 DATE:12/27/2024 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopKPS241227100436 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 8.5 MASP: 3071 Sundry No: 324-639 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"P #1 Rams 1 2-7/8" x 5"P #2 Rams 1 Blinds P #3 Rams 1 2-7/8" x 5"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 3-1/8" &2"P Check Valve 0 NA BOP Misc 2 2-1/16" gate P System Pressure P3000 Pressure After Closure P1550 200 PSI Attained P17 Full Pressure Attained P126 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P5 @ 2100 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 P21 #1 Rams P5 #2 Rams P5 #3 Rams P5 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9999 9 9 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10456 3071 5926' 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: 907-263-4742 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 121' None 7-5/8" 79'121' Upper Patch Packer P2P Lower Patch Packer P2P Baker ZXP Liner Top Packer Baker FAB1 SSSV: None 6979'5926'3965' 5-1/2" 16" 3-1/2" 3-1/2" 3-1/2" 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025519 197-046 P.O. Box 100360, Anchorage, AK 99510 50-029-22751-00-00 ConocoPhillips Alaska, Inc KRU 3K-27 Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 5930'MD/3968'TVD 5950'MD/3978'TVD 7920'MD/5046'TVD 9910'MD6478'TVD Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 4101' Burst 6190' Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size 7934' 9910' 9950' 10034' 10152-10167' 10383' 6699-6713' Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6966' Elliott Tuttle 11/18/2024 6149' 10442' Perforation Depth MD (ft): elliott.tuttle@conocophillips.com RWO/CTD Engineer Subsequent Form Required: Suspension Expiration Date: L-80 L-80 L-80 L-80 m n P s 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:07 am, Nov 19, 2024 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: 2024.11.18 12:43:48-09'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 324-6 10:04 am, Nov 19, 2024 JJL 11/19/24 10-404 Witnessed BOP Test to 3500 psi, Annular to 3500 psi. If a PC leak is confirmed notify AOGCC prior to proceeding. X 27 NOV 24 A.Dewhurst 21NOV24 DSR-11/21/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.22 08:58:47 -08'00'11/22/24 RBDMS JSB 112624 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 18, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 3K-27 (PTD# 197-046). This is a resubmittal after questions were raised by Jack Lau with AOGCC on 11/15/24. Well 3K-27 was drilled and completed in December of 1997 by Parker 245 as an A-sand Kuparuk Producer. In 2009, a surface casing repair was made by way of excavation (79" depth). The well was worked over in 2016 by Doyon 142, to swap tubing but lead to a straddle liner to isolate a deep PC leak. In 2019, a tubing leak was found and isolated by a tubing patch in 2020. In 2023, two more tubing leaks were found and fishing of the original patch failed with scale found in the tubing by CT. The IC packoffs are failing to pressure test. A seal-tite job was attempted, but was not successful. If you have any questions or require any further information, please contact me at 907-252-3347. The tubing will be pulled and replaced with a new 3 1/2" string. The IC packoffs will be addressed as well during this RWO. Steps will be taken to confirm PC integrity. 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 the author of this document Location: Date: 2024.11.18 12:44:14 -09'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 3K-27 RWO Procedure Kuparuk Producer P&R Tubing, Replace IC POs PTD #197-046 Page 1 of 3 Completed Pre-Rig Work 1. Set RBP @ 5882’ RKB (above stuck fish), attempt CDDT TxIAxOA, failed – 1/16/24 2. Pulled RBP – 1/18/24 3. Attempt IC-PO Seal tite repair, failed – 2/27/24 4. Function test LD’s/ GN’s, T-POT, T-PPPOT (passed), IC-PPPOT (failed) – 10/4/24 5. MIT-OA to 1800psi, small volume to pressure up, abandon test – 10/6/24 6. Circulate down tubing and up IA, heated NaBr/NaCl monitoring OA – assumption is OA is frozen a. If able, lube and bleed diesel in OA (Unable) – Bleed gas throughout job due to thermal (11/11/24) 7. Bullhead NaCl/ NaBr down tubing through fish – 100Bbls. Record pressures a. Pump small FP (Diesel) down tubing and IA – 4.3Bbls down tubing, 6Bbls down IA (11/11/24) 8. After 4-5 days for well to stabilize, take SBHP above fish @ 5926’ RKB, 3965’ TVD a. 2291psi @ 3965’ TVD (5926’ RKB) – 11/14/24 Remaining Pre-Rig Work 9. Ready well within 48hrs of rig arrival Rig Work MIRU 10. MIRU Nabors 7ES on 3K-27. (No BPV will be set due to internal risk assessment for N7ES MIRU/ RDMO.) 11. Record shut-in pressures on the T & IA. If there is pressure, bleed gas off IA and/or tubing. Circulate KWF as needed above obstruction, then bullhead ~45Bbls+ down tubing and complete 30-minute NFT. Verify well is dead. a. Calculated KWF: 11/14/2024 Updated Pressure Assumed Gradient (ppg) Diff TVD (ft) SBHP (psi) TVD (ft) EMW (ppg) 2291 3965 11.11 *10.2 2734 1450.1 3741.1 6699 10.74 KWF 11.0 ppg *100Bbls of 10.2ppg NaCl/ NaBr was bullheaded down three days prior to SBHP survey taken. 12. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. a. Note: Test pressure is higher than quoted MPSP on 10-403 based on a kill that CT pumped in 2023. Steps will be taken prior to RWO to confirm SBHP prior to MIRU. Retrieve Tubing, Change IC Packoffs 13. Pull BPV, MU landing joint and BOLDS. 14. Pull 3-1/2” tubing down to the seal assembly (~7933’ RKB). a. If unable to pull, RU Eline, make tubing cut above tubing obstruction at ~5925’ RKB 3K-27 RWO Procedure Kuparuk Producer P&R Tubing, Replace IC POs PTD #197-046 Page 2 of 3 b. Pull tubing from shallow cut, then fish remaining tubing out of the hole. 15. Once seals are pulled from sealbore, close BOP rams and bullhead down IAxT KW. OWFF 16. Stop POOH with tubing when tubing weight allows storm packer to be set, set storm packer, test from above and lay down DP. 17. Change out IC packoffs and test void to 3000psi. NU tubing head and BOPE’s. TIH and retrieve storm packer and lay down same, lay down rest of tubing. Cleanout Run/ Test Packer run 18. Perform a Cleanout run if necessary based on tubing condition and dress off 3.5” tubing stub if necessary or confirm sealbore is clean. 19. RIH with a test packer and a seal assembly below it. Stab seals into LT at 7920’ RKB and test PC to 2500psi (charted). If failure is observed, find casing leak with test packer. a. If PC Leak is found above Arctic Pack. (communicating to the OA), a subsidence like repair would be planned, but cannot be executed on this rig up due to inventory of cement equipment. b. If PC leak was found within an acceptable GL lift point, leak would be straddled with a stack packer and seal assembly. – state would be notified and a CAP would be submitted. Install new 3-½” Tubing 20. MU 3 ½” completion with Seal assembly, nipple and GLM’s. RIH and space out tubing hanger. Spot CI pill around Seal Assembly. a. If seals did not pull, stack packer poor boy overshot and polish bore receptacle above packer. b. Once on depth, set packer and space out as needed. c. Land tubing hanger and test PO void to 5000psi. 21. Pressure test tubing to 3000 psi for 5 minutes. 22. Pressure test inner annulus to 2500 psi for 30 minutes on chart or equivalent PSI at lowest point assuming gradient on backside of PC is 8.6ppg. ND BOP, NU Tree 23. Confirm pressure tests, then shear out SOV with pressure differential. 24. Install BPV. 25. ND BOPE. NU tree. 26. Pull BPV, freeze protect well and set BPV if necessary. Plan may be to circulate diesel down to lowest GL point to assist in unloading the well during POP. 27. RDMO. Post-Rig Work 1. RU SL a. Pull ball and rod and RHC plug body b. Set Catcher and install GL design 2. Install well house and flow lines 3. Return well to operations 3K-27 RWO Procedure Kuparuk Producer P&R Tubing, Replace IC POs PTD #197-046 Page 3 of 3 General Well info: Wellhead type/pressure rating: FMC IV, 3K Rated Casing Flange Top Production Engineer: Sydney Autry Surveillance Reservoir Engineer: Kaylie Plunkett Estimated Start Date: 11/26/2024 Workover Engineer: Elliott Tuttle (907-252-3347, 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 the seals, obtain needed barriers, change intermediate packoffs, confirm PC casing integrity and run new 3 ½” upper completion. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed N/A CMIT-TxIAxOA (failed) 1/16/24 MIT-OA – pressured up with low volume, planning a thaw prior to RWO, IC-PO’s are failing – 10/6/2024 IC POT &PPPOT failed – 10/4/2024 TBG POT &PPPOT PASSED – 10/4/2024 MPSP: 3071 psi using 0.1 psi/ft gradient Static BHP: 3247 psi / 6383’ TVD measured on 12/23/2019 – plan to update prior to RWO. Assumption is pressure has gone up based on 11ppg brine being used during a CT unit job dated 12/29/23. 3741psi @ 6699’ TVD (see calculation above) – 11/14/24 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 10,213.0 3K-27 11/29/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Patch, Coil BHA left in hole. 3K-27 12/6/2023 famaj Notes: General & Safety Annotation End Date Last Mod By NOTE:lehallf 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 6.88 41.0 6,190.4 4,101.5 29.70 L-80 BTC PRODUCTION 5.5x4.5"@10053' 5 1/2 4.90 39.2 10,442.0 6,966.1 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 37.2 Set Depth … 7,933.5 Set Depth … 5,052.9 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 37.2 37.2 0.14 HANGER 7.625 FMC Gen IV Hanger 2.992 3,258.2 2,496.7 59.24 GAS LIFT 4.725 Camco 3-1/2 x 1" KBG-2-9 Gaslift Mandrel CAMCO KBG 2-9 2.818 5,452.5 3,702.6 57.33 GAS LIFT 4.725 Camco 3-1/2 x 1" KBG-2-9 Gaslift Mandrel CAMCO KBG 2-9 2.818 6,914.3 4,487.2 55.72 GAS LIFT 4.725 Camco 3-1/2 x 1" KBG-2-9 Gaslift Mandrel CAMCO KBG 2-9 2.818 7,858.5 5,011.5 57.13 GAS LIFT 4.725 Camco 3-1/2 x 1" KBG-2-9 Gaslift Mandrel CAMCO KBG 2-9 2.818 7,914.2 5,042.0 56.15 SEAL ASSY 3.500 Baker 80-40 Seals 19.32' Overall Length 2.920 Top (ftKB) 7,920.4 Set Depth … 9,910.0 Set Depth … 6,478.0 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 7,920.4 5,045.5 55.89 PACKER 4.670 ZXP Liner Top Packer (7944.21 COE') 3.000 7,949.9 5,062.2 54.66 HANGER 4.460 Flexlock Liner Hanger 2.980 9,908.3 6,476.4 23.69 ANCHOR 3.990 KBH-22 Baker Anchor Assembly 3.010 Top (ftKB) 9,816.7 Set Depth … 10,034.2 Set Depth … 6,591.3 String Max No… 3 1/2 Tubing Description Tubing – Production 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) 9,974.1 6,536.5 24.18 XO Reducing 2.875 2.441 10,012.1 6,571.2 24.23 GAS LIFT 4.507 CAMCO KBMM 2.347 10,024.5 6,582.4 24.16 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 10,032.3 6,589.6 24.11 SEAL ASSY 4.500 BAKER GBH-22 LOCATOR /SEAL ASSEMBLY w/SBE 3.000 Top (ftKB) 9,910.1 Set Depth … 9,950.0 Set Depth … 6,514.5 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection 3.5 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) 9,910.1 6,478.0 23.71 PACKER 4.260 Baker FAB1 Packer 3.000 9,927.3 6,493.8 23.86 NIPPLE 4.500 Camco 2.75" D-Nipple 2.750 9,945.0 6,510.0 24.02 SHOE 4.500 4.75 Poor Boy OverShot Baker ( 4.31' of Swallow ) 3.910 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) 42.5 42.5 0.17 PATCH - SURFACE CASING SURFACE CASING PATCH: OAL= 79", welded sleeve w/.500 wall X65, 10" pipe 11/7/2009 6.875 4,082.0 2,940.8 56.59 LEAK Leak found with Relay @ 4082 10/15/2023 0.000 4,190.0 3,000.9 55.81 LEAK Leak found with Relay @ 4190 10/15/2023 0.000 5,461.0 3,707.2 57.25 TUBING LEAK TUBING LEAK AT 5461' CONFIRMED WTH LDL 10/8/2019 2.992 5,926.0 3,965.4 57.27 FISH TJ Disconnect Fish Neck. 2.25" BW Spear to Fish, LImar Hyd Release spear 2.437"- 2.562" Catch attached to Patch. 12/4/2023 0.000 5,930.0 3,967.6 57.50 PACKER - PATCH - UPR (Upper Patch Assembly) 2.72" OD P2P PACKER, XO, Spacer Pipe, & Anchor Latch. (OAL 20.85') CPP3 5305 12/23/2020 1.625 5,933.7 3,969.6 57.72 Spacer Pipe 2-1/16" P110 SPACER PIPE & Anchor Latch ( OAL included in upper patch assembly) CPAL 35162 12/23/2020 1.585 3K-27, 12/6/2023 6:28:32 AM Vertical schematic (actual) PRODUCTION 5.5x4.5"@10053'; 39.2-10,442.0 FLOAT SHOE; 10,440.6- 10,442.0 IPERF; 10,152.0-10,167.0 PBR; 10,031.6-10,052.6 SEAL ASSY; 10,032.2 NIPPLE; 10,024.4 GAS LIFT; 10,012.1 TUBING CUT; 9,947.0 SHOE; 9,945.0 NIPPLE; 9,927.3 PACKER; 9,910.1 ANCHOR; 9,908.3 PC LEAK; 7,968.0 XO Threads; 7,959.9 PACKER; 7,920.4 SEAL ASSY; 7,914.2 GAS LIFT; 7,858.5 GAS LIFT; 6,914.3 SURFACE; 41.0-6,190.4 FLOAT SHOE; 6,189.0-6,190.4 LANDING COLLAR; 6,056.4- 6,057.8 PATCH - LWR PKR (ME); 5,950.0 Spacer Pipe; 5,933.7 TUBING LEAK; 5,938.0 PACKER - PATCH - UPR; 5,930.0 FISH; 5,926.0 TUBING LEAK; 5,461.0 GAS LIFT; 5,452.5 LEAK; 4,190.0 LEAK; 4,082.0 GAS LIFT; 3,258.2 CEMENTER; 1,821.7-1,824.2 CONDUCTOR; 42.0-121.0 PATCH - SURFACE CASING; 42.5 HANGER; 41.0-42.5 HANGER; 37.2 KUP PROD KB-Grd (ft) 41.02 RR Date 4/19/1997 Other Elev… 3K-27 ... TD Act Btm (ftKB) 10,456.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292275100 Wellbore Status PROD Max Angle & MD Incl (°) 59.55 MD (ftKB) 3,200.00 WELLNAME WELLBORE3K-27 Annotation Last WO: End Date 6/4/2016 H2S (ppm) 180 Date 10/29/2015 Comment SSSV: NONE 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) 5,938.0 3,971.9 57.97 TUBING LEAK TUBING LEAK AT 5938' Identified with LDL. 11/21/2020 2.992 5,950.0 3,978.2 58.67 PATCH - LWR PKR (ME) (Lower )2.72" OD P2P PACKER, OAL 4.01', CPP3 5317 12/22/2020 1.625 7,968.0 5,072.7 54.68 PC LEAK DOYON 142 ISOLATED LEAK IN THE 5-1/2" PC BETWEEN 7968' AND 8017', WITH TEST PACKER ON 3.5" PH6 DP. 6/1/2016 4.900 9,947.0 6,511.8 24.03 TUBING CUT CHEMICAL CUT TUBING ON- RIG AT 9947' RKB 5/28/2016 2.440 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) 3,258.2 2,496.7 59.24 1 GAS LIFT OPEN 1 10/16/2023 5,452.5 3,702.6 57.33 2 GAS LIFT OPEN OPEN 1 12/23/2019 6,914.3 4,487.2 55.72 3 GAS LIFT DMY SDK- 1A 1 0.0 6/3/2016 0.000 7,858.5 5,011.5 57.13 4 GAS LIFT DMY SDK- 1A 1 0.0 6/3/2016 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,152.0 10,167.0 6,699.2 6,713.0 A-3, 3K-27 5/8/1997 4.0 IPERF 180 deg. phasing; Oriented (+/-) 90 deg. F/ Lowside, 2 1/8" EnerJet 3K-27, 12/6/2023 6:28:33 AM Vertical schematic (actual) PRODUCTION 5.5x4.5"@10053'; 39.2-10,442.0 FLOAT SHOE; 10,440.6- 10,442.0 IPERF; 10,152.0-10,167.0 PBR; 10,031.6-10,052.6 SEAL ASSY; 10,032.2 NIPPLE; 10,024.4 GAS LIFT; 10,012.1 TUBING CUT; 9,947.0 SHOE; 9,945.0 NIPPLE; 9,927.3 PACKER; 9,910.1 ANCHOR; 9,908.3 PC LEAK; 7,968.0 XO Threads; 7,959.9 PACKER; 7,920.4 SEAL ASSY; 7,914.2 GAS LIFT; 7,858.5 GAS LIFT; 6,914.3 SURFACE; 41.0-6,190.4 FLOAT SHOE; 6,189.0-6,190.4 LANDING COLLAR; 6,056.4- 6,057.8 PATCH - LWR PKR (ME); 5,950.0 Spacer Pipe; 5,933.7 TUBING LEAK; 5,938.0 PACKER - PATCH - UPR; 5,930.0 FISH; 5,926.0 TUBING LEAK; 5,461.0 GAS LIFT; 5,452.5 LEAK; 4,190.0 LEAK; 4,082.0 GAS LIFT; 3,258.2 CEMENTER; 1,821.7-1,824.2 CONDUCTOR; 42.0-121.0 PATCH - SURFACE CASING; 42.5 HANGER; 41.0-42.5 HANGER; 37.2 KUP PROD 3K-27 ... WELLNAME WELLBORE3K-27 3K-27 Existing 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 6190.4 4101.5 7 5/8 6.875 29.7 L-80 BTC BTC Production 5.5"10020.7 6578.9 5 1/2 4.95 15.5 L-80 LTC-MOD LTC-MOD Production 4.5"10442 6966 4 1/2 3.958 12.7 L-80 EUE-M 8rdEUE-M 8rd Tubing 7933.5 5052.9 3 1/2 2.992 9.3 L-80 EUE-M 8rdEUE-M 8rd Existing Completion 3-1/2" 9.3# L-80 Tubing to Surface 3-1/2" x 1" Camco KBG-2-9 GLM @ 3258' RKB 3-1/2" x 1" Camco KBG-2-9 GLM @ 5452' RKB Tubing Leaks @ 5461', 4190', 4082' RKB Tubing Patch with Limar Coil Spear stuck in upper patch packer @ 5926' RKB (0.28" Min ID) Tubing Leak @ 5938' RKB 3-1/2" x 1" Camco KBG-2-9 GLM @ 6914' RKB 3-1/2" x 1" Camco KBG-2-9 GLM @ 7858' RKB Baker 80-40 Seal Assembly @ 7914' RKB 3-1/2" x 5-1/2" Baker ZXP Packer @ 7920' RKB Baker KBH-22 Anchor Assembly @ 9908' RKB 3-1/2" x 5-1/2" Baker FAB-1 Packer @ 9910' RKB 3-1/2" Non-Sealing Overshot @ 9945' RKB 2-7/8" x 1" Camco KBMM GLM @ 10012' RKB Camco D Nipple @ 10024' RKB (2.25" min ID) Baker GBH-22 Seal Assembly & SBE @ 10032' RKB 7 5/8" Surface Casing Production Casing 5 1/2" x 4 1/2" 16" Conductor A-sand perfs 10152' - 10167' RKB Coil spear stuck in patch packer @ ~ 5926' RKB 3K-27 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 6190.4 4101.5 7 5/8 6.875 29.7 L-80 BTC BTC Production 5.5"10020.7 6578.9 5 1/2 4.95 15.5 L-80 LTC-MOD LTC-MOD Production 4.5"10442 6966 4 1/2 3.958 12.7 L-80 EUE-M 8rdEUE-M 8rd Tubing 7933.5 5052.9 3 1/2 2.992 9.3 L-80 EUE-M 8rdEUE-M 8rd PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco KBG-2-9 gas lift mandrels @ TBD 3-½" X Landing Nipple 3 1/2" Baker 80-40 Seal Assembly REMAINING COMPLETION LEFT IN HOLE 3-1/2" x 5-1/2" Baker ZXP Packer @ 7920' RKB Baker KBH-22 Anchor Assembly @ 9908' RKB 3-1/2" x 5-1/2" Baker FAB-1 Packer @ 9910' RKB 3-1/2" Non-Sealing Overshot @ 9945' RKB 2-7/8" x 1" Camco KBMM GLM @ 10012' RKB Camco D Nipple @ 10024' RKB (2.25" min ID) 7 5/8" Surface Casing Production Casing 5 1/2" x 4 1/2" 16" Conductor A-sand perfs 10152' - 10167' RKB Originated: Delivered to:1ͲMarͲ24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 13KͲ27 50Ͳ029Ͳ22751Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 15ͲJanͲ24 0 1 23MͲ05 50Ͳ029Ͳ21706Ͳ00 n/a Kuparuk River Multi Finger Caliper Field & Processed 13ͲFebͲ24 0 1 33MͲ05 50Ͳ029Ͳ21706Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 16ͲFebͲ24 0 1 43MͲ05 50Ͳ029Ͳ21706Ͳ00 n/a Kuparuk River SBHP Record FieldͲFinal 9ͲFebͲ24 0 1 5 6 7 8 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T38573 T38573 T38573 187-025 T38573 197-046 T38574 T38754 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 14:47:55 -09'00' 197-046 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: Seal-Tite IC-PO 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A KRU 3K-27 Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk River Field Kuparuk River Oil 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8172 6836 5926 3965 Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Jan Byrne Contact Email:jan.byrne@conocophillips.com Contact Phone:1-907-265-6471 Authorized Title: Well Integrity Specialist Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 3.5 Baker F Packer, No SSV 8146 Perforation Depth MD (ft): 7849 - 7918 8113 6571 - 6627 Perforation Depth TVD (ft): 68147 16 12 79 4672 MD 115 4090 115 4707 Length Size Proposed Pools: L-80 TVD Burst 7635 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025519 197-046 P.O. Box 100360, Anchorage, Alaska 99510 50-029-22751-00-00 ConcoPhillips Alaska, Inc Kuparuk River Oil AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 7620 MD/ 6386 TVD 1/31/2024 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY m n P s 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Jan Byrne DN: OU=Wells AK, O=ConocoPhillips, CN=Jan Byrne, E= jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2024.01.23 11:17:56-09'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne 324-030 By Grace Christianson at 1:52 pm, Jan 23, 2024 4,101' 6,979' SFD 10,422' SFD 121' 2616 SFD 1/26/2024 6,948' SFD 10,456' SFD 6,190' 10-404 VTL 02/15/2024 DSR-1/26/24 X 121' *&:JLC 2/16/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.16 13:27:34 -06'00'02/16/24 RBDMS JSB 022024 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 23, 2024 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 3K-27 (PTD 197-046) to apply Seal-Tite to the inner casing pack off to repair IAxOA communication. Please contact me at 265-6471 if you have any questions. Sincerely, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Proposal Summary for 3K-27 Seal-Tite repair of the inner casing pack o ī History: 3K-27 currently has TxIAxOA communicaƟon. AƩempts at retrieving a stuck patch in the tubing have been unsuccessful. To miƟgate risk while awaiƟng a RWO CPAI intends to repair the IAxOA communicaƟon with Seal-Tite. TesƟng has proven that the inner casing pack oī tracks both the IA and OA pressures and is believed to be the main if not sole source of the IAxOA communicaƟon. ObjecƟve: Apply Seal-Tite into the inner casing pack oī void to seal oī any leaks and regain inner casing pack oī integrity. Proposal steps: 1. Place heater over wellhead for 12 hours prior to operaƟon. 2. Fill inner casing pack oī (IC-PO) void with Seal-Tite sealant. 3. Increase pressure in 500 to 1000 psi steps and hold for a minimum of 15 minutes per step. 4. Once the IC-PO is holding 3000 psi or a 1000 psi Dp minimum, cycle the IC-PO pressure from 0 psi to test pressure several Ɵmes. 5. Lock in test pressure and allow seal to cure for 6 hours. 6. Bleed pressures oī IC-PO and monitor for pressure increase. 7. Remove heater from wellhead and monitor for pressure increase. 8. If any pressure increase is observed during these steps addiƟonal Seal-Tite will be applied. 9. Once IC-PO is observed to be staƟc and the well is thermally stable, bleed the OA pressure a minimum of 500 psi below the IA pressure to verify integrity. 10. Well will remain shut in awaiƟng RWO. 11. Submit 10-404 to AOGCC. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 10,213.0 3K-27 11/29/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Patch, Coil BHA left in hole. 3K-27 12/6/2023 famaj Notes: General & Safety Annotation End Date Last Mod By NOTE:lehallf 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 6.88 41.0 6,190.4 4,101.5 29.70 L-80 BTC PRODUCTION 5.5x4.5"@10053' 5 1/2 4.90 39.2 10,442.0 6,966.1 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 37.2 Set Depth … 7,933.5 Set Depth … 5,052.9 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 37.2 37.2 0.14 HANGER 7.625 FMC Gen IV Hanger 2.992 3,258.2 2,496.7 59.24 GAS LIFT 4.725 Camco 3-1/2 x 1" KBG-2-9 Gaslift Mandrel CAMCO KBG 2-9 2.818 5,452.5 3,702.6 57.33 GAS LIFT 4.725 Camco 3-1/2 x 1" KBG-2-9 Gaslift Mandrel CAMCO KBG 2-9 2.818 6,914.3 4,487.2 55.72 GAS LIFT 4.725 Camco 3-1/2 x 1" KBG-2-9 Gaslift Mandrel CAMCO KBG 2-9 2.818 7,858.5 5,011.5 57.13 GAS LIFT 4.725 Camco 3-1/2 x 1" KBG-2-9 Gaslift Mandrel CAMCO KBG 2-9 2.818 7,914.2 5,042.0 56.15 SEAL ASSY 3.500 Baker 80-40 Seals 19.32' Overall Length 2.920 Top (ftKB) 7,920.4 Set Depth … 9,910.0 Set Depth … 6,478.0 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 7,920.4 5,045.5 55.89 PACKER 4.670 ZXP Liner Top Packer (7944.21 COE') 3.000 7,949.9 5,062.2 54.66 HANGER 4.460 Flexlock Liner Hanger 2.980 9,908.3 6,476.4 23.69 ANCHOR 3.990 KBH-22 Baker Anchor Assembly 3.010 Top (ftKB) 9,816.7 Set Depth … 10,034.2 Set Depth … 6,591.3 String Max No… 3 1/2 Tubing Description Tubing – Production 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) 9,974.1 6,536.5 24.18 XO Reducing 2.875 2.441 10,012.1 6,571.2 24.23 GAS LIFT 4.507 CAMCO KBMM 2.347 10,024.5 6,582.4 24.16 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 10,032.3 6,589.6 24.11 SEAL ASSY 4.500 BAKER GBH-22 LOCATOR /SEAL ASSEMBLY w/SBE 3.000 Top (ftKB) 9,910.1 Set Depth … 9,950.0 Set Depth … 6,514.5 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection 3.5 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) 9,910.1 6,478.0 23.71 PACKER 4.260 Baker FAB1 Packer 3.000 9,927.3 6,493.8 23.86 NIPPLE 4.500 Camco 2.75" D-Nipple 2.750 9,945.0 6,510.0 24.02 SHOE 4.500 4.75 Poor Boy OverShot Baker ( 4.31' of Swallow ) 3.910 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) 42.5 42.5 0.17 PATCH - SURFACE CASING SURFACE CASING PATCH: OAL= 79", welded sleeve w/.500 wall X65, 10" pipe 11/7/2009 6.875 4,082.0 2,940.8 56.59 LEAK Leak found with Relay @ 4082 10/15/2023 0.000 4,190.0 3,000.9 55.81 LEAK Leak found with Relay @ 4190 10/15/2023 0.000 5,461.0 3,707.2 57.25 TUBING LEAK TUBING LEAK AT 5461' CONFIRMED WTH LDL 10/8/2019 2.992 5,926.0 3,965.4 57.27 FISH TJ Disconnect Fish Neck. 2.25" BW Spear to Fish, LImar Hyd Release spear 2.437"- 2.562" Catch attached to Patch. 12/4/2023 0.000 5,930.0 3,967.6 57.50 PACKER - PATCH - UPR (Upper Patch Assembly) 2.72" OD P2P PACKER, XO, Spacer Pipe, & Anchor Latch. (OAL 20.85') CPP3 5305 12/23/2020 1.625 5,933.7 3,969.6 57.72 Spacer Pipe 2-1/16" P110 SPACER PIPE & Anchor Latch ( OAL included in upper patch assembly) CPAL 35162 12/23/2020 1.585 3K-27, 12/6/2023 6:28:32 AM Vertical schematic (actual) PRODUCTION 5.5x4.5"@10053'; 39.2-10,442.0 FLOAT SHOE; 10,440.6- 10,442.0 IPERF; 10,152.0-10,167.0 PBR; 10,031.6-10,052.6 SEAL ASSY; 10,032.2 NIPPLE; 10,024.4 GAS LIFT; 10,012.1 TUBING CUT; 9,947.0 SHOE; 9,945.0 NIPPLE; 9,927.3 PACKER; 9,910.1 ANCHOR; 9,908.3 PC LEAK; 7,968.0 XO Threads; 7,959.9 PACKER; 7,920.4 SEAL ASSY; 7,914.2 GAS LIFT; 7,858.5 GAS LIFT; 6,914.3 SURFACE; 41.0-6,190.4 FLOAT SHOE; 6,189.0-6,190.4 LANDING COLLAR; 6,056.4- 6,057.8 PATCH - LWR PKR (ME); 5,950.0 Spacer Pipe; 5,933.7 TUBING LEAK; 5,938.0 PACKER - PATCH - UPR; 5,930.0 FISH; 5,926.0 TUBING LEAK; 5,461.0 GAS LIFT; 5,452.5 LEAK; 4,190.0 LEAK; 4,082.0 GAS LIFT; 3,258.2 CEMENTER; 1,821.7-1,824.2 CONDUCTOR; 42.0-121.0 PATCH - SURFACE CASING; 42.5 HANGER; 41.0-42.5 HANGER; 37.2 KUP PROD KB-Grd (ft) 41.02 RR Date 4/19/1997 Other Elev… 3K-27 ... TD Act Btm (ftKB) 10,456.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292275100 Wellbore Status PROD Max Angle & MD Incl (°) 59.55 MD (ftKB) 3,200.00 WELLNAME WELLBORE3K-27 Annotation Last WO: End Date 6/4/2016 H2S (ppm) 180 Date 10/29/2015 Comment SSSV: NONE 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) 5,938.0 3,971.9 57.97 TUBING LEAK TUBING LEAK AT 5938' Identified with LDL. 11/21/2020 2.992 5,950.0 3,978.2 58.67 PATCH - LWR PKR (ME) (Lower )2.72" OD P2P PACKER, OAL 4.01', CPP3 5317 12/22/2020 1.625 7,968.0 5,072.7 54.68 PC LEAK DOYON 142 ISOLATED LEAK IN THE 5-1/2" PC BETWEEN 7968' AND 8017', WITH TEST PACKER ON 3.5" PH6 DP. 6/1/2016 4.900 9,947.0 6,511.8 24.03 TUBING CUT CHEMICAL CUT TUBING ON- RIG AT 9947' RKB 5/28/2016 2.440 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) 3,258.2 2,496.7 59.24 1 GAS LIFT OPEN 1 10/16/2023 5,452.5 3,702.6 57.33 2 GAS LIFT OPEN OPEN 1 12/23/2019 6,914.3 4,487.2 55.72 3 GAS LIFT DMY SDK- 1A 1 0.0 6/3/2016 0.000 7,858.5 5,011.5 57.13 4 GAS LIFT DMY SDK- 1A 1 0.0 6/3/2016 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,152.0 10,167.0 6,699.2 6,713.0 A-3, 3K-27 5/8/1997 4.0 IPERF 180 deg. phasing; Oriented (+/-) 90 deg. F/ Lowside, 2 1/8" EnerJet 3K-27, 12/6/2023 6:28:33 AM Vertical schematic (actual) PRODUCTION 5.5x4.5"@10053'; 39.2-10,442.0 FLOAT SHOE; 10,440.6- 10,442.0 IPERF; 10,152.0-10,167.0 PBR; 10,031.6-10,052.6 SEAL ASSY; 10,032.2 NIPPLE; 10,024.4 GAS LIFT; 10,012.1 TUBING CUT; 9,947.0 SHOE; 9,945.0 NIPPLE; 9,927.3 PACKER; 9,910.1 ANCHOR; 9,908.3 PC LEAK; 7,968.0 XO Threads; 7,959.9 PACKER; 7,920.4 SEAL ASSY; 7,914.2 GAS LIFT; 7,858.5 GAS LIFT; 6,914.3 SURFACE; 41.0-6,190.4 FLOAT SHOE; 6,189.0-6,190.4 LANDING COLLAR; 6,056.4- 6,057.8 PATCH - LWR PKR (ME); 5,950.0 Spacer Pipe; 5,933.7 TUBING LEAK; 5,938.0 PACKER - PATCH - UPR; 5,930.0 FISH; 5,926.0 TUBING LEAK; 5,461.0 GAS LIFT; 5,452.5 LEAK; 4,190.0 LEAK; 4,082.0 GAS LIFT; 3,258.2 CEMENTER; 1,821.7-1,824.2 CONDUCTOR; 42.0-121.0 PATCH - SURFACE CASING; 42.5 HANGER; 41.0-42.5 HANGER; 37.2 KUP PROD 3K-27 ... WELLNAME WELLBORE3K-27 3K-27 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 3K-27 2023-11-16 960 750 -210 OA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 10,213.0 3K-27 11/29/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Patch, Coil BHA left in hole. 3K-27 12/6/2023 famaj Notes: General & Safety Annotation End Date Last Mod By NOTE:lehallf 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 6.88 41.0 6,190.4 4,101.5 29.70 L-80 BTC PRODUCTION 5.5x4.5"@10053' 5 1/2 4.90 39.2 10,442.0 6,966.1 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 37.2 Set Depth … 7,933.5 Set Depth … 5,052.9 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 37.2 37.2 0.14 HANGER 7.625 FMC Gen IV Hanger 2.992 3,258.2 2,496.7 59.24 GAS LIFT 4.725 Camco 3-1/2 x 1" KBG-2-9 Gaslift Mandrel CAMCO KBG 2-9 2.818 5,452.5 3,702.6 57.33 GAS LIFT 4.725 Camco 3-1/2 x 1" KBG-2-9 Gaslift Mandrel CAMCO KBG 2-9 2.818 6,914.3 4,487.2 55.72 GAS LIFT 4.725 Camco 3-1/2 x 1" KBG-2-9 Gaslift Mandrel CAMCO KBG 2-9 2.818 7,858.5 5,011.5 57.13 GAS LIFT 4.725 Camco 3-1/2 x 1" KBG-2-9 Gaslift Mandrel CAMCO KBG 2-9 2.818 7,914.2 5,042.0 56.15 SEAL ASSY 3.500 Baker 80-40 Seals 19.32' Overall Length 2.920 Top (ftKB) 7,920.4 Set Depth … 9,910.0 Set Depth … 6,478.0 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 7,920.4 5,045.5 55.89 PACKER 4.670 ZXP Liner Top Packer (7944.21 COE') 3.000 7,949.9 5,062.2 54.66 HANGER 4.460 Flexlock Liner Hanger 2.980 9,908.3 6,476.4 23.69 ANCHOR 3.990 KBH-22 Baker Anchor Assembly 3.010 Top (ftKB) 9,816.7 Set Depth … 10,034.2 Set Depth … 6,591.3 String Max No… 3 1/2 Tubing Description Tubing – Production 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) 9,974.1 6,536.5 24.18 XO Reducing 2.875 2.441 10,012.1 6,571.2 24.23 GAS LIFT 4.507 CAMCO KBMM 2.347 10,024.5 6,582.4 24.16 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 10,032.3 6,589.6 24.11 SEAL ASSY 4.500 BAKER GBH-22 LOCATOR /SEAL ASSEMBLY w/SBE 3.000 Top (ftKB) 9,910.1 Set Depth … 9,950.0 Set Depth … 6,514.5 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection 3.5 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) 9,910.1 6,478.0 23.71 PACKER 4.260 Baker FAB1 Packer 3.000 9,927.3 6,493.8 23.86 NIPPLE 4.500 Camco 2.75" D-Nipple 2.750 9,945.0 6,510.0 24.02 SHOE 4.500 4.75 Poor Boy OverShot Baker ( 4.31' of Swallow ) 3.910 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) 42.5 42.5 0.17 PATCH - SURFACE CASING SURFACE CASING PATCH: OAL= 79", welded sleeve w/.500 wall X65, 10" pipe 11/7/2009 6.875 4,082.0 2,940.8 56.59 LEAK Leak found with Relay @ 4082 10/15/2023 0.000 4,190.0 3,000.9 55.81 LEAK Leak found with Relay @ 4190 10/15/2023 0.000 5,461.0 3,707.2 57.25 TUBING LEAK TUBING LEAK AT 5461' CONFIRMED WTH LDL 10/8/2019 2.992 5,926.0 3,965.4 57.27 FISH TJ Disconnect Fish Neck. 2.25" BW Spear to Fish, LImar Hyd Release spear 2.437"- 2.562" Catch attached to Patch. 12/4/2023 0.000 5,930.0 3,967.6 57.50 PACKER - PATCH - UPR (Upper Patch Assembly) 2.72" OD P2P PACKER, XO, Spacer Pipe, & Anchor Latch. (OAL 20.85') CPP3 5305 12/23/2020 1.625 5,933.7 3,969.6 57.72 Spacer Pipe 2-1/16" P110 SPACER PIPE & Anchor Latch ( OAL included in upper patch assembly) CPAL 35162 12/23/2020 1.585 3K-27, 12/6/2023 6:28:32 AM Vertical schematic (actual) PRODUCTION 5.5x4.5"@10053'; 39.2-10,442.0 FLOAT SHOE; 10,440.6- 10,442.0 IPERF; 10,152.0-10,167.0 PBR; 10,031.6-10,052.6 SEAL ASSY; 10,032.2 NIPPLE; 10,024.4 GAS LIFT; 10,012.1 TUBING CUT; 9,947.0 SHOE; 9,945.0 NIPPLE; 9,927.3 PACKER; 9,910.1 ANCHOR; 9,908.3 PC LEAK; 7,968.0 XO Threads; 7,959.9 PACKER; 7,920.4 SEAL ASSY; 7,914.2 GAS LIFT; 7,858.5 GAS LIFT; 6,914.3 SURFACE; 41.0-6,190.4 FLOAT SHOE; 6,189.0-6,190.4 LANDING COLLAR; 6,056.4- 6,057.8 PATCH - LWR PKR (ME); 5,950.0 Spacer Pipe; 5,933.7 TUBING LEAK; 5,938.0 PACKER - PATCH - UPR; 5,930.0 FISH; 5,926.0 TUBING LEAK; 5,461.0 GAS LIFT; 5,452.5 LEAK; 4,190.0 LEAK; 4,082.0 GAS LIFT; 3,258.2 CEMENTER; 1,821.7-1,824.2 CONDUCTOR; 42.0-121.0 PATCH - SURFACE CASING; 42.5 HANGER; 41.0-42.5 HANGER; 37.2 KUP PROD KB-Grd (ft) 41.02 RR Date 4/19/1997 Other Elev… 3K-27 ... TD Act Btm (ftKB) 10,456.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292275100 Wellbore Status PROD Max Angle & MD Incl (°) 59.55 MD (ftKB) 3,200.00 WELLNAME WELLBORE3K-27 Annotation Last WO: End Date 6/4/2016 H2S (ppm) 180 Date 10/29/2015 Comment SSSV: NONE 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) 5,938.0 3,971.9 57.97 TUBING LEAK TUBING LEAK AT 5938' Identified with LDL. 11/21/2020 2.992 5,950.0 3,978.2 58.67 PATCH - LWR PKR (ME) (Lower )2.72" OD P2P PACKER, OAL 4.01', CPP3 5317 12/22/2020 1.625 7,968.0 5,072.7 54.68 PC LEAK DOYON 142 ISOLATED LEAK IN THE 5-1/2" PC BETWEEN 7968' AND 8017', WITH TEST PACKER ON 3.5" PH6 DP. 6/1/2016 4.900 9,947.0 6,511.8 24.03 TUBING CUT CHEMICAL CUT TUBING ON- RIG AT 9947' RKB 5/28/2016 2.440 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) 3,258.2 2,496.7 59.24 1 GAS LIFT OPEN 1 10/16/2023 5,452.5 3,702.6 57.33 2 GAS LIFT OPEN OPEN 1 12/23/2019 6,914.3 4,487.2 55.72 3 GAS LIFT DMY SDK- 1A 1 0.0 6/3/2016 0.000 7,858.5 5,011.5 57.13 4 GAS LIFT DMY SDK- 1A 1 0.0 6/3/2016 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,152.0 10,167.0 6,699.2 6,713.0 A-3, 3K-27 5/8/1997 4.0 IPERF 180 deg. phasing; Oriented (+/-) 90 deg. F/ Lowside, 2 1/8" EnerJet 3K-27, 12/6/2023 6:28:33 AM Vertical schematic (actual) PRODUCTION 5.5x4.5"@10053'; 39.2-10,442.0 FLOAT SHOE; 10,440.6- 10,442.0 IPERF; 10,152.0-10,167.0 PBR; 10,031.6-10,052.6 SEAL ASSY; 10,032.2 NIPPLE; 10,024.4 GAS LIFT; 10,012.1 TUBING CUT; 9,947.0 SHOE; 9,945.0 NIPPLE; 9,927.3 PACKER; 9,910.1 ANCHOR; 9,908.3 PC LEAK; 7,968.0 XO Threads; 7,959.9 PACKER; 7,920.4 SEAL ASSY; 7,914.2 GAS LIFT; 7,858.5 GAS LIFT; 6,914.3 SURFACE; 41.0-6,190.4 FLOAT SHOE; 6,189.0-6,190.4 LANDING COLLAR; 6,056.4- 6,057.8 PATCH - LWR PKR (ME); 5,950.0 Spacer Pipe; 5,933.7 TUBING LEAK; 5,938.0 PACKER - PATCH - UPR; 5,930.0 FISH; 5,926.0 TUBING LEAK; 5,461.0 GAS LIFT; 5,452.5 LEAK; 4,190.0 LEAK; 4,082.0 GAS LIFT; 3,258.2 CEMENTER; 1,821.7-1,824.2 CONDUCTOR; 42.0-121.0 PATCH - SURFACE CASING; 42.5 HANGER; 41.0-42.5 HANGER; 37.2 KUP PROD 3K-27 ... WELLNAME WELLBORE3K-27 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Byrne, Jan To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]KRU 3K-27 (PTD 197-046, Sundry 324-030) Date:Thursday, February 15, 2024 9:51:20 AM Attachments:AnnComm Surveillance TIO for 3K-27.pdf You don't often get email from jan.byrne@conocophillips.com. Learn why this is important Victoria, I’ve attached the 90-day TIO trend. There were some bad weather days in January where Operations was not able to access the well for pressures that are reflected in the TIO trend. The MPSP= 2616 psi. Please let me know if you need anything else, thank you for working this sundry. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, February 14, 2024 12:44 PM To: Byrne, Jan <Jan.Byrne@conocophillips.com> Subject: [EXTERNAL]KRU 3K-27 (PTD 197-046, Sundry 324-030) CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Jan, Please provide MPSP and latest TIO plot. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 13KͲ26 50Ͳ029Ͳ22764Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 16ͲJulͲ23 0 1 23KͲ27 50Ͳ029Ͳ22751Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 15ͲOctͲ23 0 1 33OͲ18 50Ͳ029Ͳ21793Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 19ͲNovͲ23 0 1 4WSWͲ06 50Ͳ029Ͳ20851Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 13ͲOctͲ23 0 1 5 6 7 8 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 1. 3K-36 PTD: 197-077 T38175 2. 3K-27 PTD: 197-046 T38176 3. 3O-18 PTD: 188-026 T38177 4. WSW-06 PTD:182-177 T38178 12/1/2023 23KͲ27 50Ͳ029Ͳ22751Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲ Final 15ͲOctͲ23 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 12:13:24 -09'00' Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-06 50-029-21336-00 906905927 Kuparuk River Multi Finger Caliper Field & Processed 6-Jan-21 0 1 2 3B-06 50-029-21336-00 906953734 Kuparuk River Packer Setting Record Field- Final 1-Feb-21 0 1 3 3K-03 50-029-21602-00 906961911 Kuparuk River Multi Finger Caliper Field & Processed 9-Feb-21 0 1 4 3K-27 50-029-22751-00 906880550 Kuparuk River Packer Setting Record Field- Final 22-Dec-20 0 1 5 3M-17 50-029-21729-00 906892184 Kuparuk River Packer Setting Record Field- Final 29-Dec-20 0 1 6 3M-17 50-029-21729-00 906892184 Kuparuk River Temperature Record Field- Final 30-Dec-20 0 1 7 3N-02A 50-029-21527-01 906798653 Kuparuk River Packer Setting Record Field- Final 31-Dec-20 0 1 8 3O-20 50-029-22750-00 906941859 Kuparuk River Multi Finger Caliper Field & Processed 24-Jan-21 0 1 9 3N-07A 50-029-21539-01 906604302 Kuparuk River String Shot Record Revised 16-Jul-20 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 1970460 E-Set: 34739 Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3H-26 50-103-20208-00 906832308 Kuparuk River Patch Setting Record Field- Final 23-Nov-20 0 1 2 3K-27 50-029-22751-00 906831229 Kuparuk River Multi Finger Caliper Field & Processed 20-Nov-20 0 1 3 3K-27 50-029-22751-00 906831376 Kuparuk River Leak Detect Log Field- Final 21-Nov-20 0 1 4 3M-17 50-029-21729-00 906811709 Kuparuk River Leak Detect Log Field- Final 28-Nov-20 0 1 5 3N-02A 50-029-21527-01 906813982 Kuparuk River Leak Detect Log Field- Final 30-Nov-20 0 1 6 3N-02A 50-029-21527-01 906804224 Kuparuk River Packer Setting Record Field- Final 5-Nov-20 0 1 7 3S-07 50-103-20430-00 906801235 Kuparuk River Leak Detect Log Field- Final 4-Nov-20 0 1 8 3S-07 50-103-20430-00 906806709 Kuparuk River Packer Setting Record Field- Final 7-Nov-20 0 1 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 01/08/2021 01/11/2021 Abby Bell PTD: 1970460 E-Set: 34559 Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3H-26 50-103-20208-00 906832308 Kuparuk River Patch Setting Record Field- Final 23-Nov-20 0 1 2 3K-27 50-029-22751-00 906831229 Kuparuk River Multi Finger Caliper Field & Processed 20-Nov-20 0 1 3 3K-27 50-029-22751-00 906831376 Kuparuk River Leak Detect Log Field- Final 21-Nov-20 0 1 4 3M-17 50-029-21729-00 906811709 Kuparuk River Leak Detect Log Field- Final 28-Nov-20 0 1 5 3N-02A 50-029-21527-01 906813982 Kuparuk River Leak Detect Log Field- Final 30-Nov-20 0 1 6 3N-02A 50-029-21527-01 906804224 Kuparuk River Packer Setting Record Field- Final 5-Nov-20 0 1 7 3S-07 50-103-20430-00 906801235 Kuparuk River Leak Detect Log Field- Final 4-Nov-20 0 1 8 3S-07 50-103-20430-00 906806709 Kuparuk River Packer Setting Record Field- Final 7-Nov-20 0 1 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 01/08/2021 01/11/2021 Abby Bell PTD: 1970460 E-Set: 34558 32%2; 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Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE 1 3A-08 50-029-21445-00 1 Kuparuk Multi Finger Caliper 2 1 906323212 3 -Feb -20 Radial Cement Bond Log 30 -Dec -19 0 1 Final -Field SBHP and Plug Setting Record 4 3K-23 50-029-22771-00 Kuparuk 906290370 String Shot Record 0 1 Final -Field 5 0 1 906290370 Tubing Punch Record 6 3K -27I 029-22751-00 Kuparuk Packer Set Record 7 8 3N-09029-21541-00 905268412 Kuparuk Packer Set Record 9 3N-15029-21592-00 906251137 Kuparuk Packer Set Record 0 3M-17029-21729-00 906236139 Kuparuk Packer Set Record Transmittal Date: RECEIVED APR 2 32020 AOGCC 197046 32005 23 -Apr -20 DATA TYPE LOGGING DATE PRINTS # CD # Final -Field 15 -Feb -20 0 1 Final -Field 18 -Feb -20 0 1 21 -Jan -20 2 -Feb -20 3 -Feb -20 Final -Field 30 -Dec -19 0 1 Final -Field 4 -Feb -20 0 1 10 -Feb -20 Final -Field 18 -Jan -20 0 1 Final -Field 19 -Feb -20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com Date: Signed: L WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 3K-27 Run Date: 10/5/2019 l • f November 21, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3K-27 REGEI.'ED Digital Data in LAS format, Digital Log file DEC 0 9 2019 1 CD Rom 50-029-2751-00 AO G C C: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: �T9 Signed: • • • kc11 - °LiLe ConocoPhillips RFCFIVED Alaska NOV 10 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC November 5, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 „ Anchorage, AK 99501 scANME® '” ,; Zug: Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Aaron Applehans at 907-659-7506, if you have any questions. Sincerely, Aaron Applehans ConocoPhillips Well Integrity Field Supervisor • . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 11/8/2016 3K-24,3K-27,2V-09,2S-1,2S-2,2S-3,2S-4,2N-314 Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 3K-24 50029229350000 1982490 NA NA NA NA 1.7 11/5/2016 3K-27 50029227510000 1970460 NA NA NA NA 3.4 11/5/2016 2V-09 50029213000000 1850370 NA NA NA NA 2 11/5/2016 2N-314 50103203550000 2001930 2' NA 2' NA 10.2 11/6/2016 2S-01 50103207270000 2152030 1.5' NA .98' 7/2/2016 2.55 11/6/2016 2S-02 50103207100000 2150700 2' NA 1' 7/2/2016 3.4 11/6/2016 2S-03 50103207290000 2152050 1.6' NA 1.04' 7/2/2016 3.4 11/6/2016 28-04 50103207210000 2151590 2.3' NA 1.125' 7/2/2016 3.4 11/6/2016 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMAtION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate f" Pull Tubing r Operations shutdown r Performed: Suspend I Perforate r Other Stimulate Alter Casing � Change Approved Program r Rug for Redrill '"'" Perforate New Pool r Repair Well r Re-enter Susp Well r Other: conductor extension (r/ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 197-046 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50-029-22751-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025519 KRU 3K-27 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/ Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10456 feet Plugs(measured) None true vertical 6979 feet Junk(measured) None Effective Depth measured 10078 feet Packer(measured) 7920, 9910 true vertical 6631 feet (true vertical) 5045,6478 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 16 121' 121' SURFACE 6149' 7 5/8 6190' 4101' Production 9957' 51/2 10032' 6589' Production 422' 41/2 10422' 6966' RECEIVED Perforation depth: Measured depth: 10152-10167 True Vertical Depth: 699-6713 SL-P 1 201 AOGCC Tubing(size,grade,MD,and TVD) 3 1/2 x2 7/8 ,L-80, 10032 MD,6590 TVD Packers&SSSV(type,MD,and TVD) NIPPLE=CAMCO DS NIPPLE @ 527 MD and 526 TVD PACKER=ZXP LINER TOP PACKER (7944.21 COE')@ 7920 MD and 504 PACKER= BAKER FAB1 PACKER @ MD and 6478 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA / Treatment descriptions including volumes used and final pressure: SCANNED t'`'.• a L i 1. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development ry Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil P. Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r'" GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-433 Contact Aaron Applehans Email: aappleh@conocophillips.com Printed Name Aaron ;pplehans Title: NSK WI Field Supervisor Signature / Phone:659-7056 Date (A.;y./ /// / YTL /c/?"/I C- et iono4 RBDMS l/ SEP 2 8 2016 Form 10-404 Revised 5/2015 �/ Submit Original Only • • Iry ConocoPhillips Alaska RECEWED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 SEP 2 7 2016 AOGCC September 24, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 3K-27, PTD 197-046 conductor extension. Please contact me at 659-7506 if you have any questions. Sincer ly, Aaron Applehans ConocoPhillips Well Integrity Field Supervisor r N. N I M t � . " �"�`te " -* `a 2e'w $ ke • +r, ' e ' . 7'*- p ` £ : '*-, • Y{. kB , +++'� ` `t F£, u e y;wp 'v'yy ,�4i ,rp4 � ,+` „ r17r ,."7:7,',-,s ai ark a= , �nx fg tz 5'i� . qd $.Hv yA .. l R Y, c \k �4 • 3K-27 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/23/16 Welded an 8" conductor extension onto the conductor with 16"62.58# .375 conductor material. • ti OF Tit 1//7, THE STATE Alaska Oil and Gas h,"�� OfA LASKA Conservation Carrirnissi®n 333 West Seventh Avenue .17-r1477 - GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland WI Project Supervisor ConocoPhillips Alaska, Inc. SCO C.JAN I °' P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3K-27 Permit to Drill Number: 197-046 Sundry Number: 316-433 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 31 day of August, 2016. RBDMS - 1 2016 III ill RECEIVED STATE OF ALASKA AUG 2 3 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION PrSN4636,j APPLICATION FOR SUNDRY APPROVALS O� J(, 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r'• Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing [J: • Other conductor extension Fi• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Exploratory r Development r • 197-0460 3.Address: Stratigraphic r Service r 6.API Number. P. O. Box 100360,Anchorage,Alaska 99510 50-029-22751-00 . 7.If perforating, 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? NA • Will planned perforations require spacing exception? Yes r No r / KRU 3K-27 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025519 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): • 10456 , 6979 , 10078' • 6631' 4000 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 16 121' 121' SURFACE 6149' 7 5/8 6190' 4101' Production 9957' 51/2 10032' 6589' Production 422' 41/2 10422' 6966' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10152-10167 ' 699-6713 31/2x27/8 L-80 10032 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE=CAMCO DS NIPPLE MD=527 TVD=526 PACKER=ZXP LINER TOP PACKER . MD=7920 TVD=5045 PACKER=BAKER FAB1 PACKER . MD=9910 TVD=6478 12.Attachments: proposal Summary r WellBore Schematic r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development P`. Service r 14.Estimated Date for 15. Well Status after proposed work: 09/15/16 OIL VVINJ Suspended Commencing Operations: r r WDSPL r P r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true Contact: MJ Loveland Printed Name MJ Loveland Phone:659-7043 Email: mi.lovelandcop.com ��//y�� /r / Title: NSK WI Project Supervisor Cj // Signature /�i '/ 'Lo'"t`?'2a✓ Date: 5.// ! C� Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \Lk^ Rug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r (..-------Th Other: RBDMS Ci S?? - 1 2016 - Post Initial Injection MIT Req'd? Yes r No i'h"( ,..,/ Spacing Exception Required? Yes r No W Subsequent Form Required: JCl 404i' ./ APPROVED BY Approved by: X--4-�— COMMISSIONER THE COMMISSION Date: 6 '3(.-1 . iliki gz ��. Vii- g/zy8b x5 6 oRrivGINA Subsin Form ane Form 10-403 Revised 11/2015 d for 12 months from the date of approval. Attachments in Duplicate 11.7 ConocoPhillips RECEIVED Alaska AUG 2 3 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC August 19, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3K-27, PTD 197-046 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska,Inc. Kuparuk Well 3K-27 (PTD 197-046) SUNDRY NOTICE 10-403 APPROVAL REQUEST 08-19-16 This application for Sundry approval for Kuparuk well 3K-27 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing/At some point during normal operations the conductor subsided about 8". With approval, the conductor extension will require the following general steps: 1. Examine surface casing for any corrosion damage if it is exposed. 2. Extend the conductor to starter head. 3. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP PROD • 3K-27 ConoccPhillips ° Well Attributes Max Angle&MD TD w Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ,,copM, 500292275100 KUPARUK RIVER UNIT PROD 59.55 3,200.00 10,456.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 36-27,7/10/201611:08:03 AM SSSV:NONE 160 11/30/2011 Last WO: 6/4/2016 41.02 4/19/1997 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,039.0 5/12/2016 Rev Reason:PULLED RHC PLUG,IBP,GLV pproven 7/10/2016 ..__ ......,. .,,.__. C/O HANGER;37.2 il. Casing Strings Casing DescriptionR OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread i I CONDUCTO16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 41.0 6,190.4 4,101.5 29.70 L-80 BTC y ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I1 to PRODUCTION 51/2 4.900 39.2 10,442.0 6,966.1 I YF, 5.5x4.5"@10053' 1 Tubing Strings II f Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(k..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection 31/2"TUBING 31/2 2.992 37.2 7,933.5 5,052.9 9.30 L-90 EUE Ord II CONDUCTOR;42.0.121L Completion Details Nominal ID a s Tap(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 37.2 37.2 0.14 HANGER FMC Gen IV Hanger 2.992 II I 7,914.2 5,042.0 56.15 SEAL ASSY Baker 80-40 Seals 19.32'Overall Length Tubing Description Stdng Me...I ID(in) ITop(ftKB) Set Depth(ft..l Set Depth(ND)(...I Wt(Ib/ft) (Grade ITN,Conne¢tlon2.920 GAS LIFT;3,258.2 g_-: 3 1/2"LINER(Top 31/2 2.992 7,920.4 9,910.01 6,478.0 9.30 L-80 EUE 8rd I I r&Ha Completion Details Nominal ID illTop(ftKB) Top(ND)(ftKB) Top Incl 7) Item Des Com (in) 7,920.4 5,045.5 55.89 PACKER ZXP Liner Top Packer 3.000 GAS LIFT;5,452.5 l (7944.21 COE') 7,949.9 5,062.2 54.66 HANGER Flexlock Liner Hanger 2.980 9,908.3 6,476.4 23.69 ANCHOR KBH-22 Baker Anchor Assembly 3.010 Tubing Description !String Ma...I ID(in) ITop(ftKB) 3¢t Depth(ft..f Sat Depth(TVD)(...I Wt(Ibfk) IGratle Top Connection l TUBING 3.5"x2.875" 31/2 2.992 9,816.7 10,034.21 6,591.3 9.30 L-80 EUEBrdMOD Completion Details Nominal ID Top(ftKB) Tap(TVD)(ftKB) Top Incl 7) Item Des Com (in) SURFACE;41.0-6,190.4-A R, 9,974.1 6,536.5 24.18 XO Reducing - 2.441 10,024.5 6,582.4 24.16 NIPPLE CAMCO D NIPPLE NO GO 2.250 10,032.3 6,589.6 24.11 SEAL ASSY BAKER GBH-22 LOCATOR/SEAL ASSEMBLY w/SBE 3.000 GAS LIFT;6,914.3 a Tubing Description StringMa...ID(in) Top(ftKB) Set Depth ft..Set Depth • p I I I ) I ( ) (6,514..IWI(IbH9. (Grade ITop Connection I 1 I STACKER PACKER 3 1/2 2.992 9,910.1 9,950.011 6,514 5 9.30 L-80 3.5 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Tap Incl(°) Item Des Com (in) GAS LIFT;7,858 5 IL1 9,910.1 6,478.0 23.71 PACKER Baker FAB1 Packer 3.000 9,927.3 6,493.8 23.86 NIPPLE Cameo 2.75"D-Nipple 2.750 9,945.0 6,510.0 24.02 SHOE 4.75 Poor Bay Overshot Baker (4.31'of Swallow) 3.910 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (kKB) (°) Des Com Run Date ID(in) SURFACE CASING PATCH:OAL=79",welded 11/7/2009 SEAL ASSY;7,914.2 -- sleeve w/.500 wall X65,10"pipe PACKER;7,920.4 1'' 00 Threads;7,959.9 Perforations&Slots II snot Dens Top(TVD) atm(ND) (shofsM I1- El (ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 10,152.0 10,167.0 6,699.2 6,713.0 A-3,3K-27 5/8/1997 Mandrel Inserts 4.0 )PERF 180 deg.phasing; Oriented(.1/-)90 deg.F/ Lowside,2 08"EnerJet ANCHOR;9,908.3 El PACKER;9,910.1 Sl ata on Top(NO) Valve Latch Port Size TRO Run _ N Top(ftKB) (ftKB) Make Model OD(In) Sere Type Type (in) (psi) Run Date Com NIPPLE;9,927.3 1 3,258.2 2,496.7'CAMCO KBG 2- 1 GAS LIFT GLV BTM 0.188 1,299.0 6/8/2016 a 9 2 5,452.5 3,702.6 CAMCO KBG 2- 9 1 GAS LIFT OV BTM 0.250 0.0 6/7/2016 SHOE;9,945.0 3 6,914.3 4,487.2'CAMCO KBG 2- -1 GAS LIFT DMY SDK- 0.000 0.0 6/3/2016 9 1A 4 7,858.5 5,011.5 CAMCO KBG 2- - 1 GAS LIFT DMY SDK- 0.000' 0.0 6/3/2016 9 1A GAS LIFT,10,012.1 ; Notes:General&Safety End Date Annotation NOTE. NIPPLE;10,024.4 i I SEAL ASSY;10,032.2 lir • (PERF;10,152.0-10,167.0 I I PRODUCTION [ 5.5x4.5.6 10053';392-10,442 0 STATE OF ALASKA { AKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon fa Plug Perforations r Fracture Stimulate la l Pull Tubing F Operations Shutdown la Performed: Suspend la Perforate la Other Stimulate la Alter Casing P, Change Approved Program Plug for Redrill E Perforate New Pool la Repair Well F Re-enter Susp Well la Other. Install Stack Packer Fi 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory (.a 197-046 3.Address: 6.API Number: la P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service ''' 50-029-22751-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25519 KRU 3K-27 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10456 feet Plugs(measured) 10078 true vertical 6979 feet Junk(measured) None Effective Depth measured 10078 feet Packer(measured) 7920,9910 true vertical 6631 feet (true vertical) 5045,6478 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 6149 7 5/8 6190 4101 PRODUCTION 10452 5.5 10442 6966 RECEIVED Perforation depth: Measured depth: 10152-10167 sO JAN 4x �a 1'1 True Vertical Depth: 6699-6713 vYe !r JUL 0 1 2016 Tubing(size,grade,MD,and ND) 3.5, L-80, 10034 MD,6591 ND , OCC Packers&SSSV(type,MD,and ND) PACKER-ZXP LINER TOP PACKER(7944.21 COE')@ 7920 MD and 5045 ND PACKER-BAKER FAB1 PACKER @ 9910 MD and 6478 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation Shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory la Development F Service r Stratigraphic I' Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas WDSPL E Printed and Electronic Fracture Stimulation Data la GSTOR r'' WINJ r WAG E GINJ E SUSP I— SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-303 Contact Andrew Beat a 265-6341 Email Andrew.T.BeatL conocoohillips.com Printed Name Andrew lijeat> Title Sr. Wells Engineer Signature Phone:265-6341 Date 7// / ....__.) Form 10-404 Revised 5/2015 V L �Z G Submit Original Only .4 0-,6 RBDMS W JUL 0 6 2016 z 0 • sr , r Operations Summary (with Timelog Depths) kr -f: 3K-27 Cono hitiips :.. f Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity CadeTime P-T-X Operation MKS); End Depth(ftKE) 5/24/2016 5/25/2016 8.00 MIRU MOVE MOB P Continue rigging down complexes, 16:00 00:00 Move Complexes away from Sub, Pull Sub off well,Move Rock washer, Shop,Pipe Shed and Sub to CPF3, 5/25/2016 5/26/2016 24.00 MIRU MOVE MOB P Prep 3S road for remaining modules 00:00 00:00 grade and mat low spots,Continue moving remaining modules to CPF3, All modules at CPF3 @ 0600 hrs,Pick up mats from CPF3 to 3S shuffle around rig. Mat and rolling road spine road from CPF3 to 3K, Lay Plywood on 3K Acess Road. 5/26/2016 5/26/2016 6.00 MIRU MOVE MOB P Continue Laying Mats and rolling road 00:00 06:00 form CPF3 to 3K,Lay plywood on 3K access road,Move Rock Washer, Shop,Pipe Shed,and Sub from CPF3 to 3K. 5/26/2016 5/26/2016 2.50 MIRU MOVE MOB P Spot sub over well,simops move 06:00 08:30 remaining complexes to 3K Pad 5/26/2016 5/26/2016 1.50 MIRU MOVE MOB P Set stompers andskid floor,simops 08:30 10:00 setting shop. 5/26/2016 5/26/2016 2.00 MIRU MOVE MOB P Spot modules pits,pump room,boiler 10:00 12:00 room and generators. 5/26/2016 5/26/2016 6.00 MIRU MOVE MOB P Continue spotting modules,plug in 12:00 18:00 electrical M/U interconnects @ swap to 3512 power. 5/26/2016 5/26/2016 2.00 MIRU MOVE RURD P Berm Rig,work on rig acceptance 18:00 20:00 check list,Rig accepted @ 2000 hrs 5/26/2016 5/26/2016 1.00 MIRU MOVE RURD P Rig up hardlines to kill well,tiger tank 20:00 21:00 and choke house. 5/26/2016 5/26/2016 2.00 MIRU WELCTL MPSP P R/U Lubricator and Pressure test U 21:00 23:00 250 psi Pull BPV as per FMC tubing pressure 150 psi,Shut in R/D lubricator. 5/26/2016 5/27/2016 1.00 MIRU WELCTL SEQP P Pressure test surface lines t/2500 psi, 23:00 00:00 B/D tiger tank Lines 5/27/2016 5/27/2016 1.00 MIRU WELCTL OTHR T Wait on KWF to be delivered,Only 1 00:00 01:00 truck available to bring brine Add hoc truck added,Simops Prep for nipple down tree 5/27/2016 5/27/2016 1.50 MIRU WELCTL KLWL P Rev Circ 225 bbls 10.3ppg brine to 01:00 02:30 tiger tank @ 4 bpm 1538 psi FCP. 5/27/2016 5/27/2016 1.00 MIRU WELCTL OWFF P Blow Down Lines Observe well for 02:30 03:30 flow well static. 5/27/2016 5/27/2016 0.50 MIRU WHDBOP MPSP P Pressure test back pressure valve in 03:30 04:00 direction of flow to 1000 psi f/10 min. 5/27/2016 5/27/2016 2.00 MIRU WHDBOP NUND P R/D Circulating hardlines&ND Tree 04:00 06:00 5/27/2016 5/27/2016 6.00 MIRU WHDBOP NUND P NU adapter spools,risers& 06:00 12:00 NUBOPE/choke and kill line. Begin loading and strapping pipe. 5/27/2016 5/27/2016 6.00 MIRU WHDBOP NUND P Continue N/U BOPE Stack and Riser 12:00 18:00 Install choke,Kill and hole fill lines. Install Turn Buckels 5/27/2016 5/27/2016 1.00 MIRU WHDBOP RURD P R/U T/test BOPE M/U test jt and 18:00 19:00 cross overs. P/U tubing handling Equipment. Page 1/6 Report Printed: 6/23/2016 Operations Summary (with Timelog Depths) 3K-27 Comoccehitiips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth. Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftK6)'' -5/27/2016 5/28/2016 5.00 MIRU WHDBOP BOPE P Test BOPE State Inspector Bob Noble 19:00 00:00 Waived witness of test,Test with 3.5" test joint to 250/4000 psi choke valves 1-14,Upper Lower and Blind rams, Annular,Manual Kill Line Valves, manual choke valves,HCR choke and Kill, FOSV,Dart,Manual and Auto IBOP,Koomey Unit Draw down test 58 sec to full pressure,8 sec to 200 psi,Test flow sensor and PVT alarms, Test Gas Alarms. 5/28/2016 5/28/2016 1.00 MIRU WHDBOP RURD P R/D all testing equipment,blow down 00:00 01:00 lines and clean the rig floor 5/28/2016 5/28/2016 2.00 MIRU WHDBOP MPSP P PJSM-suck out stack,check for 01:00 03:00 pressure below,pull test&BPV.Load weatherford power tongs on the rig floor. 5/28/2016 5/28/2016 3.00 COMPZN RPCOMP PULL P R/U 3 1/2"landing joint,screw into 03:00 06:00 hanger 7 1/2 turns,M/U top drive, BOLDS,pull hanger 10ft off seat,start working pipe up to a max of 166K. Work string. Add 4 drums of safe lube to active system 1%lube. Pump down while continuing to work string to a max of 166K. Call E-line @ 04:30. 5/28/2016 5/28/2016 2.00 COMPZN RPCOMP WAIT T Continue to work string.Begin taking it 06:00 08:00 up to a max of 195K.No movement other than pipe stretch.Continue to work pipe,pumping 4 bpm @ 1100 psi. Call E-line to check on timing- informed will not be on location till afternoon? 5/28/2016 5/28/2016 2.00 COMPZN RPCOMP WAIT T Add another 1%safe lub to pit,pump 08:00 10:00 down @ 4 bpm/1100 psi while holding max pull of 195K on string. Begin load and strapping PH-6 pipe. 5/28/2016 5/28/2016 1.25 COMPZN RPCOMP WAIT T Work pipe with 2%safe lube-gained 10:00 11:15 about 6"on stretch,Continue working pipe up to a max of 200K.Work string for an hour.Space out for slip and cut while waiting on E-line. 5/28/2016 5/28/2016 2.75 COMPZN RPCOMP SLPC P Slip and cut drilline 11:15 14:00 5/28/2016 5/28/2016 1.00 COMPZN RPCOMP WAIT T Work pipe again-no luck,set up rig 14:00 15:00 floor for SLB arrival. Continue strap and tally PH-6. 5/28/2016 5/28/2016 1.00 COMPZN RPCOMP WAIT T Clean rig floor-wait on SLB 15:00 16:00 5/28/2016 5/28/2016 4.50 COMPZN RPCOMP ELNE P PJSM w/SLB Eline P/U tools and 16:00 20:30 R/U,Re-Head cable,Hang sheave on top drive w/T Bar, P/U tool string,M/U safety valve and Cross over to Otis, Pressure test Lubricator to 1000 psi f/ 5 min,M/U cutting head Page 2/6 Report Printed: 6/23/2016 ra S Operations Summary (with Timelog Depths) hat r 3K-27 Conooillips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Oepth(ftlB) 5/28/2016 5/29/2016 3.50 COMPZN RPCOMP ELNE P RIH w/Chemical Cutter Weight Bar 20:30 00:00 and Jars tight spot @ 3426'unable to pass POOH remove Centralizers RIH Tool String Passed restriction RIH @ 4500' 5/29/2016 5/29/2016 3.00 COMPZN RPCOMP ELNE P Continue RIH w/cutter Make 00:00 03:00 corelation passes get on depth and cut tubing @ 9947',Attempt to pull out of hole taking weight 300lbs over pull came loose pull out to 9750'unable to pull, RIH tag up on nipple @ 10024' Pull out of the hole slight bobble @ 9750'Continue POOH.R/D Sheaves and Lubricator. 5/29/2016 5/29/2016 0.50 COMPZN RPCOMP RURD P R/U Pup and cross overs to top drive 03:00 03:30 Pull on tubing stage up to 167 hook load string came free 5/29/2016 5/29/2016 1.00 COMPZN RPCOMP ELNE P Finish Rigging down Eline Lay down 03:30 04:30 Lubricator and tools(Simops Clrc Bottoms up) 5/29/2016 5/29/2016 0.50 COMPZN RPCOMP SFTY P PJSM on rigging up weatherford 04:30 05:00 tubing equipment and pulling tubing 5/29/2016 5/29/2016 12.00 COMPZN RPCOMP PULL P POOH L/D 3.5"from 9947'to 1700' 05:00 17:00 Tubing Monitor displacement. Light errossion/corrsion found on joints 184-189(GLM#5 mostly the 2 7/8"joints). Pinhole found @ 8000'-first full 2 7/8" joint below GLM#4. 5/29/2016 5/29/2016 1.00 COMPZN RPCOMP CIRC T Well fluids U-Tubing up tubing M/U 17:00 18:00 cross overs and circ surface to surface148 gpm 147 psi 5/29/2016 5/29/2016 2.50 COMPZN RPCOMP PULL P Continue to POOH f/1700'to surface 18:00 20:30 Cut was clean no swelling on tube removed 303 jts of 3.5"tubing 10 jts 2.875 tubing 5 glms. 5/29/2016 5/29/2016 1.50 COMPZN RPCOMP RURD P Clean and clear rig floor,P/U fishing 20:30 22:00 BHA,Load collars in shed and strap 5/29/2016 5/30/2016 2.00 COMPZN RPCOMP BHAH P M/U and RIH w/Baker fishing BHA t/ 22:00 00:00 296' 5/30/2016 5/30/2016 9.50 COMPZN RPCOMP PULD P PJSM-P/U 3 1/2"PH-6 from pipe 296.0 9,820.0 00:00 09:30 shed. 5/30/2016 5/30/2016 1.00 COMPZN RPCOMP FISH P M/U joint and circulate down to top of 9,820.0 9,945.0 09:30 10:30 fish. 1 bpm=230 psi.Up weight 138K/down weight 101K. Make up three more joints found top of fish @ 9945'not 9846'. Pump pressure increased to 680 psi pumping 1 bpm Set down 10K P/U and warm up jars 15K over. 5/30/2016 5/30/2016 2.50 COMPZN RPCOMP JAR P Begin jarring on fish. 9,945.0 9,945.0 10:30 13:00 Jarring 60K(200K)over and straight pull 115K over.(255K) Jar 100 times-made about 8-10"from original mark. 5/30/2016 5/30/2016 0.50 COMPZN RPCOMP CIRC P P/U to 260K-pump 2.5 bpm @ 1080 9,945.0 9,945.0 13:00 13:30 psi with talk to town. Decision to keep jarring and call out a stacker packer for next run. Page 3/6 Report Printed: 6/23/2016 z i • a Operations Summary (with Timelog Depths)ik it �. ms, 3K-27 ConocoPhitiips Rig: DOYON 142 Job: RECOMPLETION Time Log epth Start Time End Time Our(hr) Phase Op Code Activity Codes Time P'-T-x Cperafon start(ftKDB) End;Depth(ftKB), 5/30/2016 5/30/2016 3.00 COMPZN RPCOMP JAR P Continue jarring working pumps while 9,945.0 9,945.0 13:30 16:30 jarring. Permission to pull 90%capacity of 2 7/8"pups.Max pull 270K. 5/30/2016 5/30/2016 0.75 COMPZN RPCOMP FISH P Release from fish as per Baker fishing 9,945.0 9,945.0 16:30 17:15 rep PUW 140k 5/30/2016 5/30/2016 0.75 COMPZN RPCOMP SFTY P L/D top joint and conduct post jarring 9,945.0 9,940.0 17:15 18:00 inspection in derrick. 5/30/2016 5/30/2016 5.00 COMPZN RPCOMP TRIP P POOH on Elevators f/9940'to 296' 9,940.0 296.0 18:00 23:00 5/30/2016 5/31/2016 1.00 COMPZN RPCOMP SHAH P L/D BHA components as per baker 296.0 169.0 23:00 00:00 fishing 5/31/2016 5/31/2016 2.00 COMPZN RPCOMP BHAH P Continue L/D BHA from 169'to 169.0 0.0 00:00 02:00 surface as per baker rep.Clean and clear rig floor remove BHA components and bring new tools to floor, 5/31/2016 5/31/2016 1.50 COMPZN RPCOMP PUTS X Maker Stacker packer completion RIH 0.0' 63.0 02:00 03:30 t/63'M/U cross overs and change floor equip. 5/31/2016 5/31/2016 6.50 COMPZN RPCOMP RCST X Trip in hole with PH6 dp from 63'to 63.0 9,912.0 03:30 10:00 9912'PUW 137k SOW 101k 5/31/2016 5/31/2016 0.50 COMPZN RPCOMP RCST X Wash down from 9912'to 9945 Locate 9,912.0 9,950.0 10:00 10:30 stub unable to wash over stub work string engage overshot over stub. Locate Fully Mule©9949.5' 5/31/2016 5/31/2016 0.25 COMPZN RPCOMP CIRC X Sot 15 bbls of 10.3ppg CI pill outside 9,950.0 9,950.0 10:30 10:45 pipe Drop Ball Ball on seat 750 stks 5/31/2016 5/31/2016 0.50 COMPZN RPCOMP PACK X Set Packer as per Baker fishing Hand 9,950.0 9,950.0 10:45 11:15 top of packer 9908' 5/31/2016 5/31/2016 4.75 COMPZN RPCOMP PRTS X R/U and test IA to 2500 psi f/10 min 9,950.0 9,908.0 11:15 16:00 test failed,verify no leaks on surface equipment retest multiple times,All failed.Discuss with town manegment, Release from Packer ball sheared @ 3173 psi 5/31/2016 5/31/2016 4.50 COMPZN RPCOMP TRIP X Trip out of the hole standing back 9,908.0 0.0 16:00 20:30 stands f/9908'to 63' 5/31/2016 5/31/2016 1.50 COMPZN RPCOMP SHAH X L/D BHA components,Clear floor,P/U 0.0 16.0 20:30 22:00 and M/U Test Packer BHA 5/31/2016 5/31/2016 1.50 COMPZN RPCOMP MPSP X RIH f/16'to 500'attempt to set packer 16.0 565.0 22:00 23:30 and pressure test unable to hold pressure,test failed leaking out tubing, RIH t/565 set packer set topdrive weight on string packer sealing Test IA to 2500 psi f/5 min test good 5/31/2016 6/1/2016 0.50 COMPZN RPCOMP TRIP X Trip in the hole from 565'to 1420' 565.0 1,420.0 23:30 00:00 PUW-60k 6/1/2016 6/1/2016 2.50 COMPZN RPCOMP TRIP X Continue RIH f/1420'to 5076' 1,420.0 5,076.0 00:00 02:30 6/1/2016 6/1/2016 0.50 COMPZN RPCOMP MPSP X Set test packer and test casing to 5,076.0 5,076.0 02:30 03:00 2500 psi f/5 min good test release packer 6/1/2016 6/1/2016 2.00 COMPZN RPCOMP TRIP X Continue RIH w/test packer f/5076'to 5,076.0 8,068.0 03:00 05:00 8068' Page 4/6 Report Printed: 6/23/2016 • • 0 Operations Summary (with Timelog Depths) 0 Corwaaillips • Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Ttme End Time Our(hr) Phase Op Code Activity Code', Time P-T-X Operation tftKS)j End(Depth(ftKS), 6/1/2016 6/1/2016 0.75 COMPZN RPCOMP MPSP X Set test packer and test casing to 8,068.0 8,068.0 05:00 05:45 2500 psi pressure bleeding off,verify surface equipment.Bleed down 6/1/2016 6/1/2016 0.25 COMPZN RPCOMP TRIP X POOH f/8068'to 7596' 8,068.0 7,596.0 05:45 06:00 6/1/2016 6/1/2016 3.00 COMPZN RPCOMP MPSP X Test casing @ 7596',7782',7878', 7,596.0 8,017.0 06:00 09:00 7968'to 2500 psi f/5 min good tests, failed @ 8017'leak between(7968'- 8017') 6/1/2016 6/1/2016 3.50 COMPZN RPCOMP TRIP X POOH w/test packer f/8075'to 764' 8,017.0 0.0 09:00 12:30 6/1/2016 6/1/2016 1.00 COMPZN RPCOMP BHAH X L/D BHA as per Baker clean and clear 0.0 0.0 12:30 13:30 floor 6/1/2016 6/1/2016 1.00 COMPZN RPCOMP OTHR P Rig up and test the fabricated MPD 1,948.0 13:30 14:30 line to 250/7500 PSI. Note:Waiting on BOT to buck up a packer assembly. 6/1/2016 6/1/2016 4.50 COMPZN RPCOMP PUTB X Make up lower packer 0.0 1,948.0 14:30 19:00 completion,baker anchor assy.RIH on 62 jts of 3.5"EUE L-80 Tubing 6/1/2016 6/1/2016 2.00 COMPZN RPCOMP SLPC P Slip and Cut drilling line 44'Service 1,948.0 1,948.0 19:00 21:00 top drive blocks and crown. 6/1/2016 6/2/2016 3.00 COMPZN RPCOMP WAIT X Wait on Liner top packer from Baker 1,948.0 1,948.0 21:00 00:00 (simops house keeping MP2. 6/2/2016 6/2/2016 3.00 COMPZN RPCOMP WAIT X Wait on BOT Liner top packer,coming 1,948.0 1,948.0 00:00 03:00 over from dead horse(Simops painting,cleaning,working on MP2) 6/2/2016 6/2/2016 2.00 COMPZN RPCOMP OTHR P P/U and M/U HRD ZXP liner top 1,948.0 2,090.0 03:00 05:00 packer, M/U cup/pack off asst'.Mix and pour Pal Mix,M/U Cross overs 6/2/2016 6/2/2016 0.50 COMPZN RPCOMP CIRC X Circulate Liner Volume as per Baker 3 2,090.0 2,090.0 05:00 05:30 bpm 425 psi 6/2/2016 6/2/2016 4.50 COMPZN RPCOMP RCST X Rlh w/3.5"PH6 from Derrick f/2090' 2,090.0 9,880.0 05:30 10:00 to 9880'137k PUW 98k SOW 6/2/2016 6/2/2016 1.50 COMPZN RPCOMP CRIH X Spot 30 bbls CI pill 2.5 bpm 690 psi 9,880.0 9,880.0 10:00 11:30 folowed by 25bbls clean 10.3ppg brine,chase with 15bbls high viscocity pill drop 29/32 ball before pumping high visc sweep,pump ball to seat hold 400 psi on ball 6/2/2016 6/2/2016 1.50 COMPZN RPCOMP PACK X Set Liner top packer as per Baker rep, 9,880.0 7,920.0 11:30 13:00 pressure up to 3500 psi,shut in pressure up to 4200 psi w/test pump to blow ball seat(failed),Bleed off pressure pressure up to 3600 w/mud pump ball seat sheared,P/U to dogs out slack off and set liner hanger. Top of liner hanger 7920.44 6/2/2016 6/2/2016 7.50 COMPZN RPCOMP PULD X POOH L/D 3.5"DP in shed f/7920'to 7,920.0 60.0 13:00 20:30 60' 6/2/2016 6/2/2016 1.50 COMPZN RPCOMP BHAH X L/D BHA as per baker making service 60.0 0.0 20:30 22:00 breaks and L/D to shed.Clean and Clear rig floor. 6/2/2016 6/2/2016 1.00 COMPZN RPCOMP TRIP P RIH w/3.5"DP from Derrick from 0.0 1,970.0 22:00 23:00 surface to 1970' 6/2/2016 6/3/2016 1.00 COMPZN RPCOMP PULD P POOH L/D 3.5"DP f/1970'to 941' 1,970.0 941.0 23:00 00:00 6/3/2016 6/3/2016 1.00 COMPZN RPCOMP PULD P Continue L/D 3.5"DP f/941'to 941.0 0.0 00:00 01:00 surface Page 5/6 Report Printed: 6/23/2016 • • r "'' `� Operations Summary (with Timelog Depths) ice:-• 3K-27 Cor,oitlips ,ssti, Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth MKS)' 6/3/2016 6/3/2016 1.00 COMPZN RPCOMP RURD P R/U and Pull Wear ring with test jt,L/D 0.0 0.0 01:00 02:00 Test Jt and retrieval tool. 6/3/2016 6/3/2016 10.00 COMPZN RPCOMP PUTB P RIH w/3.5"Upper Completion as per 0.0 7,589.0 02:00 12:00 detail.t/7589' 6/3/2016 6/3/2016 1.50 COMPZN RPCOMP PUTB P Continue RUH w/3.5"Upper 7,589.0 7,934.0 12:00 13:30 Completion as per detail f/7589'to 7934'Nogo 6/3/2016 6/3/2016 0.50 COMPZN RPCOMP PRTS T Attempt to pressure test packer By 7,934.0 7,934.0 13:30 14:00 testing down IA,prematurely shear SOV @ 2100 psi due to no psi held on tubing 6/3/2016 6/3/2016 1.00 COMPZN RPCOMP HOSO P Space out seals&M/U Hanger and 7,934.0 7,904.0 14:00 15:00 Landing jt. 6/3/2016 6/3/2016 1.00 COMPZN RPCOMP CRIH P M/U circulation equipment and pump 7,904.0 7,904.0 15:00 16:00 90 bbls CI fluid @ 4 bpm 1100 psi Chase w/69 bbls to spot. 6/3/2016 6/3/2016 0.50 COMPZN RPCOMP THGR P Land Hanger in wellhead RILDS as 7,904.0 7,933.0 16:00 16:30 per FMC 6/3/2016 6/3/2016 1.50 COMPZN RPCOMP PRTS P Drop Ball and rod and pressure test 7,933.0 7,933.0 16:30 18:00 Tubing and IA to 2500 psi f/30 min Test Hanger seals to 5000 psi f/5 min good test. 6/3/2016 6/3/2016 0.50 COMPZN RPCOMP OWFF P Observe well for flow well static 7,933.0 0.0 18:00 18:30 6/3/2016 6/3/2016 0.50 COMPZN WHDBOP MPSP P Set back pressure valve and test in 0.0 0.0 18:30 19:00 direction of flow 1000 psi f/10 min. 6/3/2016 6/3/2016 1.00 COMPZN WHDBOP NUND P Prepare to N/D stack(Simops clear 0.0 0.0 19:00 20:00 floor of tubing equipment) 6/3/2016 6/3/2016 3.50 COMPZN WHDBOP NUND P N/D stack remove riser,Dutch riser 0.0 0.0 20:00 23:30 plate,choke and kill hoses,API Blocks on mud cross,stand back stack and remove DSA's and Spools. 6/3/2016 6/4/2016 0.50 COMPZN WHDBOP NUND P Prep well head and Nipple up Tree as 0.0 0.0 23:30 00:00 per FMC. 6/4/2016 6/4/2016 1.50 COMPZN WHDBOP NUND P Nipple up Tree as per fmc test void t/ 0.0 0.0 00:00 01:30 250/5000 psi, 6/4/2016 6/4/2016 1.00 COMPZN WHDBOP PRTS P Install tree test plug,test tree U 250/ 0.0 0.0 01:30 02:30 5000 psi, 6/4/2016 6/4/2016 1.00 COMPZN WHDBOP MPSP P Pull tree test plug R/U U circ freeze 0.0 0.0 02:30 03:30 protect 6/4/2016 6/4/2016 2.00 COMPZN WHDBOP FRZP P Freeze protect well as per Hot oil 0.0 0.0 03:30 05:30 pump 50 bbls diesel anllow to u-tube intil static. 6/4/2016 6/4/2016 2.00 DEMOB WHDBOP MPSP P Install the BPV. Secure wellhead 0.0 0.0 05:30 07:30 instal flanges and remove working valves. Install gauges.Clean cellar 6/4/2016 6/4/2016 1.50 DEMOB MOVE RURD P Continue cleaning pits rig released @ 0.0 0.0 07:30 09:00 0900 hrs Page 6/6 Report Printed: 6/23/2016 KUP irOD 3K-27 Ccrn©coPhiHips 4Well Attrib Max Ang MD TD Alaska,it1C, Wellbore APUUWI Field Name Wellbore Status ncl r) MD(ftKB) 'Act Btm(ftKB) gip(, 500292275100 KUPARUK RIVER UNIT PROD 59.55 3,200.00 10,456.0 a... a, 1 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 36-27,711/20168'.14'.06 AM SSSV:NONE 160 11/30/2011 Last WO: 6/4/2016 41.02 4/19/1997 11 Vertical schematic factual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,039.0 5/12/2016 Rev Reason:WORKOVER lehallf 6/15/2016 HANGER;37.2 1 Casing Strings I Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED Casing Description SOD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth)T/D)...WtlLen(I...Grade Top Thread SURFACE 75/8 6.875 41.0 6,190.4 4,101.5 29.70 L-80 BTC yu ,, ,,,r..u...,...„. . •� „„ ' r• °° "Casing Description OD(in) ID(in) Top IRKS) Set Depth(ftKB) Set Depth)T/D(...WtlLen(I...Grade Top Thread `! I PRODUCTION 51/2 4.900 39.2 10,442.0 6,966.1 5.5x4.5"@10053' Tubing Strings "Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ftGratle Top Connection )9 31/2"TUBING 1 31/21 2.9921 37.21 7,933.51 5,052.91 9.301 L-80 IEUE 8rd CONDUCTOR;42.0-121.0 Completion Details Nominal ID Top(ik(13) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 37.2 37.2 0.14 HANGER FMC Gen IV Hanger 2.992 7,914.2 5,042.0 56,15 SEAL ASSY Baker 80-40 Seals 19.32 Overall Length 2.920 GAS LIFT;3,258.2 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. (TVD)(...Wt(lb/ft) Grade Top Connection Packer3 1/"LINER(T)p ISet Depth 31/2 2.992 7,920.4 9,910.06,478.0 9.301 L-80 EUE 8r4 I I Completion Details Nominal ID GAS LIFT,5 452.5 _ Top(MB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,920.4 5,045.5 55.89 PACKER ZXP Liner Top Packer 3.000 (7944.21 COE') 7,949.9 5,062.2 54.66 HANGER Flexlock Liner Hanger 2.980 9ll ,908.3 6,476.4 23.69 ANCHOR KBH-22 Baker Anchor Assembly 3.010 E Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection li TUBING 3.5"x2.875" 3 1/2 2.992 9,816.7 10,034.2 6,591.3 9.30 L-80 EUESrdMOD 9 Completion Details Nominal ID SURFACE;41.06,190.4 i L Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 9,974.1 6,536.5 24.18 XO Reducing 2.441 10,024.5 6,582.4 24.16 NIPPLE CAMCO D NIPPLE NO GO 2.250 GAS LIFT;6,914.3 10,032.3 6,589.6 24.11 SEAL ASSY BAKER GBH-22 LOCATOR/SEAL ASSEMBLY w/SBE 3.000 1 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ibift) Grade Top Connection STACKER PACKER 31/2 2.992 9,910.1 9,950.0 6,514.5 9.30 L-80 3.5 I Completion Details GAS LIFT;7,858.5IL Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 9,910.1 6,478.0 23.71 PACKER Baker FAB1 Packer 3.000 9,927.3 6,493.8 23.86 NIPPLE Camco 2.75"D-Nipple w/RHC Plug Body installed 2.750 9,945.0 6,510.0 24.02 SHOE '4.75 Poor Boy OverShot Baker (4.31'of Swallow) 3.910 III Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SEAL ASSY;7,914. Top(TVD) Top Incl 2 Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) PACKER;7,920.4 10,078.0' 6,631.4 23.82 IBP PLUG BAKER 2.13"IBP(OAL=40') 10/9/2015 0.000 I: :: I SURFACE CASING PATCH:OAL=79",welded 11/7/2009 sleeve w/.500 wall X65,10"pipe 00 Threads;7,9599 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com ANCHOR;9,9083 jj 10,152.0 10,167.0 6,699.2 6,713.0 A-3,3K-27 5/8/1997 4.0 (PERF 180 deg.phasing; PACKER;9,910.1 -� Oriented(+/-)90 deg.F/ III Lowside,2 1/8"EnerJet Mandrel Inserts NIPPLE;9,927.3 St I ati SHOE;8,945.0 {'." ,.:I N Top(TVD) Valve Latch Port Size TRO Run ..1. Top(ftKB) (ftKB) Make Model OD(in) Sery _ Type Type (in) (psi) Run Date Corn 1 3,258.2 2,496.7 CAMCO KBG 2- 1 GAS LIFT DMY SDK- 0.000 0.0 6/3/2016 9 1A ri 2 5,452.5 3,702.6 CAMCO KBG 2- 1 GAS LIFT SOV DCK-3 0.000 0.0 6/3/2016 9 GAS UFT;19,012.1 + 3 6,914.3 4,487.2 CAMCO KBG 2- 1 GAS LIFT 'DMY SDK- 0.000' 0.0 6/3/2016 9 1A 4 7,858.5 5,011.5 CAMCO KBG 2- 1 GAS LIFT DMY SDK- 0.000 0.0 6/3/2016 9 1A NIPPLE;10,024.4 Notes:General&Safety End Date Annotation NOTE; SEAL ASSY;10,032.2 iiIBP PLUG;10,078.0 �� (PERF;10,152.0-10,167.0 PRODUCTION j [ 5.5x4.5"610053';39.2-10,442 0 ,,, KUP 41OD 3K-27 ConocoPhillips z.I Alaska,Inc. Coroxahillips ... H2S(ppm) Date 38-27 7/1/2016 814;06:AM 180 10/29/2015 Verpral schemapc{a9Wa) HANGER;37.2 . 114jg:�'- y�yr�yyyyyy��iu��iuuuuuuuu��i��iyy i.Ux titi CONDUCTOR;42.0-121.0 L I GAS LIFT;3,256.2 I I GAS LIFT,5,452.5 �� I I SURFACE;41.08,190.4-.4h Oa ? GAS LIFT;6,914.3 I GAS LIFT,7,858.5 I} I I I SEAL ASSY;7,914.2 PACKER,7,920.4 aiir XO Threads;7,959.9 '.1111 I f�'�Ig ANCHOR;9,908.3 '�9) PACKER;9,910.1 Tr NIPPLE;9,927.3 11 SHOE;9,945.0 11 GAS LIFT;10,012.1 I NIPPLE;10,024.4 I SEAL ASSY;10,032.2 ' M IBP PLUG,10078.0 IPERF;10,152.0-10,187.0 PRODUCTION 5.5x4.5"®10053';39.2-10,442.0 SOF 7 • cw\ y7s� THE STATE Alaska Oil and Gas - � OfA T KA CO1TSeY'Vati®n CO111miSSi®n s ' tltt_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS� Fax: 907.276.7542 www.aogcc.alaska.gov Travis Smith Wells Engineer ConocoPhillips Alaska, Inc. SCANKEI P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3K-27 Permit to Drill Number: 197-046 Sundry Number: 316-303 Dear Mr. Smith: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1/2;°-4-4,1---, Cat P. Foerster Chair DATED this i?Rday of June, 2016. RBDMS Li" JUN 1 0 2016 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUN U 247 APPLICATION FOR SUNDRY APPROVALS Q7-� 6 its 20 AAC 25.280 1.Type of Request: Abandon E Plug Perforations ... Fracture Stimulate I...._ Repair Well 1 Operations Shutdown E Suspend Perforate P Other Stimulate -.... Pull Tubing T Change Approved Program F Plug for Redrill ',P Perforate New Pool( W Re-enter Susp Well Alter Casing — Other: Install stack Parker P- 2. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ....... Development 2197-046 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic I— Service 50-029-22751-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes ? No [v / KRU 3K-27 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL 25519 Kuparuk River Field/Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective e Depth T� MPSP(psi): Plugs(MD): Junk(MD): 10,456' 6,979' )'OI'7g' 6 10 3) Casing Length Size MD ND Burst Collapse Conductor 79' 16" 121' 121' Surface 6,149' 7 5/8 6,190' 4,101' Production 9,957' 51/2 10,032' 6,589' Production 422' 41/2 10,442' 6,966' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10152-10167 6699-6713 3 1/2 x 2 7/8 L-80 10,034' Packers and SSSV Type: Baker SBE&GBH-22 Locator Packers and SSSV MD(ft)and TVD(ft): 10032=MD and 6590=TVD Baker FAB Permanent Packer (added on Rig)9908=MD and 6476=TVD SSSV:NONE 12.Attachments: Proposal Summary I] Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Stratigraphic 1.". Development k Service .__. 14. Estimated Date for 5/24/2016 15.Well Status after proposed work: Commencing Operations: OIL F WINJ I...... WDSPL I....... Suspended [- 16.Verbal Approval: Date: 6/1/2016 GAS ra. WAG 1— GSTOR P SPLUG 1— Commission Commission Representative: Victoria Loepp GINJ Op Shutdown Abandoned '- 17. I hereby certify that the foregoing is true and the procedure approved Travis Smith @ 265-6450 herein will not be deviated from without prior written approval. Contact Email Travis.T.Smith(cr)conocophillips.com Printed Name Travis Smith Title Wells Engineer Signature 'iege ' Phone: 265-6450 Date l///I CVO" COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: VA.— 303 Plug Integrity ❑ BOP Test E17 Mechanical Integrity Test ❑ Location Clearance ❑ Other: 50p fie-5f f"0 46DOr5j� fo Zs�v r>S/ lI Y2 r7L,iGl✓ p VCr> tC ^ 5 >-fs t--- Post Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS �- JUN 1 0 2016 Spacing Exception Required? Yes E No V Subsequent Form Required: (I) APPROVED BY Approved by: P s6...iRCOMISSIONER THE COMMISSION Date: ._s? g Form 10-403 Re 'ed 11/2015 I G_ N A _ 7: approval.,.2 mon}hs from the date of a al.� r / satAttachments Duplicate F� and ,/- (=.77/6in • • • RECEIVED ConocoPhillipsJUN 0 2 2016 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 June 1,2016 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner Foerster: ConocoPhillips hereby submits an Application for Sundry Approval(for work already in-progress)to address a production casing leak during the workover of Kuparuk Producer 3K-27(PTD#197-046). d Well 3K-27 is a Kuparuk gas-lifted producer well. A workover operation began May 24,2016 to pull and replace the leaking 3-'14"gas lift production tubing. During this workover operation the original completion could not be pulled free from the casing seal bore. The tubing was cut and a stacked-packer was set over the old tubing stub with the intent to run new tubing to surface. Only after setting this permanent packer was a leak in the 5-'/z" production casing discovered. A subsequent test packer run located this leak between 7,968' and 8,017' MD. Per our email correspondence and verbal approval with the AOGCC,a 3-'/2"liner will be set to straddle the production casing leak between the permanent packer and the new upper packer. This work is currently in- progress. If you have any questions or require any further information,please contact me at 265-6450 or Travis.T.Smith@conocophillips.com. Oerely, Travis Smith Wells Engineer ConocoPhillips Drilling&Wells • • 3K-27 Rig Workover Straddle Packer Assembly and Replace Tubing (PTD# 194-046) Current Status: A rig workover is currently in-progress to replace the tubing. Scope of Work: Run a straddle-packer and liner to isolate production casing leak,run new tubing to surface. General Well info: MPSP: 3,610 psig(using 0.1 psi/ft gradient from reservoir to surface) Reservoir pressure/TVD: Kuparuk—4,271 psi/6,635' TVD (12.4 ppg EMW)measured 5/8/2016 Wellhead type/pressure rating: FMC Gen IV wellhead,5M Doyon 142 BOP Configuration: Annular/VBR Pipe Ram /Blind Rams/Mud Cross/VBR Pipe Ram MIT results: CMIT pre-rig—Passed 1/12/2016 to 2,500 PSI MITIA on rig—Failed 6/1/2016 with test packer at 8,017' MD MITIA on rig—Passed 6/1/2016 with test packer at 7,968' MD Well Type: Producer Start Date: May 24,2016 Production Engineer: Kenneth Martin/Toon Changklungdee Workover Engineer: Travis Smith(265-6450/Travis.T.Smith@ conocophillips.com) RWO Operations to Date: 1. MIRU RWO Rig 2. Pull BPV. Circulate brine. Verify well is dead. 3. Set BPV&blanking plug,ND tree,NU BOPE&test to 4,000 psi. 4. Pull blanking plug&BPV,screw in landing joint,BOLDS's,unseat tubing hanger. 5. PU on tubing and attempt to pull hanger to the floor. Tubing would not pull free,RU wireline. RIH and cut tubing in the lowest full joint of 3-'/2"tubing above the seal assembly.RD wireline. 6. TIH with drillpipe and fishing assembly and attempt to jar free the cut stub of tubing. Unsuccessful. 7. TIH with new 3-'h"L-80 tubing stacked-packer and overshot. Swallow cut stub of tubing from old completion, set new packer and test. MITIA fails pressure test to 2,500 psi. 8. Run test packer and locate production casing leak between 7,968' and 8,017' MD. RWO Proposed Going Forward: 9. TIH with 3-'/2"liner on drillpipe,circulate in corrosion inhibited brine to annulus,latch into permanent packer below casing leak and space out straddle packer above casing leak. Set straddle packer and release setting tool. POOH laying down drillpipe. 10. RIH with new gas lift tubing string. Locate new liner top, space out with pups,circulate corrosion inhibitor,stab into seal assembly, land hanger,and RILDS. 11. PT the tubing and IA.Bleed the IA and then the tubing.Ramp up the IA pressure quickly to shear the SOV. 12. Pull the landing joint and install BPV. 13. ND BOPE,NU and test tree.Pull BPV. 14. FP well with diesel through the SOV 15. Set BPV and RDMO RWO Rig • • • • ConocoPhillips 3K-27 Producer Proposed 121' MD: 16"62.5#, H-40 • r 3-1/2" KBG-2-9 GLMs(All) /2 I -, 4 3 " L-80 EUE-8rd to surface 6,190' MD:7-%" 29.7#, L-80 f�R 7,950':Stacked Packer 5-1/2"Production Casing Leak: ��3-1h" L-80 EUE-8rd from 7,950'to 9,908' Somewhere between 7,968'–8,017' Isolating Casing Leak Old Completion Fish: 9,908': Baker 5-1/2"x 3-1/2" FAB Permanent Cut joint of 3-1/2"Tubing Packer —� 1 Joint 2'/8"Tubing 2'/8" Pup Joint Camco 2.75" DS Nipple —► •a 2'/8" KBMM GLM Baker 4-3/a" Poor-Boy Overshot —N. ` 2'/a" Pup Joint 9,947':Tubing Cut —► -y, 2.25"Camco D-Nipple ' 3-1/2" Pup Joint Baker GBH-22 Locator/Seals 10,021' MD:5-1/2" 15.5#, L-80 �� I- 10,032': Baker 5"x 4"Seal Bore Extension 10,152'–10,167': Kuparuk A-Sand Perforations 10,442'MD:4-1/2" 12.7#, L-80 I Date: June 1,2016 Drawn By: Travis Smith • • Smith, Travis T From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday,June 01, 2016 10:53 AM To: Smith, Travis T Subject: [EXTERNAL]RE: 3K-27 (PTD# 197-046) Rig Workover Run Stacked Packer Travis, Please submit a sundry as soon as possible. You have verbal approval to proceed. Thanx, Victoria From: Smith, Travis T[mailto:Travis.T.Smith@conocophillips.com] Sent: Wednesday, June 01, 2016 10:52 AM To: Loepp, Victoria T(DOA) Subject: RE: 3K-27 (PTD# 197-046) Rig Workover Run Stacked Packer Victoria— Thank you very much for the quick response. Currently we don't a Sundry for this workover, since we were originally operating under our exemption for pull-and- replace tubing RWOs for producer wells. Thanks again, Travis From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,June 01, 2016 10:45 AM To:Smith,Travis T<Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]RE: 3K-27 (PTD#197-046) Rig Workover Run Stacked Packer Travis, Approval is granted to run the stacked packer to isolate the PC leak as outlined below. Please include this approval with your approved sundry. Thanx, Victoria From: Smith, Travis T [mailto:Travis.T.Smith@conocophillips.com] Sent: Wednesday, June 01, 2016 10:23 AM To: Loepp, Victoria T(DOA) Subject: RE: 3K-27 (PTD# 197-046) Rig Workover Hello Victoria- 1 • . With test packer work through the night and this morning, we have located the leak in the 5-Y2" production casing between 7,968' and 8,017' MD. To isolate this leak,we'd like to run a 3-%2" liner from the permanent FAB packer set at 9,908' MD to a new 3-%2"x 5%" packer set above the leak to straddle it on either side. From the new upper packer we would run a 3-%2"gas lift completion string to surface. I have attached here a schematic showing this proposed solution. Please let me know if you have any questions or would like any other information. Thank you, Travis From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, May 31, 2016 5:04 PM To:Smith,Travis T<Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]Re: 3K-27 (PTD#197-046) Rig Workover Email is fine- Sent from my iPhone On May 31, 2016, at 4:33 PM, Smith,Travis T<Travis.T.Smith@conocophillips.com>wrote: I'll be happy to let you know. The diagnostics will likely be done during the night tonight. Do you have a cell phone you'd like me to call, or would an email notification here suffice? Thanks again, Travis From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, May 31, 2016 4:31 PM To:Smith,Travis T<Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]Re: 3K-27 (PTD#197-046) Rig Workover Thank you for the notification. Let me know when you determine the leak depth. Victoria Sent from my iPhone On May 31, 2016, at 4:10 PM,Smith,Travis T<Travis.T.Smith@conocophillips.com>wrote: Hello Victoria- ConocoPhillips Alaska is currently in the process of a rig workover at Kuparuk producer well 3K-27. The planned scope of this workover was to pull-and-replace the 3%" gas-lift completion to address a tubing leak in the well. 2 • • • During the course of the rig work the well has failed an MITIA to 2500 psi and it is possible a leak in the 5-%2' production casing is the cause. To verify if the production casing leaks, and determine the depth of the leak, we are currently preparing to run a test packer. I'm sending you this to notify that we may be moving to an operation to address a leaking production casing in 3K-27. If there is indeed a leak in the production casing, and it is deep enough to not interfere with gas lifting operations, we will likely isolate it by stacking a packer above it. Please let me know if you have any questions or need more information. Thanks very much, Travis Smith Wells Engineer 907-265-6450 3 • KUP PROD 3K-27 ConocoP it ips + : Well Attributes Max Angle&MD TD Alaska Inc . Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) c_alp, ,' 500292275100 KUPARUK RIVER UNIT PROD 59.55 3,200.00 10,456 0 `m ••• Comment H2S(ppm) Date Annotation End Date KB-Gni(ft) Rig Release Date 3K-27,5/16/20161045:02 AM SSSV:NIPPLE 180 10/29/2015 Last WO 41.02 4/19/1997 _, Vertical schematic(actual)...... Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ........................................._._.._..... Last Tag:SLM 10,039.0 5/12/2016 Rev Reason:SET IBP,TAG pproven 5/16/2016 HANGER;372 i`--...= . Casing Strings �/tCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread II; �, CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Sat Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 41.0 6,190.4 4,101.5 29.70 L-80 ETC ,-/�Casing Description DD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 51/2 4.950 39.5 10,442.0 6,966.1 15.50 L-80 LTC-MOD 5.5x4.5"@10053' CONDUCTOR;42.0-121.0 Tubing Strings NIPPLE;528.5 : Tubing Description Stnng Ma...ID(in) Top(ftKB) Set Depth(ft..J Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 3.5"02.875" 3 1/2 2.992 37.1 10,034 2 6,591.4 9.30 L-80 EUEBrdMOD Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 37.1 37.1 0.14 HANGER FMC GEN IV HANGER 3.500 s 526.5 525.7 6.90 NIPPLE CAMCO DS NIPPLE 2.812 4-a 3,426.1 2,584.6 58.12 XO Reducing CROSSOVERS 3.502.875x3.5 ABOVE&BELOW EACH 2.441 GAS LIFT;3,464.8 4 MANDREL 3,508.2 2,628.3 57.37 XO Enlarging 2.992 c 5,822.9 3,907.5 55.66 XO Reducing 2.441 a 5,902.2 3,952.3 55.88 XO Enlarging 2.992 7,943.6 5,058.6 54.92 XO Reducing 2.441 8,025.6 5,106.0 54.75 XO Enlarging 2.992 4 9,189.1 5,860.9 38.60 XO Reducing 2.441 GAS LIFT;5,858.1 III 9,267.9 5,923.1 37.12 XO Enlarging 2.992 iii 9,702.6 6,289.9 27.13 XO Reducing 2.441 Ai ■. 9,784.8 6,363.4 24.71 XO Enlarging 2.992 I 9,974.1 6,536.6 24.18 XO Reducing 2.441 10,024.5 6,582.5 24.16 NIPPLE CAMCO D NIPPLE NO GO 2.250 3.000 10,032.3 6,589.6 24.(1 SEAL ASSY BAKER GBH-22 LOCATOR/SEAL ASSEMBLY w/SBE Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) SURFACE;41.0-6.190 4--AS i4610,078.0 6,631.4 23.82 IBP PLUG BAKER 2.13"IBP(OAL=40') 10/9/2015 0.000 SURFACE CASING PATCH:OAL=79",welded 11/7/2009 11 sleeve w/.500 wall X65,10"pipe Perforations&Slots GAS LIFT;7,981.5 4 Shot Dens Top(ND) Blm(TVD) (shots/f Top(RKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com r>G: 10,152.0 10,167.0 6,699.2 6,713.0 A-3,3K-27 5/8/1997 4.0 (PERF 180 deg.phasing; (t-. Oriented(o/-)90 deg.F/ Lowside,2 1/8"EnerJet ra i Mandrel Inserts GAS LIFT;9,2282 St I � a[i 11 N Top(ND) Valve Latch Port Sine TRO Run itTop(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) _ Run Date Com rz 1 3,464.8 2,605.0 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 12/17/2015 2 5,858.1 3,927.4 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 12/18/2015 3 7,981.5 5,080.5 CAMCO KBMM 1 GAS LIFT DMY BK - 0.000 0.0 11/19/2004 GAS LIFT;8,741.1 ,4 4 9,226.2 5,890.0 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 8/6/1998 111 5 9,741.1 6,324.2 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 6/22/2009 11 6 10,012.2 6,571.2 CAMCO KBMM 1 GAS LIFT OPEN 0.000 0.0 3/12/2014 Notes:General&Safety End Date Annotation 3/18/2003 NOTE:TAGGED TBG RESTRICTION @9956'SLM(9975'RKB) x7/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 5/28/2012 NOTE:LDL LOCATED LEAK @ 8012'IN 2 7/8"TUBING JOINT GAS LIFT;10,012.2 0- NIPPLE;10,024.5 1_ I SEAL ASSY;10,032.3 IBP PLUG;10,078.0 �� IPERF;10,152.0-10,187.0 I PRODUCTION j L 5.5x4.5•@10053';39.5-10,4420 • • Bettis, Patricia K (DOA) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Thursday,June 02, 2016 9:55 AM To: Bettis, Patricia K(DOA) Subject: RE: KRU 3K-27 (PTD 197-046): Sundry Application The inflatable bridge plug is our current effective depth. 10,078' MD, 6,631'TVD. Thanks, Travis From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday,June 02, 2016 9:36 AM To: Smith,Travis T<Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]RE: KRU 3K-27 (PTD 197-046): Sundry Application Travis, On Form 10-403, Box 11, data provided lists the present well condition summary such as total depth of well and effective depth of the well. Effective depth may represent a plug-back depth, top of fill or top of fish that impedes the production/injection of fluid or utilization of the wellbore below that depth. Thanks, Patricia From: Smith,Travis T [mailto:Travis.T.Smith@conocophillips.com] Sent:Thursday,June 02, 2016 9:28 AM To: Bettis, Patricia K (DOA)<patricia.bettis@alaska.gov> Subject: RE: KRU 3K-27 (PTD 197-046): Sundry Application Hello Patricia— A clarification: how are you defining current effective depth? The TD of the well, or the temporary Inflatable Bridge Plug that we have set for isolation during this workover? Thanks! Travis From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday,June 02, 2016 9:23 AM To:Smith,Travis T<Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]KRU 3K-27 (PTD 197-046): Sundry Application Good morning Travis, 1 • • Please provide the current effective depth, both MD and TVD, for KRU 3K-27. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • , Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Thursday,June 02, 2016 9:23 AM To: 'Travis.T.Smith@conocophillips.com' Subject: KRU 3K-27 (PTD 197-046): Sundry Application Good morning Travis, Please provide the current effective depth, both MD and TVD, for KRU 3K-27. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • pTD -o 4-, Loepp, Victoria T (DOA) From: Smith,Travis T <Travis.T.Smith@conocophillips.com> Sent: Wednesday,June 01,2016 3:25 PM To: Loepp,Victoria T(DOA) Subject: RE:3K-27 (PTD#197-046) Rig Workover Run Stacked Packer Attachments: 3K-27 (PTD#197-046) Sundry.pdf Follow Up Flag: Follow up Flag Status: Flagged scoter) FEB 0 LO17: Hello Victoria— I have attached a PDF of the Sundry documents discussed below. The hard copy will follow tomorrow morning with our regular delivery to the AOGCC. Will this work for you? Thanks again for the help! Travis From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,June 01,2016 10:53 AM To:Smith,Travis T<Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]RE:3K-27(PTD#197-046) Rig Workover Run Stacked Packer Travis, Please submit a sundry as soon as possible. You have verbal approval to proceed. Thanx, Victoria From: Smith,Travis T[mailto:Travis.T.Smith@)conocophillips.com] Sent: Wednesday,June 01, 2016 10:52 AM To: Loepp,Victoria T(DOA) Subject: RE: 3K-27(PTD# 197-046) Rig Workover Run Stacked Packer Victoria— Thank you very much for the quick response. Currently we don't a Sundry for this workover,since we were originally operating under our exemption for pull-and- replace tubing RWOs for producer wells. Thanks again, Travis 1 • • From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,June 01,2016 10:45 AM To:Smith,Travis T<Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]RE:3K-27(PTD#197-046) Rig Workover Run Stacked Packer Travis, Approval is granted to run the stacked packer to isolate the PC leak as outlined below. Please include this approval with your approved sundry. Thanx, Victoria From: Smith,Travis T[mailto:Travis.T.SmithOconocophillips.com] Sent: Wednesday,June 01, 2016 10:23 AM To: Loepp, Victoria T(DOA) Subject: RE: 3K-27 (PTD# 197-046) Rig Workover Hello Victoria— With test packer work through the night and this morning,we have located the leak in the 5-'/:" production casing between 7,968'and 8,017' MD. To isolate this leak,we'd like to run a 3%" liner from the permanent FAB packer set at 9,908' MD to a new 3%:"x 5%" packer set above the leak to straddle it on either side. From the new upper packer we would run a 3%"gas lift completion string to surface. I have attached here a schematic showing this proposed solution. Please let me know if you have any questions or would like any other information. Thank you, Travis From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, May 31,2016 5:04 PM To:Smith,Travis T<Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]Re: 3K-27(PTD#197-046) Rig Workover Email is fine- Sent from my iPhone On May 31,2016,at 4:33 PM,Smith,Travis T<Travis.T.Smith@conocophillips.com>wrote: I'll be happy to let you know. The diagnostics will likely be done during the night tonight. Do you have a cell phone you'd like me to call,or would an email notification here suffice? Thanks again, Travis 2 • From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, May 31,2016 4:31 PM To:Smith,Travis T<Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]Re: 3K-27(PTD#197-046) Rig Workover Thank you for the notification. Let me know when you determine the leak depth. Victoria Sent from my iPhone On May 31,2016,at 4:10 PM,Smith,Travis T<Travis.T.Smith@conocophillips.com>wrote: Hello Victoria- ConocoPhillips Alaska is currently in the process of a rig workover at Kuparuk producer well 3K-27. The planned scope of this workover was to pull-and-replace the 3-34"gas-lift completion to address a tubing leak in the well. During the course of the rig work the well has failed an MITIA to 2500 psi and it is possible a leak in the 5-%" production casing is the cause. To verify if the production casing leaks,and determine the depth of the leak,we are currently preparing to run a test packer. I'm sending you this to notify that we may be moving to an operation to address a leaking production casing in 3K-27. If there is indeed a leak in the production casing, and it is deep enough to not interfere with gas lifting operations,we will likely isolate it by stacking a packer above it. Please let me know if you have any questions or need more information. Thanks very much, Travis Smith Wells Engineer 907-265-6450 3 1/4.9, - 0 _ 7 0 N Z lilo�w U cu cu Y •u � Is-or‘} O CO X Nco t Q,\e'-r' ▪ Q a Y 0 V • H` O V OJ ZI Gp , T A a p 4f u In > O Q a p p a co Y c0 T Q QW L LEQ OOc0 0 O c0 O C m0 --I � O J Y r r T >, T ?. ''' CU O s-c Y V) Q F- 0 � �• co 10 10 R ✓I C C C fq I- J ,,,,^ f0 ?,,,^ 2 E 2 E E Y 2 4-- In oo ao " = c - > N z Q N C cD 0 Q 4J Z Q 0 O 'O O T U U Y ix ii ,_. . u cm O N C O t] 0 0 0 0 0 0 ▪ O N L W cr a W W W W W W W 00 ro p O F- LL LL LL LL LL LL LL •� N E - O Q J J J J J J J . -0 Yvs O cCo C U0 I— Q Q Q Q Q Q Q C = Q Z Z Z Z Z z z p� 0 0) O U. U- LL LL U. 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U C CD in to yyJ,� Y w ce L c II D U +' Q 8 2 N co O) J U N " jp N 7 d N Q t CO N Tr '- N N Y 21 Ol F. t ry .J N N J M Z Ol co O W N 4--, V1 Y i/• PIF-1im co L a CA c1 d F- a a Q Loepp, Victoria T (DOA) From: Loepp, Victoria T(DOA) Sent: Tuesday, August 18, 2015 1:46 PM To: 'NSK Problem Well Supv' Subject: RE: 3K-27 (197-046)Production with known TxIA leak request. Approval is granted to conduct up to 30 day test. If longer testing period is required, please request an extension for the AOGCC. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 a� q 5 2016 Work: (907)793-1247 Sir ®I ��o MAR 1 Victoria.Loepp aC�.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loean@alaska.gov From: NSK Problem Well Supv [mailto:n1F17@conocophillips.com] Sent: Thursday, August 06, 2015 3:53 PM To: Loepp, Victoria T(DOA) Cc: NSK Problem Well Supv Subject: 3K-27 Production with known TxIA leak request. Victoria- Below is a forwarded email with the detailed request from the wells engineer regarding the 3K-27 in which we discussed earlier today. Let me know if you have any questions or need further information. Attached is a copy of the well bore schematic. I appreciate your time to review this request. Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 From: Brown, H Marshall Sent: Thursday, August 06, 2015 3:23 PM To: Freeborn, Dusty (ASRC Energy Services) Subject: 3K-27 5 • • Dusty, Well 3K-27 has been shut in for about three years now(since middle of 2012). We would like to get a production test on 3K-27 to see if it is a potential rig work over candidate, as well; a good production test could indicate potential development/workover opportunities in other wells for us in the future. Unfortunately,the most current production rates from 2012 are not representative of what the well is expected to be capable of. In 2010,this well was producing at an expected rate of about+500 BOPD.Towards the end of 2010 the well appears to have fallen off of a cliff and settled down at about 50 BOPD in the beginning of 2011, by 2012 it was down to 30 BOPD and was shut in thereafter.After such a length of time, we do not know what the well is capable of due to ever changing reservoir conditions. 3K-27 was recently logged to find that there are production leaks intermittently dispersed over a+/-2,000 foot interval,the most shallow leak being at 8,012 ft. and the deepest suspected to be at 9,892 ft.This length of pipe is too large for us to patch and have a reasonable expectation of success at this point in time. (our largest successfully tubing patch length to date is+/-200 ft. and will be attempting a +/-350 ft. patch job shortly) We are asking to put 3K-27 on production with its current leaks to obtain a production rate to determine if the economics make sense for a rig workover.At the current price environment,the cost of a rig workover to replace tubing without a proper justification (expected production rate)is too great.We believe 30-60 day test would be needed in order to see a true production rate.As the well has been shut in for three years, pressure build up or depletion and oil migration could potentially give of us false tests results if we only test for a short amount of time. We believe a longer test will allow for the well to clean up and level out showing a more accurate picture of what 3k-27 is truly capable of. Please let me know if you there is anything else I can do or if there is any other information you need from me. Below is a screen shot of the production history of 3K-27 for your reference. Regards, H. Marshall Brown Wells Engineer ConocoPhillips Alaska, Inc. ATO-1842 Office: 907.265.6218 Mobile: 281.732.5844 H.Marshall.BrownPConocoPhillips.com 6 111 j97-04.(p 2►67? WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 30, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED s RE: Leak Detect Log: 3K-27 Run Date: 5/28/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-27 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22751-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: -7(1/ (\ Signed: ��.z 1110 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 29, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 I _ r RE: Multifinger Imaging Tool (MIT) : 3K-27 Run Date: 5/23/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-27 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22751-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: —1/0/\2-- Signed: Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned durin9 the initial scanning project. They are available in the original file and viewable by direct inspection. / ~' 7' ~/"/~' File Number of Well History File PAGES TO DELETE Complete RESCAN [3 Color items - Pages: GraYScale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: Other - Pages: DIGITAL DATA D Diskettes, No. Other, No/Type .OVERSIZED .Logs of vadous kinds Other COMMEN'I'~: Scanned bY: ~e~w~j Mildred-D~mtha a~Loweli oate.: ~/// TO RE-SCAN Notes: Is/ Re-Scanned by: E~ve~ Mildred Damtha Nalhan Lowell Date: /si • • <2t ( 3t -z7 Regg, James B (DOA) P't «7o4 2 From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Monday, April 16, 2012 12:55 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) - 4(47_ Cc: NSK Problem Well Supv Subject: 3K -27 (PTD 197 -046) Report of IA SCP Attachments: 3K -27 schematic.pdf Jim, Guy Kuparuk gas lifted producer 3K -27 (PTD 197 -046) was reported to have SCP on the IA when the well was SI on 04/14/12. After the well was SI, the IA pressure climbed to —2200 psi after a few hours. I he production casing is 5.5" 15.5 lb L -80 casing with a calculated burst of 7000 psi (45% = 3150 psi). A leaking GLV is suspected. Slickline will troubleshoot the leak and repair if possible. Attached are a 90 day TIO plot and schematic. Please let me know if you have any questions. SCE' Brent Rogers / Kelly Lyons Problem Wells Supervisor SCP ZZ`op5, ConocoPhillips Alaska, Inc. ATV= ��;, Desk Phone (907) 659 -7224 s D APR Pager (907) 659 -7000 pgr. 909 3 / �� y ® ,ma KRU 3K -27 PTD 1970460 4/16/2012 TIO Pressures Plot TRN ANNL ANNULUS PRESSURE TRENDS TRN_ANNL_INIT 3000. -C WELL NAME WLKRU3K -27 3000 200. 3000. 3000. 2700 3000. • 2400 3000. 2100 1800 -- ----- -- ------ -- - --- _ - - � _ __ - - - - - -}1 1500 1200 - - Pik -&-ker4.44,e-arg ‘ t 900 O. 600 0. 0. 300 O. _ 0. 0 , r. • 0 PLOT START TIME MINOR TIME P T N PLOT END TIME 17- JAN -12 11:46 MAJOR TIME WEEK HRS PICK TINE: ®® 9W Ow ®® ®�0® SC TAG NAME DESCRIPTION P - VALDE LATEST ® WL3K -27 -CHOKE FLOW TUBING CHOKE 7777777 IIIPREV WELL � „t DRILLSITE WELL ® SCRATCH 69 FLOW TUBING PRESSURE ? ?7 ? ? ?? 3 k; 2 7 ® SCRATCH_69 FLOW TUBING TEMP 7777777 NEXT WELL III AI- P3K5002 -27 GL CASING PRESSURE 7 ? ? ? ? ?? - 7? ?? ? ?? 71 ' - ' : `"'")E OPERATOR III 7 ? ? ? ? ?7 Pm OPERATOR VERIFIED III SCRATCH_69 INNER ANNULUS PRES 7777777 Por SYSTEM AUTO ENTRY M SCRATCH_69 OUTER ANNULUS PRES 777 ? ?77 P rIr BOTH KUP 3K-27 C illips _ I III . °taro , a W Ilbore APIIUWI Field Name Well Statu Inc! (°) MD (ftK8) Act Btm (ftKB bps 500292275100 KUPARUK RIVER UNIT PROD 59.55 3,200.00 10,456.0 ' Comment H2S (ppm) Date Annotation End Date KB -Ord (ft) Rig Release Date ... WNlCari33 - 3x - z7 3/18/201195303 AM ,... SSSV: NIPPLE 100 12/25/2009 Last WO: 41.02 4/19/1997 Scha mat,c : -. . Actual Annotation Depth (ftK8) End Date Annotation Last Mod ... End Date Last Tag: SLM 10,220.0 1/5/2011 Rev Reason: GLV C/O Imosbor 3/18 /2011 ,. Wit ,,.. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f,. Set Depth (TVD) .. String Wt... String ... String Top Thrd HANGER, 37 I i _ CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED -,, ` Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 6g 5 015 ; ■ SURFACE 7 5I8 6350 41.0 6,190.4 4,101.5 29.70 1 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth If... Set Depth (TVD) ... String Wt... String ... String Top e PRODUCTION 51/2 4.950 29.5 10,442.0 6,966.1 15.50 L-80 LTC -MOD 00 1 f ,irt. 5.5x4.5" Tthbi't. '-tiints - --' Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f Set Depth (TVD) String Wt... String ... String Top Thrd CONDUCTOR. " TUBING 3.5"x2.875" 3 1/2 2.992 37.1 10,034.2 6,591.4 9.30 1-80 EUE8rdMOD 4za21 CiiritOletitretaits = I ' NIPPLE. 527 Top Depth (ND) Top Incl Nonni... Top (ftl(8) (ftK8 ( °) item Descri Comment ID On) Iii g 37.1 37.1 0.46 HANGER FMC GEN IV HANGER 3.500 526.5 525.7 6.90 NIPPLE CAMCO DS NIPPLE 2.812 3,426.2 2,584.6 58.12 XO Reducing CROSSOVERS 3.5x2.875x3.5 ABOVE & BELOW EACH MANDREL 2.441 3,508.2 2,628.3 57.37 X0 Enlarging 2.992 GASLIF , T. 5,822.9 3,907.3 55,16 XO Redudng 2.441 3.4 5,902.2 3,952.3 55.88 X0 Enlarging 2.992 7,943.6 5,058.6 54.92 X0 Reducing 2.441 8,025.6 5,106.0 54.75 X0 Enlarging 2.992 1Iii 9,189.1 5,860.9 38.45 XO Reducing 2.441 9,267.9 5,923.0 36.64 X0 Enlarging 2.992 9,702.6 6,289.9 27.13 X0 Reducing 2.441 GAS LIFT, : � 9,784.8 6,363.3 23.71 XO Enlarging 2.992 5. 608 -" 9,974.1 6,536.6 24.47 XO Reducing 2.441 10,024.5 6,582.5 24.16 NIPPLE CAMCO D NIPPLE NO GO 2.250 10,032.3 6,589.6 24.11 SEAL ASSY BAKER GBH -22 LOCATOR /SEAL ASSEMBLY w /SBE 3.000 ilsve r r' _ t ots ,.... shot Top (TVD) Btm (ND) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date Ish••• T Comment 10,152.0 10,167.0 6,699.2 6,713.0 A -3, 3K -27 5/8/1997 4.0 IPERF 180 deg. phasing; Oriented ( + / -) 90 deg. F/ Lowside, 2 1/8" EnerJet Notes: General & Safety ` _ = all SURFACE, End Date Annotation 41 3/18/2003 NOTE: TAGGED TBG RESTRICTION @9956' SLM (9975' RKB) _ 11/7/2009 NOTE: Surface CSG Patch OAL= 79 ", welded sleeve w /.500 wall X65, 10" pipe (11/7/2009 WSR) 7/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, 7,982 Se GAS LIFT, 9,226 N. GAS L IFT, -- 9 ,741 gi it at GAS L IFT, 10,012 NIPPLE. 10,024 W 1 M It 1,k;,:ii Top Depth Top port ■ SEAL ASSV, (TVD) Ind OD Valve Latch Size TRO Run 10,032 b Stn Top (MKB) ( 8103 ) ( ") Make Model (in) Sery Type Type On) (psi) Run Date Com... NI, 1 3,464.8 2,604.9 57.36 CAMCO KBMM GAS LIFT GLV BK 0.188 1,279.0 3/16/2011 2 5,858.1 3,926.1 53.30 CAMCO KBMM GAS LIFT OV BK 0.188 0.0 3/16/2011 3 7,981.5 5,080.5 54.70 CAMCO KBMM GAS LIFT DMY BK 0.000 0.0 11/19/2004 4 9,226.2 5,890.1 38.12 CAMCO KBMM GAS LIFT DMY BK 0.000 0.0 8/6/1998 5 9,741.2 6,3242 26.98 CAMCO KBMM GAS LIFT DMY BK 0.000 0.0 6/22/2009 IPRF, 6 10,012.2 6,571.2 24.23 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 8/5/1998 10,152- 10.187 1 1 PRODUCTION E504 5 ". 29. 10,442 TO, 10,456 ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 1St, 2010 Mr. Guy Schwartz Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Guy Schwartz: ~~ q7- o~(v 31C- ~-~I Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. 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 November 10th, 20th and 24th, 2009. The corrosion inhibitor/sealant was pumped December 29th and 30th, 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, Perry K1 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 01/01/10 - a~~ ~e ~r_ ~n ~ ~k Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-26 50103205750000 2080940 12" n/a 12" n/a 4.25 12/30/2009 2A-27 50103206040000 2091070 36" n/a 36" n/a 12.75 12/30/2009 2C-14 50029212260000 1842100 18' 2.5 50" 11/20/2009 12.32 12/30/2009 2C-15 50029212190000 1842030 SF n/a 26" n/a 4.67 12/30/2009 2C-16 50029212180000 1842020 SF n/a 33" Na 7.22 12/30/2009 2D-02 50029211770000 1841520 SF Na 24" n/a 4.45 12/30/2009 2D-03 50029211780000 1841530 SF n/a 24" n/a 4.67 12/30/2009 2D-04 50029211760000 1841510 SF n/a 24" n/a 4.45 12/30/2009 2D-05 50029211570000 1841260 SF n/a 24" Na 4.45 12/30/2009 2D-08 50029211580000 1841270 SF n/a 28" n/a 4.67 12/30/2009 2D-13 50029210700000 1840120 21' 3.0 27" 11/10/2009' 5.1 12/3012009 2D-14 50029211830000 1841590 SF n/a 24" n/a 6.37 12/30/2009 2D-16 50029211850000 1841610 28' 4.0 26" 11/10/2009 5.1 12/30/2009 3K-27 50029227510000 1970460 7' 1.0 12" 11/24/2009 2.97 12/29/2009 ~ ~ • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 • ~~~./{..'~{.~D NOV 1 2 20Q9 November 10, 2009 Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~I~aka ~il & Gas Cons. Cornmission Anchoro~~ ~'a:~.~ 4~~. ~~ i1 i. ~ ~~~~ Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we113K-27 (197-046) surface casing excavation and repair. Please ca.ll Perry Klein or me at 659-7043 if you have any questions. ConocoPhillips Well Integrity Projects Supervisor Enclosures ~ u STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well Q Plug Perforations ~ Stimulate ^ Other Q SC patch Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter spended Well ^ 2. Operator Name: 4. Well Class Before Work: Permit to Drill Number. ConoCOPhillips Alaska, InC. Development ~ Exploratory ^ 197-046 / 3. Address: Stratigraphic ^ Service ^ API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22751-00 KB Elevation (ft): Well Name and Number: RK 75~ ~~5 r 3K-2~ 8. ~2[operty Designation: 10. Field/Pool(s): ` ADL 25519 ALK 2555 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured ~ 10456' feet true vertical ~ 6979' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121 121' SURFACE 6115' 7-5/8" 6190' 4101' PRODUCTION 9957' 5-1/2" 10032' 6589' PRODUCTION 422' 4-1/2" 10442' 6966' SC Sleeve 79" 10" 79" 79" Perforation depth: Measured depth: 10152-10167 ~~~~~~~,~ ~ true vertical depth: 6699-6713 ~ Q v ~~~~-~ y;~;; Tubing (size, grade, and measured depth) 3-1/2 & 2-7/8, L-80, 10034' MD. ~~$~(~ ~~~ $I Cj8$ COfiS. ~~l11~"i#~SIDII Anchdxgg~ Packers & SSSV (type & measured depth) Baker SsE 10033~ SSSV= NIPPLE SSSV= 526' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation NA Subsequent to operation NA 14. Attachments 5. Well Class after work: Copies of Logs and Surveys run _ - Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 6. Well Status after work: Oil~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby ceRify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-305 Contact nd I n 59-704 Prin Name Perry I in Title Well Integrity Project Supervisor Signature Phone: 659-7043 Date 11/10/09 ~ _ ~ d ~.,_,1vU~' j~ ZpQ9 .~ /!//Z- o`f Jr/, ~/~9 Form 10-404 Revised 04/2006 ~, v Submit Original Only • ~ 3K-27 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/5/2009 10/16/2009 11/6/2009 11 /7/2009 11/8/2009 1119/2009 Cut and removed 5' of conductor. Cleaned surface casing and after further visual inspection by WI supervision it was determined to excavate cellar another couple of feet. Pressured up tc 400 psi on OA before leak was found @ 13.5" below bottom of flute and 23.5" below braden head. Final T/I/O = SI/0/0. Welder removed 2 feet of conductor for a total of 7 foot removed. Chip cement out of conductor and cleaned A& B band for inspection by KAKIVIK. Drilled and tapped 1/2" hole in SC @ 13.5" with no fluid. T/I/O = 0/0/0. Cooper heat preheated starter head to 500 degrees. welded two double wedding bands Pabricated from .500 wall X65 10" pipe. Welded sleeve fabricated from .500 wall X65 10" pipe. Sleeve length is 63". Overall patch length is 79" . Called Kakivik for inspection. Re installed IA vr plug and normal wellhead jewelry. MIT OA (passed), Initial T/I/O = SI/0/0. Pressured up with 1.85 bbls of diesel. Start T/I/O = SI/0/1800, 15 min T/UO = SI/O/1760, 30 min T/I/O = SI/O/1760. 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Y.~ .a ~~J~~~~~~#I ~I I .,~~ts T~' , , , ~ ~? #.~`~ V~~ lc ~~ k }2 ~ . y~ , 4 X : ~~~ ~ ~ ~ ~~~. ~ f r^ &~f~~'?'~' '23~' 'f'h.. ! r ~ 1 ~ ~ `~~4 ~3 ~ . ~~}-..Y I ".~ ,~- ,r~~"",9l~~'pW T i f *._, ~ - r ~~~~~'Kp~hs~ k ~ f ~ ~ }h * ~k' ~ J F~P j ,f ~~ ~~ ~~ r ~, `'[~,iY~,~ fM.r„ ~, ~I . ~' .( 3 I . aa'i~ 5 , ~~ ~ x ~ ~ ~ ;~ ~~ ~ ~ ~ ~. F, r ~` , + ', : ~~ S . ;; ~ !~ ~ ~'~ . 3 1 ' Y'~ ~~` ~ 1 ~ `~ ~~ ~ ~ i? ~ _ :,1 'A~v`''.` ~.3 ~r ~ V~ Y , .. ~ ~. ~ ~ti r' ~ : ~~ , ~~ ~ I j ' +~ `rs ~ " 4 :~ ~ a y. ~ ,. . . r A . ~u~K~n ~~. ~ '~~~`~ ~~ , ~i ~'~~`.. ~ ~ ~~ .r~i~ ~~ ~ - . ,~ ,iar ~ ' ~, , I4 . tiyN ~ ; ~ , • ~ 1 j ~~ 1 ~} , 1 ~R y r~~~ ~ ~ ~ ' ~ T r ~ r~'' L u ~' l~: ': ~ ~ - . . . . ! *~, f , ~ ~ ;~ff~~~u ~, ~ .. t . ,~:' - ~ 'w ,* ~ ~ ~S: ~ ~t.. ~ _ , ~ ~ ~ ~ . ~ . . ' . # - .~; ~ .~ ,~ t~' . ~F . .1 ~ :` 1~ ~~ ~ +!.AY r~ , S ~:, ~- ~: ~~' re2 .~ ~ ~.~ . _ ._ " ~' ~ti ~ • "-~~ ~ °~ _ ~;;w~' ~ ~ ~R.~~,~ ,w „ ~-~ ~- _ _~, ~ ~ ~ ~ `'~. ~' ~~~ ~~ ~ ~~ ~~. ~ ~~~~~ ~ ~~~ ~ ~~ ~~ ~ ~~ ~,. ~ ~ ~ ~ ~~ ~ ~ ~ ~ ° ~ ~ ~ ~ r° ~~ ~ ~ ~ ~ ~ ~, " ~ ~ ~ ~ SEAN PARNELL, GOVERNOR ~~~ ~~ ~ ~ ~~ ~ .~ ~ p ~ ~~ ~ ~~,~ ~~ "~~ ° ~ ~ -~~ ~~~ ~. ~ ~a:~~ ~~ ~a ~ r_~.: ~ ~ ~.~ ~~. ~, ~~ ~ ~-7~ 0~ t11sy t7r~-.7 ~ 333 W. 7thAVENUE SUITE 100 COI~TSERQATI011T COMl-IISSIOl~ ~~~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. M.J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 ~~ r~ ~~ ~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K-27 Sundry Number: 309-305 Dear Mr. Loveland: '=".`~ ~ ~"~°`°° ~ . ' :~~~~`i Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Cha.ir DATED this ~ day of September, 2009 Encl. • ~ • • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 28, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~ , r,. ~ ~.~,; `' ` ~~,~ ~;~' ~ ;~ ~.« ~; '~. ~s . . _ . a ~ s.~? Y~ . ~~ ~ ~~~;~~r .:~ ._. ~ ~ . $.. . t . Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we113K-27 (PTD 197-046) surface casing repair. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, i~~i//~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures ,,/~ ` ~' ~ `~ ~ ., O~ ~I17 ' " . - .. . .,.a, >.~ , • aJ ~ ~ ~ ~~ STATE OF ALASKA ` ~ ~~ ~ > s ; ~' ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ APPLICATION FOR SUNDRY APPROVAL~~~`- ~~ ~- -.~~~ s~~~~~ 20 AAC 25.280 1. Type Of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ OYher Q Alter casing ^ Repair well ~^ Plug Perforations ^ Stimulate ^ Time E~ension ~ SC patch Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. oeve~opment Q Exploratory ^ 197-046 ' 3. Address: SVatigraphic ~ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22751-00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y@S ^ NO ~ 3K-27 • 9. Property Designation: 10. KB Elevation (ft): 11. FieldlPool(s): ADL 25519 -ALK 2555 RKB 75' Kuparuk River Field / Kuparuk Oil Pool ° 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective oepth nno (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10456' ~ 6979' • Casing Length Size MD ND Burst Collapse CONDUCTOR 121 16" 121 121 SURFACE 6115' 7-5/8" 6190' 4101 PRODUCTION gg57' 5-1/2" 10032' 6589 PRODUCTION 422' 4-1/2" 10442' 6966 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10152-10167 6699-6713 3-1/2 & 2-7/8 L-$~ 10034' Packers and SSSV Type: Packers and SSSV MD (ft) Baker SBE 10033' SSSV= NIPPLE SSSV= 526' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ~^ ' Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat October 15, 2009 Oil ~^ • Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Loveland/Klein 659-7043 Printed Name MJ Lov land ~ Title: Well Integrity Project Supervisor Signature L~ Phone 659-7043 Date ~` ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -~~j' Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ ~~~itr~LC~ j) ~l,~. ~p GC 0 Gt.~, m t~4 Tl ~ 0 _ Other: l~l n ~ / O ! 4n n ~.X , (U 0 ~ ~ =n~d Ge.~3y- tS .i1 L Gt~ 4 ~s 'G / . . . . A ~ / ~ Subsequent Form Required: ~ _ Y ~ ,M • \ r ~/ ~''~+ ~ ~~'n- ~°:~ t~ a~ ~ LU~~ ~ ~, ..:: .~ ~ ~ ~ ~ ~/ APPROVED BY ~~ ~ ~ ^~ MMISSIONER THE COMMISSION Date: Approved by: Form 10-403 Revised 06/20061 `„J (~( U ~~ U/~ L ~ b~~iin Duplicate ~y vY4j ~ ~ ~` ~ ~ 1 ~~ ConocoPhillips Alaska, Inc. Kuparuk We113K-27 (PTD 197-046) g ' ,~... ~km" ~ ~ s a.- ~ ~ ~~~ ~ ~ ~~ * ~ . y~~ ~~ ~ ~ ~~'~~ar SUNDRY NOTICE 10-403 APPROVAL REQUEST August 28, 2009 This application for Sundry approval for Kuparuk we113K-27 is for the repair of a surface casing leak. The well is a producer, originally completed in April 1997. On July 11, 2007 fluids were observed at the conductor top by the Operator and the suspected surface casing leak was reported to AOGCC the following day. An OA cement shoe was subsequently pumped which temporarily stopped the leak which was believed to be located near surface. Subsequent testing indicated a near surface leak in the surface casing. With approval, repair of the surface casing will require the following general steps: Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 2. Excavate wellhead location. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. 6. Repair damaged surface casing to return the casing to operational integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection of the casing damage. 7. QA/QC the repair welds and MIT-OA to verify integrity 8. Install anti-corrosion coating on exposed surface casing. 9. Patch the conductor and top off the conductor void with cement and waterproof sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to injection. 12. Submit 10-404 report of repair operations to AOGCC. . ConocJPhillips Alaska . RECEIVED P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 AUG 0 ? 2007 iU(1ska Oil & GDmmissioff August 6, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SC.¿\NNED AUG 1 ,42,007 Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. we1l3K-27 (PTD 197-046). The reports record the completion of the surface casing cement shoe repair on this well. / Please call MJ Loveland at 659-7043 or Brent Rogers or Perry Klein at 659-7224 if you have any questions. ;;fµ~- M J Loveland Well Integrity Supervisor Attachments '" "'''" "" r' i', 1. Operations Performed: Abandon D Repair Well Q <i Plug Perforations D Stimulate D ,",!(Iåthe './H "'" '1 ther þ,~ ". Alter Casing D D Waiver D µ2 ;;',¡r;; Pull Tubing Perforate New Pool D Time Extension "- Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Q I D / Development Exploratory 197-046/307-237 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22751-00 / 7. KB Elevation (ft): 9. Well Name and Number: RKB 75' 3K-27 / 8. Property Designation: 10. Field/Pool(s): ADL25519 / ALK2555 Kuparuk River Field I Kuparuk Oil Pool / 11. Present Well Condition Summary: Total Depth measured 1 0456' / feet true vertical 6979' / feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 6115' 7-5/8" 6190' 4101' PROD. CASING 9957' 5-1/2" 1 0032' 6589' PROD. CASING 422' 4-1/2" 1 0442' 6966' Perforation depth: Measured depth: 10152'-10167' true vertical depth: 6699'-6713' Tubing (size, grade, and measured depth) 3-1/2" & 2 7/8" , L-80, 10034' MD. Packers & SSSV (type & measured depth) Packer = Baker SBE & GBH-22 locator Packer = 10,032' SSSV= NIP SSSV= 526' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino 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 proposed work: Exploratory D Q / D Copies of Logs and Surveys run _ Development Service Daily Report of Well Operations _X 16. Well Status after proposed work: OilQ / GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 307 -237 Contact M J Loveland Printed Name M J Loveland./ Title Well Integrity Supervisor Signature AA_A~ _ -' Phone 659-7043 Date ~-6-~7 /"';'/ ~~ Form 1¿ Revised 04/2004 ¡;~ fiÞ tJ· g. C7 Submit n . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS REC A'IIi" i\ '7 \.) IJ \j I o R f GIN A L RBDMS BFL AUG 1 3 1007 \ ~f!ó7 .. . 3K-27 . DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 7/27/2007 Pump OA cement shoe, 25 bbls 15.8 ppg class G with 1.5 ppg CemNET bullheaded down the OA. Estimate 4 bbls cement pumped out the shoe, 1260' column of cement left in the OA. Cement displaced with diesel freeze protect. No returns to the conductor during treatment. 7/29/2007 MITOA-1 TIIIO= 1040/1350/25. Pressured up OA with 1 bbl diesel. T/I/O= 1040/1350/1800. 15 min reading 1040/1350/1630. 30 min reading T/I/O= 1040/1350/1620. ( pass) . MITOA-2 T/I/O= 1040/1350/1620. Repressured OA T/I/O= 1040/1350/1800. 15 min reading T/I/O= 1040/1350/1760. 30 min reading TIIIO= 1040/1350/1760. ( pass ). 3K-27 PTD # 197-046, notic.surface casing leak . Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv (n1617@conocophillips.com] Sent: Sunday, July 29,20077:40 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: ~.~1'9'7&Q46, notice of surface casing leak Tom, Today DHD verified a surface casing leak in 3K-27, PTD 197-046, gas lift producer. A cement shoe was pumped on 7/27/0. DHD performed a passing MITOA to 1800 psi with diesel today. No fluid flow to the conductor was observable during the MITOA. The OA was bled and then re-pressured with Nitrogen to 940 psi. Bubbles were observable in the open flutes of the OA. A personal gas meter was used to verify the bubbles were nitrogen. We suspect a thread leak at the collar that connects the landing joint to the first full joint of casing. The well is shut in and freeze protected. TIIIO= 1040/1350/20 psi. I'll submit the 10-404 for the recent cement shoe shortly. let me know if you have any questions. Perry Klein SCANNED JUL 3 1 2007 Problem Well Supervisor office (907)659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com 7/30/2007 . ~V~VŒ (ID~ ~~~~~~ . AItA~1iA. OIL AND GAS CONSERVATION COMMISSION SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Marie McConnell Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 SCANNED JUL 2 7 2007 Re: Kuparuk River Field, Kuparuk Oil Pool, 3K-27 Sundry Number: 307 -237 Dear Ms. McConnell: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~day of July, 2007 Enc!. 1'ì'1-04(,p 90765. NSK WELLS GRO. ø ·1; 7/?;f)1 RECEIVED STATE OF ALASKA ~,\ JUL 1 3 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION ~ APPLICATION FOR SUNDRY APPROVALAlaska ail & Gas Cons. Commission 20 AAC 25,280 Anchorage p, O. Box 100360, Anchoraae, Alaska 99510 7. 11 perforating, closest approach In pool($) OPèr'Jèd by this operation to nearest prop!!!rty line whel"ê owner~híp Qr landQwnership changes: Spacing EJllceptlon Required? Yes n No 0 3K-27 9, Property Designation; 10. KB Elevation (ft): 11, Field/F'OOI(s); AOl25519 " ALK2555 RKB 75' KU'Jaruk River Field 1 Kuparuk Oil Pool ., 12. PRESENT WELL. CONDITION SUMMARY Total depth MD (ft): To~el Deptt'l ND (ft); Effective Depth MD (ft); Effective Oepth ND (ft): Plugs (ml!lasured): Junk (measured); . 10458' / 6979' .f CasIng Length CONDUCTOR .SUR. CASING Perforation Depth MD (ft): Perlol1ltion Depth 1VD (ft): 1t11~2'-10167' 6699'.6713' Plilckers and SSSV Tyl'~: Packêrs and SSSV MP (ft) PackE!r = Saker SBE & GBH-22 locator Packer" 1 0,032' S$SV;:; NIP SSSV" 526' 13. AttaChments; Description Summary of Proposal [-2] 14. Wall Clas$ after propo5ed work: Detaîle(l Operations Program D BOP Ske~ch 0 Exploratory 0 DevelQpment 15. E$~ir'l'latèd Date for 16. Well Statu$ after þrtlposed wQrk; Commenc:ing Operation5; July 15, 2007 011 0· Gas D 17. V~rbal APprQv;;¡1; Date; 7/12/07 - . k~i 11I\ WAG D GINJ D Commission Rêpres~ntatÎve: Tom Maunder,/' 15. I hereby œr!ify that the forè!;lQíng is true and correct to the best of my knQwledge, Printed Name Marie McConnell ~A -- ~.A&. - -":.- ~.Ai"/ .oiIY~/ ./..t'/ 07/13/2007 11:30 1. Type of Request: Abandon 0 Su!\pend 0 O)cr~tjQnal Shutdown 0 Al'\er CIIsíng 0 Repair well 0· Plug PerfQr.i!tlons D Change ~pproveCl program 0 Pull Tubing D Perforate New Pwl 0 2, Operatgr Name; 4. Current Wall Class: ConocoPhillips Alaska, Inc, Development 0 3. Addl'1!!ss: Stratigraphic D Si2P. MD 121' 16" 121' 6115' 7-6/8" 6190' PROD. CASING PROD. CASING 5-112" 9957' 422' 10032' 10442' 4-1/2" Signature A"/ Commission Use Only Conditions of approval: Notify CommisSion so that a representative may wi~r'le9S Plug Intagrity D aop Te5t 0 Mechanical Integrity Test 0 other: .......,en! 'onn "",""'" 1..1. () ~ 1# App""," by, -~'-1 )'!t,1MISSION.~ Fonn 1~' -- _006 0 ~1G I~A L PAGE 01 Perforate 0 o wail/Glr 0 Time E)Ctenslon 0 Re-enter S\lspend~d Well 0 5_ Permit to Drill Number: 197-046 "" a, API Number: 50-029--22751-00 ." a. Well Name and Number; other 0 Stimulate Exploratory 0 Service 0 TVIJ Burst CollapSE! 121' 4101' 6589' 6966' Tubing Size: 3-1/2" & :2 7/8" Tubing Grade: L~BO Tubing MD (ft): 10034' 0' Service D Plugged D WINJ 0 Abandoned 0 WDSÞl. 0 Contact: MarIe McCOIine1l1 Perry Klein Title: Problem Well Supervisor Phone 659-7224 Deteft'11Æeer 7h~Jð7 Sundry Number: n '>'7 c.~~- ñl,''}J Loca~ion Clearance 0 RBDMS BfL JUL 2 6 2007 Date: ~.l£'ðr APÞROVED BY THE COMMISSION Submit In Duplicate ~?¡Í& /þ 7. IS'. 07 07/12/2007 14:16 90765. NSK WELLS GR04IIÞ PAGE 01 ConocJ'Phillips Alaska ~~c JUl l2'lv~D AI"ka Oil 1 /J ZOO? & Gas C. Aile/, 0/18. COJh....! 'Or'le ""'"81;011 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-036Q July 11,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Subject: KRU 3K-27 OA Shoe Sundry Application. PTD 197-046 Dear Mr. MaWlder: Enclosed is a 10-403 SlUldry Application to pump cement into the outer annulus of 3K-27 (PTD 197-046) to seal offthe open shoe,' The remedial cement shoe is needed ASAP due to a near surface, surface casing leak to atmosphere via the conductor. The outer annulus sustains approximately 300 psi and can not be bled down. to stop the active fluid seep to .,./ surface Due to the environmental and safety hazard if the surface casing leak worsens, an expedited approval is requested. :Please contact me at 659~ 7224 ifthere are any questions. Sin.cerety, Marie McCon.nell Problem Well Supervisor Attachments 07/12/2007 14:16 90765. NSK WELLS GRO~ PAGE 03 ConocoPbillips Alaska, Inc. Kuparuk WeIl3K-:27 (PTD 197-046) SUNDRY NOTICE 10-403 REQUEST July 11,2007 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhUHps Ala,ska~ Inc., intent to pump a cCtn.ent sboe in the surface casing of Kupamk producing we1l3K-27. The ccme.nt shoe is required to stop a fluid leak to surface through an appa.rent hole in the surface casing into the conductor casing. 3K~27 was drilled in 1997and ha.g been on production since that time. A surface casing cement shoe was not pumped at the time of original completion, the shoe was len open after it was drilled out for the next casing stn.ng. On JulylO, 2007 a small pool of standing diesel was found. at the conductor top. Diagnostics tests on July 11, 2007 verified communication between the outer armulus (OA) and the conductor. A small volume of nitrogen was injected into the OA and nitrogen bubbles were observed in the conductor fluids. Bleeding pressure off the outer annulus stopped the nitrogen bubbles. The OA sustains about 260 psi, and recharges from the open shoe immediately after being bled down. Isolating the surface casing from formation pressure with cement will allow the OA to be kept at zero pressure eliminating the leak to surface. The proposed plan includes the pumping a cement shoe to shut off the pressure support and the leak to surface to avoid a spill and safely perfonn additional diagnostics. Subsequent diagnostics will be perfonned to determine the depth and severity of the leak to develop a repair plan. AOGCC approval will be obtained as needed prior to proceeding with repair work. 07/12/2007 14:16 90765.4 . NSK WELLS GR~ CønøQQPhUUps Alaska, Inc> ""',, "'. ;.:,.:.,.",,;::::.::'.;:,;. NIP (528·527, OD;3,500¡ G35 Lilt· anClreltvalVa , (94S~-34aB, !¡Io. ~t, ~ndr~lVaIY~ 2 r.;;~~H.~g, C3A" Lift ,d,eIICùmmy Valva 3 (1E8'-?9B~, OD~U07) Ga, LIt!, 1C1rAllDummy viillve4 (E2~6.&227 , OD:4.507) Gft~ UIt ,drolll:lummy V31ve 5 (E74,.Q74?" OD~~ .507) G8~ UIt, '1drnllDulTlmy Valve ~ oa,:¡"oD13, OD:4.507} NIP 00:24-1002~, OD:2.975) PROD. . CAsiNG (0-10032, 0&1:5.500, W;;1~,!!iO) I.OC¡1oTOR . D03?'-'OD3~, OD~4.500) ?t:r1 01S'.101S7} ; ,., 1'1'1·]11 ... ::. . , .¡:[:"~' : ': .:~: :,..'. ;)ij :!¡ij : :: :::¡;:.:~:: :: ::\tH:: :I¡: "':'" ..::;\!..... :.: .. " .,:.¡ :: : . ::;; ~ ::~ . ):; .'.' ~ ~ ' . ,: ;:¡¡¡¡ i¡: :: - - - - - '3K.:.27':' :,: :,::: .. ";"::"::.:."," ~ Well Tvne: PROD oricr ComDlot/Qn: 4119/1997 Last W/O: Ref Loa ~~: m: 10456 ftKB M~x Hole An"le: 60 de" filJ 3200 Ai='I: 5O~92275100 SSSV Tvee: NicDle Annular Fluid: Reference Loa: Last fa a: 10157 Lest Tea Date: 11/13/2004 Citiii't'!êlSmnd'¡ió:AL.L 'STRINGS ....... DescrlP;~on SiZe CONDUCTOR 16.000 SUR. CASING 7.625 PROD. CASING $,$00 PROD, CA$ING 4,500 ,1TübinQ¡St~lnQ,,.(r:uÐtNCJ::.'::'··· . Size Tón Bottom TVP 3.500 0 3426 '564 2.875 34:.16 350B 2628 3.500 3508 5823 :3808 2.875 SS:.13 5902 3952 3.500 5902 7944 50$9 2.875 7944 a021$ 5106 3.500 8026 91 e9 saa1 2.a71$ 9169 9268 5923 3.500 9268 9703 6290 . 2.875 9703 97eS f33S4 3.500 9785 9974 6536 2.875 9974 10026 6584 3.500 1 D026 10034 6591 :p:t!r.fØr.atfÓr:r~::Summ~r;;:·:::- :', :"''':.:':."':.,, ,,:;. ;..::.;',"' ',".:' ,"::';:::,;::-:', .,,'" Interllal TVD Zon& $t~t"$ pt SPF 10152 -10167 aees· 6713 A~ 15 4 Ton o o o 10020 ,.,::,:::.:'...... St MD Nt! Man Man Typ~ V M1r V Type V 00 Mfr 1 3465 2605 Cs mot> KBMM 2 ~ 3927 Ca mco KBMM $ 7961 50SO c~ ".,co KBMM 4 9226 5890 Cs meo KBMM 5 9741 6324 Camet> KBMM 6 10012 6571 Cameo KIiMM ·Otlirllif'{ lul:u;····iI ï¡lIm;;:'~teiJ,;,·¡J~"'RV, : . Del: tl'1 TV) Tvce ~6 525 NIP 10024 &i82 NIP 100:32 6Se9 LOCATOR 10033 19590 SBE :Oêòer-,!I:kNote!l·::·· ... Date I Note 3I16120031':A~1!.i~" TBG RESTRICTION 11M19SS'SlM-{j975' RKST 'G:Ii!U,;;ift'Ms'ndrelsNIII11Iel:·: . GLV OV OMY CMY CMY DMY ,.. N.",,··· Cameo 'OS' Nipple Camc:o '0' NII:IDlê NO 00 Baker 'G6H·22' Baker .",,"."..:.",.' , f-- ~ I---- ~ ¡....- PAGE 04 KRU 3K..27 '" ....... ......'....,..,....'....,. """"."..:.,::.:.: ::':':"'::".'. ":.':' .".........'. ...:.,.::..... Anðlê fl'ðTS: 24 <:lOCI 1B19951C1 Anae r8J TO: 23 deD Ii'!! 10456 Rev Resson: TaD. GlV design Last UDdate: 121412004 ...... "'.,,.... Bottom 121 a1SO 10002 10442 TVD Wt Gr:\d~ Tl'lre~d 121 132,50 H-40 4101 ;(IUO L-SO 6589 15.50 L·80 69613 12.60 L-80 " ,,:;.:;..::,:!,:;:.;::::':' Wt Orade Thread 9.30 L.,go EUE 8RD MOD 6,50 L-50 ~UE 8fi:1J 9.30 L-80 IWE 8RD MOD 6,$0 L-ao EUE a~b 9,3(1 L-80 EUE SRO MOD 6,50 L-SO ~UE; S~p 9,30 1.-80 EUE SRD MOD 6.50 L-60 EUE 8RO 51.:30 !.rOO IiUr: 6R¡;) MOO (1,50 L-ao EUE aRC 9.30 l.s<J EUE 8RD MOD 6.50 L-50 EUE 8RD 9.~ L.ao ¡WE 8RD MOD ',...'........,.:,.:..::.:...:.'.... .:.:..:......,::..::.::.:..... D~te ~ 51811997 IPERF CDmml!"~ 180 deg. pha5ing; Oriented (+1-) 90 deQ. Fllowside. 2 118" ~nérJêt Latch Port mo Date Vlv Run Cmnt 0,155 126$ 1119/2004 0.188 0 ~ 1119/;!OQ./l 0.000 0 111912004 0.000 0 et6l199!! 0.000 0 61511996 0.000 0 ðlS/199!! 1.0 1.0 1.0 1.0 1.0 1,0 ElK BK BK ElK ElK BK . ...."..,..,...,' " ,"" ',' "." . ....'..':.,:,.....'., ... .,.,.::.:..:......,'..'. DescriDfJan 10 2.812 2,2$0 MOO 3.000 ,... " . ." "", """;:,,:::;,.;,::¡..:..,.,,. RE: 3K-27 (PTD 197-046) rw ofSC leak to atmosphere - OA shoe4JroVal requested Page 1 of2 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, July 12, 20075:18 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: 3K-27 (PTD 197-046) report of SC leak to atmosphere - OA shoe approval requested Tom, Thanks for the quick response and verbal approval. I faxed the 10-403 to AOGCC around 3:30 pm today. Please let me know if you don't receive it. Marie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov) Sent: Thursday, July 12, 20075:10 PM To: NSK Problem Well SuI)¥¡,~James B (DDA) Subject: RE: 3K;'U~ 197-(46)feport of SC leak to atmosphere - OA shoe approval requested Marie, I have attempted to reach the Commissioners without success. Given the urgent need for the "fix", you have my oral approval to proceed with pumping the OA down squeeze. Please have the sundry submitted as soon as practical. Call me on the cell if needed. Tom Maunder, PE AOGCC 529-1645 -----Original Message----- From: NSK Problem Well Supv [mªi!to;n 1617@conQcophillips.cQm] Sent: Thu 7/12/2007 3:21 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: 3K-27 (PTD 197-046) report ofSC leak to atmosphere - OA shoe approval requested >Tom, > > A surface casing leak was identified on Kuparuk gas lift producer > 3K-27 (pTD 197-046) on 7/11/07, a small pool of standing diesel was > found at the conductor top. Diagnostics verified communication > between the outer annulus (OA) and the conductor. A small volume of > nitrogen was injected into the OA and nitrogen bubbles were observed > in the conductor fluids. Bleeding pressure off the OA stopped the > nitrogen bubbles. The OA sustains about 260 psi, and recharges from > the open shoe immediately after being bled down. Attached is a > schematic and 90 day no. > > A temporary pit liner has been installed and the conductor top is > being monitored closely for any change in the fluid seeping from the > leak. A remedial cement shoe is needed ASAP due to the near surface, > surface casing leak to atmosphere via the conductor. Approval is > requested to pump an OA shoe so that the OA may be bled down for > diagnostic work. Isolating the surface casing from the formation > pressure with cement will allow the OA to be kept at zero pressure > eliminating the leak to surface. Once the OA cement shoe has been > performed, additional diagnostics will be performed to determine the 7/13/2007 RE: 3K-27 (pTD 197-046) rw ofSC leak. to atmosphere - OA shOe"rOVal requested Page 2 of2 > leak rate and depth to determine repair options. > Due to the environmental and safety ha7Md if the surface casing leak worsens, an expedited sundry approval is requested. I'll fax a 10-403 in a few minutes. Please contact me if there are any questions. «3K-27.pdt» «3K-27 90 day no plot 06-12-07.git» Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com 7/13/2007 . . Conoc;P'hillips Alaska JUL 0 3 Z007 g! P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 \ C17-0~ SCANNED JUL {) 5 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. 4¡~ M.J. Loveland ConocoPhillips Well Integrity Supervisor c------/ . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/1/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na Qal 1C-19 203-054 28" none 28" na 12 6/24/2007 1 C-123 201-084 22" none 22" na 24 7/1/2007 1C-127 201-114 18" none 18" na 12 7/1/2007 1 C-133 201-077 16" none 16" na 8.5 7/1/2007 -- 203-003 27" none 27" na 10 6/2. - - i:iji:::¡~ ill 3K-12 186-165 6" none na 3 6/24/2007 3K-19 201-108 6" none 6" na 3 6/24/2007 3K-20 201-088 4" none 4" na 1 6/24/2007 3K-23 197-097 8" none 8" na 5 6/24/2007 3K-24 198-249 4" none 4" na 1 6/24/2007 3K-25 198-081 6" none 6" na 3 6/24/2007 3K-26 197-077 8" none 8" na 5 6/24/2007 3K-27 197-046 6" none 6" na 3 6/24/2007 3K-31 198-082 8" none 8" na 5 6/24/2007 3K-34 198-077 7" none 7" na 4 6/24/2007 3K-35 197-109 3" none 3" na 2 6/24/2007 MEMORANDUM- State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor . .~' DATE: May 18, 2001 FROM: John Crisp, SUBJECT' Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3K Pad May 18,2001' I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, SSV on 3K-27 would not pass the DP test. The valve was serviced & passed the re-test The AOGCC test report is attached for reference. I inspected 14 well houses on lQ Pad w/no problems witnessed. 'SUMMARY: I witnessed SVS testing in Kuparuk River Field. 14 wells, 28 components tested, 1 failure witnessed. 3.57% failure rate. 14 well houses inspected. Attachments- SVS KRU 3K 5-18-01jc CC,; NON-CONFIDENTIAL SVS KRU 3K 5-18-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phil!ips Alaska, , Operator Rep: Ernie Bamdt AOGCC Rep: John Crisp Submitted By: Date: Field/Unk/Pad: K..uparuk River Unit 3K Pad Separator psi: LPS 65 HPS 5/18/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE ,3K-61 186i0i0 65 70 "50 V "1~ OIL ., 3K-03 1861030 65 70[ 55 P P OIL . . 3K-06 1861240 65 70 50 P P OIL . . . 3K-09A 1861740 65 60 54 P P OIL 3K-10 1861630 65 70 52 P P OIL , 3K-11 1861640 65 70 50 P P OIL 3K-14 1861370! 65~ 60 58 P P OIL 3K-16 1861390 65: 70 ' 70 P' .... P ' OIL 3K'17 1861520 ' 65! 60 35 P' P' OIi~ 3K-23 1970970 65 ~0 58 P P ..... OIL 3K-24 1982490 65 70 50 p p '1 OI~ . ~7,'-~-~-::~-~:~¢~-' 1970460 65 70 52 p 4 OIL 3K-32 1970760 65 70 55! e P ·" OIL , 3K-35 1971090 65 70 50 P P . O!~L , Wells: 14 Components: 28 Failures: I Failure Rate: 3.57% Remarks: RJF 1/16/01 Page 1 of 1 SVS KRU 3K 5-18-01jc 01'40g ggFO C:LOg.Ikl~B-M'DOC PERMIT DATA AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 05/24/99 T DATA PLUS RUN RECVD 97-046 MWD SRVY 97-046 CMT MAP 97-046 7756 97-046 MWD SRVY 97-046 DGR/EWR4-MD 97-046 DGR/EWR4-TVD 97-046 8074 97-046 GAS LIFT 10-407 ~0~10456 0 ~10030-10350 FINAL 0 ~SCHLUM GR/PDC 1 0 ~ERRY 0-10456 0 ~/~200-10456 FINAL 0 5/07/97 7/25/97 7/31/97 7/09/97 8/20/97 8/20/97 8/20/97 FINAL 07/13/98 ~_re dry ditch samples required? yes ~ And received? Was the well cored? yes ~ Analysis description received? Are well tests required?.~ ~yes ~, Received? Well is in compliance Initial COMMENTS T D BOX -- ARCO Alaska, Inc. Post Office Box ,,~0360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 9, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular Injection during the first quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume . Volume Volume Quarter Total Total 2N-315 25326 ] 100 0 25426 See Note #1 below 25426 2L-325 8397 ! 100 0 8497 11883 20380 i 2N-321A 27507 i 100 0 27607 0 27607 3K-23 15 I 0 0 15 0 15 3K-25 4202 ! 100 0 4302 0 4302 1C-15 16695 . 100 0 16795 0 16795 2L-313 8554 I 100 0 ~ 8654 I 0 8654 Note #1' Well # 2N-315. The previously r~ ~orted vohtme of 220 barrels was pumped into this annuhts during the drilling of the well. This was the volume required toj'Iush and freeze protect the annulus during initial drilling operations, not a volume of disposal fluids injected prior to the receipt authorization.tbr annular injection. Total Volumes into Annuli for which b~jection Authorization Expired during the quarter Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume I Volume Volume Injected Status of Annulus 1C-12 34995 ] 100 0 35095 Open, Freeze Protected 1C-13 26800tl 100 . 0 26900 Open, Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO's, we would like to repeat and supplement information we provided with our letter of February 26,1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26th letter, and are only reported here again for the sake of clarity. ARCO Alaska, inc. is a SuDsidiary of Atlantic Richfield Company ~R3B-6003-C Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two Total Total h(1) Total h(2) Total h(3) Volume Current Status of Well Name Volume Volume Volume Injected Annulus 2A-22 16749 100 i 0 16849 i Open, Freeze Protected 2F-19 20725 100 0 20825 Open. Freeze Protected 3K-27 37173 I 100 0 37273 Open, Freeze Protected 3K-26 33970 I 100 0 34070 Open, Freeze Protected 1E-31 33645 I 100 0 33745 Open, Freeze Protected 1E-32 45205I i00 0 45305 Open, Freeze Protected 3Q-22 6245 I 100 0 6345 [ Open, Freeze Protected 1Q-24 23158 I 100 0 23258 [ Open, Freeze Protected 1Q-26 25931 [ 100 i 0 26031[, , Open. Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files 7/9/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11326 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 A-20 PRODUCTION PROFILE 9 80531 I 1 1D-10 ~' CBT 98051 8 I 1 1 D- 124 FLOWING TEMP/PRESS 98052 4 I 1 1 D- 130 ~, \ (~ - INJECTION PROFILE 9 8042 3 I 1 1 D- 133 FLOWING TEMP/PRESS 9 8052 4 I 1 1 E-23 tA.~, tJ - INJECTION PROFILE 980523 I 1 2 A- 17 PRODUCTION PROFILE 980522 1 2 A- 19 PRODUCTION PROFILE 980510 I 1 2 D- 14 ~.A,\ ~, WATER INJECTION PROFILE 980531 I 1 2 D- 16 ~ l r~. - WATER INJECTION PROFILE 9 8053 0 I 1 2 F- 02 L_k ~ C. . WATER INJECTION PROFILE 9 8052 8 I I ..... 2F-03 tvt,~ (.. .-.WATER INJECTION PROFILE 980529 I 1 2 M-23 TEMPERATURE SURVEY 9 80507 I 1 3 C- 04 PRODUCTION PROFILE 9 80505 I 1 3C-04 GAS LIFT SURVEY 980505 I 1 3F-06 GAS LIFT SURVEY 98051 2 I 1 3 F-06 PRODUCTION PROFILE 9 8051 2 I 1 3 F- 14 PRODUCTION PROFILE 98051 4 I 1 3K-27 GAS LIFT SURVEY 980504 I 1 1D-09 ,CBT 980517 I I SIGNED: ..... Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: D i:t I I--I--I [M G _ WELL LOG TRANSMITTAL To: State of Alaska August 20, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. ~./[. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 3K-27, AK-NlM-70098 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Yrm Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3K-27: 2"x 5" MD Resistivity & Gamma Ray Logs: 50-029-22751-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22751-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia, 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 7/31/97 ~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie No. 11202 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Kuparuk (Reservoir Analysis Logs) Well ' Job # Log Description Date BL RF Sepia LIS Tape 3K-22 6~ 7. ©(~. ~ -'/'i 5._%- 97332 GR (PDC) 970509 1 3K-27 ~7'O~ -~'71~ 97331 GR(PDC) 970508 1 ,, ; SIGNED: ~~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 7/22/97 GeoQuest ~ 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Field: NO. 11171 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive r Anchorage, AK 99501 Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1C-06 '~1-©D.<~ I_~-.- WATER INJEC.TION PROFILE 970422 I 1 1H-1 ~,' ~ r~©q~, PRODUCTION LOGW/DEFT 970423 I 1 2 F- 19 ~l C~ ' ~ © I CEMENT MAPPING TOOL 970501 I 1 2 F- 19 ',~ CEMENT MAPPING TOOL 970501 I 1 .2Z-01 -~ . c.~-~ .~ TDT WATER FLOW LOG 970331 I 1 2Z-13 ~ ' I ©~-~ WATER FLOW LOG 970419 I 1 3B-13 '~_~:~ ' (_'~ ~_~ PRODUCTION PROFILE 97041 0 I 1 3H-07 ~'~, ~,,)-~ ~ L~ \ (~.-. INJECTION PROFILE 970424 I 1 3K-22 ~'7 ' O~(-P (2,-~ ~ CEMENT MAPPING TOOL 970509 I 1 3 K-27 dj --'{, O ~ (.p ~.~ CEMENT MAPPING TOOL 970508 I 1 3 K- 32 ~ "] ' O-7 (~''& CEMENT BOND LOG 970527 I 1 · SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: JUL 2 5 '~997 ARCO Alaska, Inc. Post Office Box 10036u Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 8, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-27 (Permit No. 97-46) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3K-27. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad .... STATE OF ALASKA ':' ALASI.,-, OIL AND GAS CONSERVATION C.~MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well [] Oil [] Gas [] Suspended [] Abandoned [] Service \ 2. Name of Operator ARCO Alaska Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 Classification of Service Well i 7. Permit Number 97-46 8. APl Number 50-029-22751 Location of well at surface 1247' FSL, 317' FWL, Sec 35, T13N, R9E, UM At top of productive interval 1724' FSL, 2061' FWL, Sec. 36, T13N, R9E, UM At total depth 1712' FSL, 2245' FWL, Sec. 36, T13N, R9E, UM 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3K-27 11. Field and Pool Kuparuk River Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Rig RKB 41' Pad 35' 1 ADL 25519, ALK 2555 12. Date Spudded i13. Daie T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore I16. No. of Completions 4~9~97 i 4116~97 I 5~8~97 I N/A MSL! One !'17. T°tal Depth (MD+TV[~) 118. Piug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set J21. Thickness of Permafrosl 10456 6939 FTJ 10376 6866' F~ I~Yes ONo [[ N/A MD| 1650' (Approx.) 22. Type Electric or Other Logs Run GR/Res, GR/CCL/CMT 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 16" 7.625" : W-r. PER FT. 151.5# 29.7# 15.5/27 GRADE X-65 SE'FI'lNG DEPTH ToP I HOLE" Bo'FrOM i S!.z...E.. Surf. L-80 Surf. L-80 10030' 121' ] 30" 6190' 10442' j 6.75'_' t I 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) MD TVD MD TVD 10152'-10167' 6659'-6673' 4 spf CEMENTING RECORD _+ 125 AS I 466 sx ASLW, 500 sx ClassG, 60 sx AS I 180 sx Class G 25. TUBING RECORD AMOUNT PULLED 141620 # prop in perfs, 1114# left in pipe SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 1 0034' 26. ACID FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10152'-1 0167' 27. Date First Production PRODUCTION TEST iMeth'dcl of Operation (Flowing, gas lift, etc.) Gas Cons. ¢0mmis~,, 5/15/97 Gas Lift Date of Test i Hours Tested PRODUCTION FoR IOIL-BBL 6/22/97 I 1 6 'rE--S-T-__-PER~_-O--D-_ ~ 1 ....... -1-_~9-7- Flow TubingiCasing Pressure CALCULATED · IOIL-BBL Press. 1511 1305 ?4-HouR RATE J. 1767 28. :GAs-MCF WATER-BBL 1 O44 229 GAS-MCF 1168 CORE DATA WATER-BBL 343 CHOKE SIZE ~,~-~:~I~t:~ATIO 64 ! 661 OIL GRAVITY-APl (CORR) 0 Brief description of tithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Mark~"~-' 30. r- _Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk C 9990' 6511' Total pump volumes for this event: Bottom Kuparuk C 10034' 6551' Category 1. 37173 Top Kuparuk A 10136' 6645' Category 2. 100 Bottom Kuparuk A 10267' 6765' Category 3. 0 Total: 37273 Total To Date: 37273 Total annular pumping volume inadvertantly exceeded permitted 35,000 bbl limit. Contacted Blair Wondzell on 7/14/97; no remedial action beyond reporting should be required. t Annulus left open - freeze protected with diesel. 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereb¥~ce~e forego, j,Q~ is true and correct to the best of my knowledge Signed\, ~ ........... ~:~--~~ ......... Title _~r'.., I\ '_.~"'-k, ~(~-~, v..,,,.~._~¢- Date "q- I ~ ~ I(-'~ ~ Prepare~'By Nam"-"e/Number: 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 cementing and the location of the cementing tool. IT£M 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 6/19/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3K-27 WELL ID: AK8765 TYPE: -- AFC: AK8765 AFC EST/UL:$ STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:04/09/97 START COMP: RIG:PARKER 245 OM/ 1600M BLOCK: FINAL' WI: 0% SECURITY:0 API NUMBER: 50-029-22751-00 04/08/97 (D1) TD: 121' (121) SUPV:GRW DAILY:$ 04/09/97 (D2) TD: 1556' (1435) SUPV:GRW DAILY:$ 04/10/97 (D3) TD: 5157' (3601} SUPV:GRW DAILY:$ 04/11/97 (D4) TD: 6200' (1043) SUPV:GRW DAILY:$ 04/12/97 (D5) TD: 6200'( SUPV:GRW 0) DAILY:$ 04/13/97 (D6) TD: 6848' (648) SUPV:GRW DAILY:$ 04/14/97 (DU) TD: 9069' (2221) SUPV:GRW DAILY:$ 04/15/97 (DS) TD:10264' (1195) SUPV:DCL DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 DRILLING Move rig to DS 3K-27. Accepted rig @ 22:30 hrs. 4/8/97. 55,824 CUM:$ 55,824 ETD:$ 0 EFC:$ 55,824 MW: 9.2 VISC: 96 PV/YP: 33/31 DRILLING Function test diverter. Drill to 1556'. 87,244 CUM'$ 143,068 ETD:$ 318,581 EFC:$ APIWL: 8.2 -175,513 MW: 9.1 riSC' 60 PV/YP: 20/22 CBU Drill from 1556' to 5157'. 74,961 CUM:$ 218,029 ETD:$ 538,357 EFC:$ AP IWL: 6.2 -320,328 MW: 9.2 rISC: 44 PV/YP: 11/15 RUNNING CASING Drill from 5157' to 6200' 81,986 CUM:$ 300,015 ETD:$ 605,228 EFC:$ APIWL: 6.0 -305,213 MW: 9.3 VISC: 48 PV/YP: 16/16 APIWL: 5.8 P/U DRILLPIPE Hold safety meeting. Run 7-5/8" casing to 6190' Pump cement. Test BOPE to 300/3000 psi. 216,978 CUM:$ 516,993 ETD:$ 605,228 EFC:$ -88,235 MW: 8.4 VISC: 52 PV/YP: 10/13 APIWL: 11.6 DRILLING @ 7750' Drill cement from 5837' to 6046' Test casing to 2000 psi for 30 min., no leakoff. Drill cement to 6056', landing collar @ 6101', cement ~o 6188', shoe, cement to 6200', and 20' of new hole to 6220'. Run FIT to 16 EMW. Drill 30' to 6250' Run FIT to 16.0 EMW. Drill 6250' to 6848'. 132,692 CUM:$ 649,685 ETD:$ 707,901 EFC:$ -58,216 MW: 9.0 VISC: 50 PV/YP: 15/20 APIWL: 6.2 DRILLING @ 9525' Drill from 6848' to 9069' Circ lo vis/hi vis sweep around. 76,977 CUM:$ 726,662 ETD:$ 1,059,809 EFC:$ -333,147 MW: 10.5 VISC: 53 PV/YP: 21/26 APIWL: 4.2 WIPERTRIP Drill from 9069' to 9718' Perform OH LOT, EMW = 12.6 ppg at shoe and 11.8 ppg at TD. Drill from 9718' to 10231' Gas and oil cut mud to surface. Circ and increase weight to 10.5 ppg. Drill from 10231' to 10264' 91,272 CUM:$ 817,934 ETD:$ 1,249,152 EFC:$ -431,218 Date: 6/19/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/16/97 (D9) TD:10456' (192) SUPV: DCL DAILY:$ 04/17/97 (D10) TD:10456' ( 0) SUPV:DCL DAILY: $ 04/18/97 (Dll) TD: 10456' ( 0) SUPV: DCL DAILY:$ 04/19/97 (D12) TD: 10456' ( 0) SUPV: DCL DAILY:$ MW: 10.6 VISC: 57 PV/YP: 24/26 APIWL: 4.5 RUN WL LOGS Drill from 10264' to 10456'. Circ and condition mud. Pump lo/hi vis sweep. Wiper trip to shoe no problems. Drop survey. Pump dry job. POH to shoe. Had slight flow out annulus. RIH to TD. No problems. Circ and condition mud. No gas at bottoms up. POH. No problems. 69,564 CUM:$ 887,498 ETD:$ 1,279,574 EFC:$ -392,076 MW: 10.6 VISC: 56 PV/YP: 25/25 APIWL: 4.8 NU WELL HEAD RIH w/GR/CNL/LDT/DITE tools. Unable to work tools below 6910' POH. RIH. Unable to work tools below 9125'. RIH 4.5" x 5.5" casing to 10466' 122,808 CUM:$ 1,010,306 ETD:$ 1,279,574 EFC:$ -269,268 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 ND BOPE Pump cement. Install packoff. Test packoff to 3000 psi. Freeze protect annulus. RIH with 3.5" x 2.875" completion equipment. 227,667 CUM:$ 1,237,973 ETD:$ 1,279,574 EFC:$ -41,601 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Finish RIH with 3.5" x 2.875" completion equipment. Test casing to 3500 psi for 30 min. Test tubing to 3500 psi for 10 min. OK. Test annulus to 3500 psi for 10 min. OK. Install tubing head. Test pack off to 5000 psi. Release rig at 1000 hrs. 4/19/97. 44,245 CUM:$ 1,282,218 ETD:$ 1,279,574 EFC:$ 2,644 End of WellSummary for Well:AK8765 SPE~,.,f-SUN DRILLING SERVICES ANCHOP~AGE ALASKA PAGE A/~CO Alaska, Inc. Kuparuk River Unit / 3K-27 500292275100 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/30/97 DATE OF SURVEY: 041697 MWD SURVEY JOB NUMBER: AK-MM-70098 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC TRUE St/B-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -75.30 121.00 121.00 45.70 177.00 177.00 101.70 267.00 267.00 191.70 356.00 355.94 280.64 0 0 0 30 30 N .00 E .00 .00N .00E N .00 E .00 .00N .00E N .00 E .00 .00N .00E N 68.00 E .56 .15N .36E S 68.00 E 3.55 .73S 3.24E .00 .00 .00 .38 3.17 465.87 465.43 390.13 559.56 558.44 483.14 652.08 649.82 574.52 742.34 738.11 662.81 835.60 828.31 753.01 6 9 7 33 10 23 13 33 15 53 N 77.80 E 3.47 .74S 12.12E N 78.25 E 1.50 1.58N 23.07E N 83.52 E 3.19 3.76N 37.32E N 89.92 E 3.78 4.70N 56.00E N 81.09 E 3.48 6.69N 79.55E 12. 02 23. 12 37.51 56.20 79. 83 928.14 916.71 841.41 1020.63 1003.43 928.13 1110.36 1085.83 1010.53 1201.83 1168.18 1092.88 1294.87 1249.87 1174.57 18 28 22 8 24 26 27 10 29 58 N 79.99 E 2.81 ll.21N 106.52E N 82.04 E 4.03 16.17N 138.23E N 81.75 E 2.57 21.17N 173.34E N 81.91 E 2.99 26.83N 212.75E N 82.56 E 3.04 32.83N 256.84E 107.08 139.09 174.50 214.24 258.68 1386 . 17 1327 . 70 1252 . 40 1481 . 42 1406 . 93 1331 . 63 1568 . 89 1478 . 11 1402 . 81 1662 . 98 1552 . 17 1476 . 87 1754 · 12 1621.76 1546 . 46 33 2 34 23 36 39 39 29 40 57 N 83.35 E 3.38 38.67N 304.20E N 84.63 E 1.60 44.19N 356.77E N 84.22 E 2.60 49.13N 407.34E N 83.75 E 3.03 55.22N 465.03E N 83.12 E 1.66 61.95N 523.49E 306.35 359.20 410.01 468.00 526.82 1846.22 1689.92 1614.62 1937.38 1754.22 1678.92 2030.47 1816.17 1740.87 2122.13 1873.09 1797.79 2216.63 1927.99 1852.69 43 34 46 42 49 50 53 22 55 35 N 83.20 E 2.85 69.33N 584.98E N 81.34 E 3.73 78.04N 648.99E N 81.20 E 3.37 88.59N 717.65E N 81.08 E 3.85 99.65N 788.61E N 80.95 E 2.35 111.67N 864.57E 588.71 653.22 722.51 794.15 870.84 2400.46 2031.25 1955.95 2586.96 2136.38 2061.08 2774.71 2241.96 2166.66 2958.18 2339.87 2264.57 3235.52 2480.90 2405.60 56 3 55 18 56 15 59 14 59 37 N 82.70 E .83 133.28N 1015.10E N 85.13 E 1.15 149.62N 1168.23E N 87.65 E 1.22 159.38N 1323.13E N 87.05 E 1.65 166.56N 1478.10E N 85.36 E .54 182.37N 1716.35E 1022.64 1176.60 1331.77 1486.81 1725.55 3511.57 2624.62 2549.32 3878.12 2818.61 2743.31 4159.28 2970.45 2895.15 4435.96 3124.85 3049.55 4711.32 3276.73 3201.43 57 36 58 28 56 7 56 1 57 1 N 85.79 E .74 200.56N 1951.28E N 85.05 E .29 225.40N 2261.28E N 85.35 E .84 245.21N 2497.01E N 84.77 E .18 264.98N 2725.75E N 85.83 E .48 283.78N 2954.64E 1961.18 2272.17 2508.73 2738.32 2967.99 ORIGINAL SPE .... f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO Alaska, Inc. Kuparuk River Unit / 3K-27 500292275100 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/30/97 DATE OF SURVEY: 041697 MWD SURVEY JOB NUMBER: AK-MM-70098 KELLY BUSHING ELEV. = 75.30 FT. OPER3tTOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 4988.94 3429.49 3354.19 56 13 N 88.75 E .92 294.77N 3186.16E 5267.32 3580.48 3505.18 58 4 N 86.97 E .86 303.54N 3419.81E 5488.76 3698.80 3623.50 57 19 N 86.60 E .37 314.03N 3606.68E 5819.18 3880.68 3805.38 55 52 N 85.50 E .52 333.01N 3881.84E 6123.88 4043.52 3968.22 59 30 N 84.35 E 1.23 355.84N 4138.30E 3199.63 3433.19 3620.30 3896.09 4153.55 6405.27 4190.06 4114.76 57 44 N 87.64 E 1.18 372.68N 4377.88E 6588.42 4286.17 4210.88 58 57 N 89.05 E .93 377.17N 4533.70E 6865.81 4435.89 4360.59 55 43 N 86.14 E 1.46 386.86N 4766.95E 7141.62 4589.12 4513.82 56 46 N 86.55 E .40 401.47N 4995.80E 7510.74 4794.21 4718.91 55 42 N 86.03 E .31 421.32N 5302.03E 4393.71 4549.36 4782.61 5011.89 5318.71 7788.30 4947.73 4872.43 57 7 N 86.45 E .52 436.47N 5532.74E 8066.49 5102.63 5027.33 55 12 N 88.20 E .87 447.29N 5763.49E 8345.64 5259.87 5184.57 56 13 N 87.00 E .51 456.97N 5993.91E 8437.86 5313.19 5237.89 53 7 N 86.72 E 3.38 461.08N 6069.03E 8529.26 5369.94 5294.64 50 5 N 88.46 E 3.63 464.12N 6140.59E 5549.89 5780.74 6011.17 6086.38 6157.94 8623.93 5431.17 5355.87 49 18 S 89.23 E 2.04 464.61N 6212.78E 8716.65 5492.03 5416.73 48 37 N 89.12 E 1.53 464.67N 6282.72E 8807.70 5553.22 5477.92 46 54 N 88.45 E 1.97 466.10N 6350.11E 8900.43 5616.43 5541.13 47 8 N 87.98 E .45 468.21N 6417.93E 8992.99 5680.31 5605.01 45 34 N 88.02 E 1.70 470.55N 6484.86E 6229.93 6299.63 6366.91 6434.67 6501.56 9082.66 5745.00 5669.70 42 4 N 88.36 E 3.90 472.52N 6546.91E 9178.45 5817.27 5741.97 39 55 N 88.63 E 2.25 474.17N 6609.73E 9269.03 5887.74 5812.44 37 54 N 88.31 E 2.25 475.68N 6666.60E 9363.33 5962.95 5887.65 36 17 N 88.11 E 1.71 477.46N 6723.44E 9456.14 6038.47 5963.17 34 46 N 87.79 E 1.65 479.39N 6777.34E 6563.57 6626.31 6683.11 6739.90 6793.77 9547.52 6114.91 6039.61 31 40 N 87.58 E 3.39 481.40N 6827.35E 9639.21 6194.15 6118.85 28 42 N 86.79 E 3.26 483.65N 6873.40E 9731.93 6275.98 6200.68 27 22 S 89.16 E 2.51 484.59N 6916.95E 9821.59 6356.84 6281.54 23 47 S 87.90 E 4.03 483.62N 6955.64E 10001.74 6521.46 6446.16 24 7 S 87.34 E .22 480.58N 7028.74E 6843.78 6889.86 6933.33 6971.82 7044.41 10096.68 6608.26 6532.96 23 42 S 86.42 E .59 478.49N 7067.16E 10187.95 6692.00 6616.70 23 10 S 85.05 E .83 475.80N 7103.36E 10376.49 6865.52 6790.22 22 52 S 87.18 E .47 470.79N 7176.92E 10456.00 6938.77 6863.47 22 52 S 87.18 E .00 469.27N 7207.79E 7082.53 7118.38 7191.27 7221.92 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7223.05 FEET AT NORTH 86 DEG. 16 MIN. EAST AT MD = 10456 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 85.26 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD SPE~xY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO Alaska, Inc. Kuparuk River Unit / 3K-27 500292275100 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/30/97 DATE OF SURVEY: 041697 JOB NUMBER: AK-MM-70098 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -75.30 .00 N .00 E 1000.00 984.27 908.97 15.09 N 130.67 E 2000.00 1796.32 1721.02 85.06 N 694.81 E 3000.00 2361.26 2285.96 168.41 N 1513.99 E 4000.00 2882.33 2807.03 234.37 N 2364.79 E .00 15.73 15.73 203.68 187.95 638.74 435.06 1117.67 478.93 5000.00 3435.64 3360.34 294.97 N 3195.35 E 6000.00 3979.28 3903.98 345.83 N 4032.86 E 7000.00 4511.47 4436.17 394.32 N 4877.57 E 8000.00 5064.68 4989.38 445.58 N 5708.92 E 9000.00 5685.23 5609.93 470.72 N 6489.85 E 1564.36 446.69 2020.72 456.36 2488.53 467.80 2935.32 446.79 3314.77 379.45 10000.00 6519.88 6444.58 480.62 N 7028.03 E 10456.00 6938.77 6863.47 469.27 N 7207.79 E 3480.12 165.35 3517.23 37.11 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE~,~f-SI/N DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO Alaska, Inc. Kuparuk River Unit / 3K-27 500292275100 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/30/97 DATE OF SURVEY: 041697 JOB NUMBER: AK-MM-70098 KELLY BUSHING ELEV. = 75.30 OPERATOR: ARCO ALASK3t INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA VERTICAL DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .0 75.30 75.3 175.30 175.3 275.30 275.3 375.40 375.3 -7 10 20 30 5.30 .00 0.00 0.00 0.00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .00 E .00 .00 .16 N .47 E .00 .00 1.08 S 4.44 E .10 .10 475.80 475.3 576.58 575.3 678.03 675.3 780.68 775.3 884.64 875.3 4O 5O 6O 7O 8O 0.00 0.00 0.00 0.00 0.00 .51 S 13.16 E 2.03 N 25.35 E 4.21 N 42.20 E 5.05 N 65.27 E 8.94 N 93.38 E .50 .40 1.28 .78 2.73 1.45 5.38 2.65 9.34 3.96 990.40 975.3 1098.79 1075.3 1209.86 1175.3 1324.38 1275.3 1443.09 1375.3 9O 100 110 120 130 0.00 0.00 0.00 0.00 0.00 14.58 N 127.28 E 20.49 N 168.61 E 27.35 N 216.42 E 34.73 N 271.71 E 42.17 N 335.22 E 15.10 5.76 23.49 8.39 34.56 11.07 49.08 14.52 67.79 18.71 1565.40 1475.3 1692.95 1575.3 1826.16 1675.3 1968.45 1775.3 2125.83 1875.3 140 150 160 170 180 0.00 0.00 0.00 0.00 0.00 48.93 N 405.27 E 57.29 N 483.98 E 67.70 N 571.34 E 81.49 N 671.55 E 100.11 N 791.55 E 90.10 22.31 117.65 27.55 150.86 33.21 193.15 42.29 250.53 57.38 2300.36 1975.3 2479.36 2075.3 2655.34 2175.3 2835.52 2275.3 3027.46 2375.3 190 200 210 220 230 0.00 0.00 0.00 0.00 0.00 122.53 N 932.79 E 141.60 N 1080.03 E 154.39 N 1224.25 E 161.55 N 1373.93 E 169.62 N 1537.55 E 325.06 74.53 404.06 79.01 480.04 75.98 560.22 80.18 652.16 91.94 3224.44 2475.3 3419.50 2575.3 3606.18 2675.3 3795.27 2775.3 3986.55 2875.3 240 250 260 270 280 0.00 0.00 0.00 0.00 0.00 181.60 N 1706.83 E 194.85 N 1873.75 E 206.43 N 2030.96 E 219.31 N 2190.92 E 233.38 N 2353.37 E 749.14 96.99 844.20 95.06 930.88 86.68 1019.97 89.09 1111.25 91.28 4167.98 2975.3 4347.28 3075.3 4526.25 3175.3 4708.70 3275.3 4891.12 3375.3 290 3OO 310 320 330 0.00 0.00 0.00 0.00 0.00 245.79 N 258.27 N 271.80 N 283.62 N 292.25 N 2504.21 E 1192.68 81.42 2652.51 E 1271.98 79.30 2800.31 E 1350.95 78.97 2952.45 E 1433.40 82.45 3104.77 E 1515.82 82.42 SPE~,.,~-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO Alaska, Inc. Kuparuk River Unit / 3K-27 500292275100 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/30/97 DATE OF SURVEY: 041697 JOB NUMBER: AK-MM-70098 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5071.33 3475.30 3400 5257.53 3575.30 3500 5445.24 3675.30 3600 5630.44 3775.30 3700 5809.59 3875.30 3800 .00 .00 .00 .00 .00 296.26 N 3254.63 303.10 N 3411.51 311.86 N 3570.11 321.11 N 3725.72 332.39 N 3873.93 E 1596.03 80.21 E 1682.23 86.20 E 1769.94 87.71 E 1855.14 85.20 E 1934.29 79.16 5992.51 3975.30 390 6186.13 4075.30 400 6377.54 4175.30 410 6567.34 4275.30 420 6756.44 4375.30 430 0.00 0.00 0.00 0.00 0.00 345.26 N 4026.54 360.77 N 4191.60 371.64 N 4354.44 376.87 N 4515.64 381.67 N 4676.05 E 2017.21 82.92 E 2110.83 93.62 E 2202.24 91.41 E 2292.04 89.79 E 2381.14 89.11 6935.78 4475.30 440 7116.40 4575.30 450 7298.93 4675.30 460 7477.18 4775.30 470 7654.96 4875.30 480 0.00 0.00 0.00 0.00 0.00 390.75 N 4824.63 400.20 N 4974.73 409.39 N 5127.16 419.40 N 5274.37 429.53 N 5421.01 E 2460.48 79.33 E 2541.10 80.62 E 2623.63 82.53 E 2701.88 78.25 E 2779.66 77.78 7839.08 4975.30 490 8018.60 5075.30 500 8193.82 5175.30 510 8373.03 5275.30 520 8537.60 5375.30 530 0.00 0.00 0.00 0.00 0.00 439.11 N 5575.30 446.06 N 5724.19 450.58 N 5868.00 458.17 N 6016.51 464.29 N 6146.99 E 2863.78 84.11 E 2943.30 79.52 E 3018.52 75.22 E 3097.73 79.21 E 3162.31 64.58 8691.33 5475.30 540 8840.02 5575.30 550 8985.83 5675.30 560 9123.44 5775.30 570 9253.27 5875.30 580 0.00 0.00 0.00 0.00 0.00 464.38 N 6263.72 466.74 N 6373.71 470.37 N 6479.74 473.29 N 6574.18 475.40 N 6656.92 E 3216.03 53.73 E 3264.72 48.69 E 3310.53 45.81 E 3348.14 37.61 E 3377.97 29.83 9378.66 5975.30 590 9500.57 6075.30 600 9617.64 6175.30 610 9731.15 6275.30 620 9841.77 6375.30 630 0.00 0.00 0.00 0.00 0.00 477.76 N 6732.51 480.36 N 6802.17 483.09 N 6862.93 484.59 N 6916.58 483.32 N 6963.78 E 3403.36 25.39 E 3425.27 21.92 E 3442.34 17.06 E 3455.85 13.52 E 3466.47 10.61 9951.16 6475.30 640 10060.69 6575.30 650 10169.79 6675.30 660 10278.56 6775.30 670 10387.11 6875.30 680 0.00 0.00 0.00 0.00 0.00 481.54 N 7008.09 479.39 N 7052.72 476.41 N 7096.24 472.72 N 7138.88 470.59 N 7181.04 3475.86 9.39 3485.39 9.53 3494.49 9.10 3503 .26 8.77 3511.81 8.55 SPE~,..f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 ARCO Alaska, Inc. Kuparuk River Unit / 3K-27 500292275100 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/30/97 DATE OF SURVEY: 041697 JOB NUMBER: AK-MM-70098 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10456.00 6938.77 6863.47 469.27 N 7207.79 E 3517.23 5.42 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 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 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 1247' FSL, 317' FWL, Sec. 35, T13N, RgE, UM At top of productive interval 1729' FSL, 2040' FWL, Sec. 36, T13N, R9E, UM At effective depth 1716' FSL, 2216' FWL, Sec. 36, T13N, R9E, UM At total depth 1718' FSL, 2248' FWL, Sec. 36, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 1 0456 feet 6938 feet 6. Datum elevation (DF or KB) RKB 37 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-27 9. Permit number/approval number 97-46 10. APl number 5o-029-22751-00 11. Field/Pool feet Plugs (measured) Kuparuk River Field/Oil Pool None Effective depth: measured 10376 feet true vertical 6865 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 6185' 10432' Size I 6" 7-5/8" 4.5"x5.5" Cemented Measured depth True vertical depth measured 10152'-10167' true vertical 6659'- 6673' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 10034' Packers and SSSV (type and measured depth) 200 CF (Approx) 121' 466 Sx ASLW & 61 9 0' 500 Sx Class G w/60 Sx AS I Top Job 180 Sx Class G 1 0442' 121' 4078' 6925' 0RI61N/ L 1997 Pkr: Baker GBH-22 Locator @ 10032'; SSSV: None, Camco nipple @:526~.~.¢~_0~~ 13. Stimulation or cement squeeze summary Perforate 'A' Sands on 5/8/97. Intervals treated (measured) 10152'-10167' Treatment description including volumes used and final pressure Perforate using 2-1/8" EJ w/ BH Charges, 4 spf, 180° PH, oriented +/- 90° f/ Iowside, fp = 1000 psi. 14. Representative Daily Average Production or Iniection Data Oil~Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 980 500 Subsequent to operation 1 9 7 5 812 299 980 280 15. Attachments Copies of Logs and Surveys run __ Daily 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~.,~ ~~--~¢'~)~ Title Wells Superintendent Form ,~-~"~4~ Rev/~5/8~¢'') "- Date ~---/~--'~ ? SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT ~ K1(3K-27(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-27 PERFORATE, PERF SUPPORT 0423971541.4 DATE DAILY WORK UNIT NUMBER 05/08/97 CBL, GYRO, & PERF "A" SANDS DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~ Yes O NoI ® Yes O No SWS-BAILEY CH~,NE iY, FIELD AFC~ CC# DAILY COST ACCUM COST SijCn¢ ESTIMATE AK8765 230DS36KG $31,715 $33,161 /¢./% /¢'~ Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Out'er Ann "~Final Outer Ap/t 0 PSI 1000 PSI 0 PSI I 1000 PSII 0 PSI DALLY SUMMARY OBTAINED GOOD CBL AND GYRO LOG. PERF'D "A" SAND INTERVAL @ 10152' RKB-10167' RKB W/15' ENERJET GUN, BIG HOLE CHGS.4 JSPF, 180 DEGREE PHASING, ORIENTATION +/-90 DEGREES FROM THE LOW SIDE OF THE HOLE. WHTP BUILT FROM 500 PSI TO 1000 PSI. TIME LOG ENTRY 07:00 STOOD-BY FOR CRANE, SWS MAST UNIT BROKE DOWN. 09:00 MIRU SWS. HELD SAFETY MTG. 11:00 RIH W/CMT, GR, & CCL. TIED IN AND OBTAINED GOOD CEMENT BOND LOG. POOH. 14:30 ON SURFACE. 15:00 RIH W/GYRO TOOL TO 3409' RKB AND SAT DOWN IN 2-7/8" X-OVER POOH. 16:00 ON SURFACE. REMOVED CENTRALIZERS. 17:00 RIH W/GYRO TOOL TO 10,OOO' RKB. 24' ABOVE THE "D" NIPPLE. OBTAINED LOG AND POOH, LOGGING UP. 19:10 ON SURFACE. 21:00 RIH W/2-1/8" WEIGHT BAR (4'), CCL,MPD, AND 15' ENERJET GUN, BIG HOLE CHGS,2 SPF, 180 DEGREE PHASING, OREINTATION +90 DEGREES FROM THE LOW SIDE OF THE HOLE. 23:30 TIED IN AND PERF'D INTERVAL FROM 10152' RKB - 10167' RKB. POOH. 00:30 ON SURFACE AND ALL SHOTS FIRED. 01:30 RIH W/2-1/8" WEIGHT BAR (4'), CCL,MPD, AND 15' ENERJET GUN, BIG HOLE CHGS,2 SPF, 180 DEGREE PHASING, OREINTATION -90 DEGREES FROM THE LOW SIDE OF THE HOLE. 03:00 ON SURFACE AND ALL SHOTS FIRED. RDMO SWS E/LINE AND SECURED WELL. READY FOR S/LINE. 04:00 SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $3,700.00 $3,700.00 GYRODATA $2,000.00 $2,000.00 HALLIBURTON $0.00 $1,446.00 SCHLUMBERGER $26,015.00 $26,015.00 TOTAL FIELD ESTIMATE $31,715.00 $33,1 61.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1247' FSL, 317' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1729' FSL, 2040' FWL, Sec. 36, T13N, R9E, UM At effective depth 1716' FSL, 2216' FWL, Sec. 36, T13N, R9E, UM At total depth 1718' FSL, 2248' FWL, Sec. 36, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 10456 6938 Effective depth: measured I 0376 true vertical 6 8 6 5 feet feet feet feet 6. Datum elevation (DF or KB) RKB 37 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-27 9. Permit number/approval number 97-46 10. APl number 50-029-22751-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Junk (measured) No,ORIGINAL Casing Length Structural Conductor 8 0' Surface 61 8 5' Intermediate Production 10432' Liner Perforation depth: Size 16" 7-5/8" 4.5"X5.5" measured 10152'-10167' true vertical 6659' 6673' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 10034' Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 200 CF (Approx) 121' 466 Sx ASLW & 61 9 0' 500 Sx Class G w/60 Sx AS I Top Job 180 Sx Class G 10442' 121' 4O78' 6925' · " i997 Pkr: Baker GBH-22 Locater @ 10032'; SSSV: None, Camco nipple @ 526' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 5/14/97. Intervals treated (measured) ..... 10152'-10167' Treatment description including volumes used and final pressure Pumped 141.6 Mlbs of 20/40, 12/18, and 10/14 ceramic proppant into formation, fp = 8000 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 980 1000 Subsequent to operation 1 9 7 5 812 299 980 280 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations Z Oil X Gas Suspended -- 7. I hereb/¢ ce"~ify that the foregoing is true and correct to the best of my knowledge. Signed//~.,~,~.,,~ ~~,)~,~ Title Wells Superintendent Service Form / Date SUBMIT IN DUPLICATE ARCO' Alaska, Inc. KUPARUK RIVER UNIT '~- WELL SERVICE REPORT '~' K1(3K-27(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-27 FRAC. FRAC SUPPORT 0509971846.6 ' DATE DAILY WORK UNIT NUMBER 05/14/97 A SAND FRAC 'DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 (~ Yes O No (~) Yes O No DS-YOKUM JORDAN FIELD AFC_,~ CC~ DAILY COST ACCUM COST Signed ESTIMATE 998675 230DS36KG $1 03,967 $105,870 Initial Tb.q Press FinaI.Tb_q Press Initial Inner Ann Final Inner Ann , Initial Outer Ann , Final Outer Ann 1250 PSi 4363 PSI 637 PSI 3500 PSII 1900 PSI 900 PSI DAILY SUMMARY PUMPED A SAND FRAC. 141620 LBS PROP IN PERFS, 1114 LBS LEFT IN PIPE. TIME LOG ENTRY 06:00 MIRU DS FRAC UNIT. TGSM - SIMULTANEOUS DRILLING AND SERVICE OPERATIONS. 15 ON LOCATION. 08:20 PT 8300 PSI. SD - LEAK IN ~2 TURBINE PUMP DISCHARGE LINE. ISOLATE. 08:29 PT 10,100 PSI OK. 08:38 PUMP BREAKDOWN STAGE AND FLUSH. ISlP 2201. 10:09 PUMP DATA FRAC AND FLUSH. ISIP 2238. 11:27 PUMP FRAC STAGES THROUGH FLUSH AVERAGE PRESS 4051. MAX 8000 ! SD PRESS 4363.. 141,620 LBS PROP IN PERFS. 1114 LBS LEFT IN PIPE. 16:00 RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $o.oo APC $4,500.00 $4,500.00 DOWELL $95,967.00 $95,967.00 HALLIBURTON $0.00 $1,904.00 LI'I-I'LE RED $3,500.00 $3,500.00 TOTAL FIELD ESTIMATE $1 03,967.00 $1 05,871.00 sper r, -sun 0 I::! I I--I-- I N [~ Sel:l~JI C E~: May 1, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 3K-27 Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 3K-27 Tie in point 0.00', and interpolated depth at 10,456.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company May 1, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 3K-27 Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 3K-27 Tie in point 0.00', and interpolated depth at 10,456.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 17, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-27 Dear Mr. Commissioner: Enclosed please find two LOT plots, cementing detail and the casing detail sheets for Kuparuk Well 3K-27. These forms are to satisfy AOGCC's request for information on this well prior to ARCO beginning annular disposal operations. One of the LOT plots achieved 16 ppg EMW FIT at the shoe. We did not want to attempt leakoff higher than that. The second open hole LOT was 11.8 ppg EMW above the Kuparuk. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad cc: Blair Wondzell CASING AND LEAK-OFF FRACTURE TESTS Well Name: Supervisor: KRU 3K-27 Date: 4/12/97 G.R. Whitlock 7 5/8", 29.7#, L-80, BTC Casing Size and Description: Casing Setting Depth' Mud Weight: 8.4 61 90 TMD 4077' TVD ppg EMW = Leak-off Pressure (PLO) + MW 0.052 x TVD LOT = 1600 psi / (0.052 x 4077 ft) + 8.4 ppg = 15.95 ppg Fluid Pumped = 2.04 bbls. Hole Depth (md)= 6250' Pump output = .085 bps 20OO 1900 1800 1700 1600 1500 1400 1300 1200 .. 1100 100o 900 800 700 600 500 400 300 200 100 0 --e-- LEAK-OFF TEST --B-CASING TEST 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 STROKES CASING AND LEAK-OFF FRACTURE TESTS Well Name: KRU 3K-27 Supervisor: Donald Lutrick Date: 4/15/97 Casing Size and Description: 7 5/8", 29.7#, L-80, BTC Casing Setting Depth: 61 90 TMD 4077' TVD Mud Weight: 10.25 ppg EMW = Leak-off Pressure (PLO) + MW 0.052 x TVD LOT = 500 psi / (0.052 x 4077 ft) + 10.25 ppg = 12.6 ppg LOT = 500 psi / (0.052 x 6260 f't) + 10.25 ppg = 11.8 ppg Fluid Pumped = 1.02 bbls. Hole Depth (md)= 9719' Hole Depth (tvd)= 6260' Pump output = .085 bps LU 600 5O0 400 300 2OO lOO / i' / / / --e-- LEAK-OFF TEST --B-- CASING TEST 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 STROKES ARCO Alaska, Inc. Well#: Cementing Details 3K-27 Field: KUPARUK Date: 4/1 2/97 Hole Diameter Hole Angle I Shoe Depth Float Depth I % washout 9.875" 60° I 6,190' 6,056' I State type used, intervals covered and spacing 40 Gemco centralizers. Jts # 1 - 38 and on either side of ES cementer Casing Size 7 5/8" Centralizers Mud Spacer Lead Cement STAG E 1/2 Tail Cement STAG E 1/2 Weight 9.5/9.3 Gels before 7/14 Type Water YP(prior cond) 18 lbs/100 ft2 Gels after 5/8 Type I Mix wtr temp ASLW I 7 0 YP(after cond) I PV(prior cond) 16 lbs/100 ft21 14cP Total Volume Circulated 5 bbls Volume 5O/2O No. of sacks 200/266 Weight 1 0.5/1 0.5 PV(after cond) 16 cP Weight 8.3 PPG Yield 4.41 Additives G + 3.5% DO44, .6% DO46, 30% D53, 1.5% DO79, 50% D124, 1.5% SOO1 Type IMixwatertempl Ne. of sacks I WeightI Yield G/AS 1 70 500/60 15.8/15.8 1.15/0.93 STAGE 1' G , 2.66% DO29, .2% DO46, .3% DO65, 1.5% SOO1 STAGE 2: AS I Displacement Rate(before tail at shoe) Rate(tail around shoe) Str. Wt. Up 13 13 240 Reciprocation length 15 Reciprocation speed 10 fpm Str. Wt. Dn. 135 Theoretical Displacement Actual Displacement STAGE 1/2 278/83.6 282.5/87.2 Calculated top of cement I CIP 4/12/97 Bumpedplug I Floats held 1822'/surface 13:04/14:42 yes/yes yes/yes Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Stage 1- Reciprocated csg until cement rounded shoe. Had full returns through out job Str. Wt. Mud Stage 2: Opened ES cementer w/3100 psi. Circ out 32.2 bbl cement contaminated mud. Had cement to surface w/ 209 bbls cement pumped. Switched to tail. Displaced w/ rig pumps. Closed cementer w/ 1450 psi. Floats OK Cement Company Dowell IRig Contractor Parker ISignature G.R. Whitlock CASING / TUBING / LINER DETAIL ARCO ALASKA / Subsidiary of Atlantic Richfield WELL: 3K-27 DATE: 4/10/97 PAGE: 1 of 1 # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH 7 5/8" SURFACE CASING TOPS Above RKB -4.53 Landing Joint 45.53 -4.53 7 5/8", 29.7#, L-80 Fluted mandrel hanger 1.52 41.00 41 Jts 7 5/8", 29.7#, L-80, BTC, R-3, Class A 1738.87 42.52 B Jt 7 5/8", 29.7#, L-80, BTC, R-3, Class A-BakerLocked 40.34 1781.39 Halliburton ES Cementer 2.43 1821.73 A Jt 7 5/8", 29.7#, L-80, BTC, R-3, Class A-BakerLocked 37.88 1824.16 98 Jts 7 5/8", 29.7#, L-80, BTC, R-3, Class A 4194.38 1862.04 Halliburton Landing Collar 1.34 6056.42 1 Jts 7 5/8", 29.7#, L-80, BTC, R-3, Class A 43.35 6057.76 Gemoco 7 5/8" Float Collar 1.40 6101.11 2 Jts 7 5/8", 29.7#, L-80, BTC, R-3, Class A 86.46 6102.51 Gemoco 7 5/8" Float Shoe 1.46 6188.97 6190.43 ES Cementer and lock Jts (A & B)between jt #101 - #102 ID = 6200.00 PBTD = 6056.42 RATHOLE = 9.57 ,,, I Parker 245 RKB to Wellhead = 41.32 FLUTED HANGER GOES IN TOP OF JT, #142 *'21 Jts (#143 -#163) stay in the shed **. BAKER-LOCK TO TOP OF BAFFLE COLLAR JT. National lead free mod. (BOL 2000) TORQUED TO BASE OF TRIANGLE (avg 9000 Ft-Lbs) RAN. 38 bow spring centralizers on jt #1 thru #38 2 bowspring centralizers on jt #A and #B RIG SUPERVISOR: G.R. Whitlock TONY KNOWLE$, GOVERNOR ~LASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 27, 1997 Michael Zanghi Drill Site Development Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Kuparuk River Unit 3K-27 ARCO Alaska. Inc. Permit No: 97-46 Sur. Loc.: 1247'FSL. 317'FWL. Sec. 35, TI3N. R9E. UM Btmhole Loc: 2218'FSL. 2166'FWL. Sec. 36. T13N, R9E, UM Dear Mr. Zanghi: Enclosed is tile approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law' from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. This approval includes annular disposal of drilling wastes and is contingent on obtaining a ,,veil cemented surface casing confirmed by a valid Formation lntegri~' Test (FIT) - cementing records, FIT data. and any CQLs run are to be submitted to the Commission prior to the start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance xvith 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed betbre drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting tile Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Mary.' Marshburn Commissioner BY ORDER OF THE COMMISSION dlffenclosures cc: Department offish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA ALASi'~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.OO5 la. Type of Work Drill X Redrill [] 1 b Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone X Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Ri9 RKB 41', Pad 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25519, ALK 2555 4. Location of well at surface 7, Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 1247' FSL, 317' FWL, Sec. 35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2203' FSL, 2060' FWL, Sec. 36, T13N, RgE, UM 3K-27 #U-630610 At total depth 9. Approximate spUd date Amount 2218' FSL, 2166' FWL, Sec. 36, T13N, RgE, UM 4/8/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3K-09A 10465' MD 2060 @ Target feet 10.7' ~ 375' feet 2560 6991' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 56.5° Maximum surface 2424 psig At total depth (TVD) 3200 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD -I-VD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 9.875" 7.625" 29.7# L-80 LTC 6126' 41' 41' 6167' 4094' 1740 Sx Arcticset III & HF-ERW 390 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 10002 41' 41' 10043' 6595' 120 Sx Class G HF-ERW 6.75" 4.5" 12.8# L-80 EUE8rdM 422' 10043' 6595' 10465' 6991~ Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: tr%eeaSvU;ertdical ff;eett Plugs (measured) 0 R I C INA L Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor .~~ ~ 1 V Surface Intermediate Production MAR 1 3 1997 Liner Perforation depth: measured ."~.aS[Cu~ Oil & Gas Cons, Commi~,sio~ true vertical 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the fo,~oing is true~d correct to the best of my knowledge Signed ' ~, {~-~ I~ Commission Use Only r I APl n~-mber ~,~ I Approval date ~ ~ I See cover letter for Permit/~,,, ~,~, I50-O'"~-~'' II other requirements Conditions of approval Samples required [] Yes [~' No Mud log required ~] Yes [] No Hydrogen sulfidemeasures [] Yes [] No Directional survey required [] Yes [] No Required working pressure for BOPE [] 2M r~ 3M [] 5M [] 10M [] 15M Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3K-27 , , , , o , o , 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 (6,167')according to directional plan. Run and cement 7-5/8" casing, using stage collar placed at the base of permafrost, and light weight lead cement. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test, maximum pressure allowed 16.0 ppg EMW. Drill 6-3/4" hole to total depth (10,465) according to directional plan. Run open hole evaluation 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 polished 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 perforating. .Alaska Oii& gas Cons, Cos~miss~o~ DRILLING FLUID PROGRAM Well KRU 3K-27 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 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% 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- Weight up to TD 10.4 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2424 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3K-27 is 3K-09A. As designed, the minimum distance between the two wells would be 10.7' @ 375'. Drilling Area Risks- Risks in the 3K-27 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 10.4 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 3K-27 Incidental fluids developed from drilling 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 will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3K-27 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. It is requested that 3K-27 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3K surface casing shoes will be set ___200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 4055 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst "7.625 29.7 L-80 3 LTC 4790 4072 6890 5857 5.500 15.5 L-80 3 LTC-M 4990 4242 7000 5950 ,, Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). ARCO ALASKA, Inc. Pad 3K 27 slot #27 Kuparuk River Unit North Slope, ALaska 3-D M I N I M U M D I S T A N C E C L E A R A N C E by Baker Hughes INTEQ REPORT Your ref : 27 Version #2 Our ref : prop1784 License : Date printed : 27-Feb-97 Date created : 22-Aug-96 Last revised : 27-Feb-97 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nTO 25 48.667, w149 45 49.2 Slot location is nTO 26 0.931,w149 45 39.898 Slot Grid coordinates are N 6008240.705, E 529307.999 Slot local coordinates are 1247.00 N 317.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object weltpath PGMS <O-9843'>,,18,Pad 3K PGMS <O-9584'>,,17, Pad 3K PGMS <O-9038'>,,16,Pad 3K PGMS <O-9275'>,,15,Pad 3K PGMS <O-8960'>,,14,Pad 3K PC-MS <O-8580'>,,13,Pad 3K PGMS <O-7770'>,,12,Pad 3K PGMS <O-7853'>,,11,Pad 3K PGMS <O-7300'>,,10,Pad 3K PMSS <5275 - 7443'>,,9,Pad 3K PGMS <O-7580'>,,gA,Pad 3K PP..d4S <O-8500'>,,8,Pad 3K PGMS <O-8500'>,,7, Pad 3K P~S <O-8100'>,,6,Pad 3K PGMS <O-8140'>,,5,Pad 3K PGMS <O-8980'>,,4,Pad 3K PGMS <O-8900'>,,3,Pad 3K PGMS <O-9960'>,,2,Pad 3K 3K-35IE Version #1,,IE,Pad 3K 3K-22D Version #3,,22D,Pad 3K L Version #1,,L,Pad 3K E Version #2,,E,Pad 3K ID Version #1,,ID,Pad 3K H Version #2,,H,Pad 3K 3K-F Version #1,,F,Pad 3K Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 10-0ct-96 288.1 0.0 0.0 10-0ct-96 262.1 0.0 0.0 10-0ct-96 238.1 0.0 0.0 10-0ct-96 213.1 0.0 0.0 10-0ct-96 187.1 100.0 300.0 10-0ct-96 163.2 0.0 10265.3 10-0ct-96 137.5 325.0 325.0 10-0ct-96 112.0 375.0 375.0 10-0ct-96 87.2 100.0 100.0 10-0ct-96 10.7 375.0 375.0 10-0ct-96 10.7 375.0 375.0 10-0ct-96 12.0 100.0 9654.3 10-0ct-96 37.2 100.0 500.0 10-0ct-96 62.4 0.0 375.0 10-0ct-96 84.1 550.0 550.0 10-0ct-96 112.2 0.0 0.0 10-0ct-96 137.2 100.0 525.0 10-0ct-96 162.2 0.0 525.0 25-Feb-97 225.0 200.0 200.0 25-Feb-97 123.7 550.0 550.0 26-Feb-97 24.8 425.0 2720.0 26-Feb-97 97.0 625.0 625.0 26-Aug-96 125.0 300.0 300.0 8-0ct-96 50.0 200.0 200.0 11-0ct-96 100.0 300.0 2127.3 ARCO ALASKA, Inc. o 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 8000 6500 7000 Structure : Pad 3K Well : 27 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 500 0 500 1000 1500 2000 2500 3000 3500 4000 4600 5000 5500 I I I I I I I I I I I I I I I I I I I I I I I I I EST. SURFACE LOCATION: 1247' FSL, 317' F-WL SEC. 35, T13N, R9E RKB ELEVATION: 76' KOP TVD=300 TMD=300 DEP=O 3.00 9.00 15.00 21.00 DLS: 3.00 deg per 100 ft 27.00 33.00 39.00 8/ RERMAFROST TVD=1641 TMD=1787 DEP=550 45.00 51.00 EOC TVD=1892 TMD=2182 DEP=854 TARGET LOCATION: 2205' FSL, 2060' FWL SEC. 36, T13N, R9E TARGET TVD=6697 TM0=10153 DEP=7087 NORTH=956 EAST=7023 6000 6500 7000 7500 I ~ I ~ ~ ~ 1500 1000 500 500 T/ UGNU SNDS TVD=2692 TMD=3630 DEP=2061 TD LOCATION: 2218' FSL, 2166' FWL SEC. 36, T13N, RgE 82.25 Deg Az (7087' TO TARGET) MAXIMUM ANGLE 56.45 DEG T/ W SAK SNDS TVD=3415 TMD=4938 DEP=3152 7 5/8" CSG PT TVD=4094 TMD=6167 DEP=4176 BEGIN ANGLE DROP TV0=5289 TMD=8330 DEP=5978 TARGET ANGLE CA~ T SNIPS wo=sgo9 TUO=~247 20 DEG ./HRz WD:6246 1MD=9654 DEP=6877 K-1 MARKER WD=6330 TMD=9750 DEP=6924 T/ KUP UNIT O WD=6~65 TMD:9899 DEP=6990 -,,', -~ ~ ~ T/ UNIT C ~D=6557 TMD=IO002 DEP=7032 ~F?~ ~ ~¢~ ~-- T/ UNIT B ~D=6595 TMD=10045 DEP=7048 . . T/ UNIT A ~D=6683 TMD=10158 DEP=7082 TARGET - A3 INT (EOD) TVD=6697 TMD=tO153 DEP=?08? B/ KUP SNDS ~D=6803 TMD=10265 DEP=7126 56.00 52.00 48.00 44.00 40.00 DLS: 2.00 deg per 100 ft 36.00 32.00 28.00 24.00 i i i i i 500 1000 i i I i i i i] t i i I ii i i i i i 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 Vertical Section (feet) -> Azimuth 82.25 with reference 0.00 N, 0.00 E from slot #27 i i i i i i 6500 7000 7500 ICreoted by finch For: D PETRASIt Dote plotted : 27-Fcb-97 Plot Reference is 27 Versron 1~2. Coordinates are In feet reference slot ~27. True Verticel Depths ~RKB (Porker #245) ARCO ALASKA, Inc. Structure : Pad 5K Well : 27 Field : Kuparuk River Unit Location : North Slope, Alaska 120 10o 8O 60 40 ~-' o o~ ~o I V 40 6o 8o 100 120 140 East (feet) -> 40 20 0 20 40 60 80 1 O0 120 140 160 180 200 220 240 260 280 ,300 320 540 360 580 400 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I .~200 t 1000 ..... ..... - .... ' 1200 6~.2_ _0_0_ _ _' - ...... 4200 800 2600 ...... .............. .... 000 ......................... ~ 2200 3600 2000 % 10.~ 800 ......... "' 600 3400 _ .%~18oo 'aoo---//~ ~"~ ~- _ .,/3000 ~ ................ 1200 ..................... 1 ooo(.,. / d'o~ ' .......... O~'~p''/2600 6'On __ -w .... 1400 Ooe/._S/:..:.¢_ .......... 4200 O0 2.00 / 2600 30006 ........... f?_?_ ................. ~?_? .............................. 22°_2 ........................................... J__~27. .......................................................... 2_?_ ............... ~.~i__.f-°--°- ........ , O' e-~2° \ ' 40 20 0 20 40 60 80 1 O0 120 140 160 180 200 220 240 260 280 .300 520 .340 .360 580 400 East (feet) -> 120 100 6O 20 U2 0 C --I- 0 20 _~ I 40 V 60 8o lO0 120 14o > 13 5/8" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 5 BOP STACK TEST 1. 16"- 2000 PSI STARTING HEAD 2. 11"- 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. 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 TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE DOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. ~'",4AR '1 5 !997 Gas ue~s. Commission ~n,shorage KOPARUK RIVER UNI'i 20" DIVERTER SCHEMATIC 6 I4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES· . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIPK:)N WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 WELL PERMIT CHECKLIST:o INIT CLASS GEOL AREA PROGRAM: expD dev~redrlD servO wellbore segD ann di~ para req~ , WIT# ON,OFF SHO ADMINISTRATION ENGINEERING 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. I N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party ............. . N 10. Operator has appropriate bond in force ........ ' N 11. Permit can be issued without conservation order .... ' N 12. Per, it can be issued without administrative approval. N 13. Can permit be approved before 15-day wait.' ...... N 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ .~ N 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... .~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been .approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOP Es adesqUat~ ............. ~ .... 26. BOPE pres ra lng adequate; test to ~ psig.~. N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N REMARKS GEOLOGY ~DPR DATE 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y-- 32. Seismic analysis of shallow gas zones .......... y N /~ ~. //7 33. Seabed condition survey (if off-shore) ....... N 34. Contact name/phone for weekly progress reports . ./.. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOWldlf- A:\FORMS\chekiist rev 01/97 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 Aug 13 16:36:46 1997 Reel Header Service name ............. LISTPE Date ..................... 97/08/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/08/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: 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: MWD RUN 3 AK-MM-70098 S. BURKHARDT G. WHITLOCK ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 3K-27 500292275100 ARCO ALASKA INC. SPERRY-SUN DRILLING SERVICES 13-AUG-97 35 13N 9E 1247 317 .00 75.30 34.30 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 7.625 6190.0 6.750 10456.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PPLAS E- 4 ( EWR4 ) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN DENISE PETRASH OF ARCO ALASKA, INC. AND ALI TURKER OF SPERRY-SUN DRILLING SERVICES ON 07/18/97. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10456'MD, 6939 ' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. 'SGRC = SMOOTHED GAP94A 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 ....... 97/08/13 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 SUMPLARY PBU TOOL CODE START DEPTH GR 6142.0 FET 6180.5 RPD 6180.5 RPM 6180.5 RPS 6180.5 STOP DEPTH 10393.5 10400.5 10400.5 10400.5 10400.5 RPX 6180.5 10400.5 ROP 6200.0 10456.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 6200.0 10456.0 $ REMARKS: 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 DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHNfiM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD OHMM 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 6142 10456 8299 8629 ROP 9.7059 2471.48 181.513 8513 GR 30.8225 495.227 107.05 8504 RPX 0.3068 71.2555 3.10769 8441 RPS 0.2501 2000 3.59507 8441 R?M 0.0624 2000 4.50102 8441 RPD 0.2311 2000 5.51695 8441 FET 0.2038 45.091 1.00947 8441 First Reading 6142 6200 6142 6180.5 6180.5 6180.5 6180.5 6180.5 Last Reading 10456 10456 10393.5 10400.5 10400.5 10400.5 10400.5 10400.5 First Reading For Entire File .......... 6142 Last Reading For Entire File ........... 10456 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/13 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 ....... 97/08/13 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 6142.0 6180 5 6180 5 6180 5 6180 5 6180 5 6200 0 2.17f SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10393.5 10400.5 10400.5 10400.5 10400.5 10400.5 10456.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 16-APR-97 ISC 4.88/4.96 CIM 5.46/SP4 5.03/DEPII MEMORY 10456.0 6200.0 10456.0 22.9 59.0 TOOL NUMBER P0694SP4 P0694SP4 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 M3~X 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 6.750 6.8 LSND 10.50 53.0 8.8 5O0 4.2 2.800 1.500 3.400 2.400 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAP I 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 RPX MWD 3 OHMM 4 1 68 12 4 RP S MWD 3 Oh74M 4 1 68 16 5 RPM MWD 3 OHMM 4 1 68 20 6 RPD MWD 3 OHMM 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 53.9 First Name Min Max Mean Nsam Reading DEPT 6142 10456 8299 8629 6142 GR 30.8225 495.227 107.05 8504 6142 ROP 9.7059 2471.48 181.513 8513 6200 RPX 0.3068 71.2555 3.10769 8441 6180.5 RPS 0.2501 2000 3.59507 8441 6180.5 RPM 0.0624 2000 4.50102 8441 6180.5 Last Reading 10456 10393.5 10456 10400.5 10400.5 10400.5 RPD 0.2311 2000 5.51695 8441 FET 0.2038 45.091 1.00947 8441 6180.5 6180.5 10400.5 10400.5 First Reading For Entire File .......... 6142 Last Reading For Entire File ........... 10456 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/13 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 ..................... 97/08/13 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 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... RECEIVEO JUL ~ ~ 1997 Oit & Gas Cons, Commission Anchorage COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 3K-27 FIELD NAME : KUPARUK RIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA API NUlV~ER : 500292275100 REFERENCE NO : 97331 LIS Tape Verification ,.isting Schlumberger Alaska Computing Center 30-JUL-1997 23:40 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/07/30 ORIGIN · FLIC REEL NAME : 97331 CONTINUATION # : PREVIOUS REEL : COMFiF2TT : ARCO ALASKA INC, KUPARUK, 3K-27, API #50-029-22751-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/07/30 ORIGIN : FLIC TAPE NAFiE : 97331 CONTINUATION # : 1 PREVIOUS TAPE : coF~_J~r : ARco ALASKA INC, KUPARUK, 3K-27, API #50-029-22751-00 TAPE HEADER KUPARUK RIVER UNIT CASED HOLE WIRELINE LOGS WELL NAMe: 3K-27 API AU]FiBER: 500292275100 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 30-JUL-97 JOB NUMBER: 97331 LOGGING ENGINEER: BAILEY/HARTL OPERATOR WITNESS: CHANEY SURFACE LOCATION SECTION: 35 TOWNSHIP: 13N RANGE: 9E FNL: FSL: 1247 FEL: FWL : 317 ELEVATION (FT FROM MSL O) KELLY BUSHING: 139.50 DERRICK FLOOR: 138. O0 GROUND LEVEL: 34.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 4.500 12.60 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Disting Schlumberger Alaska Computing Center 30-JUL-1997 23:40 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS ND?4~ER : DATE LOGGED: LOGGING COMPANY: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH $ REMARKS: This tape contains an LDWG edit for ARCOALASKA well 3K-27 Gamma Ray to be used for primary depth control. Digital data was not available so the main pass gamma ray was digitized. The gamma ray was obtained while logging a 1 11/16 slim hole cement mapping tool on 8-MAY-1997. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREFiEJgT: 0.5000 FILE SUmmARY LDWG TOOL CODE START DEPTH STOP DEPTH CET 10400.0 9930.0 $ CURVE SHIFT DATA - PASS TO PASS (M~.ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... LIS Tape Verification ,,isting Schlumberger Alaska Computing Center 30-JUL-1997 23:40 PAGE: RE~IARI~S: THIS FILE CONTAINS THE CLIPPED MAIN PASS DATA. THIS LOG IS THE PRIMARY DEPTH CONTROL AND NO DEPTH SHIFTING WAS PERFO~. DATA WAS DIGITIZED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAMIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CET O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10400.000 GRCH. CET 80.327 DEPT. 9930.000 GRCH. CET 86.543 ** END OF DATA ** LIS Tape Verification Disting Schlumberger Alaska Computing Center 30-JUL-1997 23:40 PAGE: **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUPI~ER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10400.0 9930.0 CET $ LOG HEADER DATA DATE LOGGED: 8-MAY-97 SOFTWARE VERSION: RELOO31A TIFiE LOGGER ON BOTTOM: 1900 08-MAY-97 TD DRILLER (FT) : 10442.0 TD LOGGER (FT) : 10350.0 TOP LOG INTERVAL (FT) : 10030.0 BOTTOM LOG INTERVAL (FT) : 10359.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CET CEMENT BOND RCENM21 CET CEMENT BOND TEL37 CET CEMENT BOND RCENM2 3 CET CEMENT BOARD SCMT1 CET CEMENT BOND R CENM21 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1997 23:40 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 0.0 10442.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: TIED INTO SPERRY GR LOG LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 LIS Tape Verification ~,isting Schlumberger Alaska Computing Center 30-JUL-1997 23:40 PAGE: TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAlViE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 GR PS1 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10400.000 GR.PS1 80.327 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/07/30 ORIGIN : FLIC TAPE NAME : 97331 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, KUPARUK, 3K-27, API #50-029-22751-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1997 23:40 PAGE: **** REEL TRAILER **** SERVICE NAFiE : EDIT DATE : 97/07/30 ORIGIN : FLIC REEL NAME : 97331 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, KUPARUK, 3K-27, API #50-029-22751-00