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Home My WebLink About218-1551. 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 9243'feet None feet true vertical 6643' feet None feet Effective Depth measured 9243'feet 6590', 6666', 6699'feet true vertical 6643'feet 6180', 6250', 6281'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 J-55 6540' 6704' 6133' 6286' Packers and SSSV (type, measured and true vertical depth)6590' 6666' 6699' 6180' 6250' 6281' 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: 6354-6410' (Squeezed), 6468-6476' (Squeezed), 6485-6493' (Squeezed) 6778-6838' (Squeezed), 6900-6908' (Squeezed), 6918-6926' (Squeezed) 6638' 6224' 9-5/8" 5-1/2" x 3-1/2" Burst Collapse Production Slotted Liner 7402' Casing Conductor 6982'7441' 9243' 6646' 4424'Surface Tie-Back 16"80' 4383' measured TVD 7x5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 218-155 50-029-22457-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025648 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1B-16A 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) 196 Gas-Mcf MD 121' Size 121' 4164' 1092 120662 N/A 134 324-271 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: SLB Blue Pack Packer: FB-1 Permenant Packer: Northern Solutions Liner Top SSSV: None Jonathan Coberly jonathan.coberly@conocophillips.com (907) 265-1013Staff RWO/CTD Engineering Supervisor 2033' 2-3/8" Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 6599' By Grace Christianson at 8:57 am, Jul 31, 2024 Page 1/6 1B-16 Report Printed: 7/29/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/23/2024 14:00 6/23/2024 16:00 2.00 MIRU, MOVE MOB P Rig down interconnect between rig, and pits. Rig down lines, and secure cellar. Take down berms, and containment around the rig. 0.0 0.0 6/23/2024 16:00 6/23/2024 17:00 1.00 MIRU, MOVE MOB P Hook up Cruz trucks to pits, and pull away from sub, and stage on pad. 0.0 0.0 6/23/2024 17:00 6/23/2024 18:30 1.50 MIRU, MOVE MOB P Pull sub off of 1B-09, and move by 1B- 16. Set mats under both ends of the sub, and set down. 0.0 0.0 6/23/2024 18:30 6/24/2024 00:00 5.50 MIRU, MOVE OTHR P Perform between well maintenance on BOPs. C/O annular element. Change upper pipe rams to 3 1/2" x 5 1/2" VBR, and lower pipe rams to 2 7/8" x 5" VBR. 0.0 0.0 6/24/2024 00:00 6/24/2024 01:30 1.50 MIRU, MOVE OTHR P Continue between well maintenance on BOPs. C/O annular element. Change upper pipe rams to 3 1/2" x 5 1/2" VBR, and lower pipe rams to 2 7/8" x 5" VBR. 0.0 0.0 6/24/2024 01:30 6/24/2024 06:00 4.50 MIRU, MOVE MOB P Jack up sub, remove rig mats. Spot sub over 1B-16. Spot in pits complete pre- acceptance checklist. 0.0 0.0 6/24/2024 06:00 6/24/2024 09:00 3.00 MIRU, WELCTL RURD P Accept rig at 0600. Start taking on fluids. build 50 BBL deep clean pill. T/IA/OA=50/220/0 0.0 0.0 6/24/2024 09:00 6/24/2024 11:00 2.00 MIRU, WELCTL KLWL P PJSM to kill well. PT lines to TT to 1500 PSI. Line up and pump down Tbg up the IA. 4BPM=780 PSI. load well with 50 BBL deep clean pill. Chase with seawater till clean returns at TT. 318 BBL's 8BPM 1660 PSI. 0.0 0.0 6/24/2024 11:00 6/24/2024 11:30 0.50 MIRU, WELCTL OWFF P OWFF IA flow rate decreasing tbg 0 flow. Continue to monitor. 0.0 0.0 6/24/2024 11:30 6/24/2024 12:00 0.50 MIRU, WELCTL SVRG P Service and prep power tongs for L/D tbg. continue to monitor cellar. 0.0 0.0 6/24/2024 12:00 6/24/2024 14:30 2.50 MIRU, WELCTL RURD P Offloading 10# NaCl spike fluid in pits. While continuing to monitor well. On highline at 13:00 0.0 0.0 6/24/2024 14:30 6/24/2024 16:00 1.50 MIRU, WELCTL KLWL P Pump 9.8# NaCl down tubing take returns up IA. Pumped 315 BBL's at 6BPM= ICP=650 PSI FCP=880 PSI 0.0 0.0 6/24/2024 16:00 6/24/2024 16:30 0.50 MIRU, WELCTL OWFF P OWFF Tubing 0 IA showing flow. U-tube Tbg and IA. Monitor for flow: Static. 0.0 0.0 6/24/2024 16:30 6/24/2024 17:30 1.00 MIRU, WELCTL MPSP P Set BPV. Line up on the IA and perform rolling test to 1000 PSI: GOOD. 0.0 0.0 6/24/2024 17:30 6/24/2024 19:30 2.00 MIRU, WELCTL OWFF P OWFF: diminishing flow from the IA, monitor until flow stops. R/D circulating lines, and prepare for N/D N/U. 0.0 0.0 6/24/2024 19:30 6/24/2024 20:30 1.00 MIRU, WELCTL NUND P N/D nuts and studs on adaptor flange and tree. 0.0 0.0 6/24/2024 20:30 6/24/2024 23:30 3.00 MIRU, WELCTL NUND P R/U to pull tree, and adaptor flange. Pull up to 25K. (max safe pull for rigging). Work tree from 5 to 25K attempting to break. Attempt to use wedges, and flange jacks without change. Steam well head for 30 min, attempt to work, and use wedges/ jacks. R/U jacks to push on adaptor flange studs, sucessfully break adaptor flange from tubing spool. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/2/2024 Page 2/6 1B-16 Report Printed: 7/29/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/24/2024 23:30 6/25/2024 00:00 0.50 MIRU, WELCTL NUND P R/D lifting gear from tree to blocks. R/U winch lines. Move tree and hang off into storage position in the cellar. 0.0 0.0 6/25/2024 00:00 6/25/2024 01:30 1.50 MIRU, WELCTL NUND P Inspect hanger/ hanger neck. Install test dart. 0.0 0.0 6/25/2024 01:30 6/25/2024 04:00 2.50 MIRU, WHDBOP NUND P N/U BOP, and adapter flange. 0.0 0.0 6/25/2024 04:00 6/25/2024 07:00 3.00 MIRU, WHDBOP BOPE P R/U to test BOP. Purge lines and shell test BOP. 0.0 0.0 6/25/2024 07:00 6/25/2024 13:30 6.50 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, w/3 -1/2", 4" and 5-1/2" test joints. LVBR's w/3-1/2" and 4" and test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, Dart valve and IBOP. Tested 3- 1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3,100 PSI, after closure=1,450 PSI, 200 PSI attained =20 sec, full recovery attained = 2min/10 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5.53 sec. LVBRs=5.5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2,100 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Sean Sullivan. Note: Tested Upper and Lower rams with 3 1/2", 4" and 5 1/2" test Joints. Tested Annular with 3 1/2" test joint. F/P: Choke HCR failed high, regreased - test good. All alarms tested. 0.0 0.0 6/25/2024 13:30 6/25/2024 14:15 0.75 MIRU, WHDBOP RURD P Blow down surface lines, R/D testing equipment. 0.0 0.0 6/25/2024 14:15 6/25/2024 16:15 2.00 COMPZN, RPCOMP BHAH P Load BHA into pipe shed, RU Rig floor for layind down tubing - Spooler, tongs. Tallied DP, 210 Jnts total in Pipe Shed. 0.0 0.0 6/25/2024 16:15 6/25/2024 16:30 0.25 COMPZN, RPCOMP BHAH P Make up BHA #1, 3.947" Itco Spear w/ no PO 0.0 0.0 6/25/2024 16:30 6/25/2024 17:30 1.00 COMPZN, RPCOMP PULL P Stab hanger w/spear, stack out 10K, BOLDS, pull hanger to RF. Brake over 105k, PUW=95k 6,650.0 6,625.0 6/25/2024 17:30 6/25/2024 18:30 1.00 COMPZN, RPCOMP CIRC P RU to circulate STS @ 5 BPM @ 450 psi OWFF- static 6,625.0 6,625.0 6/25/2024 18:30 6/25/2024 19:00 0.50 COMPZN, RPCOMP SVRG P Service power tongs. 6,625.0 6,625.0 6/25/2024 19:00 6/25/2024 22:30 3.50 COMPZN, RPCOMP PULL P Pull 4" completion F/6625' T/4775' PUW 90K Pull 15K over at 6025' went back down and pull up thru clean 6,625.0 4,775.0 6/25/2024 22:30 6/25/2024 23:00 0.50 COMPZN, RPCOMP RURD P LD SSSV RD HLB Spooler and send out 4,775.0 4,775.0 Rig: NABORS 7ES RIG RELEASE DATE 7/2/2024 Page 3/6 1B-16 Report Printed: 7/29/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/25/2024 23:00 6/26/2024 00:00 1.00 COMPZN, RPCOMP PULL P Pull 4" completion F/4775' T/4130' PUW 75K 4,775.0 4,130.0 6/26/2024 00:00 6/26/2024 05:30 5.50 COMPZN, RPCOMP PULL P Pull 3.5" completion F/4130' PUW *** Note: 17 stainless bands recovered 4,130.0 0.0 6/26/2024 05:30 6/26/2024 07:30 2.00 COMPZN, RPCOMP PULL P Cut joint 15.94', LD to shed Unload pipe shed 0.0 0.0 6/26/2024 07:30 6/26/2024 08:00 0.50 COMPZN, RPCOMP BHAH P Set wear ring 0.0 0.0 6/26/2024 08:00 6/26/2024 09:00 1.00 COMPZN, RPCOMP BHAH P Load and M/U BHA #2 0.0 0.0 6/26/2024 09:00 6/26/2024 10:15 1.25 COMPZN, RPCOMP FISH T Unable to pass through wellhead. POOH, suck out stack, observe stainless bands across wear bushing, RU and pull Wear bushing, RU to fish stainless bands for well, unable to fish bandings, bandings fell down hole, drift through wellhead without wear ring (good), re-install wear ring, drift through wear ring (good) 0.0 0.0 6/26/2024 10:15 6/26/2024 16:15 6.00 COMPZN, RPCOMP PULD P PU BHA #2 w/3.5" Dress off shoe, oil jars, boot basket x 2, casing scraper, string magnet, fishing jars, and 4-3/4" DC x 6, (OAL=246.11'') single in hole w/DP At 4500' UWT 100K/ DWT 80K 0.0 4,500.0 6/26/2024 16:15 6/26/2024 17:30 1.25 COMPZN, RPCOMP SLPC P Hang off topdrive, Slip and Cut 80' /12 wraps dilll line. 4,500.0 4,500.0 6/26/2024 17:30 6/26/2024 18:00 0.50 COMPZN, RPCOMP SVRG P Grease and inspect brake linkage. 4,500.0 4,500.0 6/26/2024 18:00 6/26/2024 20:00 2.00 COMPZN, RPCOMP PULD P Clontinue single in hole with DP. At 6620' UWT 140K/DWT 115K 4,500.0 6,620.0 6/26/2024 20:00 6/26/2024 21:30 1.50 COMPZN, RPCOMP WASH P Wash over TBG stump. Tag fill at 6630' with 5K down. Wash down 5BPM, 1000 psi, 60 RPM, 3.1K TQ off bottom, 4.5K TQ on Bottom, PUW 140 K/DWT 115K/RWT 125K. Wash down to 6642', tag stump and dress off 1' of TBG stump to 6643'. PU and slide over tubing stump. Clean packer setting depth at 6583'. 6,620.0 6,643.0 6/26/2024 21:30 6/26/2024 23:00 1.50 COMPZN, RPCOMP CIRC P Pump 25 bbl Hi Vis sweep at 3 BPM 450 psi Chase with 238 bbl at 6 BPM 1300 psi OWFF- static LD 2 jts and BD TD 6,643.0 6,585.0 6/26/2024 23:00 6/27/2024 00:00 1.00 COMPZN, RPCOMP TRIP P TOOH F/6585' PUW 140K T/4410' PUW 110K 6,585.0 4,410.0 6/27/2024 00:00 6/27/2024 02:00 2.00 COMPZN, RPCOMP TRIP P TOOH F/4410 T246' PUW 36K 4,410.0 246.0 6/27/2024 02:00 6/27/2024 04:30 2.50 COMPZN, RPCOMP BHAH P LD BHA #2. Clean magnets and boot baskets. 246.0 0.0 6/27/2024 04:30 6/27/2024 05:30 1.00 COMPZN, RPCOMP BHAH P MU BHA #3 w/7" test packer (OD 5- 7/8"), spring loaded running head, XO, and pup joint (OAL=17.65') 0.0 17.6 6/27/2024 05:30 6/27/2024 08:30 3.00 COMPZN, RPCOMP TRIP P TIH on stands, BHA #3, F/surface T/5,504' 17.6 5,504.0 6/27/2024 08:30 6/27/2024 08:45 0.25 COMPZN, RPCOMP MPSP P Set pliug PUH to 5,490' PUW=114k, SOW=96k, throw 1.5 turns of torque into sting, set down 30k 5,504.0 5,504.0 Rig: NABORS 7ES RIG RELEASE DATE 7/2/2024 Page 4/6 1B-16 Report Printed: 7/29/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/27/2024 08:45 6/27/2024 09:15 0.50 COMPZN, RPCOMP PRTS P P/T below 7" test packer (OD=5.78") to top of 2.725" PIIP RBP Plug @ 6,682', 1,000 psi for 30 mins (Charted). Good test, bleed pressure off. 5,504.0 5,504.0 6/27/2024 09:15 6/27/2024 09:45 0.50 COMPZN, RPCOMP MPSP P Release plug, R/D testing equipment, prep RF for TOOH sideways. 5,504.0 5,504.0 6/27/2024 09:45 6/27/2024 15:15 5.50 COMPZN, RPCOMP TRIP P TOOH, L/D DP PUW=98k, SOW=38k 5,504.0 0.0 6/27/2024 15:15 6/27/2024 15:45 0.50 COMPZN, RPCOMP BHAH P L/D BHA #4 and inspect RBP, wrap up, send to pipe shed 0.0 0.0 6/27/2024 15:45 6/27/2024 16:15 0.50 COMPZN, RPCOMP TRIP P TIH with remaining stands in derrick F/Surface T/847' PUW=47k, SOW=37k 0.0 847.0 6/27/2024 16:15 6/27/2024 17:00 0.75 COMPZN, RPCOMP TRIP P TOOH sideways laying down DP to shed 847.0 0.0 6/27/2024 17:00 6/27/2024 17:30 0.50 COMPZN, RPCOMP SVRG P Grease crown, blocks, drawworks, roughneck and top drive. 0.0 0.0 6/27/2024 17:30 6/27/2024 19:30 2.00 COMPZN, RPCOMP BHAH P PU RBP and running tool and RIH to 140' COE. Set RBP, release off of it and LD single joint of DP w/running tool. 0.0 140.0 6/27/2024 19:30 6/27/2024 20:30 1.00 COMPZN, RPCOMP MPSP P RU test equipment and PT RBP to 1000 psi for 30 minutes. Good test. 140.0 0.0 6/27/2024 20:30 6/27/2024 21:00 0.50 COMPZN, RPCOMP BHAH P Pull wear ring 0.0 0.0 6/27/2024 21:00 6/27/2024 22:30 1.50 COMPZN, RPCOMP NUND P Remove riser, remove bolts on DSA and stand back stack. 0.0 0.0 6/27/2024 22:30 6/28/2024 00:00 1.50 COMPZN, RPCOMP NUND P Remove IA valvesand blank flange F/TBG Spool RU Cameron subsidence package on wellhead. 0.0 0.0 6/28/2024 00:00 6/28/2024 04:00 4.00 COMPZN, RPCOMP NUND P Max force recorded at beginning of growth was 132K. Let 7" casing grow 18.25", wait 30 mins, no growth, R/D Equipment, prep wellhead equipment and cellar, MU 7" casing spear, spear 7" casing, stretch 7" casing 16" more with 125K over block weight for a total of 34.25". 0.0 0.0 6/28/2024 04:00 6/28/2024 09:30 5.50 COMPZN, RPCOMP WWSP P LD Spear, install wellhead, cut 7" casing, engage slips and pack-off, RILDS, install new casing spool, test void 3,000 psi for 15 mins, Good test, Bleed pressusre 0.0 0.0 6/28/2024 09:30 6/28/2024 11:30 2.00 COMPZN, RPCOMP NUND P Nipple up BOPE, Set BOP on casing spool, MU same Sim-ops - load and tally 5.5" casing in shed. 0.0 0.0 6/28/2024 11:30 6/28/2024 12:30 1.00 COMPZN, RPCOMP BOPE P Set test plug, test BOPE brake after new casing spool, 250 low/2,500 high, Good Test, RD testing equipment 0.0 0.0 6/28/2024 12:30 6/28/2024 13:00 0.50 COMPZN, RPCOMP MPSP P Pull and LD test plug 0.0 0.0 6/28/2024 13:00 6/28/2024 14:30 1.50 COMPZN, RPCOMP MPSP P P/U RBP running tools, TIH, pull RBP @ 140', TOOH, LD plug TIH with 2 stands 0.0 217.0 6/28/2024 14:30 6/28/2024 15:15 0.75 COMPZN, RPCOMP PULD P TOOH sideways 217.0 0.0 6/28/2024 15:15 6/28/2024 21:00 5.75 COMPZN, RPCOMP OTHR P Load 5.5" casing in pipe shed, drift and tally. 0.0 0.0 6/28/2024 21:00 6/28/2024 21:30 0.50 COMPZN, RPCOMP SVRG P Grease the draw works 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/2/2024 Page 5/6 1B-16 Report Printed: 7/29/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/28/2024 21:30 6/28/2024 22:30 1.00 COMPZN, RPCOMP RURD P RU GBR to torque turn while verifying the running order. 0.0 0.0 6/28/2024 22:30 6/29/2024 00:00 1.50 COMPZN, RPCOMP PUTB P Run 5.5" HYD 563 liner Torque turn to 6200ft/lbs 0.0 121.0 6/29/2024 00:00 6/29/2024 09:30 9.50 COMPZN, RPCOMP PUTB P Run 5.5" HYD 563 liner Torque turn to 6200ft/lbs 121.0 6,612.0 6/29/2024 09:30 6/29/2024 12:00 2.50 COMPZN, RPCOMP PUTB P MU Joint 158, PUW=120k, SOW=96k, bring pump online 270 psi 2 bpm, slowly RIH, notice pressure increase 270 psi - 549 psi, observe pins shear 6,634', fulling located @ 6,639', PUW=120k, 6,638', Repeat same results. Confirm depths, pressure, 6,612.0 6,638.0 6/29/2024 12:00 6/29/2024 13:15 1.25 COMPZN, RPCOMP CIRC P MIRU LRS, into cellar, pressure test line 3,500 psi, Bring LRS on line w/45 bbls of 9.8 ppg CI down the 5.5" x 7" at 1,350 psi pump pressure, 700 psi at wellhead, followed by 18 bbls Diesel FP. Bleed pressure off, stand by w/LRS. Realize space out is 3.5' from well head/slips.in casing spool 6,638.0 6,638.0 6/29/2024 13:15 6/29/2024 14:15 1.00 COMPZN, RPCOMP PUTB P Open up to cuttings tank displace diesel out of well, observe well for flow, no flow, brake out joints 158 and 157, add 10.09' pup joint to allow full joint under 5.5" slips. 6,638.0 6,638.0 6/29/2024 14:15 6/29/2024 17:15 3.00 COMPZN, RPCOMP PUTB P Continue to spaceout on rig floor, unable to set RBP in 5.5" as barrier, Teams meeting with town engineer, SL well supervisor, SLB completion hand, and Nabors Disucss plan forward LD 2 jts 5.5 casing, run 10' pup then full joint. Space out with 10' and 5' pups to get the right working height to RU SL. 6,638.0 6,638.0 6/29/2024 17:15 6/29/2024 18:00 0.75 COMPZN, RPCOMP DISP P Line up to reverse circ 45 bbls 9.8 ppg CI and cap with 18 bbls diesel freeze protect in 5.5" x 7". Pumping 2 BPM at 1350 psi. 0.0 0.0 6/29/2024 18:00 6/29/2024 20:00 2.00 COMPZN, RPCOMP PACK P Drop B&R and set packer per SLB rep with 3500 psi for 30 minutes. 0.0 0.0 6/29/2024 20:00 6/29/2024 23:30 3.50 COMPZN, RPCOMP SLKL P RU SL. RIH and pull B&R. RIH and pull RHC plug. 0.0 0.0 6/29/2024 23:30 6/30/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service pipe handler. 0.0 0.0 6/30/2024 00:00 6/30/2024 01:00 1.00 COMPZN, RPCOMP PRTS P PT 5.5" liner and packer F/below to 2150psi w/9.8ppg brine. 30 minute good test 0.0 0.0 6/30/2024 01:00 6/30/2024 03:00 2.00 COMPZN, RPCOMP SLKL P RIH on SL and install a D-nipple CA-2 plug in the D-nipple at 6615'. PT to 1000 psi for 10 minutes as a second barrier for ND the stack to install the TBG spool. RD SL. 0.0 0.0 6/30/2024 03:00 6/30/2024 04:00 1.00 COMPZN, RPCOMP NUND P ND stack, lift up high enough to install Wachs cutter 3.0', pump out 5.5" casing to ground level, prepare cellar and weelhead, set 5.5" in slips w/25k over string weight, engage packoff, torque up slip body. 0.0 0.0 6/30/2024 04:00 6/30/2024 07:00 3.00 COMPZN, RPCOMP RURD P MIRU, Cameron WellheadTech equipment, Install Wachs cutter, cut and dress 5.5" casing 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/2/2024 Page 6/6 1B-16 Report Printed: 7/29/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/30/2024 07:00 6/30/2024 11:00 4.00 COMPZN, RPCOMP RURD P RD Cameron Wellhead Wachs cutter, install new 3.5" tubing spool Test void to 3,000 psi for 15 mins. Good test 0.0 0.0 6/30/2024 11:00 6/30/2024 14:30 3.50 COMPZN, RPCOMP NUND P NU BOPE with DSA, LD 5.5" pups and cut joint length 15.16' Set riser, install test plug 0.0 0.0 6/30/2024 14:30 6/30/2024 15:30 1.00 COMPZN, RPCOMP PRTS P RU to test, fluid pack surface lines and BOPE, test and chart 250/2,500 psi, Good test. RD testing equipment. Pull test plug, blow down surface lines. 0.0 0.0 6/30/2024 15:30 6/30/2024 16:30 1.00 COMPZN, RPCOMP PUTB P RD GBR casing tongs, and load out to truck, RU RF for running 3.5" completion 0.0 0.0 6/30/2024 16:30 6/30/2024 17:00 0.50 COMPZN, RPCOMP SVRG P Service rig Eckel tongs 0.0 0.0 6/30/2024 17:00 7/1/2024 00:00 7.00 COMPZN, RPCOMP PUTB P Run 3.5" 9.3# EUE completion per tally. F/surface T4215' SOW 60K 0.0 4,215.0 7/1/2024 00:00 7/1/2024 03:00 3.00 COMPZN, RPCOMP PUTB P Run 3.5" 9.3# EUE completion per tally. F/4215 T/6,621', PUW=85k, SOW=72 4,215.0 6,539.8 7/1/2024 03:00 7/1/2024 06:00 3.00 COMPZN, RPCOMP PUTB P M/U XO to joint 204, KU, pump 1.5 bpm 150 psi, observed pressure increase/spike as seals engage @ 6,524', shut down pump bleed pressure off, tag no-go @ 6,541', stack out 5k, Mark pipe, 2' F/fully located. L/D 3 joints, Calculate space out. M/U pup joints 10.20' and 8.18' and joint 202, R/U head pin and cement hose to landing joint, M/U hanger and landing joint. 6,539.8 6,539.8 7/1/2024 06:00 7/1/2024 07:30 1.50 COMPZN, RPCOMP CIRC P Circulate 9.8 ppg CI 136 bbls, 3 bpm/650 psi 6,539.8 6,539.8 7/1/2024 07:30 7/1/2024 08:30 1.00 COMPZN, RPCOMP RURD P Bleed pressure, blow down stack, choke, kill lines and brake down hoses 6,539.8 6,539.8 7/1/2024 08:30 7/1/2024 09:00 0.50 COMPZN, RPCOMP PUTB P Land hanger, PUW=85k, SOW=73k, RILDS 6,539.8 0.0 7/1/2024 09:00 7/1/2024 11:00 2.00 COMPZN, RPCOMP PRTS P PT tubing to 3,000 psi for 30 mins charted, bleed down to 1,500 psi, PT IA to 2,500 psi for 30 min charted, bleed pressure off to shear SOV @ 6,475', brake down testing equipment, and LD landing joint. 0.0 0.0 7/1/2024 11:00 7/1/2024 12:00 1.00 COMPZN, WHDBOP MPSP P Set BPV w/Cameron Wellhead hand, PT BPV in direction of flow 1000 psi charted, bleed off 0.0 0.0 7/1/2024 12:00 7/1/2024 13:00 1.00 COMPZN, WHDBOP NUND P Nipple down stack and all rig floor equipment, choke manifold, mud line, mud pumps, hole fill, secondary kill, Pull riser, and clean pits 0.0 0.0 7/1/2024 13:00 7/1/2024 16:00 3.00 COMPZN, WHDBOP NUND P NU tree and test void T/5k psi for 15 min, RU to tree and test 5k psi, good test, 0.0 0.0 7/1/2024 16:00 7/1/2024 17:30 1.50 COMPZN, WHDBOP MPSP P Pull BPV as per Wellhead rep. 0.0 0.0 7/1/2024 17:30 7/1/2024 19:30 2.00 DEMOB, MOVE FRZP P Spot in LRS, hook up lines to tree, reversse down the IA 24 bbls diesel, Hook up 2 inch hole, allow well to U- tube. 0.0 0.0 7/1/2024 19:30 7/2/2024 00:00 4.50 DEMOB, MOVE MOB P Work pre-move checklist, bridle up, lay over derrick. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/2/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1B-16A jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Installed post RWO GLD. Pulled plugs 1B-16A 7/10/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Mandrel at 6560' can allow TxOA. 7"x5-1/2" OA is the old IA. 7/4/2024 spilch 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 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 40.8 4,424.1 4,164.5 40.00 L-80 BTC PRODUCTION 7"x5" @ 6690' 7 6.28 38.9 7,441.1 6,697.8 26.00 L-80 BTC MOD Tie-Back String 5 1/2 4.95 38.9 6,638.0 6,224.2 15.50 L-80 Hyd 563 LINER AL1 COMPLETION CTD 2 3/8 1.99 6,689.6 9,069.0 6,656.2 4.60 L-80 STL A LINER COMPLETION (CTD) 2 3/8 1.99 7,210.1 9,243.0 6,645.5 4.60 L-80 STL Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 38.9 Set Depth 6,539.8 String Max No 3 1/2 Set Depth 6,133.0 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) 38.9 38.9 0.00 Hanger 6.980 3.5" x 11" TUBING HANGER Cameron Gen 4 FMC Gen 5 2.992 1,966.6 1,892.8 23.54 Nipple 4.190 2.813" X-Nipple HES HES 2.813 2,864.2 2,721.2 22.17 Mandrel 4.757 3.5" x 1" KBG-2-9, IBT (SN 24183- 14) KBG SLB 2.992 4,925.8 4,631.7 21.64 Mandrel 4.757 3.5" x 1" KBG-2-9, IBT (SN 24183- 13) KBG SLB 2.992 6,076.1 5,703.1 21.58 Mandrel 4.757 3.5" x 1" KBG-2-9, IBT (SN 24183- 12) KBG SLB 2.992 6,475.8 6,073.6 21.95 Mandrel 4.757 3.5" x 1" KBG-2-9, IBT (SN 23681- 10) KBG SLB 2.992 6,503.2 6,099.0 21.90 Nipple 4.190 2.813" X-Nipple HES HES 2.813 6,520.5 6,115.1 21.86 Shoe - Mule 3.980 80-40 GBH-22 LTSA, 3-1/2" EUEM mod Box x 1/2 Mule shoe Baker Baker 3.500 Top (ftKB) 6,638.0 Set Depth 6,704.4 String Max No 3 1/2 Set Depth 6,286.0 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade J-55 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) 6,665.3 6,249.7 21.61 SEAL ASSY 4.000 GBH-22 LOCATOR w/ 10' Seal Assy Baker 3.000 6,666.2 6,250.4 21.61 PACKER 6.150 FB-1 PERMENANT PACKER Baker 4.000 6,669.6 6,253.6 21.60 SBE 5.000 SEAL BORE EXTENSION 4.000 6,687.6 6,270.4 21.58 NIPPLE 4.520 D NIPPLE NO GO. (MILLED OUT TO A 2.80") Camco 2.800 6,703.6 6,285.2 21.56 SOS 4.000 PE 500 SHEAR OUT SUB Camco 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 5,325.0 5,003.2 21.49 LEAK - CASING CASING LEAK AT 5325' IDENTIFIED WITH WFL LDL 3/9/2024 6.280 6,699.0 6,281.0 21.56 LINER TOP PACKER 2.72" Liner top packer w/ 1.781" R-Profile Nipple (10.66'" from top of Packer to R-Nipple / 11.91'' OAL) on 1B- 16AL1 Northern Solutions 6/18/2019 1.781 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) 2,864.2 2,721.2 22.17 1 GAS LIFT GLV BTM 1 1,260.0 7/8/2024 0.250 4,925.8 4,631.7 21.64 2 GAS LIFT GLV BTM 1 1,270.0 7/8/2024 0.313 6,076.1 5,703.1 21.58 3 GAS LIFT DV BTM 1 0.0 7/1/2024 0.000 6,475.8 6,073.6 21.95 4 GAS LIFT OV BTM 1 0.0 7/8/2024 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,524.7 6,119.0 21.86 SBR 4.500 4.5" 12.6# H521 Pin x H563 Pin Baker 80-40 SBR 3.990 6,560.8 6,152.5 21.79 Mandrel GAS LIFT 5.947 SLB 3.5" MMG w/ 1.5" DV with RK latch (no mandrel insert entry b/c WV doesn't recognize mandrels in anything called a casing) SLB MMG 2.920 6,590.3 6,179.9 21.73 PACKER 5.996 SLB BluePack 2.881 6,615.1 6,202.9 21.69 Nipple - D 4.504 2.75" D Nipple SLB D Nipple 2.750 6,636.3 6,222.7 21.65 Overshot 4.500 Baker Poorboy Overshot 3.980 6,689.6 6,272.2 21.57 SBR 2.630 Seal Bore Receptical, 3.0" GS Profile, 2.25" Polish Bore BOT Billet 1.910 7,210.1 6,698.2 85.94 ALUMINUM BILLET 2.630 Aluminum Liner Top Billet for 1B- 16A (inaccessible) BOT Billet 1.920 1B-16A, 7/30/2024 1:29:39 PM Vertical schematic (actual) A LINER COMPLETION (CTD); 7,210.1-9,243.0 LINER AL1 COMPLETION CTD; 6,689.6-9,069.0 PRODUCTION 7"x5" @ 6690'; 38.9-7,441.1 WHIPSTOCK; 7,025.0 APERF; 6,900.0-6,908.0 APERF; 6,918.0-6,926.0 IPERF; 6,778.0-6,838.0 LINER TOP PACKER; 6,699.0 PACKER; 6,666.2 Tie-Back String; 38.9-6,638.0 Nipple; 6,503.2 Mandrel; 6,475.8 Mandrel; 6,076.1 LEAK - CASING; 5,325.0 Mandrel; 4,925.8 SURFACE; 40.8-4,424.1 Mandrel; 2,864.2 Nipple; 1,966.6 CONDUCTOR; 41.0-121.0 Tubing; 74.9 Tubing; 39.7 Hanger; 38.9 KUP PROD KB-Grd (ft) 41.11 RR Date 3/25/1994 Other Elev 1B-16A ... TD Act Btm (ftKB) 9,243.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292245701 Wellbore Status PROD Max Angle & MD Incl (°) 95.97 MD (ftKB) 7,354.30 WELLNAME WELLBORE1B-16A Annotation Last WO: End Date 7/1/2024 H2S (ppm) 87 Date 7/5/2023 Comment Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,778.0 6,838.0 6,354.4 6,410.3 UNIT D, C-4, C- 3, 1B-16 11/7/1994 6.0 IPERF 2 1/8" Enerjet, 90 deg phasing 45 deg orient 6,900.0 6,908.0 6,468.2 6,475.7 C-1, 1B-16 6/10/2008 6.0 APERF 2.5" PJ HSD, 60 deg random 6,918.0 6,926.0 6,485.1 6,492.6 C-1, 1B-16 6/10/2008 6.0 APERF 2.5" PJ HSD, 60 deg random 1B-16A, 7/30/2024 1:29:40 PM Vertical schematic (actual) A LINER COMPLETION (CTD); 7,210.1-9,243.0 LINER AL1 COMPLETION CTD; 6,689.6-9,069.0 PRODUCTION 7"x5" @ 6690'; 38.9-7,441.1 WHIPSTOCK; 7,025.0 APERF; 6,900.0-6,908.0 APERF; 6,918.0-6,926.0 IPERF; 6,778.0-6,838.0 LINER TOP PACKER; 6,699.0 PACKER; 6,666.2 Tie-Back String; 38.9-6,638.0 Nipple; 6,503.2 Mandrel; 6,475.8 Mandrel; 6,076.1 LEAK - CASING; 5,325.0 Mandrel; 4,925.8 SURFACE; 40.8-4,424.1 Mandrel; 2,864.2 Nipple; 1,966.6 CONDUCTOR; 41.0-121.0 Tubing; 74.9 Tubing; 39.7 Hanger; 38.9 KUP PROD 1B-16A ... WELLNAME WELLBORE1B-16A Certificate Of Completion Envelope Id: 579451A6F0854B3B9E53A931FB5F7D6B Status: Completed Subject: Here is your signed document: KRU 1B-16A 10-404.pdf Source Envelope: Document Pages: 9 Signatures: 1 Envelope Originator: Certificate Pages: 5 Initials: 0 Jonathan Coberly AutoNav: Disabled EnvelopeId Stamping: Disabled Time Zone: (UTC-06:00) Central Time (US & Canada) 925 N Eldridge Pkwy Houston, TX 77079 Jonathan.Coberly@conocophillips.com IP Address: 138.32.8.5 Record Tracking Status: Original 7/31/2024 11:41:58 AM Holder: Jonathan Coberly Jonathan.Coberly@conocophillips.com Location: DocuSign Signer Events Signature Timestamp Jonathan Coberly Jonathan.Coberly@conocophillips.com Security Level: Email, Account Authentication (None) Signature Adoption: Pre-selected Style Using IP Address: 138.32.8.5 Sent: 7/31/2024 11:42:09 AM Viewed: 7/31/2024 11:42:17 AM Signed: 7/31/2024 11:43:20 AM Freeform Signing Electronic Record and Signature Disclosure: Accepted: 10/21/2021 1:38:44 PM ID: 816074ce-6cf9-4a8e-a803-d7ca1a5695a7 In Person Signer Events Signature Timestamp Editor Delivery Events Status Timestamp Agent Delivery Events Status Timestamp Intermediary Delivery Events Status Timestamp Certified Delivery Events Status Timestamp Carbon Copy Events Status Timestamp Jenna Taylor Jenna.L.Taylor@conocophillips.com ConocoPhillips Security Level: Email, Account Authentication (None) Sent: 7/31/2024 11:43:21 AM Viewed: 7/31/2024 11:45:40 AM Electronic Record and Signature Disclosure: Accepted: 10/16/2023 5:54:47 PM ID: 67551fd2-158e-440c-8245-f971ef8ee62c Witness Events Signature Timestamp Notary Events Signature Timestamp Envelope Summary Events Status Timestamps Envelope Sent Hashed/Encrypted 7/31/2024 11:42:09 AM Certified Delivered Security Checked 7/31/2024 11:42:17 AM Signing Complete Security Checked 7/31/2024 11:43:20 AM Completed Security Checked 7/31/2024 11:43:21 AM Payment Events Status Timestamps Electronic Record and Signature Disclosure ELECTRONIC RECORD AND SIGNATURE DISCLOSURE From time to time, ConocoPhillips (we, us or Company) may be required by law to provide to you certain written notices or disclosures. 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Originated: Delivered to:5-Jul-24 Alaska Oil & Gas Conservation Commiss 05Jul24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD4-586 50-103-20857-00-00 223-046 Colville River WL TTiX-PPROF FINAL FIELD 3-Mar-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX-PPROF FINAL FIELD 7-Mar-24 2M-12 50-103-20181-00-00 192-090 Kuparuk River WL SCMT FINAL FIELD 8-Mar-24 1B-16A 50-029-22457-01-00 218-155 Kuparuk River WL RST FINAL FIELD 9-Mar-24 CD4-588 50-103-20853-00-00 223-029 Colville River WL TTiX-PPROF FINAL FIELD 22-Mar-24 CD5-23 50-103-20761-00-00 217-155 Colville River WL Packer Setting FINAL FIELD 24-Mar-24 3F-08 50-029-21464-00-00 185-246 Kuparuk River WL SCMT FINAL FIELD 30-Mar-24 2M-03 50-103-20160-00-00 191-141 Kuparuk River WL SCMT FINAL FIELD 31-Mar-24 2B-14 50-029-21143-00-00 184-111 Kuparuk River WL WFL FINAL FIELD 3-Apr-24 2T-41 50-103-20675-00-00 213-146 Kuparuk River WL PPROF FINAL FIELD 7-Apr-24 MT7-03A 50-103-20830-01-00 223-084 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 22-May-24 MT7-01 50-103-20832-00-00 221052 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 27-May-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39122 T39123 T39124 T39125 T39126 T39127 T39128 T39129 T39130 T39131 T39132 T39133 1B-16A 50-029-22457-01-00 218-155 Kuparuk River WL RST FINAL FIELD 9-Mar-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.05 10:30:21 -08'00' 218-155 T38931 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 08:51:23 -08'00' Operations shutdownRepair WellFracture StimulatePlug PerforationsAbandon1. Type of Request: Change Approved ProgramPull TubingOther StimulatePerforateSuspend Alter CasingPerforate New Pool Re-enter Susp WellPlug for Redrill 5. Permit to Drill Number:4. Current Well Class:2. Operator Name: DevelopmentExploratory 3. Address:ServiceStratigraphic 6. API Number: 8. Well Name and Number:7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? NoYes 10. Field:9. Property Designation (Lease Number): Kuparuk Oil Pool 11. Junk (MD):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft): None13759243' CollapseCasing Conductor Surface Production Slotted Liner Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type: 13. Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic ServiceDevelopmentExploratory StratigraphicDetailed Operations Program BOP Sketch 15. Well Status after proposed work:14. Estimated Date for WDSPLOIL WINJCommencing Operations:Suspended SPLUGGSTORWAGGASDate:16. Verbal Approval: AOGCC Representative: GINJ AbandonedOp Shutdown Contact Name:James Ohlinger Authorized Title: Sundry Number:Conditions of approval: Notify AOGCC so that a representative may witness Location ClearancePlug Integrity BOP Test Mechanical Integrity Test Other Conditions of Approval: Post Initial Injection MIT Req'd? NoYes APPROVED BY Date:THE AOGCCCOMMISSIONERApproved by: Sr Res EngSr Pet GeoSr Pet EngComm.Comm. None6643'9243' 6/30/2023 9243'2033' 4"x3.5" 6646' Packer: Baker FB Permenant SSSV: CAMCO TRDP-4A 7441' Perforation Depth MD (ft): 6778-6838' (Squeezed) 6900-6908' (Squeezed) 6918-6926' (Squeezed) 7402' 6354-6410' (Squeezed) 6468-6476' (Squeezed) 6485-6493' (Squeezed) 6982' 16" 9-5/8" 80' 4383' 121' 4164' 121' 4424' J-55 BurstTVD 6704' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025648 218-155 50-029-22457-01-00P.O. Box 100360, Anchorage, AK 99510 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing MD (ft):Tubing Grade: Packer: 6666'MD/6250'TVD SSSV: 1893'MD/1825'TVD Perforation Depth TVD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length KRU 1B-16A Other: Replace Tubing N/A Kuparuk River Field james.j.ohlinger@conocophillips.com CTD/RWO Drilling Engineer Size Kuparuk Oil Pool 6643' Plugs (MD): Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 2-3/8" 7x5" Contact Email: Contact Phone: 907-265-1102 By Grace Christianson at 3:15 pm, May 03, 2024 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E=James.J.Ohlinger@ cop.com Reason: I am the author of this document Location: Date: 2024.05.03 14:25:25-08'00' Foxit PDF Editor Version: 13.0.0 James J. Ohlinger 324-271 X DSR-5/6/24SFD 5/7/2024 X VTL 5/13/2024 10-404 BOPtestto2500psig Annular preventer test to 2500 psig JLC 5/13/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.05.13 13:13:11 -08'00'05/13/24 RBDMS JSB 052824 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 3, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: James Ohlinger Staff CTD/RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 1B-16A (PTD# 218-155-0). Well 1B-16 was drilled and completed in March of 1994 as a Kuparuk A-sands and C-sands producer. It was then cemented across the A&C perforations and CTD sidetracked into the A-sand. In 2023 the well became a RWO candidate due to AnnComm issues caused by leaks. If you have any questions or require any further information, please contact me at +1 907-265-1102 The tubing will be removed from above the packer and replaced with a 5.5" tieback liner from there to surface. This will create a new IA. New 3-1/2" tubing will be run inside down to a PBR at the bottom of the 5.5" liner. 1B-16A RWO Procedure Kuparuk Producer - RWO PTD #218-155 Page 1 of 3 General Well info: Wellhead type/pressure rating: McEvoy Gen IV Production Engineer: Banabas Dogah Reservoir Development Engineer: Cody Keith Estimated Start Date: 6/30/24 Workover Engineer: James Ohlinger (265-1102/ James.J.Ohlinger@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 pre-rig cut above the packer. A new 5-1/2” tie-back liner will be installed via a 3-1/2” Poor-boy overshot and stack packer. Then a new 3-1/2” tubing completion will be ran in hole. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Tubing leak at 5468' CMIT-TxIA Failed – 12/16/24 MIT-OA Passed 1805 psi – 3/21/24 IC POT Passed – 10/25/2023 T-POT & PPPOT Passed – 10/25/2023 MPSP: 1375 psi using 0.1 psi/ft gradient Static BHP: 2001psi / 6257’ TVD measured on 7/3/2019 Remaining Pre-Rig Work 1. IC-POT, IC-PPPOT, T-PPPOT and T-POT tests. 2. MIT-OA. 3. SBHP. 4. Open lowest GLM in upper completion. Dummy off other GLMs. 5. Cut the tubing nominally at ~6650 RKB in the middle of the first full joint above the packer @ 6666’ RKB 6. Prepare well within 48 hrs of rig arrival. 1B-16A RWO Procedure Kuparuk Producer - RWO PTD #218-155 Page 2 of 3 Rig Work MIRU 1. MIRU Nordic 3 on 2B-16A (No BPV will be installed due to risk assessment done for MIRU/RDMO on N3 w/o BPV.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut (~6650’ RKB). a. If not all tubing comes due to subsidence, then work additional steps below to clear buckled 7”, then pull remaining completion. b. *Depending on drifts, go to “Contingency for Subsidence on 7.0”. Run New 3.5” x 5.5” Tie-back Liner 6. RIH with 3.5” overshot, Nipple profile, 3.5” x 7.0” packer, 3.5” GLM, 3.5” x 5.5” crossover, PBR, and 5.5” tie-back liner to surface. 7. Reverse circulate in CI fluid and freeze protect as needed. 8. Pressure up on 5.5” to set the 3.5” x 7.0” packer. 9. PT 5.5” liner to 2500 psig for 30 minutes and chart. (This is the new IA envelope.) 10. Set 5.5” RBP near surface. PT to confirm as barrier. 11. ND BOPE. Finish 5.5” termination. NU new tubing spool. NU BOPE. Test flange breaks. 12. Pull 5.5” RBP. Freeze protect new OA at opportune moment. Install in 3-½” Completion 13. MU 3 ½” completion with seal assembly, nipples, and GLMs. RIH with completion. 14. Once on depth, stab in seals and space out as needed. Reverse circulate in CI fluid at opportune time as needed. 15. Pressure test tubing to 3000 psi for 30 minutes and chart. 16. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 17. Confirm pressure tests, then shear out SOV with pressure differential. 18. Install BPV. 19. ND BOPE. NU tree. PT tree. 20. Pull BPV, freeze protect well at opportune time, and set BPV if necessary. 21. RDMO. Post-Rig Work 22. Install GLD. 23. Pull Ball and Rod 24. Pull any remaining plugs in well. 25. Turn over to operations. 1B-16A RWO Procedure Kuparuk Producer - RWO PTD #218-155 Page 3 of 3 Contingency for Subsidence on 7.0” Pull Subsided 7.0” Casing 26. Set storm packer or plug in 7” casing and PT to confirm as barrier. 27. ND BOPE. ND old tubing spool. NU BOPE and test flange break. a. Grow/stretch and Cut 7” casing at surface as necessary to deal with subsidence in this step. b. Can’t test flange break with test-joint since packoffs are removed and 7” is above flange. Test 11” 3k flange break to 3000 psig at earliest opportunity. 28. Pull storm packer or plug. Condition fluid as needed. 29. RU Eline and log 7.0” casing for OA cement 30. Cut 7.0” casing with cutter above OA cement. a. Circulate out Arctic Pack diesel/slurry if needed. 31. Pull 7.0” casing down to cut (~2000’). a. Make addition cut/pulls/BHA runs as necessary to remove 7”. b. Test 11” 3k flange to 3000 psig if not already done so. Bore out 9-5/8” and run 7.0” Tie-Back Subsidence Before Running of 5.5” x 3.5” tie-back 1. PU mills and bore out 9-5/8” as necessary to obtain drift for new 7.0” tie-back. a. As drift is regained, pull any additional 7.0” or 3.5” tubing as needed to get 7.0” removed down to cement in OA. 2. Run new 7.0” tie-back casing with overshot. 3. Test casing to 2500 psig. 4. Cement OA to surface. 5. Perform 30 minute no flow test, split stack and land slips, cut excess casing and install IC packoffs. Installed Tie- back spool and terminate 7.0”. Land stack and MU to casing flange. a. Test flange break to BOPE test pressure. 6. Mill plugs in cementer. 7. Circulate out sand on IBP or any lower plug. 8. Pull any lower plugs or remaining 3.5”. 9. Return to “Run New 3.5” x 5.5” Tie-back Liner”. Total Subsidence = 71.8” (2.4” per year) Tubing Cut 6650 1B-16 Existing Schematic 9-5/8" 40# L-80 shoe @ 4424' MD 7" x 5" shoe @ 7441' MD 16" 62# H-40 shoe @ 121' MD A-sand perfs 7124' - 7158' MD KOP @ 7046' MD 3-1/2" x 5" TTWS C-sand perfs Squeezed 6778' - 6838' MD 6900' - 6908' MD 6918' - 6926' MD 4-1/16" 5M McEvoy Gen iV Tubing Hanger w/ 4" BTC Mod pin-down 4" 11# J-55 Tubing 4104' MD to surface Camco 4" TRDP-4A Safety Valve @ 1893' MD (6" OD) Locked Out: 8/2/2017 Merla TMPD GLM @ 2624' MD Cross-over 4"x3.5" @ 4104' MD 3-1/2" 9.3# J55 EUE 3-1/2" Camco gas lift mandrels @ 4139', 5204', 5987', & 6620' MD Baker FB-1 packer @ 6666' MD (4.0" ID) Baker SBE @ 6670' MD 3-1/2" Camco D landing nipple @ 6688' MD (2.80" min ID, Milled Out) 3-1/2" Camco SOS @ 6700' MD 3-1/2" x 2-3/8" Northern Solutions Liner Top Paker @ 6682' MD 1B-16APB1 TD @ 7478' MD 1B-16AL1 TD @ 9693' MD Liner @ 9069' MD Top of Liner @ 6690' MD 1B-16A TD @ 9243' MD Billet @ 7205' MD KOP @ 7026' MD 3-1/2" x 5" TTWS 1B-16AL1PB1 TD @ 8886' MD Billet @ 8149' MD 7" PC Leak ~5325' Tubing Leak ~5468' Catcher ~6677' MD RBP ~6682' MD 1B-16A Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Conductor 121 121 16 15.06 62.5 H-40 Surface 4424.1 4164.5 9.625 8.83 40 L-80 Production 7441 6983 7 x 5 6.28 40 L-80 Liner 6665 6250 5.5 4.95 15.5 L-80 Tubing 6565 6157 3.5 2.992 9.3 L-80 •Tubing head adapter flange had corrosion damage, will need replaced PROPOSED 3.5" COMPLETION 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco KBG-29 gas lift mandrels @ TBD 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Seals PROPOSED 5.5" x 3.5" Tie-Back 5-1/2", 15.5#, L80, HYD563 MS (5.873" OD) to Surface PBR for 3-1/2" Seals 3-1/2" x 5-1/2" Crossover 3-1/2" Camco MMG gas lift mandrel 3-1/2" x 7" Packer 2.75" D or XN nipple at xxxx' RKB (2.75" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Packer @ 6666' RKB 2.75" D nipple @ 6688' RKB Surface Casing Production Casing Conductor A and C-sand perfs 7" PC Leak ~5325' A-Sand CTD Tubing Cut ~ 6650' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 9,059.0 1B-16 7/18/2019 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Annotate Casing Leak 1B-16 3/9/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic10.0 2/20/2019 jennalt NOTE: View Schematic w/ Alaska Schematic9.0 8/9/2010 ninam NOTE: EST. 132' RATHOLE BELOW BOTTOM PERF POST FCO 2/27/2009 TRIPLWJ Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 40.8 4,424.1 4,164.5 40.00 L-80 BTC PRODUCTION 7"x5" @ 6690' 7 6.28 38.9 7,441.1 6,982.5 26.00 L-80 BTC MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 38.8 Set Depth … 6,704.4 Set Depth … 6,286.0 String Max No… 4 Tubing Description TUBING 4"x3.5" Wt (lb/ft) 11.00 Grade J-55 Top Connection BTC MOD ID (in) 3.48 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) 38.8 38.8 0.05 HANGER 10.800 MCEVOY GEN IV HANGER 4.000 1,893.1 1,825.3 23.23 SAFETY VLV 6.000 CAMCO TRDP-4A SAFETY VALVE (LOCKED OUT TRDP 8-2-2017) 3.312 2,623.5 2,498.0 21.86 GAS LIFT 5.844 MERLA TMPD 3.361 4,104.1 3,866.9 21.93 XO REDUCING 4.000 CROSSOVER 4 x 3.5, ID 2.992, #9.3, J-55, EUE8RDMOD 3.500 4,139.3 3,899.5 21.84 GAS LIFT 5.390 CAMCO KBUG 2.920 5,203.5 4,890.1 21.43 GAS LIFT 5.390 CAMCO KBUG 2.920 5,986.9 5,620.0 21.22 GAS LIFT 5.390 CAMCO KBUG 2.920 6,619.8 6,207.3 21.68 GAS LIFT 6.016 CAMCO MMM 2.920 6,665.3 6,249.7 21.61 SEAL ASSY 4.000 BAKER GBH-22 LOCATOR w/ 10' SEAL ASSEMBLY 3.000 6,666.2 6,250.4 21.61 PACKER 6.150 BAKER FB-1 PERMENANT PACKER 4.000 6,669.6 6,253.6 21.60 SBE 5.000 SEAL BORE EXTENSION 4.000 6,687.6 6,270.4 21.58 NIPPLE 4.520 CAMCO D NIPPLE NO GO. (MILLED OUT TO A 2.80") 2.800 6,703.6 6,285.2 21.56 SOS 4.000 CAMCO PE 500 SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 5,325.0 5,003.2 21.49 LEAK - CASING CASING LEAK AT 5325' IDENTIFIED WITH WFL LDL 3/9/2024 6.280 5,468.0 5,136.2 21.57 LEAK - TUBING Relay LDL found leak in tubing @ 5468' RKB 12/27/2023 2.990 6,677.0 6,260.5 21.59 CATCHER Set Patch Catcher on top of RBP (OAL = 53") 12/24/2023 0.000 6,681.6 6,264.7 21.59 RBP 2.725" PIIP RBP MID- ELEMENT AT 6684' RKB, OAL 7.88' TTS PIIP RBP CPP3 5134 10/22/2023 0.000 6,699.0 6,281.0 21.56 LINER TOP PACKER 2.72" Northern Solutions Liner top packer w/ 1.781" R-Profile Nipple (10.66'" FROM TOP OF PACKER TO R-NIPPLE / 11.91'' OAL) 6/18/2019 1.781 7,025.0 6,585.8 19.22 WHIPSTOCK 2.63" OD BAKER GEN 2 DELTA WHIPSTOCK, 13.0' OAL, 2 RA TAGS AT 7032.3', 0 DEGREE HIGH SIDE ORIENTATION 1/16/2019 0.000 7,045.0 6,604.7 19.00 WHIPSTOCK 2.63" OD BAKER GEN 2, 13.0' OAL, 9.55' TRAY, 7.35' FROM TOW TO RA TAG, 330° ROHS ORIENTATION 12/3/2018 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,623.5 2,498.0 21.86 1 GAS LIFT GLV BK2 1 1,311.0 2/5/2019 0.156 4,139.3 3,899.5 21.84 2 GAS LIFT GLV STRI P 1 1,305.0 12/28/1999 strip fishin g neck 0.188 5,203.5 4,890.1 21.43 3 GAS LIFT DMY BK 1 0.0 12/24/2023 0.000 5,986.9 5,620.0 21.22 4 GAS LIFT DMY BK 1 0.0 8/14/1999 0.000 6,619.8 6,207.3 21.68 5 GAS LIFT DMY RK 1 1/2 0.0 8/13/1999 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,778.0 6,838.0 6,354.4 6,410.3 UNIT D, C-4, C- 3, 1B-16 11/7/1994 6.0 IPERF 2 1/8" Enerjet, 90 deg phasing 45 deg orient 1B-16, 3/10/2024 7:15:28 AM Vertical schematic (actual) PRODUCTION 7"x5" @ 6690'; 38.9-7,441.1 FLOAT SHOE; 7,439.6-7,441.1 FLOAT COLLAR; 7,353.9- 7,355.0 IPERF; 7,124.0-7,158.0 WHIPSTOCK; 7,045.0 WHIPSTOCK; 7,025.0 LINER AL1 COMPLETION CTD; 6,689.6-9,069.0 APERF; 6,900.0-6,908.0 APERF; 6,918.0-6,926.0 IPERF; 6,778.0-6,838.0 LINER TOP PACKER; 6,699.0 SOS; 6,703.6 SBR; 6,689.6-6,696.0 NIPPLE; 6,687.6 RBP; 6,681.6 CATCHER; 6,677.0 SBE; 6,669.6 PACKER; 6,666.2 SEAL ASSY; 6,665.3 GAS LIFT; 6,619.8 GAS LIFT; 5,986.9 LEAK - TUBING; 5,468.0 LEAK - CASING; 5,325.0 GAS LIFT; 5,203.5 SURFACE; 40.8-4,424.1 FLOAT SHOE; 4,422.5-4,424.1 FLOAT COLLAR; 4,338.9- 4,340.3 GAS LIFT; 4,139.3 GAS LIFT; 2,623.5 SAFETY VLV; 1,893.1 CONDUCTOR; 41.0-121.0 HANGER; 40.8-44.5 HANGER; 38.9 KUP PROD KB-Grd (ft) 41.11 RR Date 3/25/1994 Other Elev… 1B-16 ... TD Act Btm (ftKB) 7,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292245700 Wellbore Status PROD Max Angle & MD Incl (°) 23.63 MD (ftKB) 2,230.41 WELLNAME WELLBORE1B-16A Annotation Last WO: End DateH2S (ppm) 20 Date 8/12/2016 Comment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,900.0 6,908.0 6,468.2 6,475.7 C-1, 1B-16 6/10/2008 6.0 APERF 2.5" PJ HSD, 60 deg random 6,918.0 6,926.0 6,485.1 6,492.6 C-1, 1B-16 6/10/2008 6.0 APERF 2.5" PJ HSD, 60 deg random 7,124.0 7,158.0 6,679.6 6,711.9 A-4, 1B-16 6/5/1994 4.0 IPERF 3 3/8" HSD CSG Guns,180 deg phasing 1B-16, 3/10/2024 7:15:29 AM Vertical schematic (actual) PRODUCTION 7"x5" @ 6690'; 38.9-7,441.1 FLOAT SHOE; 7,439.6-7,441.1 FLOAT COLLAR; 7,353.9- 7,355.0 IPERF; 7,124.0-7,158.0 WHIPSTOCK; 7,045.0 WHIPSTOCK; 7,025.0 LINER AL1 COMPLETION CTD; 6,689.6-9,069.0 APERF; 6,900.0-6,908.0 APERF; 6,918.0-6,926.0 IPERF; 6,778.0-6,838.0 LINER TOP PACKER; 6,699.0 SOS; 6,703.6 SBR; 6,689.6-6,696.0 NIPPLE; 6,687.6 RBP; 6,681.6 CATCHER; 6,677.0 SBE; 6,669.6 PACKER; 6,666.2 SEAL ASSY; 6,665.3 GAS LIFT; 6,619.8 GAS LIFT; 5,986.9 LEAK - TUBING; 5,468.0 LEAK - CASING; 5,325.0 GAS LIFT; 5,203.5 SURFACE; 40.8-4,424.1 FLOAT SHOE; 4,422.5-4,424.1 FLOAT COLLAR; 4,338.9- 4,340.3 GAS LIFT; 4,139.3 GAS LIFT; 2,623.5 SAFETY VLV; 1,893.1 CONDUCTOR; 41.0-121.0 HANGER; 40.8-44.5 HANGER; 38.9 KUP PROD 1B-16 ... WELLNAME WELLBORE1B-16A Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1B-16A jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set K-Valve, CTD Sidetrack 1B-16A jennalt Casing Strings Casing Description A LINER COMPLETION (CTD) OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 7,210.1 Set Depth (ftKB) 9,243.0 Set Depth (TVD) … 6,645.5 Wt/Len (l… 4.60 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,210.1 6,698.2 85.94 ALUMINUM BILLET Aluminum Liner Top Billet 1.920 Notes: General & Safety End Date Annotation 2/20/2019 NOTE: View Schematic w/ Alaska Schematic10.0 Comment 1B-16A, 3/5/2019 9:10:34 AM Vertical schematic (actual) A LINER COMPLETION (CTD); 7,210.1-9,243.0 LINER AL1 COMPLETION CTD; 6,689.6-9,069.0 PRODUCTION 7"x5" @ 6690'; 38.9-7,441.1 WHIPSTOCK; 7,025.0 APERF; 6,900.0-6,908.0 APERF; 6,918.0-6,926.0 IPERF; 6,778.0-6,838.0 SOS; 6,703.6 NIPPLE; 6,687.6 LINER TOP PACKER; 6,682.0 SBE; 6,669.6 PACKER; 6,666.2 SEAL ASSY; 6,665.3 GAS LIFT; 6,619.8 GAS LIFT; 5,986.9 GAS LIFT; 5,203.5 SURFACE; 40.8-4,424.1 GAS LIFT; 4,139.3 GAS LIFT; 2,623.5 SAFETY VLV; 1,893.1 K VALVE; 1,893.0 CONDUCTOR; 41.0-121.0 HANGER; 38.9 KUP PROD KB-Grd (ft) 41.11 Rig Release Date 3/25/1994 Annotation Last WO: End Date 1B-16A H2S (ppm) 20 Date 8/12/2016... TD Act Btm (ftKB) 9,243.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292245701 Wellbore Status PROD Max Angle & MD Incl (°) 95.97 MD (ftKB) 7,354.30 WELLNAME WELLBORE1B-16A Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1B-16AL1 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set K-Valve, CTD Sidetrack 1B-16AL1 jennalt Casing Strings Casing Description LINER AL1 COMPLETION CTD OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 6,689.6 Set Depth (ftKB) 9,069.0 Set Depth (TVD) … 6,652.2 Wt/Len (l… 4.60 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,689.6 6,272.2 21.57 SBR Seal Bore Receptical, 3.0" GS Profile, 2.25" Polish Bore 1.910 Notes: General & Safety End Date Annotation 2/20/2019 NOTE: View Schematic w/ Alaska Schematic10.0 Comment 1B-16AL1, 3/5/2019 9:11:24 AM Vertical schematic (actual) LINER AL1 COMPLETION CTD; 6,689.6-9,069.0 PRODUCTION 7"x5" @ 6690'; 38.9-7,441.1 WHIPSTOCK; 7,025.0 APERF; 6,900.0-6,908.0 APERF; 6,918.0-6,926.0 IPERF; 6,778.0-6,838.0 SOS; 6,703.6 NIPPLE; 6,687.6 LINER TOP PACKER; 6,682.0 SBE; 6,669.6 PACKER; 6,666.2 SEAL ASSY; 6,665.3 GAS LIFT; 6,619.8 GAS LIFT; 5,986.9 GAS LIFT; 5,203.5 SURFACE; 40.8-4,424.1 GAS LIFT; 4,139.3 GAS LIFT; 2,623.5 SAFETY VLV; 1,893.1 K VALVE; 1,893.0 CONDUCTOR; 41.0-121.0 HANGER; 38.9 KUP PROD KB-Grd (ft) 41.11 Rig Release Date 3/25/1994 Annotation Last WO: End Date 1B-16AL1 H2S (ppm) 20 Date 8/12/2016... TD Act Btm (ftKB) 9,693.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292245760 Wellbore Status PROD Max Angle & MD Incl (°) 100.57 MD (ftKB) 8,149.02 WELLNAME WELLBORE1B-16A Or i g i n a t e d : D e l i v e r e d t o : 1ͲMa r Ͳ24 Ha l l i b u r t o n A l a s k a O i l a n d G a s C o n s e r v a t i o n C o m m . Wi r e l i n e & P e r f o r a t i n g At t n . : Na t u r a l R e s o u r c e T e c h n i c i a n At t n : F a n n y H a r o u n 3 3 3 W e s t 7 t h A v e n u e , S u i t e 1 0 0 69 0 0 A r c t i c B l v d . A n c h o r a g e , A l a s k a 99 5 0 1 An c h o r a g e , A l a s k a 9 9 5 1 8 Of f i c e : 9 0 7 Ͳ27 5 Ͳ26 0 5 FR S _ A N C @ h a l l i b u r t o n . c o m Th e t e c h n i c a l d a t a l i s t e d b e l o w i s b e i n g s u b m i t t e d h e r e w i t h . P l e a s e a d d r e s s a n y p r o b l e m s o r co n c e r n s t o t h e a t t e n t i o n o f t h e s e n d e r a b o v e WE L L N A M E A P I # S E R V I C E O R D E R # F I E L D N A M E J O B T Y P E D A T A T Y P E L O G G I N G D A T E P R I N T S # D I G I T A L # E S E T # 11 B Ͳ16 A 5 0 Ͳ02 9 Ͳ22 4 5 7 Ͳ01 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 2 7 ͲDe c Ͳ23 0 1 21 D Ͳ13 0 5 0 Ͳ02 9 Ͳ22 8 1 5 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 4 ͲDe c Ͳ23 0 1 31 D Ͳ14 1 A 5 0 Ͳ02 9 Ͳ22 9 6 7 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 5 ͲDe c Ͳ23 0 1 41 H Ͳ10 2 5 0 Ͳ02 9 Ͳ23 5 8 0 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 4 ͲJa n Ͳ24 0 1 51 Y Ͳ06 A 5 0 Ͳ02 9 Ͳ20 9 5 8 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 0 ͲFe b Ͳ24 0 1 62 A Ͳ10 A 5 0 Ͳ10 3 Ͳ20 0 5 6 Ͳ01 9 0 9 1 7 6 6 9 3 K u p a r u k R i v e r P e r f o r a t i o n R e c o r d F i e l d Ͳ Fi n a l 2 6 ͲFe b Ͳ24 0 1 72 C Ͳ12 5 0 Ͳ02 9 Ͳ21 2 2 2 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 3 0 ͲDe c Ͳ23 0 1 82 F Ͳ15 5 0 Ͳ02 9 Ͳ21 0 4 8 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 5 ͲFe b Ͳ24 0 1 92 U Ͳ05 5 0 Ͳ02 9 Ͳ21 2 8 1 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d & P r o c e s s e d 8 ͲDe c Ͳ23 0 1 10 2 W Ͳ01 5 0 Ͳ02 9 Ͳ21 2 7 3 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 6 ͲDe c Ͳ23 0 1 PL E A S E A C K N O W L E D G E R E C E I P T B Y S I G N I N G A N D R E T U R N I N G A C O P Y O F T H E T R A N S M I T T A L L E T T E R T O T H E A T T E N T I O N O F : Fa n n y H a r o u n , H a l l i b u r t o n W i r e l i n e & P e r f o r a t i n g , 6 9 0 0 A r c t i c B l v d . , A n c h o r a g e , A K 9 9 5 1 8 FR S _ A N C @ h a l l i b u r t o n . c o m Da t e : Si g n e d : Tr a n s m i t t a l D a t e : T3 8 5 7 5 T3 8 5 7 6 T3 8 5 7 7 T3 8 5 7 8 T3 8 5 7 9 T3 8 5 8 0 T3 8 5 8 1 T3 8 2 8 2 T3 8 5 8 3 T3 8 5 8 4 21 8 - 1 5 5 19 7 - 1 8 3 20 8 - 0 1 6 21 7 - 0 9 7 19 7 - 1 3 4 22 3 - 0 9 2 18 4 - 2 0 6 18 3 - 1 7 2 18 5 - 0 1 8 18 5 - 0 1 0 Me r e d i t h G u h l Di g i t a l l y s i g n e d b y M e r e d i t h G u h l Da t e : 2 0 2 4 . 0 3 . 0 4 1 5 : 1 9 : 5 8 - 0 9 ' 0 0 ' 1B Ͳ16 A 21 8-1 55 DATA SUBMITTAL COMPLIANCE REPORT 4/29/2019 Permit to Drill 2181550 Well Name/No. KUPARUK RIV UNIT 1B -16A p;01. , Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22457-01-00 MD 9243 TVD 6645 Completion Date 1/31/2019 Completion Status 1 -OIL Current Status SUSP UIC No REQUIRED INFORMATION HEADERS ED C Mud Log No Samples No ✓ Electronic Data Set, Filename: 1B-16AP81 Directional Survey Yes f DATA INFORMATION GAMMA RES.Ias List of Logs Obtained: GR/Res C 30253 Digital Data (from Master Well Data/Logs) Well Log Information: ED C 30253 Digital Data Log/ Electr Electronic File: 1B-16APB1 5MD Final Log.cgm ED C Data Digital Dataset Log Log Run Interval OH / Electronic File: 1B-16APB1 5TVDSS Final Type Med/Fant Number Name Scale Media No Start Stop Cry Received Comments __ ED C 30196 Digital Data C 1/4/2019 Electronic File: 1B-16APB1 EOW - NAD27.pdf ED C 30196 Digital Data ED 1/4/2019 Electronic File: 1B-16APBI EOW - NAD27.txt ED C 30196 Digital Data Electronic File: 1B-16APB1 51VID Final Log.pdf 1/4/2019 Electronic File: 1B-16APB1 EOW-NAD83.pdf ED C 30196 Digital Data 1/16/2019 1/4/2019 Electronic File: 1B-16AP81 EOW - NAD83.txt Log C 30196 Log Header Scans 0 0 2181550 KUPARUK RIV UNIT 1B -16A LOG AOGCC Page 1 of Monday, April 29, 2019 HEADERS ED C 30253 Digital Data 6628 7478 1/16/2019 Electronic Data Set, Filename: 1B-16AP81 GAMMA RES.Ias ED C 30253 Digital Data 1/16/2019 Electronic File: 18-16APB1 21VID Final Log.cgm ED C 30253 Digital Data 1/16/2019 Electronic File: 1B-16APB1 5MD Final Log.cgm ED C 30253 Digital Data 1/16/2019 Electronic File: 1B-16APB1 5TVDSS Final Log.cgm ED C 30253 Digital Data 1/16/2019 Electronic File: 1B-16APB1 21VID Final Log.pdf ED C 30253 Digital Data 1/16/2019 Electronic File: 1B-16APB1 51VID Final Log.pdf ED C 30253 Digital Data 1/16/2019 Electronic File: 1B-16APB1 5TVDSS Final Log.pdf ED C 30253 Digital Data 1/16/2019 Electronic File: 1B-16AP81 EOW - NAD27.pdf ED C 30253 Digital Data 1/16/2019 Electronic File: 18-16APB1 EOW - NAD27.txt ED C 30253 Digital Data 1/16/2019 Electronic File: 1B-16APB1 Final Surveys 7478 TD.csv ED C 30253 Digital Data 1/16/2019 Electronic File: 1B-16APB1 Final Surveys 7478 TD.xlsx ED C 30253 Digital Data 1/16/2019 Electronic File: 1B-16APB1 Survey Listing.txt AOGCC Page 1 of Monday, April 29, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/29/2019 Permit to Drill MD 9243 2181550 Well Name/No. KUPARUK RIV UNIT 1B -16A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22457-01-00 TVD 6645 Completion Date 1/31/2019 Completion Status 1 -OIL Current Status SUSP UIC No ED C 30253 Digital Data 1/16/2019 Electronic File: 113-16AP131 Surveys.txt ED C 30253 Digital Data 1/16/2019 Electronic File: 1B- 16APB 1_25_tapescan_BHI_CTK.txt ED C 30253 Digital Data 1/16/2019 Electronic File: 1B- 16AP61_5_tapescan_B H I_CTK.txt ED C 30253 Digital Data 1/16/2019 Electronic File: 1B-16APB1_output.tap ED C 30253 Digital Data 1/16/2019 Electronic File: 1B-16APB1 21VID Final Log.tif ED C 30253 Digital Data 1/16/2019 Electronic File: 1B-16APB1 51VID Final Log.tif ED C 30253 Digital Data 1/16/2019 Electronic File: 1B-16APB1 5TVDSS Final Log.tif Log C 30253 Log Header Scans 0 0 2181550 KUPARUK RIV UNIT 1B -16A PB1 LOG HEADERS ED C 30404 Digital Data 2126/2019 Electronic File: 113-16A EOW - NAD83.pdf ED C 30404 Digital Data 2/26/2019 Electronic File: 1 B-1 6A EOW - NAD83.txt ED C 30404 Digital Data 2/26/2019 Electronic File: 16.16A EOW NAD27.pdf ED C 30404 Digital Data 2/26/2019 Electronic File: 1 B-1 6A EOW NAD27.txt Log C 30404 Log Header Scans 0 0 2181550 KUPARUK RIV UNIT 1 B -16A LOG HEADERS Log C 30404 Log Header Scans 0 0 2181550 KUPARUK RIV UNIT 113-16A LOG HEADERS Log C 30417 Log Header Scans 0 0 2181550 KUPARUK RIV UNIT 1B -16A LOG HEADERS ED C 30417 Digital Data 6628 9243 2/28/2019 Electronic Data Set, Filename: 115-16A GAMMA RES.Ias ED C 30417 Digital Data 2/28/2019 Electronic File: 1B -16A 21VID Final Log.cgm ED C 30417 Digital Data 2/28/2019 Electronic File: 1B -16A 5MD Final Log.cgm ED C 30417 Digital Data 2/28/2019 Electronic File: 1B -16A 5TVDSS Final Log.cgm ED C 30417 Digital Data 2/28/2019 Electronic File: 1 B-1 6A 21VID Final.pdf ED C 30417 Digital Data 2/28/2019 Electronic File: 1 B -16A 5MD Final.pdf ED C 30417 Digital Data 228/2019 Electronic File: 1B -16A 5TVDSS Final.pdf ED C 30417 Digital Data 2/28/2019 Electronic File: 1B -16A EOW NAD27.pdf ED C 30417 Digital Data 228/2019 Electronic File: 18-16A EOW NAD27.txt ED C 30417 Digital Data 2/28/2019 Electronic File: 1B -16A Survey Listing.txt AOGCC Page2 of4 Monday, April 29, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/29/2019 Permit to Drill 2181550 Well Name/No. KUPARUK RIV UNIT 1B -16A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22457.01-00 MD 9243 TVD 6645 ED C 30417 Digital Data ED C 30417 Digital Data ED C 30417 Digital Data ED C 30417 Digital Data ED C 30417 Digital Data ED C 30417 Digital Data ED C 30417 Digital Data ED C 30417 Digital Data ED C 30417 Digital Data Well Cores/Samples Information Name INFORMATION RECEIVED Completion Report In Production Test Infonnatio �Y�/ NA Geologic Markers/Tops I Y 1 COMPLIANCE HISTORY Completion Date 1/31/2019 Completion Status 1-0IL Interval Start Stop Sent Received Current Status SUSP UIC No 2/28/2019 Electronic File: 1 B -16A Surveys.txt 2/28/2019 Electronic File: 1 B-16A_awp Final Surveys Sample Set Number Comments Directional / Inclination Data Y� Mud Logs, Image Files, Digital Data Y / A) Core Chips Y A Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Y� Core Photographs Y / A Daily Operations Summary 0 Cuttings Samples Y NA Laboratory Analyses Y / N Completion Date: 1/31/2019 Release Date: 12/6/2018 Description Date Comments AOGCC Page 3 of 4 Monday, April 29, 2019 9243.csv 2/28/2019 Electronic File: 18-16A_awp Final Surveys 9243.xlsx 2/28/2019 Electronic File: 1B- 16A_25_tapescan_BH I_CTK.txt 2/28/2019 Electronic File: 1B-16A_5_tapescan_BHI_CTK.txt 2/28/2019 Electronic File: 1B-16A_output.tap 2/28/2019 Electronic File: 1B -16A 2MD Final Log.tif 2/28/2019 Electronic File: 1 B-1 6A 5MD Final Log.tif 2/28/2019 Electronic File: 1 B -16A 5TVDSS Final Log.tif Sample Set Number Comments Directional / Inclination Data Y� Mud Logs, Image Files, Digital Data Y / A) Core Chips Y A Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Y� Core Photographs Y / A Daily Operations Summary 0 Cuttings Samples Y NA Laboratory Analyses Y / N Completion Date: 1/31/2019 Release Date: 12/6/2018 Description Date Comments AOGCC Page 3 of 4 Monday, April 29, 2019 DATA SUBMITTAL COMPLIANCE REPORT 412912019 Permit to Drill 2151550 Well Name/No. KUPARUK RIV UNIT 1B -16A Operator CONOCOPHILLIPS ALASKA, INC. MD 9243 TVD 6645 Completion Date 1/31/2019 Completion Status 1-0IL Current Status SUSP Comments: Compliance Reviewed By: API No. 50.029-22457-01-00 UIC No Date: AOGCC Page 4 of Monday, April 29, 2019 STATE OF ALASKA ALASKA OIL AND f;AG r.nNRr:RVATInN rnnnnnlecinni WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil21 - Gas[] SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. Well Class: Development [Z Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 1/31/2019 14. Permit to Drill Number / Sundry: 218-155 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 12116/2018 15. API Number: 50-029-22457-01-00 4a. Location of Well (Governmental Section): Surface: 501' FNL, 244' FEL, Sec 9, T11N, R10E, UM Top of Productive Interval: 3725' FNL, 1311' FEL, Sec 4, TI N, R10E, UM Total Depth: 5221' FNL, 2229' FEL, Sec 4, T11 N, R10E, UM 8. Date TD Reached: 1/25/2019 16. Well Name and Number: • KRU 1B-16AI1B-16APB1 9. Ref Elevations: KB:102 GL:61 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Plug Back Depth MD/TVD: NIA 18. Property Designation: ADL 25648 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 550195 y- 5969647 Zone- 4 TPI: x- 549110 y- 5971695 Zone- 4 Total Depth: x- 548206 y- 5970194 Zone- 4 11. Total Depth MD/TVD: . 9243/6645 • 19. DNR Approval Number: LONS 79-016 12. SSSV Depth MD/TVD: 1893/1825 20. Thickness of Permafrost MD/TVD: 1588/1544 5. Directional or Inclination Survey: Yes Ej (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: • 7026/6587 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD AMOUNT CASING WT. PER SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD GRADE TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 41 121 41 121 24 200 sx ASI 9.625 40 L-80 41 4424 41 4164 12.25 1000 sx ASIII Lead, 420 sx G Tail 7x5 26 L-80 39 7441 39 6982 8.5 350 sx Class G 2318 4.6 L-80 7210 9243 6698 6646 3 24. Open to production or injection? Yes E No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): R SLOTTED LINER @: / /0!_/� `/ / "� 7219-9235 MD and 6699-6646 TVD LLL/III `( !� COMP..LLLCCCICON f /�_ V/ / ]� 2 CC �� VERIFIED i Y 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4x 3.5 6704 6666/6250 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes EJNo ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 2/18/2019 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 2123/2019 Hours Tested: 14.4hrs Production for Test Period Oil -Bbl: 689 Gas -MCF: 743 Water -Bbl: 160 Choke Size: 100 Gas -Oil Ratio: 1079 Flow Tubing Press. 152 Casing Press: Calculated 24 -Hour Rate Oil -Bbl: 8 Gas -MCF: 12 Water -Bbl: 2 Oil Gravity - API (torr): 1 2 Form 10-407 Revised 5/2017 VTG- -3/2 //l 9 CONTINUED ON PAGE 2 RBDMSIf2'JMAR 0 6 2019 Sub it ORIGINIAL on 28. CORE DATA Conventional Corals): Yes ❑ No 3 ' Sidewall Cores: Yes ❑ No 0 . If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� - If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1588 1544 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7146 6679 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk A4 18-16APB1 7478 6691 TD 9243 6645 Formation at total depth: Ku aruk A4 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological r 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: t , I yt (Lc-I- Contact Name: William Lon Authorized Title: --�-, Staff-GT-En neer , -7,)I (Zt GTO Contact Email: William.R.Lon co .com Authorized Contact Phone: 263-4372 Signature: Date: 3I11 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item ta: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only R 0 3 (L 7 @Fm k � CO ); e/ 00 �\ g ƒg LO 0 §k k \ co \ ) % g S {EL \a 0 \ / \ Q ` g - g w! FD- k \k /2 / / k \ \\ / k\ / \ - a § ( m � ■ § 0 0 0 o q (L 7 @Fm k � CO ); e/ 00 �\ � ƒg LO 0 §k (L 7 @Fm k � CO ); KUP PRnD WELLNAME 1B -16A WELLBORE 1B_16 � E'� Well Attribute: I Max Angie & ConocoPI1)ll)p5 tlNama Wellbore APYUW WNlboreB lus Mo1XNb, Blml pl Alaska, �nC. KUPARUK RIVER UNIT 50029224900 PROD 3.113 2,23041 7,4500 1IFIA 2T4623t9&4R12AM Last Tag veruwlaGinnua(aOwp MnNed- DapulXKia 1EM Date wellpore LAN MW By ........................................................................................... Last Tag: RK8(Tagged Fill in 5"Casing) Q9680 11102019 i I 18-16 Iverrouse, Last Rev Reason nPor ;a49- g Anmmorm, End Do* wellbore Unit Moa 6y Rev Reason: Installed GLV's B 50 Liner Top Packer 'wieul9 1&16 zembaej Casing Strings caving DezcriptlOn p0Dn1 III (I,) Top mKel set polar set pepW IWO).-WULen i._Grade Top TbreM CONDUCTOR 16 15.06 41.11 121.0 121.0 62.50 H40 WELDED oranp oeserlPTun OD lint Dad T.11"" S""And"Mel eN DepM "Go" WSLen i1...L im TOP iM1rutl SURFACE 9518 8.83 40.8 1470.V 4,424.1 4,184.5 40.00 Lim BTC eoxollCTOR: of D19n Csslip peurlptlan Op am PRODUCTION ] Plan TopplKan 628 38.9 SeIrm"me, Set Oaplb pVol....Ame n..Bnae Top TMeaa ],441.1 6,982.5 26.00 L-80 BTC MOD ]"x5" @ 6690' Tubing Strings TubinP pezcrip4on Seing Ma... m (In le (flKBI Sel Pepin (tL. Sel Pepin (NDI 1... wtpbmt Graae TOp Connecllon TUBING 4•'x3.5" 4 3.48 38.8 6,]114.4 6,286.0 1100 J-55 BTC MOD 6PFET, Y7 -V; t 091 f Completion Details mp(NDI Tomo, Nominal (MSHFT:26218 Top MKS) Mail) (] Am Des Orion Plan) 38.8 36.8 005 HANGER MCEVOY GEN N HANGER 4.000 1,893.1 1,8253 23.23 SAFETYVLV CANCO TRDP-4A SAFETY VALVE3312 (LOCKED OUT TRDP 8-2-201]) 4,104.1 3,866.9 21.93 XO REDUCING CROSSOVER 4 x 3.5. ID 2.992, M9.3, J-55, EUE8RDMOO 3.500 pnsun; 4Jasa 6.665.3 6,2493 21.81 SEAL ASSY BAKER GBH -22 LOCATOR w/ 10 SEAL ASSEMBLY 6,6662 6,250.4 21.81 PACKER BAKER FB -1 PERMENANT PACKER 4000 6,669.8 8,253.6 21.60 §SS SEAL BORE EXTENSION 4.000 6,68].6 6,2]0.4 21.58 NIPPLE CAMCO D NIPPLE NO GO. (MILLED OUT TO A 280") 2.800 suRFACE; aoa,4uu- 6]03.6 I 6,285.221.56 SOS CAMCO PE 500 SHEAR OUT SUB 3.000 ors uFr; sans Other o Hole )elfireline retrievable plugs, valves, pumps, fish, etc.) TnptNp) TOpincl wsuFr. gem.a TopMKB) MKS) ri De, com Run wm Ip pnl 6,682.0 6,265.1 21.58 LINER TOP 2 ]T' NoMem Solupons Liner top pac erwl 1.78V R- 2/612019 1 781 PACKER Profile Nipple (10' GAL) ],025.0 6,585.8 19. WHIP ST K 2.63" OD BAKER GEN2 E ST 1I1fi2019 0.000 crs uFT;gnee DAL, 2 RA TAGS AT ]032.3', 0 DEGREE HIGH SIDE I ORIENTATION ],04.5.0 6,8047 19.00 WHIPSTOCK 2.63" O BAKER GEN 2,13 0' OAL, 9.55 A , . 12/32018 0.000 seALAsse e.sess FROM TOW TO RA TAG, 330" ROHS ORIENTATION PFCNEq; B,B69.a Perforations 8 Slots saE; ga89.8 an. Ocn Top INP) Bim INpI IzbOtLX ONERTOP PACKER; a,892p Top IryKB) BMMKIN828.0 (111(5) 16.41 20na DM¢ ) Type COm xIPPLE;gmTs 6,06.0 8,838.0 6,354.4 8,410.3 UNIT O, C-4, C- ITD, 11!111994 60 /PERF/ ne0el, Ddeg LINER COMPLETION 3.18-16 Fresim, 45 deg pdeal Cro;gma.ae,omo 6,9000 6,908.0 6,468.2 6,4]5.] C-1, 16-16 6/162008 6.0 APERF 2.5'P HSO, 60 ep random 6,918.0 6,926b 6,465.1 6,492.6 C-1.1&16 61162008 6.0 APERF 2.5'PJHSD,60deg random sps; s.Tose 7,1240 7,158.0 6,6]9.6 6,711.9 Ai, 1B-16 &511994 40 JPERF (PERF3318"HSD CSG Guns,180 deg phasing Mandrel Inserts st an prefer.B.TTBDAMil O Top IVolvo01 Volarch PM4re TRO Run N TOpMad, 0") Make Maatl OD On) Sam Type Tye (In) brep Run peb Co. 1 2,623.5 2,496.0 MERLA TMPD 1 GAS LIFT GLV BK2 0.156 1,311.0 2152019 APERF: gelgoa.ane- 2 4,139.3 3,899.5 CAMCO KBUG 1 GAS LIFT GLV STRIP 0.188 1,305.0 12/2811999 ship fishm MERE, e.Lfaaps.Spa.e- g neck 3 5,203.5 4,890.1 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 252019 4 5, 6.9 5.620.0 CAMCO KBUG i GAS LIFT DMY BK 0.000 0.0 8114/1999 5 6.619.8 6,207.3 CANDO MMM 1112 GAS LIFT DMV RK 0,000 00 8113/1999 Notes: General & Safety End Dar, AnawM1ticn 22]12009 NOTE: EST. 132' RATHOLE BELOW BOTTOM PERF POST FCO WRles.k, T,oxn (U9201D NOTE- Vim Schel W Alaska Srlle7atir0.0 Wimenc CKT.Oa50 2202019 NOTE: No. SolumaOc wl Alaska SchematiclaD /PERF;Tlaaaal.lyda vgooucnorf "a9 . Operations Summary (with Timelog Depths) 113-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start ayth Start Time End Time Dur (nn Phase Op Code ActlAy Code Time P-T-X Operadon (0KB) End Depm(fil(B) 12/13/2018 12/13/2018 - 1.50 MIRU MOVE RURD P Break down TT hard-line, secure BOP, 0.0 0.0 21:00 22:30 continue RD checklist 12/13/2018 12/14/2018 1.50 MIRU MOVE RURD P Disconnect PUTZ lines, chain off reel, 0.0 0.0 22:30 00:00 move mats away from rig, complete RD check list, Peak trucks arrive on pad 12/14/2018 12/14/2018 2.00 MIRU MOVE RURD P RU & move shop & half-way house to 0.0 0.0 00:00 02:00 1 2A-Pad 12/14/2018 12/14/2018 3.00 MIRU MOVE RURD P Truck back on site, rig up to sows, pull 0.0 0.0 02:00 05:00 sub & pits off well 12/14/2018 12/14/2018 6.50 MIRU MOVE MOB P Move from 2T-Pad to 1B-Pad 0.0 0.0 05:00 11:30 12/14/2018 12/14/2018 1.50 MIRU MOVE MOB P On 1 B pad, Remove jeeps from units. 0.0 0.0 11:30 13:00 Check tree status, Rig up cellar herculite 12/14/2018 12/14/2018 1.50 MIRU MOVE MOB P Spot modules 0.0 0.0 13:00 14:30 12/14/2018 12/14/2018 3.00 MIRU MOVE RURD P Crew change, PJSM, Safe out 0.0 0.0 14:30 17:30 location, Build scaffolding in cellar, Start working rig up check lists 12/14/2018 12/14/2018 1.50 MIRU MOVE NUND P MU PUTZ, NU BOPE, continue RU 0.0 0.0 17:30 19:00 checklist " Rig Accept 19:00 hrs 12/1412018 12/14/2018 2.50 MIRU MOVE RURD P Grease swab & tango valves, 0.0 0.0 19:00 21:30 harmmer up flanges, swap out riser, engergize koomy 12/14/2018 12/14/2018 2.10 MIRU MOVE RURD P Grease HCR's (change out bad 0.0 0.0 21:30 23:36 pump), complete RU checklsit 12/14/2018 12/15/2018 0.40 MIRU WHDBOP DISP P Line up valves, begin fluid packing 0.0 0.0 23:36 00:00 lines 12/15/2018 12/15/2018 0.20 MIRU WHDBOP DISP P Complete fluid packing lines, displace 0.0 0.0 00:00 00:12 coil to freshwater 12/15/2018 12/15/2018 0.30 MIRU WHDBOP PRTS P Shell test, good 0.0 0.0 00:12 00:30 12/15/2018 12/15/2018 1.30 MIRU WHDBOP BOPE P Begin BOP test (witness waive by 0.0 0.0 00:30 01:48 Adam Ead ofAOGCC), "Low 250 psi, high 3500 psi 12/15/2018 12/15/2018 1.00 MIRU WHDBOP BOPE T Difficulty holding low test #5(Chadie 0.0 0.0 01:48 02:48 7), grease valve, good test 12/1512018 6.70 MIRU WHDBOP BOPE P Continue BOP lest, install test joint, 0.0 0.0 112/15/2018 02:48 09:30 continue test, No other failures. Test PVT & gas detectors - all good, 9 hour test 12/15/2018 12/15/2018 1.90 MIRU WHDBOP PRTS P Fluid pack CT and pressure test inner 0.0 0.0 09:30 11:24 reel valve. Unstab injector, PT TT line and PDL's 12115/2018 12/15/20180.60 PROD1 WHPST CTOP P Change out upper quick connect and 0.0 0.0 11:24 12:00 1 1rehead E-line 12/152018 12/15/2018 1.50 PRODI WHPST PULD P PJSM, M/U and deploy BHA#1 0.0 74.2 12:00 13:30 Window milling BHA with 2.81 mill, 2.8 string reamer, and .6° AKO motor 12/15/2018 12/15/2018 1.00 PROD1 WHPST PULD T Unable to accuate master valve, Call 74.2 74.2 13:30 14:30 out valve crew. Valve is pressure locked 12/15/2018 12/15/2018 0.80 PROD1 WHPST PULD P Master open. WHP=525, Continue 74.2 74.2 14:30 15:18 with deployment, Make up coil to BHA and surface test - Good. Stab on injector. Tag up and set counters 12/15/2018 12/15/2018 1.60 PROD1 WHPST TRIP P RIH BHA#1 to mill window. On 74.2 6,655.0 15:18 16:54 seawater returns to Tiger tank Page 1122 Report Printed: 2/14/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time EM Tone Dxf1r) Phase Op Corte ArAivity Corte Tim P -T -X Operation (ftKB) End Depth (ORB) 12/15/2018 12/15/2018 0.10 PROD1 WHPST OLOG P Log K1 for+1.5' correction 6,655.0 6,684.0 16:54 17:00 12/15/2018 12/15/2018 1.20 PROD1 WHPST DISP P Continue RIH, flush well W` seawater, 6,684.0 6,760.0 17:00 18:12 unable to establish returns, bull -head seawater to window (2 bpm, 200 psi WHIP) 12/15/2018 12/15/2018 0.40 PRODi WHPST DISP P Displace coil to DuoVis 6,760.0 6,760.0 18:12 18:36 12/15/2018 12115/2018 2.30 PROD1 WHPST WAIT P Await building 50 bbl 150K LSRV pill, 6,760.0 6,760.0 18:36 20:54 coordinate trucks & fluids for possibility of no returns should pill not help Obtain SBHP while waiting on pill: MD = 6760', TVD sensor= 6296.9', BHP = 2717 psi, EMW = 8.3 ppg 12/152018 12/15/2018 2.00 PROD1 WHPST DISP P Bullhead 50 bbl 150K LSRV pill 6,760.0 6,760.0 20:54 22:54 followed by DuoVis down to perfs (pushing away seawater), WHIP climbs from 150 psi to —850 psi at parts, then begins to drop (100 bbis away, 40 bbl squeezed into perfs) 12/15/2018 12/15/2018 0.60 PROD1 WHPST TRIP P Pump attempting to get returns, 6,760.0 7,049.3 22:54 23:30 returns start @ 40% , quickly demininish to —21%, decision made to close choke & mill window, PUW = 41 K, RIH, dry tag WS pinch point @ 7049.81, PUH, bring on pumps 121152018 12/16/2018 0.50 PROD1 WHPST WPST P Tag WS pumping @ 7049.3', FS = 550 7,049.3 7,050.0 23:30 00:00 psi @ 1.9 bpm,, CWT = 24.6K, WOB = 0.31K, BHP = 2866 psi, circ = 3567 psi 12/16/2018 12/16/2018 3.50 PROD1 WHPST WPST P Continue milling window, CWT= 7,050.0 7,052.8 00:00 03:30 21.4K, WOB = 1.81K, BHP = 2906 psi, circ = 3324 psi, dosed choke, 1.87 bpm 12/16/2018 12/16/2018 1.50 PROD1 WHPST WPST P Continue milling window, CWT= 7,052.8 7,054.7 03:30 05:00 22.8K, WOB = 2K, BHP = 2933 psi, circ = 3272 psi Pre -load build BHA 12/16/2018 12/16/2018 2.60 PRODi WHPST WPST P Milling window, WOB = 2.51K, BHP = 7,054.7 7,057.3 05:00 07:36 2952 psi, circ = 3364 psi, WHIP = 12 psi TF=30R 12/162018 12/16/2018 2.00 PROD1 WHPST WPST P Called BOW @ 7056.3, Reamer out 7,057.3 7,071.0 07:36 09:36 @ 7057.3. Drill ralhole. 1.9 BPM @ 3400 PSI FS, BHP=2993 12/162018 12/16/2018 2.00 PROD1 WHPST REAM P TO Rathole, start reaming passes. As 7,071.0 7,071.0 09:36 11:36 drilled, 30L, 30R, and 180° out of as drilled tool face. Dry drift window - Good. 12/16/2018 12116/2018 1.20 PRODi WHPST TRIP P POOH, PUW=36K 7,071.0 74.0 11:36 12:48 12/1612018 12/16/2018 1.00 PROW WHPST PULD P At surface, Tag up and space out. 74.0 0.0 12:48 13:48 Flow check well. PJSM. Well dead. Static losses — 20 BPH. Lay down BHA#1. Mill and string reamer out @ 2.79 No Go 12116/2018 12/16/2018 1.20 PROD1 DRILL PULD P P/U BHA#2, was pre loaded in PDL. 0.0 72.2 13:48 1500 Make up to coil and surface test, Check pack offs 12/16/2018 12/16/2018 1.30 PROD1 DRILL TRIP P RIH BHA#2 72.2 6,650.0 1500 16:18 Page 2122 Report Printed: 211412019 Operations Summary (with Timelog Depths) 113-116 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth start Time End Time Dur (m) Phase Op Code q vitt' Code Time P-T-X Operation (rtKa) End Depth (itKB) 12/16/2018 12/16/2018 0.20 PROD? DRILL DLOG P - log Kt for+.5', PUW=36K, Close EDC 6,650.0 6,670.0 16:18 16:30 12/16/2018 12/16/2018 0.20 PROM DRILL TRIP P Continue in well. Clean pass through 6,670.0 7,071.0 16:30 16:42 window 12/1612018 12/16/2018 1.40 PROD1 DRILL DRLG P 771', Drill, 1.9 BPM @ 3214 PSI FS, 7,071.0 7,160.0 16:42 18:06 BHP=2950, Choke shut, WHP=O, RIW=19.2K, DHWOB=1.5, Bleed IA down from 1070, crew change, PUW = 40K 12/16/2018 12/16/2018 1.20 PROD1 DRILL DRLG P Drilling, FS = 530 psi @ 1.9 bpm, 7,160.0 7,215.0 18:06 19:18 closed choke, CWT = 21 K, WOB = 1.41K, BHP = 3050 psi, circ = 3404 psi, WHIP = 0 psi Difficulty, achieving 45° DLS, reduce rate to 1.5 bpm & increase WOB per DO request, geo's confer w/town geology 12/16/2018 12/16/2018 0.30 PROD1 DRILL WAIT P Geo/DD wiper, allow geo's time to 7,215.0 7,215.0 19:18 19:36 discuss deeper build landing, PUW = 40K, decision made to continue drilling 12/16/2018 12/16/2018 1.50 PROD1 DRILL DRLG P Drilling, CWT = 19K, WOB = 3.5K, 7,215.0 7,267.0 19:36 21:06 BHP = 3091 psi, WHIP = 33 psi, circ = 2820 psi Continue at 1.5 bpm & increase WOB in attempt to achieve higher DLS, PUW = 38K 12/16/2018 12117/2018 2.90 PROD1 DRILL DRLG P Drilling, FS = 550 psi @ 1.9 bpm, 7,267.0 7,378.0 21:06 00:00 CWT =17.6K, WOB =4K, BHP= 3134 psi, WHIP = 62 psi, varialbe ROP (12 fph -115 fph), PUW = 40K, begin pulling 46K & -3 WOB 12/1712018 12/17/2018 0.30 PROD1 DRILL WPRT P Continue wiper to window, pull up past 7,378.0 6,640.0 00:00 00:18 1 1 1 perfs at 6788' 12/17/2018 12/17/2018 0.30 PROM DRILL DLOG P Log K1 for+1' correction, continue in- 6,640.0 7,090.0 00:18 00:36 hole, log RA @ 7053' TOWS = 7046, TOW = 7048', BOW = 7056, RA = 7053 12/17/2018 12/17/2018 0.20 PROM DRILL WPRT P Wiper in-hole, RIW=20K, weight 7,090.0 7,378.0 00:36 00:48 bobbles at 7277'& 7355'(-1 K WOB) 12117/2018 12/17/2018 1.40 PROM DRILL DRLG P Drilling, FS = 568 psi @ 1.9 bpm, 7,378.0 7,470.0 00:48 02:12 CWT =19.8K, WOB =1.8K, BHP= 3229 psi, WHIP = 120 psi, circ = 3602 psi, closed choke, drill to called EOB @ 7470 Work PDL's to avoid freeze-up 12117/2018 12/17/2018 1.80 PROD1 DRILL TRIP P POOH, PUW = 40K, pull heavy 7,470.0 71.0 02:12 04:00 through 7365', 7342'& 7242 (up to - 4K WOB), open EDC, tag up, flow check, have flow 12/17/2018 12/17/2018 0.90 PROM DRILL PULD P PUD BHA#2, pumping managed 71.0 0.0 04:00 04:54 pressure 12/17/2018 12/17/2018 2.00 PROD1 DRILL PULD P PD BHA #3 "A" Lateral Assembly 0.0 78.0 04:54 06:64 (NOV Agitator, 0.5' AKO motor, RS HYC A2 bit), slide in cart, check pack- offs, MU to coil, tag up 12/17/2018 12/17/2018 1.20 PROM DRILL TRIP P Trip in hole, BHA#3A lateral section, 78.0 6,655.0 06:54 08:06 Shallow test agitator 12/17/2018 12/172018 0.20 PROD1 DRILL DLOG P Log K1 tor +.5', PUW=37K 6,655.0 6,680.0 08:06 08:18 I Page 3/22 ReportPrinted: 211412019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Starl Depth Start Tme Endnm_ Dur (hr) Phase Op Code Ach* Code Time PJA Operation (WB) EM Depth MKS) 12/17/2018 12/17/2018 0.20 PROD? DRILL TRIP P Continue in well, Clean trip through 6,680.0 7,478.0 08:18 08:30 window. Clear to bottom @ 7478 12/17/2018 12/17/2018 0.50 PROD1 DRILL TRIP T 7478 PUH. Tight spots with pack offs 7,478.0 6,608.0 08:30 09:00 and high negative weight on bit. Hole in poor condition. Get up to cased hole. Jet 5 112 tubing in preparation for Polyswell pill. 12/17/2018 12/17/2018 2.40 PROD? DRILL CIRC T Poly Swell material coming for 6,608.0 6,608.0 09:00 11:24 1 1 1 Deadhorse. recap 5 1/2 tubing 12117/2018 12/17/2018 2.00 PROD? DRILL CIRC T Stand by for polly swell 6,608.0 6,655.0 11:24 13:24 12/17/2018 12/17/2018 0.10 PROM DRILL DLOG T Log K1 for+3' correction 6,655.0 6,682.0 13:24 13:30 12/17/2018 12/17/2018 0.10 PROM DRILL TRIP T Trip in hole 6,682.0 6,700.0 13:30 13:36 12/17/2018 12/17/2018 0.20 PROD1 DRILL CIRC T Line up to pump down back side for 6,700.0 6,700.0 13:36 13:48 baseline pressures for poly swell job, 1 BPM Pump=315 PSI, BHP=2928, 1.5 BPM Pump=475PSI, BHP=3001, WHP=420, 2 BPM Pump=600PSI, BHP=3083, 2.5 BPM, Pump=700PS1, BHP=3137, 3 BPM Pump=800PSI, BHP=3177, 12/17/2018 12117/2018 1.30 PROD1 DRILL CIRC T PJSM to mix and pump poly swell 6,700.0 6,715.0 13:48 15:06 12/17/2018 12/17/2018 0.50 PROD1 DRILL CIRC T Pump 20 BBI poly swell pill down back 6,715.0 6,715.0 15:06 15:36 side, 3 BBI/Min, Pump Pressure 1100 PSI, WHP=25 PSI. 12/17/2018 12/17/2018 0.10 PROD1 DRILL TRIP T 6715 At 60 Bela pumped down back 6,715.0 6,096.0 15:36 15:42 side Pull up hole out of pill, PUW=38K 12/17/2018 12/17/2018 1.00 PROD1 DRILL OTHR T 6096, out of pill. Wait for poly swell to 6,096.0 6,096.0 15:42 16:42 activate. 12/17/2018 12/17/2018 0.20 PRODt DRILL CIRC T Start pumping down back side .5 6,096.0 6,096.0 16:42 16:54 BPM, WHP=23PSI, No change durin pumping, BHP=2745 12/17/2018 12/17/2018 0.80 PRODt DRILL OTHR T Shut down pump. No pressure build 6,096.0 6,096.0 16:54 17:42 up, Batch up second 20 BBL pill of poly swell 12/17/2018 12/17/2018 0.40 PROM DRILL CIRC T Pump 20 BBI pill of poly swell down 6,096.0 6,714.0 17:42 18:06 backside follow with duo vis RIH to below TT 12/17/2018 12/17/2018 2.40 PROM DRILL OTHR T At 6714. Wait on poly swell to activate, 6,714.0 6,714.0 18:06 20:30 1 1 2 Hrs 12117/2018 12/17/2018 1.00 PROD1 DRILL CIRC T Online with pump down back side .5 6,714.0 6,714.0 20:30 21:30 BPM, BHP=2830, Climbed slowly to 3210 12/17/2018 12/1712018 0.60 PROD1 DRILL TRIP T Trip in hole, Start prepping 3rd Poly 6,714.0 6,094.0 21:30 22:06 pill, 30 BBis 12/17/2018 12117/2018 0.50 PROD1 DRILL CIRC T Pump 30 BBI poly pill down back side 6,094.0 6,094.0 22:06 22:36 at 2 BPM under displace pill 30 Pill and 20 BBIs duo vis. 2 BPM BHP=3210 12/17/2018 12/18/2018 1.40 PROD1 DRILL WAIT T Pill spotted, PUH out of pill to 4000', 6,094.0 4,000.0 22:36 00:00 1 1 Wait 2 hours for swelling action 12/18/2018 12/18/2018 1.20 PROD1 DRILL WAIT T Continue to allow poly swell pill swell 4,000.0 4,000.0 00:00 01:12 1 1 time, estimate 35 bbl above perfs Page 4122 Report Printed: 2/1412019 Summary (with Timelog Depths) 1B-16 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log scan Oepo, start Time End Time Our (nq Phase Op Code Activit' Cade Time P -T -X Operaw MM) End Oepm (MB) 12/18/2018 12/18/2018 0.70 PROD1 DRILL DISP T Pump 0.5 bpm down back -side, bit 4,000.0 4,000.0 01:12 01:54 depth = 4000', (attempting to achieve 1500 psi over stabalized annular pressure of 2750 psi) Annular quickly rises to 2600 psi, 2 bbl away, annular = 2750 psi _ 5 bbl away, annular = 3000 psi 10 bbl away, annular= 3217 psi 15 bbl away, annular= 3387 psi 17.5 bbl away, annular = 3412 psi (up to 13.7 ppg, and began to flatten) Shutdown pumps, pressure drops to -2600 psi relatively quickly, then began to slow 12/18/2018 12/18/2018 1.10 PROD? DRILL WAIT T Confer w/ town on plan forward 4,000.0 4,000.0 01:54 03:00 12/18/2018 12/18/2018 3.20 PROD1 DRILL DISP T Decision made to pump away 4,000.0 4,000.0 03:00 06:12 remaining 8.5 bbl Poly Swell, maintaining 11.4 ppg at window (2650 psi annular @ bit depth of 4000') Began pumping, annular quickly jumps to 3200 psi, allow to drop to 2650 psi, shut down pumps, continue pumping small ammounts and shutting down pump to maintain 11.4 ppg. (-1100 psi WHP), swap to managed pressure in attempt to reduce annular fluctuations, rate in began to increase quickly from nominal to hold 11.4 ppg to .45 bpm, difficulty holding 11.4 ppg at window Begin prepping for 4th Poly Swell pill should it be required (30 bbl) 12/18/2018 12118/2018 1.00 PROM DRILL DISP T Begin circulating down coil, unable to 4,000.0 6,715.0 0612 07:12 hold 11.4 ppg at window, confer w/ town, decision made to build & pump 4th Poly Swell pill (30 bbl) 12/18/2018 12/1812018 0.60 PRODt DRILL DISP T 50 bbl bullhead away 30 bbl Poly 6,715.0 3,826.0 07:12 07:48 Swell follow by 20 bbl DuoVis, reduce rate & PUH to 3826' pumping pipe displacement, PUW = 38K, (-26 bbl Poly Swell above Paris in cased hole) 12/18/2018 12/18/2018 2.00 PROM DRILL WAIT T Wait on swell time, pumps off (9.0 ppg 3,819.0 3,819.0 07:48 09:48 1 1 1 at window) 12/18/2018 12/18/2018 0.70 PRODt DRILL DISP T Squeeze 22 bbl away attempting to 3,819.0 3,819.0 09:48 10:30 hold 12.4 ppg at window, begin pumping at 1.8 bpm to build to 11.76 ppg ppg, 10 bbl away, reduce rate to .5 bpm attempting to build to 12.4 ppg, unable to achieve 12.4 ppg, drop to 10.4 ppg 12/18/2018 12/18/2018 2.00 PRODt DRILL WAIT T Conferw/town, MI formulating plan 3,819.0 78.0 10:30 12:30 forward W FORM-A-BLOK pill (recipe & volume requirements), perform lab tests w/ product on rig, PUH, tag up in prep for pumping 12/18/2018 12/18/2018 2.20 PROM DRILL WAIT T Await super sucker to clear pits, super 78.0 78.0 12:30 14:42 sucker arrives on site Coordinate w/ facilites for 3C-08 pre - rig work, begin RDMO paperwork should that become plan forward Page 5/22 Report Printed: 2114/2019 Operations Summary (with Timelog Depths) 113-16 Rig: NABORS CDR3-AC Jab: DRILLING SIDETRACK Time Log Start Depth Start Time End Tim Dur hr ( ) Phase O Code p viy Actl Code Time P-T-X O Aeration (W[3) End Depth (tIKB) 12/18/2018 12/18/2018 1.00 PROD1 DRILL CLEN T Suck out pits, wash down & clean of 78.0 78.0 14:42 15:42 all polymer 1211812018 12/18/2018 2.80 PROD1 DRILL CIRC T Build 10 bbl KCI spacers & 23 bbl 78.0 78.0 15:42 18:30 FORM-A-BLOK pill (40 ppb product) 12/18/2018 12/18/2018 0.80 PROD1 DRILL CIRC T PJSM, Pump 5 bbl KCL spacer, @ 3 78.0 78.0 18:30 19:18 bpm, Pump 20 bbls Form-A-Blok from 3-0.25 bpm, lots of issues pumping, lost C pump pressure, Triplex jacking off, pum - 1.0 bbl duovis, unable to initially catch prirme with KCL, swap to KCL once pump lined up, Pump 5 bbls KCL @ 3 bpm, Swap to duovis displacement, chase LCM to parts @ 3 bpm, CT 650 psi, WH 612 psi, 12118/2018 12/18/2018 0.30 PRODt DRILL CIRC T At 77 We total treatment away, with 78.0 78.0 19:18 19:36 Form-A-Blok at the perfs reduce rate to 0.5 bpm, pump 10 bbls of Form-A- Blok to the formation, CT 195 psi, WH fell from 596 psi to 165 psi @ 5 bbls away, then climbed slowly to 179 psi at 10 We away 12/18/2018 12118/2018 3.70 PROD1 DRILL CIRC T SID for 30 min, On line, - 1 bbl away 78.0 78.0 19:36 23:18 to fit hole / catch pressure. Squeeze away 1.8 bbls (total away 89.8 bbls) well head climbed to 137 psi then broke over, SID for 30 min, WH fell to 0 psi Catch pressure with 1 bbl away, squeeze 1 bbl, WH climbed to 140 psi. SID for 30 min. WH fell to 0 psi Catch pressure imeditty, squeeze 1 bbl away, WH climbed to 183 psi. SID for 30 min. WH fell to 3 psi Catch pressure imeditly, squeeze 1 bbl away, WH climbed to 218 psi. SID for 30 min. WH fell to 33 psi Catch pressure imeditty, squeeze 1 bbl away, WH climbed to 245 psi. SID for 30 min. WH fell to 50 psi Catch pressure imeditly, squeeze 1 bbl away, WH climbed to 290 psi. SID for 30 min. WH fell to 83 psi 12/18/2018 12/19/2018 0.70 PROD1 DRILL CIRC T Move pipe, RIH 100 feet, POOH, 78.0 96.8 23:18 00:00 bump up, space out PJSM, Start batching 50 bbls of Pro V, 40 bbls water, 3 sacks viscosifyer, and Pro V plus LCM pill 12/19/2018 12/19/2018 3.00 PROD1 DRILL CIRC T Complete building 52 We pill of Pro 96.8 96.8 00:00 03:00 V+ LCM pill, (92 lb/bbl). 12/19/2018 12/19/2018 2.10 PROD1 DRILL CIRC T Lead in with duovis - mud, establish 96.8 96.8 03:00 05:06 injection 1 bpm WH 350 psi, swap to Pro V, pump 9.8 bbls, lock up Pump #1, troubleshoot issues. Swap to pump #2, get 7.6 bbls away lost pump #2. Pull apart pump # 1, LCM packing off and floating the valves. Tear down and clean Pump#1. "ProV = 9.32 ppg Page 6122 Report Printed: 211412019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log s art oepM BUrt Time End Time Ow (hr) Phase Op Code AdINry CoOe Time P -T-% Operetion (ItKB) End OePN (Po(B) 12/19/2018 12/19/2018 0.80 PROD1 DRILL CIRC T Back on line, estimate 17.4 bbls of 96.8 96.8 05:06 05:54 plug on the backside, meter indicated - 33 bbls on restat due to clearing lines. Ignoring fallout lead of plug at parts with 92.6 bbls away end of plug is 110 bbls away. Displace at 2 bpm, WH 610 pi. WH broke trend @ 76 bbls, cul rate to 1 bpm @ 81 bbs away. WH increased to 720 psi then broke back, reduced rate to 0.5 bpm. WH climbed and started to break over. Shut down trapping 555 psi on the WH 12/19/2018 12M 9/2018 1.30 PROD1 DRILL CIRC T Wait on dehydration 96.8 96.8 05:54 07:12 12/19/2018 12/19/2018 0.70 PROD1 DRILL CIRC T Discussed w/ Procor rep, decision 96.8 78.0 07:12 07:54 made to squeeze away all 5.75 bbl & attempt again w/ more volume (ie the remaining 45 bbl in pits), Squeeze away bbl 11.4 bbl, WHP climbs to 785 psi, WHP w/ pumps off drops to 69 psi Shut 2-3/8" rams to isolate EDC, trap 105 psi WHP to ensure rams & checks are holding, pump down MP line, DPS is below rams (so will see dip, though is not affecting EDC) 12/19/2018 12119/2018 1.20 PROD1 DRILL CIRC T PJSM, discuss w/ Procor rep method 78.0 78.0 07:54 09:06 of getting LCM in-hole given earlier packed off pump issue, decision made to pump remaing -45 bbl of Pro V, 5 bbl Pro V followed by -2 bb DuoVis (both in-hole), chase 60 bbl "pill' w/ DuoVis 72 bbl away, Pro V @ parts (Note:132 bbl total pumped will be tail of Pro V pill through the parts) 12/19/2018 12/1912018 0.30 PROD1 DRILL CIRC T Squeeze away 20 bbl @ 1 bpm (92 78.0 78.0 09:06 09:24 total pumped), WHP climbs to 850 psi 12/19/2018 12!19/2018 1.00 PROM DRILL CIRC T Wait, WHP drops to 79 psi @ 1 hr 78.0 78.0 09:24 10:24 12/19/2018 12/19/2018 0.20 PROM DRILL CIRC T Squeeze 12 bbl, WHP = 875 psi, 78.0 78.0 10:24 10:36 103.75 bbl total pumped, 28.25 bbl pill remains 12/1912018 12/19/2018 0.50 PRODt DRILL CIRC T Wait, WHP drops to197 psi 78.0 78.0 10:36 11:06 12119/2018 12/19/2018 1.50 PROM DRILL CIRC T Pump at .1-.2 bpm until WHP = 600 78.0 78.0 11:06 12:36 psi, wait 20 min, WHP drops to 210 psi, (pumped 110 bbl total, 22 bbl remain) 12/19/2018 12/19/2018 0.70 PROM DRILL CIRC T Pump at .1-.2 bpm until WHP = 650 78.0 78.0 12:36 13:18 psi, wait 20 min, WHP drops to 221 psi,(pumped 113.7 bbl total, 19 bbl remain) 12/19/2018 12/19/2018 0.80 PROD1 DRILL CIRC T Pump at -.3 bpm until WHP begins to 78.0 78.0 13:18 14:06 plateaus @ 888 psi, WHP quickly w/ pumps off, (pumped 125.8 bbl total, 6.2 bbl remain) 12/19/2018 12/19/2018 0.50 PROM DRILL CIRC T Pump remaining 6.2 bbl at .5 bpm, 78.0 78.0 14:06 14:36 WHP climbs to 962 psi, with tail out perfs WHP drops to 856 psi, then climbs to 990 psi (142 bbl total pumped) Page 7122 Report Printed: 211412019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depth De Stan Time End lime Dur hr ( ) Phase O Code p Activity Code Tem P -T -X Operation (n End Depth (fll(B) 12/19/2018 12/19/2018 1.10 PRODI DRILL CIRC T Line up down coil, RIH to 2000', 78.0 78.0 14:36 15:42 pumping 1.3 bpm, At 2000' ** 1.8 bpm, 1 -far -1 returns at holding 9.7 ppg at window ** 1.8 bpm, 11.2 ppg, 72% returns, WHIP = 818 psi 12/1912018 12119/2018 1.00 PROD1 DRILL TRIP T Continue RIH, pumping .75 bpm, 78.0 6,620.0 15:42 16:42 holding 11.2 ppg 12/19/2018 12/19/2018 0.40 PROD1 DRILL DLOG T Difficulty finding K1, PUH to 6620'& re 6,620.0 6,676.0 16:42 17:06 -log, PUW = 34K 12/19/2018 12/19/2018 2.00 PROD1 DRILL CIRC T Continue in-hole, slow through tubing- 6,676.0 6,676.0 17:06 19:06 tail & down to TOWS Make two down passes jeting max rate @ 20 f lmin from 6723' to 7035'. 12/19/2018 12/19/2018 1.50 PROD1 DRILL TRIP T POOH 6,676.0 83.0 19:06 20:36 12/19/2018 12/19/2018 1.20 PROD1 DRILL PULD T PJSM, atempt to bleed WH and lay 83.0 0.0 20:36 21:48 down over a dead well, presure built to 8 psi. PUD BHA#3. 12/19/2018 12/192018 0.50 DEMOB WHDBOP PULD P Pick up a nozzle, stab back on. 0.0 0.0 21:48 22:18 12/192018 1220/2018 1.70 DEMOB WHDBOP DISP P Bullhead 220 bbls seawater 1.9 BPM, 0.0 0.0 22:18 00:00 CT 4047 psi, WH 774 psi. LR on location, PJSM, confirm customer valve clear with air, RU, PT to 4 k psi, good. 12120/2018 12/20/2018 0.20 DEMOB WHDBOP DISP P Complete bullheading 180 bbls 0.0 0.0 00:00 00:12 seawater 1.9 BPM, CT 4047 psi, WH 774 psi. LR on location, PJSM, confirm customer valve clear with air, RU, PT to 4 k psi, good. 12/202018 12/202018 1.00 DEMOB WHDBOP DISP P LRS, Bullhead 30 bbls diesel FP 1.0 0.0 0.0 00:12 01:12 BPM, CT 1400 psi, WH 454 psi. *** S/I well with 490 psi on the tubing 1220/2018 12/20/2018 1.00 DEMOB WHDBOP CIRC P Pop off, install jet nozzle, stab back 0.0 0.0 01:12 02:12 on, Jet stack. 1220/2018 12202018 1.00 DEMOB WHDBOP CTOP P Pop off, install night cap flush lines, 0.0 0.0 02:12 03:12 blow down. 12/20/2018 12/20/2018 1.00 DEMOB WHDBOP CTOP P Pop off, vac stack, Bore 0 scope BOP 0.0 0.0 03:12 04:12 1 1 stack. 12/20/2018 12/20/2018 4.80 DEMOB WHDBOP RURD P Work rig down checklist, ND BOP 0.0 0.0 04:12 09:00 **Rig Released: 12/20/18 @ 09:00 hrs 1/19/2019 1/19/2019 3.00 MIRU MOVE RURD P Continu to work RD checklist. 0.0 0.0 00:00 03:00 1/19/2019 1/19/2019 1.00 MIRU MOVE RURD P Peak truck( trackor/ trailer for shops) 0.0 0.0 03:00 04:00 broke down in middle of acces pad road just off pad. Crew towing truck to pad so sows can access the rig. PJSM 1/19/2019 1/19/2019 2.00 MIRU MOVE RURD Pull pits & sub off well, pull flow -block, 0.0 0.0 04:00 06:00 gate valve, & adapter flange from tree, clear pad, perform environmental walk -around 1/19/2019 1/19/2019 2.50 MIRU MOVE RURD P Jeep up, load shop & pull shop mats 0.0 0.0 06:00 08:30 Page 8122 Report Printed: 211412019 Operations Summary (with Timelog Depths) 1B-16 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Suit Time End Time Dur (hr) Phase Op Code ACMY Cada Tine P -T -X Operation sen Depth (RKB) End DepN(ftKB) 1/19/2019 1/19/2019 4.50 MIRU MOVE MOB P Move from 3H pad to 1 B pad 0.0 0.0 08:30 13:00 1/19/2019 1/19/2019 6.00 MIRU WHDBOP RURD P "' Rig Accept 20:00 0.0 0.0 13:00 19:00 adjust scaffold, and stack riser. Capture RKBs. Grease valves, complet RU check list, flood up 1/19/2019 1/19/2019 2.70 MIRU MOVE MOB P Arrive at 1B -Pad, de jeep, lay 0.0 0.0 19:00 21:42 herculite, spot sub & pits, lay mats Note: 38 minutes to place mats for sub & pits 1/19/2019 1120/2019 2.30 MIRU WHDBOP TURD P Begin RU checklist, get COMMS on- 0.0 0.0 21:42 00:00 line, lower stairs & landings, MU PUTZ, bring on steam, began building scaffolding around tree, unlock reel & injector. Shop and 1/2 way house spotted at entrance to the pad. Make up managed pressure line, stab BOP stack. Spot tiger tank, ri in same. 1/20/2019 1/20/2019 4.20 MIRU WHDBOP BOPE P ""BOP test start 0:00 0.0 0.0 00:00 04:12 Shell test, 250 low, 3500 psi high good test. AOGCC witness waived by Austin McLeod R1 leaking, replace R1 Got test 5 Test against R1, with upper swab shut, open a the night cap, fluid apears to be going through the master, dump SSV, same, call valve crew. Contiune to trouble shoot, close lower blinds, held, not going through master, swab2 is leaking, fluid a the nigh cap. 1120/2019 1/20/2019 2.80 MIRU WHDBOP BOPE P Valve crew sevice swab 2 Nabors 0.0 0.0 04:12 07:00 crew regreased stack valves, continue w/ BOP test 1/20/2019 1/20/2019 1.60 MIRU WHDBOP BOPE T Difficulty w/ high on test 8, trouble- 0.0 0.0 07:00 08:48 shoot, change out test pump bleeder valve, re-tesel, continue trouble- shooting, eliminate choke maniford, track to Romeo2, grease R2, test, good 1/20/2019 1/20/2019 0.90 MIRU WHDBOP BOPE T Continue w/ BOP test, difficulty 0.0 0.0 08:48 09:42 holding low on test 9, re -grease Romeo 3, test, pass 1/20/2019 1/20/2019 2.30 MIRU WHDBOP BOPE P Continue w/ BOP test, install test 0.0 0.0 09:42 12:00 joint, drew down test, LD test jnt, test complete 1/20/2019 1/20/2019 1.00 MIRU WHDBOP CIRC P Slide in cart, stab on, line up to 0.0 0.0 12:00 13:00 seawater, pump slack forward (1.5X coil volume @ 2 bpm) 1/20/2019 1/20/2019 1.00 MIRU WHDBOP PRTS P Reverse circulate, test inner reel 0.0 0.0 13:00 14:00 valve. PT figer-tank line to 2500 psi & blow down 1120/2019 1/20/2019 0.80 MIRU WHDBOP PRTS P Pop off injector, break off no&e, 0.0 0.0 14:00 14:46 install pressure plate, PT CTC to 4000 psi, install UOC checks, PT PDL's 1/20/2019 1/20/2019 1.70 SLOT WELLPR OTHR P Valve crew opens grease locked 0.0 0.0 14:48 16:30 master valve (quite difficult to open), pressure up above SSV (588 psi), open SSV, no change in pressure 1/20/2019 1/20/2019 1.40 PROD1 WHPST PULD P PD BHA #4 Window Milling Assembly 0.0 74.0 16:30 17:54 (0.6° AKO motor, 2.79" string reamer, & 2.80" DSM) Page 9122 Report Printed: 211412019 . Operations Summary (with Timelog Depths) 1B-16 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log De Sten De Start Thne End Tete Dur (W) Phase Op Code Activity Code Tim P -7-X operation (rt End Depth (flKB) 1/20/2019 1/20/2019 3.30 PRODt WHPST PULD T Test MWD - Short! 0.0 74.0 17:54 21:12 Unstab, break off, test meg 0. Cut lead off & troubleshoot. 9.1Mega ohm from office to whip, 8.7 Mega Ohm from whip to office. Test surface lines from office to coil - good. Call out electrician, found some water in collector, pulled anchor, cut wire back same issue, cut back coil on whip end -5' same issue. 1/20/2019 1120/2019 1.80 PROD1 WHPST PULD T Organize new string (# 52795) to be 0.0 74.0 21:12 23:00 loaded and staged @ peak yard for morning move. SLB N2 crews houed out will mobilize from deadhorse to rig @ 04:00 Install anchor and rehead CTC, pull test 35 k lbs, good. PT CTC and inner reel iron to 2,500 psi - good. Skid cad back 1/20/2019 1/21/2019 1.00 PROD1 WHPST PULD T Grab lunch, PUD BHA #4, LD tools. 0.0 74.0 23:00 00:00 1/21/2019 1/21/2019 1.50 PROD1 WHPST PULD T Continue to PUD & LD BHA #4. 0.0 0.0 00:00 01:30 Struggle with frozen tugger line. 1121/2019 1/21/2019 1.50 PROD1 WHPST CTOP T Skid cart, torque up nozzle, stab 0.0 0.0 01:30 03:00 injector, RIH, POOH to change coil position on reel in preparation to unstab. S/I master with 1000 psi trapped below. 1/21/2019 1/21/2019 4.00 PROD1 WHPST CTOP T Prep for reel blow down and unstabing 0.0 0.0 03:00 07:00 1 1 coil while waiting on N2. 1/21/2019 1/21/2019 2.20 PROD1 WHPST CTOP T SLB arrives at rig, PJSM, PT customer 0.0 0.0 07:00 09:12 line to 3500 psi, lock -out reel & MU pressure bulk -head, pump 15,000 SCF N2 (100° F), bleed down coil 1/21/2019 1/21/2019 2.30 PROD1 WHPST CTOP T Unlock reel, pop off, disassemble 0.0 0.0 09:12 11:30 inner -reel iron, install grapple 1/21/2019 1/21/2019 2.00 PROD? WHPST CTOP T PJSM, Pull test grapple/CTC to 900 0.0 0.0 11:30 13:30 psi, check grapple connection, unstab coil & secure 1/21/2019 1/21/2019 1.00 PROD1 WHPST CTOP T PJSM, lower whip end of pipe w/ 0.0 0.0 13:30 14:30 tugger from goose -neck to rig floor, prep to cut coil at reel end 1/21/2019 1/21/2019 1.70 PROD? WHPST CTOP T Cut pipe on rig floor, prep reel for 0.0 0.0 14:30 16:12 removal, remove saddle clamps, reel in slings 1/21/2019 1/21/2019 1.30 PRODt WHPST CTOP T Reel arrives on pad, PJSM, pick reel 0.0 0.0 16:12 17:30 from rig, pick & set new reel (# 52795) 1/21/2019 1/21/2019 1.00 PROD1 WHPST CTOP T Safety Stand -down meeting w/all 0.0 0.0 17:30 18:30 personnel on rig, followed by pre tour for night crew 1/21/2019 1/21/2019 2.50 PROD1 WHPST CTOP T Complete cutting coil & clear pipe from 0.0 0.0 18:30 21:00 rig floor, clear snow from new reel & heat w/ steam, connect TT soft line to rig, begin changing out brass 1/21/2019 1/21/2019 1.50 PROD? WHPST CTOP T Reel set down in saddle, begin MU 0.0 0.0 21:00 22:30 saddle clamps, re -assemble injector, test wire in reel - Good. 1/21/2019 1/22/2019 1.50 PRODt WHPST CTOP T String grapple line, MU grapple, prep 0.0 -Do 22:30 00:00 to stab pipe 1/22/2019 1/22/2019 2.80 PROD1 WHPST CTOP T PJSM, Pull test grapple to 900 psi - 27 0.0 0.0 00:00 02:48 k lbs - good. Pull pipe past horses head, lock out reel, damp coil in head, unlock reel, stab pipe into gripper blocks. Page 10122 Report Printed: 2/1412019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Tima End Time Da(hd Phase Op Code Activity Code Time P -T -x Opetallen (rt (Wit) Entl Depth ft(S) 1/22/2019 1/22/2019 3.20 PROM WHPST CTOP T Skid cart forward, cut pipe install CTC, 0.0 0.0 02:48 06:00 install inner reel iron. 1/22/2019 1/22/2019 4.00 PRODi WHPST CTOP T complete inner rell iron, install 0.0 0.0 06:00 10:00 pressure bulkhead 1/22/2019 1/22/2019 0.40 PROD1 WHPST CTOP T Electrical test 68.8 Ohms > 2k M 0.0 0.0 10:00 10:24 Ohms, polarity good, Unlock reel LRS on location, PJSM, RU, PT 1/22/2019 1/22/2019 1.10 FROM WHPST CTOP T Pull test to 35 k lbs, MU upper Quick - 0.0 0.0 10:24 11:30 no flaots, Test UQC, 66.2 ohms >2 K M Ohms, make up nozzle, skid cart and stab on 1/2212019 1/22/2019 2.00 PROM WHPST CTOP T Line up to LRS, Pump 5 We neat 0.0 0.0 11:30 13:30 MetOH. Check pack offs, Line up to seawater, fluid pack the reel. Find leak in 90 ° , inner reel iron, S/D and lock out rig. Hammer up iron, unlock reel, Circ MethOH to the tiger tank. 1/22/2019 1/22/2019 2.50 PROD1 WHPST CTOP T Leak manifest its self again, locked 0.0 0.0 13:30 16:00 out reel, hammered up double wing under HP bulkhead. Pumped slack forward @ 2.2 bpm & 4256 psi. Drip healed as fluid warmed up. Pressure test & chat inner reel valve to 4400 psi - god. PT CTC to 4200 psi good. Test upper quick, install checks, 1/22/2019 1/22/2019 1.30 FROM WHPST PULD T PD BHA#5, miling asembly PT tiger 0.0 85.0 16:00 17:18 tank line. test tool - good 1/22/2019 1/22/2019 0.20 FROM WHPST PULD P Continue to PD BHA#5 0.0 85.0 17:18 17:30 1/22/2019 1/22/2019 1.35 FROM WHPST TRIP P RIH, with window milling BHA #5 85.0 6,625.0 17:30 18:51 1/22/2019 1/22/2019 0.60 PROM WHPST DLOG P Logging K1 marker, missed it, PBUH 6,625.0 6,684.3 18:51 19:27 to start logging higher, start logging 6,625', correction of plus 25.5'. PUW 34 k 1/22/2019 1/22/2019 0.25 FROM WHPST TRIP P Continue RIH, flushing well) with SW 6,684.3 6,792.0 19:27 19:42 1/22/2019 1/22/2019 1.00 PRODt WHPST CIRC P Set down lO k Top of pert section, 6,792.0 6,699.0 19:42 20:42 PUW 41 k, continue circulating SW flush from well, swap to milling fluid 1/22/2019 1/22/2019 0.75 PROM WHPST TRIP P Inspect and torque up Hub Bolts, suck 6,699.0 6,699.0 20:42 21:27 out tiger tank 1/22/2019 1/22/2019 2.00 FROM WHPST TRIP P Continue IH, mill past pert intervals, 6,699.0 6,750.0 21:27 23:27 6,790', 6,810', 6,810', and 6,904' with HS TF. PUWs 36-38 k, PUH to above Initial set down to 6,750', RBIH 1/22/2019 1/22/2019 0.25 FROM WHPST TRIP P Dry tag TOWS @ 7,029', PUH obtain 6,750.0 7,029.0 23:27 23:42 pumping parameters 1/22/2019 1/23/2019 0.31 PROD1 WHPST WPST P OB milling window @ 7,029', 1.9 bpm 7,029.0 7,029.3 23:42 00:00 at 4,430 psi, Diff=460 psi, WHP=592, BHP= -0,016, IA=618, OA=2 1/23/2019 1/23/2019 4.50 PROD1 WHPST WPST P OB milling window exit, 1.87 bpm at 7,029.3 7,033.2 00:00 04:30 4,423 psi, Diff -450 psi, WHP=610, BHP=4,033, IA=630, OA=1 1/23/2019 1/23/2019 4.00 PROD1 WHPST WPST P OB milling window exit, 1.87 bpm at 7,033.2 7,037.2 04:30 08:30 4,423 psi, Diff --450 psi, WHP=610, BHP=4,033, IA=630, OA=1 1/23/2019 1/23/2019 2.20 PROD1 WHPST WPST P Drillig ahead, CT Wt 17 k lbs, Ct 4440 7,037.2 7,051.0 08:30 10:42 psi @ 1.88 bpm in 1.88 bpm out, WOB 1.64 6.5 Mr. Page 11122 Report Printed: 2/14/2079 I Operations Summary (with Timelog Depths) 1B-16 li p Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Tim I End Time Dur(hd PhaseOp Code Activity Code Time P -T -X Operation SI(11m)� End Depth MKB) 1/23/2019 1/2312019 1.60 PRODi WHPST REAM P TD rat hole @ 7051' PU 38 klbs, 7,051.0 7,051.0 10:42 12:18 perform reaming passes, HS, 30 L 30 R and LS. Dry drift clean. Tag bottom, pump 5 x 5 TD sweep, 1/23/2019 1/23/2019 0.50 PROD1 WHPST CIRC P PUH slowly waiting for sweeps to exit. 7,051.0 6,977.0 12:18 1248 1/23/2019 1/23/2019 1.60 PROD1 WHPST TRIP P Open EDC, POOH 6,977.0 79.0 12:48 14:24 1/23/2019 1/23/2019 1.00 PROD1 WHPST PULD P PUD BHA#5 bot mil and string remer 79.0 0.0 14:24 15:24 came out 2.79" NG 1/23/2019 1/23/2019 1.40 PROD1 DRILL PULD P PD BHA #6 , PT tiger tank line, re- 0.0 72.0 15:24 16:48 torque the upper Quick, Check pack offs - good 1/23/2019 1/23/2019 1.40 PROD1 DRILL TRIP P RIH 72.0 6,635.0 16:48 18:12 1/23/2019 1/23/2019 0.20 PROD1 DRILL CLOG P Logged the Kt marker correction of 6,635.0 6,639.0 18:12 1824 plus 6.0', close EDC, PUW 34 k 1/23/2019 1/23/2019 0.20 PROD1 DRILL TRIP P RIH 6,639.0 7,051.0 18:24 18:36 1/23/2019 1/23/2019 0.25 PRODt DRILL DRLG P OBD, 1.87 bpm at 4,274 psi, Dift=606, 7,051.0 7,065.0 18:36 18:51 WHP=570, BHP=4,114, IA=810, OA=2 1/23/2019 1/23/2019 0.15 PROW DRILL DRLG P Stall, PUW 36 k, pumping 1.86 bpm at 7,065.0 7,078.0 18:51 19:00 4,300 psi, Diff=606, WHP=570, BHP=4,114, IA=810, OA=2 1/23/2019 1/23/2019 1.00 PROD1 DRILL DRLG P Stall, PUW 35 k, pumping 1.88 bpm at 7,078.0 7,135.0 19:00 20:00 4,365 psi, Diff -693, WHP=601, BHP=4,142, IA=814, OA=2 - 1/23/2019 1/23/2019 2.30 PROD1 DRILL DRLG P Stacking weight, PUH, PUW 45 k, 7,135.0 7,363.0 20:00 22:18 1.88 bpm at 4,432 psi, Ditt=684, WHP=601, BHP=4,142, IA=814, OA=2 1/23/2019 1/23/2019 0.20 PROD1 DRILL WPRT P 1 00'wiper up hole, PUW 42 k 7,363.0 7,363.0 22:18 22:30 1/23/2019 1/24/2019 1.50 PRODi DRILL DRLG P Set down 7,354'work to bottom, drill 7,363.0 7,439.0 22:30 00:00 ahead 1.82 bpm at 4,296 psi, Diff --687, WHP=601, BHP=4,142, IA=814, OA=2 1/24/2019 1/24/2019 0.25 PROD1 DRILL DRLG P OBD, 1.82 bpm at 4,296 psi, Diff -687, 7,439.0 7,480.0 00:00 00:15 WHP=601, BHP=4,142, IA=814, OA=2 1/24/2019 1/24/2019 0.50 PROD1 DRILL WPRT P TO Build section, (avg digs 38.9°), 7,480.0 7,025.0 00:15 00:45 PUW 38 k, chase sweep up hole, RBIH to confirm hole is clean. Pull up hole to window. 1/24/2019 1/24/2019 0.25 PROD1 DRILL WPRT P Perform jog back in hole to above WS 7,025.0 7,004.0 00:45 01:00 w/sweep, open EDC 1/24/2019 1/242019 1.35 PRODt DRILL TRIP P POOH to surface chasing 10x10 7,004.0 72.2 01:00 02:21 sweep 1/24/2019 1/24/2019 1.20 PROD1 DRILL PULD P At surface, space out, PUD build 72.2 0.0 02:21 03:33 assembly 124/2019 1/242019 1.20 PROD1 DRILL PULD P PD lateral drilling assembly 0.0 72.0 03:33 0445 1/24/2019 1/24/2019 1.50 PROD1 DRILL TRIP P RIH, close EDC, Shallow test agitator, 72.0 6,640.0 04:45 06:15 1156 Delta p @ 1.88 bpm. Continue to RIH 1/24/2019 1/24/2019 0.10 PROD1 DRILL DLOG P Tie int the K1 for a+4' correction 6,640.0 6,674.0 06:15 06:21 1/24/2019 1/24/2019 0.10 PROD1 DRILL TRIP P PU Wt 36 k Ibs, continue to RIH 6,674.0 7,050.0 06:21 06:27 1/24/2019 1/24/2019 0.20 PROD1 DRILL TRIP P Log the RA tag 7033.3" 7,050.0 7,080.0 06:27 06:39 Page 12122Report Printed: 2/14/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tma EM Tme Dur(IV) Phase OP Code Activity Code Time P-T-% Operellon Start DepN (fi%a) End DepN (M(B) 1/24/2019 1/24/2019 0.20 PRODt DRILL TRIP P Continue to RIH 7,080.0 7,480.0 06:39 0651 1/24/2019 1/24/2019 2.60 PROM DRILL DRLG P On bottom drilling, New mud at the bit 7,480.0 7,830.0 06:51 0939 7480'. Once new mud all the wy aroud picked up to reaquire numbers, PU 36 k Ibs. RBIH CT 4765 psi at 1.90 bm in, 1.90 bpm out, Delta P 1011 psi, Annular 4125 psi, WH 500 psi, IA 409 psi, OA psi. CT Wt 16 k lbs, WOB 1-2 k lbs, ROP 100-200 O/ hr, losses started at 7536', healed quickly to loosing 0.1 bpm. 7829' PU 35 k lbs ROP 125 R/hr 1/24/2019 1/24/2019 0.30 PROD1 DRILL WPRT P PU 40 K lbs, short wiper - 400'to end 7,830.0 7,830.0 09:39 09:57 of build, RBIH Swap from pump #2 to Pump #1 - packing leak 1/24/2019 1124/2019 3.80 PRODt DRILL DRLG P Ct 4803 psi @ 1.88 bpm in and 1.80 7,830.0 8,311.0 09:57 13:45 bpm out, delta P 1007 psi, BHP 4164 11.8 EMW, WH 588 psi, 11.9 CT Wt, 2+ k bs WOB. 8057' PU 35 k lbs 8198' PU 38 k lbs ROP = 126 ft/hr 1/24/2019 1/24/2019 0.30 PROD1 DRILL WPRT P PU 38 k lbs, short wiper - 300'to 8,311.0 8,311.0 13:45 14:03 8032'. RBIH 1/24/2019 1124/2019 1.60 PRODt DRILL DRLG P Ct 4877 psi @ 1.89 bpm in and 1.73 8,311.0 8,527.0 14:03 15:39 bpm out, delta P 1004 psi, BHP 4185 psi 11.8 EMW, WH 540 psi, 9.7 CT Wt, 1.8 k bs WOB. Start snubbing -8450' 8481' Pu 37 k lbs -17/2-4/2019 ROP = 135 ft/hr 119 0.50 PROD? DRILL WPRT P PU 38 k lbs, Long wiper for tie in 8,527.0 7,649.0 15:395:39 16:096:09 1124/2019 1/24/2019 0.10 PROD1 DRILL DLOG P Tie into the RA tag for +1' correction 7,649.0 7,086.0 16:09 16:15 1/24/2019 1/24/2019 0.20 PROD1 DRILL WPRT P RBIH from wiper trip 7,086.0 8,527.0 16:15 1627 *** Note, had to reduce rate to get past 8470' 1/24/2019 1/24/2019 1.55 PRODt DRILL DRLG PCt 4893 psi @ 1.91 bpm in and 1.81 8,527.0 8,612.0 16:27 18:00 bpm out, delta P 1037 psi, BHP 4217 psi 11.8 EMW, WH 573 psi, 1.7 CT Wt, 1.9 k bs WOB. 1/24/2019 1/24/2019 2.00 PROM DRILL DRLG P OBD, 1.82 bpm at 4,296 psi, Diff--687, 8,612.0 8,768.0 18:00 20:00 WHP=601, BHP=4,142, IA=814, OA=2 1/24/2019 1/24/2019 0.50 PROD1 DRILL WPRT P Short wiper up hole, PUW 42 k, hard 8,768.0 7,904.0 20:00 20:30 time working back to bottom 8,470', continue wiper up hole to 7,904' 1/24/2019 1/24/2019 0.70 PRODt DRILL WPRT P 800', Wiper back in hole, lowering 7,904.0 8,768.0 20:30 21:12 pump rate to 1.3 bpm 1/24/2019 1/25/2019 2.80 PROM DRILL DRLG P BOBD, 1.9 bpm at 5,050 psi, 8,768.0 8,904.0 21:12 00:00 Dif--1,143 psi, WHP=595, IA=754, OA=8 1/2512019 1/25/2019 2.00 PROD1 DRILL DRLG P OBD, 1.9 bpm at 5,202 psi, Diff=1,147 8,904.0 9,015.0 00:00 02:00 psi, WHP=572, BHP=4,249, IA=887, OA=12 Page 13122 Report Printed: 2114/2019 Summary (with Timelog Depths) 1B-16 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SwItTime End Time Dur r (n) Phase Op Code Addy Code Time P -T -X Opereuon Start Depm (MKB) End Depth (ftKB) 1!25/2019 1/25/2019 1.00 PROD1 DRILL DRLG P OBD, 1.91 bpm at 5, 142 psi, 9,015.0 9,055.0 02:00 03:00 Diff -1,030 psi, WHP=553, BHP=4,249, IA=917, OA=13, Zero Coil Weight, 1.5 k=DHWOB, ROP 20- 74 fph 1/25/2019 1/25/2019 0.20 PROD1 DRILL DRLG P OBD, 1.91 bpm at 5,142 psi, 9,055.0 9,058.0 03:00 03:12 Diff -1.030 psi, WHP=553, BHP=4,249, IA=917, OA=13, Minus 5.0 k=CTSW, 1.3 k=DHWOB, ROP=30 fish 1/25/2019 1/25/2019 0.30 PROD1 DRILL WPRT P Wiper up hole, PUW 38 k, pulled 9,058.0 8,059.0 03:12 03:30 heavy from 8,436-8,411', work pipe up hole, PUW's 40-62 k 1/25/2019 1/25/2019 1.35 PROD1 DRILL WPRT P Wiper back in hole, RIW 8-11 k, set 8,059.0 8,400.0 03:30 04:51 down 8,459' PUW 49 k, PUH to 8,400', continue IH, working pipe through light spot 8,411'-8,721', pull back up hole to 8,400'. 1/25/2019 1/2512019 0.60 PROD1 DRILL WPRT P Wiper back in hole, set down 8,453', 8,400.0 9,052.0 04:51 05:27 1 work pipe down hole, 1/25/2019 1125/2019 5.00 PROD1 DRILL DRLG P CT 5082 psi, Q 1.9 bpm in, 1.7 bpm 9,052.0 9,238.0 0527 1027 out, delta P 1040 psi, BGP 4251 psi, 567 psi WH, Ct Wt -5 k lbs, 1.1 k WOB. Struggle with weight transfer and ankerite, bottoms up from 9090 - 40% ankerite. Build pill out of active mud with 2/2% 776/1 -ow Torque. Able to put 3.7 k WOB. Break out, drill ahead tll next ankerite lens, TD called eady by town. 1/2512019 1/25/2019 3.10 PROD1 DRILL WPRT P Pump TD sweeps, PU Wt 44 k lbs, 9,238.0 72.0 10:27 13:33 followed by sweeps staged to exit before the trouble spot at 8,430'. Drive by RA tag, +11'. Jog 5", continue out of hole on wiper trip. 1/25/2019 1/25/2019 1.70 PROD1 DRILL TRIP P Tag up, reset counters, RBIH. 72.0 6,655.0 13:33 15:15 14:24 - 4452', slowed running speed to- 27 ft/min possible bonitron issues. Continued in hole. 125/2019 1/25/2019 0.20 PROD1 DRILL DLOG P Tie into the Kt fora +11' correction. 6,655.0 6,994.0 15:15 15:27 1/25/2019 1/25/2019 0.20 PROD1 DRILL DLOG P Park at 6999' MD/ 6516' TVD Trap 6,994.0 6,999.8 15:27 15:39 11.8 EMW, 4015 psi and observe pressure fall to 3782 psi in 4 minutes, back on the pump. BHP less than 11.16 ppg EMW PU Wt 40 k lbs 1/25/2019 1/25/2019 3.00 PROD1 DRILL TRIP P RIH, window clean, confirmed TD 6,999.8 9,243.0 15:39 16:39 9,243', completed building Liner Running pill 1125/2019 1/25/2019 1.87 PROD1 DRILL TRIP P POOH, laying in beaded 11.8 ppg 9,243.0 78.2 18:39 20:31 LRP, painting EDP flags at 7,160' (yellow), and 4,800' (white) 1/2512019 1/25/2019 0.50 PRODt DRILL PULD P At surface, check well for flow, PJSM 78.2 78.2 20:31 21:01 125/2019 1/2512019 0.75 PROD1 DRILL PULD P LD drilling BHA on a dead well. 78.2 0.0 21:01 21:46 1/2512019 1/25/2019 0.30 COMPZI CASING PUTB P RU RF for liner ops, Crew Change, 0.0 0.0 21:46 22:04 PJSM 1/25/2019 1126/2019 1.93 COMPZI CASING PUTB P PUALateral 2-3/8" slotted liner 0.0 1,188.8 22:04 00:00 completion 40 joints and 7.47' pup joint Page 14122 Report Printed: 2/14/2019 Operations Summary (with Timelog Depths) 113-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log swarm Ertl Time our (hr)Phew op code Activity Coda Time P -T -X �r0on De et( (ft Depth Fwd Depth (fixe) 1/26/2019 1/26/2019 0.75 COMPZI CASING PUTB P Continue PUAslotted 2-3/8" liner 1,188.8 2,015.7 00:00 00:45 completion(28jts) 1/26/2019 1/26/2019 0.50 COMPZ1 CASING PUTB P RD, liner equipment, PJSM 2,015.7 2,015.7 00:45 01:15 1/26/2019 1/26/2019 0.75 COMPZ1 CASING PULD P PU/MU CoilTrak tools, roll cart 2,015.7 2,077.1 01:15 0200 forward, MU tools, perform surface test (good -test) 019 019 1.00 COMPZ1 CASING RUNL P RIH, w/A liner assembly 2,077.1 6,878.7 02:00 02:00 03:00 03:00 1/26/2019 1/26/2019 0.15 COMPZ1 CASING RUNL P Correct to the EOP flag correct minus 6,878.7 6,877.1 03:00 03:09 1.6', PUW 40 k CTSW, minus 5.Ok DHWOB 1/26/2019 1/26/2019 1.00 COMPZI CASING RUNL P Continue IH, Work pipe towards 6,877.1 8,599.0 03:09 04:09 bottom, set down 8,599' PUW 55k, 8,620' PUW 54k, 8,939' PUW 50k, 9,053' PUW 55k, 9,132' PUW 55k, continued IH, setting down on bottom 9,243', bring pump up to 1.5 bpm @ 4,366 psi, 1,265 psi diff, PUW 38k, remove liner length from counters 1/26/2019 1/26/2019 1.40 COMPZI CASING TRIP P POOH 8,599.0 72.0 04:09 05:33 1/26/2019 1/2612019 1.40 COMPZI CASING TRIP P LD BH # 8 , A lateral completion 72.0 0.0 05:33 06:57 running BHA over a dead well. 1/26/2019 1/26/2019 0.50 PROD2 STK BOPE P Performe BOPE Function test - good. 0.0 0.0 06:57 07:27 - 1/26/2019 1/26/2019 0.50 PROD2 STK PULD P Pick up BHA#9, AL1 KO / tum drilling 0.0 72.0 07:27 07:57 assembly, install checks, check pack offs- good. 1/26/2019 1/26/2019 1.00 PROD2 STK PULD T Attempt to open EDC, error message, 0.0 72.0 07:57 08:57 Pop off, swap top coil track, stab injector, bump up. 1/26/2019 1/26/2019 1.20 PROD2 STK PULD P RIH 72.0 6,650.0 08:57 10:09 1/26/2019 1/26/2019 0.20 PROD2 STK DLOG P Tie in for a +4' correction. 6,650.0 6,678.0 10:09 10:21 1/26/2019 1/26/2019 1.20 PROD2 STK DISP P Continue to displace tubing an well to 6,678.0 6,993.0 10:21 11:33 drilling fluid. PU Wt 34 klbs, Close EDC. 1/26/2019 1126/2019 0.10 PROD2 STK TRIP P Continue in hole, window clean, dry 6,993.0 7,205.5 11:33 11:39 tag TOB @ 7,205' 1/26/2019 1/26/2019 2.40 PROD2 STK KOST P PU Wt 37 k lbs, CT 4600 psi @ 1.88 in 7,205.5 7,208.0 11:39 14:03 XX bpm out, delta P 580 psi, BHP 4130 psi, 11.8 ppg EMW, WH 520 psi, IA 483 psi, OA 7 psi. CT RIH Wt 20 k lbs, WOB and motor work 7205.5' start timed side track from liner top billet. V@ 1 ft/hr, V@ 2 ft/hr - Stall @ 7207', PU 39 k lbs. RESET, Delta P 472 psi, RBIH and restart 7206.8' V@3 fl/hr 1/26/2019 1/26/2019 1.60 PROD2 DRILL DRLG P Drilling ahead. 7,208.0 7,460.0 14:03 15:39 CT 4648 psi, 1.85 bpm in 1.83 bpm, annular 4137 psi, Ct Wt 17 k lbs, WOB 1.75 k lbs, drill to 7305' PU 40 klbs, RBIH, dry drift billet - clean. ROP 158 ft/hr, 1/26/2019 1/26/2019 1.10 PROD2 DRILL TRIP P TD turn, PU Wt 40 k lbs, POOH 7,460.0 72.0 15:39 16:45 1/26/2019 1/26/2019 1.92 PROM DRILL PULD P PUD BHA# 9. 72.0 0.0 16:45 18:40 1 Page 15122 ReportPrinted: 2114/2019 Operations Summary (with Timelog Depths) 113-16 .. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log I start Depth start Time End Thee Ouf (hr) Phase Op Code Activity Code Time PJA Operation (ftKB) End Depth (aKB) 1/26/2019 1126/2019 0.17 PROD2 DRILL PULD P Reconfigure BHA 0.0 0.0 18:40 18:50 1/26/2019 1/26/2019 1.10 PROD2 DRILL PULD P PD Lateral Drilling Assembly BHA #10 0.0 78.3 18:50 19:56 1126/2019 1/26/2019 1.20 PROD2 DRILL TRIP P Tag up re -set counter depths, inspect 78.3 6,678.6 19:56 21:08 pac-ofrs, RIH, surface test agitator (good -test) 1/26/2019 1/26/2019 0.20 PROD2 DRILL DLOG P Log the K1 marker correction of plus 6,678.6 6,680.6 21:08 21:20 1 2.0' 1/26/2019 1/26/2019 0.60 PROD2 DRILL TRIP P Continue IH 6,680.6 7,460.0 21:20 21:56 1/26/2019 1/26/2019 0.20 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 4,681 psi, 7,460.0 7,487.0 21:56 22:08 Diff -800 psi, WHP=541, BHP=4,527, IA=563, OA=15 — Note: New mud system #2 at the bit 7,465' 1/26/2019 1/26/2019 0.20 PROD2 DRILL WPRT P Plug off choke, PUH 35 k, line up to 7,487.0 7,487.0 22:08 22:20 1 choke "S" 1126/2019 1/26/2019 0.20 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 4,292 psi, 7,487.0 7,527.0 22:20 22:32 Diff -4,175 psi, WHP=683, BHP=4,193, IA=538, OA=15 1/26/2019 1/2612019 0.15 PROD2 DRILL WPRT P PUH, PUW 41 k, Mud system #2 at 7,527.0 7,527.0 22:32 22:41 surface, obtain new pump parameters.- arameters:1/26/2019 1/2612019 1/27/2019 1.32 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 4,325 psi, 7,527.0 7,822.0 22:41 00:00 Diff -882, WHP=721, BHP=4,175, IA=533, OA=15 1127/2019 1/27/2019 0.75 PROD2 DRILL DRLG P OBD, 1.9 bpm at4,341 psi, Diff -900, 7,822.0 7,860.0 00:00 00:45 WHP=730, BHP=4,165. IA=508, OA=18 1/27/2019 112712019 0.20 PROD2 DRILL WPRT P 820', wiper up to the bottom of the 7,860.0 7,020.0 00:45 00:57 1 billet, PUW 41 k 1/27/2019 1/27/2019 0.15 PROD2 DRILL WPRT P Wiper back in hole, RIW 7,020.0 7,860.0 00:57 01:06 1/27/2019 1/27/2019 0.90 PROD2 DRILL DRLG P OBD, 1.91 bpm at 4,385 psi, 7,860.0 8,003.0 01:06 02:00 Diff -4,141, WHP=732, BHP=4,144, IA=548, OA=16, DD unable to drop in section, PU and set back down 5 times to initiate drop. Continue Drilling ahead. Note: Fault Crossing @ 7,940' 1/2712019 1/27/2019 0.50 PROD2 DRILL DRLG P OBD, 1.88 bpm at 4,385 psi, Diff -864, 8,003.0 8,060.0 02:00 02:30 WHP=714, BHP=4,186, IA=548, OA=16 1/27/2019 1/27/2019 0.42 PROD2 DRILL WPRT P Geo wiper up hole, PUW 42 k 8,060.0 8,060.0 02:30 02:55 1127/2019 1/27/2019 0.65 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 4,432 psi, 8,060.0 8,176.0 02:55 03:34 Diff --900, WHP=701, BHP=4,149, IA=632, OA=16 1/27/2019 1/2712019 0.15 PROD2 DRILL WPRT P Stacking weight, PUH and restarrt, 8,176.0 8,176.0 03:34 03:43 1 1 PUW 38 k 1/27/2019 1/27/2019 0.15 PROD2 DRILL DRLG P BOBD, 1.91 bpm at 4,740 psi, 8,176.0 8,196.0 03:43 03:52 Diff -1,100 psi, WHP=707, BHP=4,176, IA=649, 0A=16 1/27/2019 1127/2019 0.15 PROD2 DRILL WPRT P Stacking weight, PUH and restart, 8,196.0 8,196.0 03:52 04:01 PUW 48k 1/27/2019 1/27/2019 0.20 PROD2 DRILL DRLG P BOBD, 1.91 bpm at 4,740 psi, 8,196.0 8,260.0 04:01 04:13 Diff -1,100 psi, WHP=707, BHP=4,176, IA=649, OA=16 1/27/2019 1/27/2019 0.30 PROD2 DRILL WPRT P Wiper to the EOB, PUW 38 k 8,260.0 7,460.0 04:13 04:31 Page 16122 Report Printed: 211412019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sit Time End Too Dur (hr) Phase Op COEe pctiviy code Tone P -T -X Operadw Slav Depot (RKB) EM DeM(MB) 127/2019 1/2712019 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 15 k 7,460.0 8,260.0 04:31 04:46 1/27/2019 1/272019 2.10 PROM DRILL DRLG P BOBD, 1.91 bpm at 4,736 psi, 8,260.0 8,425.0 04:46 06:52 Diff -1,226 psi, WHP=723, BHP=4,143, IA=679, 0A=11 127/2019 1/272019 1.00 PROD2 DRILL WPRT P PU Wt 43 k lbs, PUH on early long 8,425.0 6,546.0 06:52 07:52 wiper to the K1 for tie in. Cahsed 5x5 _ off bottom, jogged below build @ 7460' to allow second sweep out. Chase out of hole. 1/27/2019 1/272019 0.10 PROD2 DRILL DLOG P Tie into the K1 for a +3.5' correction 6,546.0 6,573.0 07:52 07:58 1/27/2019 1272019 0.70 PROD2 DRILL WPRT P RBIH, window and billet clean, WOB 6,573.0 8,406.0 07:58 08:40 spikes around 7960-800'. Was oriented low side though. 1272019 1/27/2019 0.70 PROD2 DRILL DRLG P S/D 8406, PU 43 k lbs, RBIH work 8,406.0 8,506.0 08:40 09:22 through trouble spot-150API gamma, with reduced pump rate 1.5 bpm. Drill ahead, CT 4609 psi, 1.9 bpm in, 1.9 bpm out, BHP 4167 psi, WH 700 psi, CT 4.8 k lbs, WOB 1.3 k lbs 1/27/2019 1/27/2019 0.80 PROD2 DRILL WPRT P PU Wt 45 k lbs, Pull above trouble 8,506.0 8,506,0 09:22 10:10 spot, tum around at 8380', RBIH. some WOB spikes, Running past trouble spot @ 1.5 bpm and 30 f 1min 1/27/2019 0.90 PROD2 DRILL DRLG P CT 4516 psi @ 1.87 bpm in no 1.84 8,506.0 8,540.0 10:10 11/27/2019 11:04 bpm out, dela P 866 psi, BHP 4165 psi - 11.8 ppg EMW at the window. Ct Wt 3.6 k lbs, WOB 2.1 k lbs, ROP 90 1/27/2019 1/27/2019 0.30 PROD2 DRILL DRLG P CT 4516 psi @ 1.87 bpm in and 1.83 8,540.0 8,553.0 11:04 11:22 bpm out, delta P 839 psi, BHP 4131 psi - 11.8 ppg EMW at the window. Ct Wt 2 k lbs, WOB 0.87 k lbs, ROP 110 PU Wt 46 k lbs, Pull above trouble spot, turn around at 8443', RBIH. WOB spikes, stack some coil Wt @ 8470'. Running past trouble spot @ 1.5 bpm and 30 ft/min 127/2019 1/27/2019 0.30 PROD2 DRILL WPRT P Struggle to get restarted, PU 47 k lbs, 8,553.0 7,490.0 1122 11:40 drug up to 50 k lbs, Short time on bottom until pick up required, PUH on wiper, pump 5x5 Ct Wt 40 to 36 k lbs. 1/27/2019 1/272019 0.20 PROD2 DRILL WPRT P RBIH, 2.8 k Ibs WOB spike @ 8438', 7,490.0 8,553.0 11:40 11:52 bounced through. 1272019 1/27/2019 1.90 PROD2 DRILL DRLG P CT 4540 psi @ 1.90 bpm in and 1.83 8,553.0 8,633.0 11:52 13:46 bpm out, delta P 1000 psi, BHP 4162 psi - 11.8 ppg EMW at the window. Ct Wt 2 k lbs, WOB 0.87 k lbs, ROP 110 1/27/2019 1/27/2019 0.20 PROD2 DRILL WPRT P Geo wiper after sudden drop in 8,633.0 8,633.0 13:46 13:58 gamma @ 8599'. RBIH, WOB spikes @ 8410' and 8513' 1/272019 1/27/2019 4.50 PROD2 DRILL DRLG P Ct 4479 psi @ 1.9 bpm in 1.90 bpm 8,633.0 8,886.0 13:58 18:28 out, delta P 846 psi, BHP 4195 psi, CT Wt 2.1 k lbs, WOB 1.6 k lbs. Reaquire the A4 pay @ 8780'. Pump 5x5 sweep. 1/27/2019 1/27/2019 0.40 PROD2 DRILL WPRT P Chase sweeps out of hole on 1000' 8,886.0 7,876.0 18:28 18:52 wiper #2 PU 42 k lbs @ 8570' pull into 53 k CT Wt, -6 k lbs WOB. RIH S/D 2 k WOB, PU, 4 k continue to PUH. more minor neg MOB spikes @ 8460'. Page 17122 Report Printed: 2/1 412 01 9 Operations Summary (with Timelog Depths) 1121-116 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log al) Sled Time ENTim (hr)Stan Our (hr)pth Phase Op Code Activity Code Time P -T -x Oporabon (flK End Depth (111®) 1/27/2019 1/27/2019 1.30 PROD2 DRILL WPRT P RBH, Start spiking WOB @ 8400', 7,876.0 8,811.0 18:52 20:10 8480', 8498', 8522, and multiple times at 8,550'. PU weights 46k lbs. Reduce rate to 1.2 bpm ran through. Stuggled again up to 8764'. 1/27/2019 1/27/2019 1.60 PROD2 DRILL WPRT P PU, 46, pump 10 bbl High vis, PUH, 8,811.0 8,370.0 20:10 21:46 pulling heavy and packing off, pulled above trouble zones 8400'. Small amount of gas a the shaker from pack off event. launch 5x5, consult wtown engineering.clean out to 8370' chase sweeps up hole. 1/27/2019 1/27/2019 1.25 PROD2 DRILL WPRT T PUH chasing sweeps out of the well. 8,370.0 78.2 21:46 23:01 Billet and window clean. Large unload of cuttings, flakes of silt and metal. 1/27/2019 1/28/2019 0.99 PROD2 DRILL PULD T At surface, PUD drilling BHA #10 78.2 0.0 23:01 00:00 1/28/2019 1/28/2019 0.25 PROM DRILL PULD T Continue PUD drilling BHA 0.0 0.0 00:00 00:15 1/28/2019 1/2812019 0.30 PROD2 DRILL PULD T Reconfigure BHA 0.0 0.0 00:15 00:33 1/28/2019 1/28/2019 1.00 PROD2 STK PULD T PD Open Hole Anchored Billet 0.0 72.7 00:33 01:33 1/28/2019 1/28/2019 1.50 PROD2 STK TRIP T RIH, w/Open Hole Anchored Billet 72.7 6,655.0 01:33 03:03 BHA#11, 80 fpm as per BOT rep. 1/28/2019 1128/2019 0.20 PROD2 STK DLOG T Log the K1 marker plus 3.0' 6,655.0 6,678.0 03:03 03:15 1/28/2019 1/28/2019 0.80 PROD2 STK TRIP T Continue IH 6,678.0 8,161.8 03:15 04:03 1/28/2019 1/28/2019 0.15 PROD2 STK WPST T PUW 39 k, RBIH to setting depth, 8,161.7 8,150.0 04:03 04:12 PUH to neutral weight, bring pump on line 1.3 bpm to shear 4,800 psi, set down 5.0 k, PUH, PUW 35 k 1/28/2019 1/26/2019 1.50 PROD2 STK TRIP T POOH, following MP 8,150.0 72.7 04:12 05:42 1/28/2019 1/28/2019 1.20 PROD2 STK PULD T PUD, setting tools 72.7 0.0 05:42 06:54 1/28/2019 1/28/2019 1.20 PROM STK PULD T PD, kickoff/drilling assembly, surface 0.0 78.3 06:54 08:06 test Coifrrak tools (good -test) 1/28/2019 1/28/2019 1.40 PROD2 STK TRIP T Tag up, reset counters, RIH w/Drilling 78.3 6,655.0 08:06 09:30 BHA#12 1/28/2019 1/28/2019 0.20 PROD2 STK DLOG T Log the K7 marker correction of plus 6,655.0 6,675.0 09:30 09:42 2,0' 1/28/2019 1/28/2019 0.50 PROD2 STK TRIP T Continue IH, close EDC, PUW 39 k 6,675.0 8,150.0 09:42 10:12 1/28/2019 1/28/2019 0.30 PROD2 STK TRIP T Dry drift billet@ 8,150' 8,150.0 8,150.0 10:12 10:30 1/28/2019 1/28/2019 3.80 PROD2 STK KOST T PUH, bring pump on-line 1.89 bpm at 8,150.0 8,153.0 10:30 14:18 4,717 psi, Diff=1,135 psi ,WHP=643, BHP=4,186, IA=398, OA=8, time mill off billet 3.0' 1/28/2019 1/28/2019 1.00 PROD2 DRILL DRLG T Drill ahead, 1.89 bpm at 4,717 psi, 8,153.0 8,257.0 14:18 15:18 Diff=1,050 psi ,WHP=643, BHP=4,186, IA=398, OA=8 1/28/2019 1/28/2019 0.20 PROD2 DRILL WPRT T PUH to drift window area (clean), 8,257.0 8,257.0 15:18 15:30 RBIH 1/28/2019 1/28/2019 1.80 PROD2 DRILL DRLG T Drill ahead, 1.87 bpm at 4,717 psi, 8,257.0 8,550.0 15:30 17:18 Diff --1,050 psi ,WHP=625, BHP=4,173, IA=756, OA=8 1/28/2019 1/28/2019 0.90 PROD2 DRILL WPRT T 8550', Wiper trip to 7488, PUW=42K 8,550.0 81550.0 17:18 18:12 Page 18/22 ReportPrinted: 2/14/2019 Operations Summary (with Timelog Depths) IB -16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Lo® stremma Eno note our (hr) Phase Op Cade Activity Code Tune P -T -X Operation Start Deem (0KB) End Depth (AKB) 1128!2019 1/28/2019 2.70 PROM DRILL DRLG T 8550', Drill, 1.87 BPM @ 4 990PSI FS, 8,550.0 8,840.0 18:12 20:54 BHP=4235 1/28/2019 1/2812019 0.10 PROD2 DRILL WPRT T8840'1 BHA Wiper, PUW=45K 8,840.0 8,840.0 20:54 21:00 1/28/2019 1/28/2019 0.20 PROD2 DRILL DRLG T 8840', Drill, 1.87 BPM @ 4690 PSI 8,840.0 8,886.0 21:00 21:12 FS, BHP=4225 1/28/2019 1/28/2019 0.70 PROD2 DRILL DRLG P 8886. reached TO before billet, Off T 8,886.0 8,950.0 21:12 21:54 1 time 1/28/2019 1/28/2019 0.70 PROD2 DRILL WPRT P Wiper to billet @ 8150, PUW=43K 8,950.0 8,950.0 21:54 22:36 1/28/2019 1/29/2019 1.40 PROD2 DRILL DRLG P 8950', drill, 1.88 BPM @ 4320 PSI FS, 8,950.0 9,114.0 22:36 00:00 BHP=4200, New mud at bit 9012'. Old system out @ 2288' drilled, 0.85% drill solids 1/29/2019 1/29/2019 3.50 PROM DRILL DRLG P 9114', Drill, 1.89 BPM @ 4320 PSI FS, 9,114.0 9,310.0 00:00 03:30 BHP=4180 1/29/2019 1/29/2019 0.10 PROD2 DRILL WPRT P BHA Wiper, PUW=49K 9,310.0 9,310.0 03:30 03:36 1/29/2619 1/29/2019 0.30 PROD2 DRILL DRLG P 9310', Drill, 1.85 BPM @ 4360 PSI 9,310.0 9,350.0 03:36 03:54 IFS, BHP=4150 1/29/2019 1/2912019 1.20 PROD2 DRILL WPRT P Wiper trip to window with 5 X 5 9,350.0 7,035.0 03:54 05:06 sweeps, PUW=48K 1129/2019 1/29/2019 0.20 PROD2 DRILL DLOG P Log the RA marker correction of plus 7,035.0 7,060.0 05:06 05:18 7,0' 1/29/2019 1/29/2019 1.20 PROD2 DRILL WPRT P Continue wiper back in hole, set down 7,060.0 9,350.0 05:18 06:30 9,122', PUH lowered pump rate 1.2 bpm, continued IH 1/29/2019 1/29/2019 2.20 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 4,636 psi, 9,350.0 9,650.0 06:30 08:42 Diff=964, WHP=964, BHP=4,302, IA=424, OA=5, started tossing -24 bbVhr 1/29/2019 1/2912619 0.60 PROD2 DRILL WPRT P 1000', wiper up hole, PUW 48 k 9,650.0 8,650.0 08:42 09:18 1/29/2019 1/29/2019 1.00 PROD2 T5RILL WPRT P Wiper back in hole, set down x 3 @ 8,650.0 9,650.0 09:18 10:18 9,157', and 9,249', lower pump rate to 1.2 bpm made it through 1/29/2019 1/29/2019 1.15 PROD2 DRILL DRLG P BOBO, 1.89 bpm at 4,693 psi, 9,650.0 9,694.0 10:18 11:27 Diff -938, WHP=635, BHP 4,693, IA=407, OA=5 1/29/2019 1/29/2019 3.30 PROD2 DRILL WPRT P TO called early, pump 10x10 sweep, 9,694.0 78.3 11:27 14:45 chase sweeps to surface, performing jog from 1/29/2019 1/29/2019 0.20 PROD2 DRILL TRIP P Tag up, reset counters 78.3 78.3 14:45 14:57 1/29/2019 1/29/2019 1.10 PROD2 DRILL TRIP P RIH 78.3 6,655.0 14:57 16:03 1/29/2019 1/29/2019 0.20 PROD2 DRILL DLOG P Log the Kt marker correction of plus 6,655.0 6,678.0 16:03 16:15 0.5' 1/29/2019 1129/2019 0.20 PROD2 DRILL TRIP P Continue IH, perform static pressure 6,678.0 7,010.0 16:15 16:27 surface above window area 1/29/2019 1/29/2019 0.20 PROD2 DRILL TRIP P Perform static pressure surface above 7,010.0 7,010.0 16:27 16:39 window area Sensor depth 6,423.8', Annular pressure 3,762, 11.8 ppg down to 11.1 ppg, PUW 39 k 1/29/2019 1/29/2019 0.30 PROD2 DRILL TRIP P Continue IH, set down x 3 @ 9,112', 7,010.0 7,112.0 16:39 16:57 PUH to log the K1 1/29/2019 1/29/2019 0.20 PROD2 DRILL TRIP P PUH, to log the K1 7,112.0 6,655.0 16:57 17:09 1/29/2019 1/29/2019 0.20 PROD2 DRILL DLOG P Log the K1 correction plus 0.5', 6,655.0 6,677.0 17:09 17:21 1 Page 19/22 Report Printed: 211412019 Operations Summary (with Timelog Depths) 113-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tima End Time our (hr) phase Op Code Activity Code Tame P -TA operation Start Depth (ftKB) End Depth (ftKB) 1/29/2019 1129/2019 1.10 PROD2 DRILL TRIP P POOH 6,677.0 92.0 17:21 18:27 1/29/2019 1/29/2019 1.50 PROD2 DRILL PULD P Al surface, Tag up and space out, 92.0 0.0 18:27 19:57 PUD BHA#12, Lay down tools.Bit out @ 1-1. Change motor AKO from 1 to 1.25° 1/29/2019 1/29/2019 0.90 PROD2 DRILL PULD T PD BHA#13 with D-331 mill, 1.25° 0.0 68.4 19:57 20:51 AKO motor, no USR. Make up o coiltrak and surface test 1/29/2019 1/29/2019 1.40 PROD2 DRILL TRIP T RIH BHA #13, Surface test agititator 68.4 6,650.0 20:51 22:15 1/29/2019 1/29/2019 0.10 PROD2 DRILL DLOG T Log K1 for+1 foot correction 6,650.0 6,677.0 22:15 2221 1/29/2019 1/29/2019 0.20 PROD2 DRILL TRIP T Continue in hole. Clean pass through 6,677.0 7,112.0 22:21 22:33 window. Dry tag @ 7112. PUH 1/29/2019 1/29/2019 0.10 PROD2 DRILL REAM T PUH to 7100, Bring on pumps 1.9 7,112.0 7,114.0 22:33 22:39 BPM @ 4761 PSI FS. Start working down @ 1 FPM. Start sweeps down CT.See motor work and WOB @ 7112. Start to speed up @ 7114. Stall motor 1/29/2019 1/29/2019 0.50 PROD2 DRILL REAM T PUH ater stall, restart. See torque and 7,114.0 7,180.0 22:39 23:09 vibration @ 7111. Maintain reaming @ - 1.5 FPM to 7120 then go to 5 FPM down to 7140. Recip up at 1.86 BPM up to 7098. Initial sweeps at shaker. Nothing coming across shaker. RBIH to 7180 mostly dean at higher speed 1/29/2019 1/29/2019 0.70 PROD2 DRILL REAM T PUH to 7097. Turn around clean trip 7,180.0 7,180.0 23:09 23:51 down. To 7180. Pump another seris of sweeps and recip area. Little to no material on shaker 1/29/2019 1/30/2019 0.15 PROD2 DRILL REAM T 7180, Line up to go past billet @ 7205. 7,180.0 7,194.0 23:51 00:00 Stack ou @ 7188 when we reduced rate to pass billet. PUH to 7166. 1/30/2019 1/30/2019 1.10 PROD2 DRILL TRIP T Run in hole, set down @ 8668' work 7,194.0 8,682.0 00:00 01:06 pipe down o 8682 1/30/2019 1/30/2019 0.80 PROD2 DRILL TRIP T Pump Sweeps, PUH to 8177, 8,682.0 8,177.0 01:06 01:54 PUW=45K 1/30/2019 1/30/2019 0.20 PROD2 DRILL TRIP T RBIH, 1.5 BPM set down @ 8704 8,177.0 8,735.0 01:54 02:06 work to 8735 1/30/2019 1/30/2019 0.10 PROD2 DRILL TRIP T 8735, PUH to 8590, 1.8 BPM 8,735.0 8,590.0 02:06 02:12 1130/2019 1/30/2019 0.10 PROD2 DRILL TRIP T 8590 RBIH, 1.5 BPM @ 8783 set 8,590.0 8,783.0 02:12 02:18 down. 1/30/2019 1/30/2019 0.10 PROD2 DRILL TRIP T 8783', PUH to 8570, 1.8 BPM, 8,783.0 8,570.0 02:18 02:24 PUW=46K 1/30/2019 1/30/2019 0.20 PROD2 DRILL TRIP T 8570', RIH to setdown @9088', 1 8,570.0 9,088.0 02:24 02:36 BPM, Choppy going 1/30/2019 1/30/2019 0.10 PROD2 DRILL TRIP T 9088', PUH, PUW=44K, 1.8 BPM 9,088.0 8,970.0 02:36 02:42 1/30/2019 1/30/2019 1.20 PROD2 DRILL TRIP T 8970, RBIH to 9157'recip 3 times. 8,970.0 9,157.0 02:42 03:54 Hard setdowns 1/30/2019 1130/2019 0.40 PROD2 DRILL TRIP T 9157. Get through 9157 at redused 9,157.0 9,693.0 03:54 04:18 rate 1/30/2019 1/30/2019 0.60 PROD2 DRILL TRIP T 9693, PUH slowly waiting on sweeps, 9,693.0 7,010.0 04:18 04:54 Continue up hole, Poor hole conditions @ 9290 up to 9050 with overpulls some with negaive WOB. Max pull 60K. Hard to get running back in hole. Cleared up above 9000' 1/30/2019 1/30/2019 2.75 PROD2 DRILL WPRT T Jog the 5" with multiple sweeps 7,010.0 6,650.0 04:54 0739 Page 20/22 Report Printed: 211 412 01 9 Operations Summary (with Timelog Depths) IB -16 .so Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time I End Tme Dur(ho Phase Op Code Activit' Code Tore PJAOperaVon Stad Depth (Wfl) End Depth (NCB) 1/30/2019 1/30/2019 0.30 PROM DRILL TRIP T RIH, to logging depth 6,650.0 6,655.0 07:39 07:57 1/30/2019 1/30/2019 0.20 PROD2 DRILL DLOG P Log the Kt marker correction of plus 6,655.0 6,683.0 07:57 08:09 7.5' 1/30/2019 1/30/2019 1.00 PROD2 DRILL TRIP P RIH, through window (clean), continue 6,683.0 9,071.0 08:09 09:09 RIH to 9,070' 1/30/2019 1/30/2019 0.75 PROD2 DRILL CIRC P Send 11.8 ppg completion fluid down 9,071.0 9,071.0 09:09 09:54 1 coil 1/30/2019 1/30/2019 2.00 PROD2 DRILL TRIP P POOH, laying in beaded liner running 9,071.0 68.0 09:54 11:54 pill, painting EDP flags, liner pill up into Luing @ 5,400' 1/30/2019 1/30/2019 0.50 PROD2 DRILL PULD P At surface check well for flow. 68.0 68.0 11:54 12:24 1/30/2019 1/30/2019 0.60 PROD2 DRILL PULD P LD cleanout BHA#13 68.0 0.0 12:24 13:00 1/30/2019 1/30/2019 0.50 COMPZ2 CASING PUTB P Prep RF for iner ops 0.0 0.0 13:00 13:30 1/30/2019 1/30/2019 2.65 PROD2 CASING PUTS P PU/MU slotted liner (68 jts) 0.0 1,971.2 13:30 16:09 1/30/2019 1/30/2019 0.60 PROD2 CASING PUTB P PU/MU solid liner (13 jts) 1,971.2 2,373.0 16:09 16:45 1/30/2019 1/30/2019 1.10 PROD2 CASING PULD P PU/MU CoilTrak tools. M/U to coil and 2,373.0 2,425.2 16:45 17:51 perform surface test (good -test). Check packofis. Change out checks in UQC. 1/30/2019 1/30/2019 1.00 PROD2 CASING RUNL P RIH, w/AL1 liner completion 2,425.2 6,931.0 17:51 18:51 1/30/2019 1/30/2019 0.10 PROD2 CASING DLOG P Correct to flag for -5.55', PUW=45K 6,931.0 6,925.0 18:51 18:57 1/30/2019 1/30/2019 0.80 PROD2 CASING RUNL P Continue in hole,Clean through 6,925.0 9,069.6 18:57 19:45 window. Set down @ 6792 then run to set depth 1/30/2019 1/30/2019 0.10 PROD2 CASING RUNL P At set depth. Pumps on 1.5 BPM, 9,069.6 6,674.0 19:45 19:51 PUW=34K PUH to 9055 and remove liner length left in hole. Open EDC 1/30/2019 1/30/2019 3.30 DEMOB WELLPR WAIT T Wailing on seawater, Static 6,674.0 6,674.0 19:51 23:09 BHP=3689 PSI, Sensor depth 6660', TVD 6135' 1/30/2019 1/31/2019 0.85 DEMOB WELLPR TRIP P Circulate seawaer down coil. Displace 6,674.0 6,100.0 23:09 00:00 well to seawater, start out of hole 1/31/2019 1/31/2019 1.80 DEMOB WELLPR TRIP P Continue trip out, Freeze protect well 6,100.0 41.2 00:00 01:48 with 30 BSIs diesel 1/31/2019 1/31/2019 1.30 DEMOB WELLPR PULD P Tag up and space out, PJSM, PUD 41.2 0.0 01:48 03:06 BHA# 13, Lay down tools, FSITP=620 PSI 1/31/2019 1/31/2019 1.00 DEMOB WELLPR CIRC P Stab on injector, Displace CT back to 0.0 0.0 03:06 04:06 WMud 1/31/2019 1/31/2019 0.50 DEMOB WELLPR CIRC P Drilling WMud around, start takeing 0.0 0.0 04:06 04:36 baseline pressures .5 BPM @ 830 PSI, 1 BPM @ 1280 PSI, 1.5 BPM @ 1940 PSI, 1.75 BPM @ 2320 PSI, 2 BPM @ 2780 PSI, 2.25 BPM @ 3250 PSI, 2.5 BPM @ 3710 PSI, 2.75 BPM @ 4250 PSI, 3 BPM @ 4920. Unstab to make up NS liner release tool 1131/2019 1/31/2019 0.20 DEMOB WELLPR CIRC P PJSM, M/U NS release tool and stab 0.0 0.0 04:36 04:48 back on well Page 21/22 Report Printed: 2/1412019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start-rime Eno Time our (hr)Phase Op Cotle Aolivily Cotle Time P-T-k Operation Start Depth (ftKB) End Depth(ftKB) 1/31/2019 1/31/2019 1.50 DEMOB WELLPR CIRC P Start Flow tests with tool on. .5 BPM 0.0 0.0 04:48 06:18 @ 950 PSI, 1 BPM @ 2000 PSI, L5 BPM @ 3700 PSI, Heard tool shift @ 1.73 BPM. unstab injector to verify. Tool has shifted. Test over. Lay down tool 1/31/2019 1/31/2019 6.00 DEMOB MOVE DMOB P Work on rig move check list, 0.0 0.0 06:18 12:18 disconnect tiger tank line, remove fluid from tank, call out DTH to move tiger tank, remove all fluids and clean pits. 1/31/2019 1/31/2019 3.70 DEMOB MOVE DMOB P Proactively change out lower blind 0.0 0.0 12:18 16:00 shear rams, remove 4-1/16" valves and installed blind flange onto well. 1/31/2019 1/31/2019 0.00 DEMOB MOVE DMOB P RIG RELEASE @ 1600 hrs, standby 0.0 0.0 16:00 1600 for trucks Page 22122 ReportPrinted: 2/14/2019 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1B Pad IB -16A 50-029-22457-01 Baker Hughes INTEQ Definitive Survey Report 14 February, 2019 BA ER F UGHES ConocoPhillips B 0 ConocoPhillips Defirl Survey Report Company: ConocoPhillips Alaska lnc Kupamk P.J.": Kupmuk River Unit Sde: Kupamk 18 Pad Well: 1&16 Wellbore: 11 1lm Design: 18-16A Project Kupamk River Unit, NOM Slope Alaska, United States Map System: US Slate Plane 1929 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 1S-16 Local Coardinam Reference: Wall 18-16 TVD Reference: 18-16 ®102.00usn (18-16) MD Reference: 18-16 ® f 02.00usn (18-16) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Well Position +NIS 0.00 usfl Northing: Using geodetic scale factor .I fm 0.00 usfl Easting: Position Uncertainty Longinus.. 0.00 usM1 Wellhead Elevation: Wellbore 113-10A 102.00 0.00 Magnetics Model Name Data 2/1312019 -- Sampo Dao From BGGM2018 21112019 Design 1B -16A Survey(Wallhom) Tool lame Audit Nates Mean Sea Level 1u Using Well Reference Point To On Depth: 6,023.00 Using geodetic scale factor 5.969,646.63us6 Latitude: 550,195.14usfl Longinus.. use Ground Level: Designed" Dip Angle 1'1 I'1 16.76 80.88 Versmn'. 1u Inas.: Ac mAL To On Depth: 6,023.00 Vertical a...... Depth From (TVD) .FLS 12312019 1QM019 Pan) (usM1) 102.00 0.00 Survey Program Data 2/1312019 -- --_ _ From To (usfl) U.1t) Survey(Wallhom) Tool lame 193.59 6.823.00 1&16(18-16) MWD 7 026.00 7,114.59 18-16A MWD-INC(18-16A) MWO-INC_ONLY ],145.11 9,199.05 1B -16A MWO(1 B -16A) MWD 0EUIV IaaM 0.00 Description MWD -Standard MWD-INC—ONLY FILLER MWD -Standard 70° 19'40,2Q N 149° 35' 34.510 W 0.00 usfl Field Strength (nn 57 426 Dheedon Survey Survey Stan Dote End Dead 82512000 12312019 1QM019 12312019 1QM019 2/!12019 O480MM Papal COMPASS 5000.14 BWd 650 �ER i u0cH%s Annotation TIP KOP Intaryolatad Azimuth Inhryclatel Azimuth Inkryalalad Azimuth 2H4WO19 8'4896AM Pa v 3 COMPASS 500014 SeW 650 ConocoPhillips COnOCOPhlllip5 Definitive Survey Report Company: ConocoPh0lips Alaska lnc Kupamk Local Ce rdinate Reference Mil 18-16 Project: Kuparuk River Unit TVD Reference: 1&16@102.00ustt(]B-16) she Kupaek lB Pact MD Reference: 18-16 a 102.0ouatt(1 B-16) Welt 1&16 Notth Reference: True Wellbore 111-16A Survey Calculation Method: Minimum Curvalue Deaien: 1B -16A Database: EDT 14 Alaska PmEucOon �ER i u0cH%s Annotation TIP KOP Intaryolatad Azimuth Inhryclatel Azimuth Inkryalalad Azimuth 2H4WO19 8'4896AM Pa v 3 COMPASS 500014 SeW 650 Map Map Vertical ND them Im 19 Azl 1'1 TVD TVD55 loan) +E/ -W Northing Eazlin9 DLS Section Survey Tool Name 1u6n1 lusrcl loan) lusrcl Ittl Inl (./low) Ittl 6,023.01 21.06 336.64 639634 629434 1,991.70 -1,43]8 5,811631.39 5x9138.15 024 -1.203.03 M INC ONLY (2) 7.026.00 1821 33722 6488.71 6484.71 205658 -1,071.41 5.971,696% 549'110.10 the -1.24534 MN41NC ONLY (2) 7.05426 2401 325.80 661291 051891 2,06578 -1,0]6.55 5,071]0516 549,104.93 2485 -1,250.74 M NC_ONLY (2) 7.08449 38.97 31949 6.63852 6.536,52 2,078.32 -1,086,34 5,971.717.0 549.seem 48.06 -1R56]0 MWWNC_ONLY(2) 7,114.59 49.17 315.49 6.660.13 6.55813 2,093.60 -1,10052 5,971,M90 5,49,01 35.11 -1,52.92 MWN1 ONLY(2) ],145.11 57,74 31258 6.67828 6,5]6$8 211868 -1.118.15 5.971,749.11 540,06300 29.12 .1,58.82 MYD(3) ],1]495 ]03] 30864 6.89132 6,58942 21510 -1,138118 5.9]1,76].05 54puz5a 4178 -1.27375 MND(3) ],2052] 0468 306.54 6697,05 6,59585 2146.14 -1161.85 5,9]1]04.94 549,019.07 47.]] -1,2]].68 MNO(3) 7,23S.1l 0246 300.82 66W% 8596,60 2,16266 -118865 5,9]1.8315 5189949 3235 -1 Y19.59 vent (3) 7.5500 91.84 30769 6697,47 B595A7 2,179.46 -1,21132 5,9]1,81].93 5 thi 23.06 -1,51.81 Moo (3) 7,55,05 8681 301 6.697.03 6,59583 2,196.01 -1,234,96 59]1,83832 540,94562 16.95 -1286.0.5 MWD(3) 7,32525 80.07 29421 6.699.10 6597.18 221567 -1,50.64 5,971.651.60 548.919.84 4763 4,280]8 MPo➢(3) ],354.33 85.97 286.18 iso th 6,595.16 ;22160 -1,57.84 5,07186163 548,892.58 30.75 -128184 MN➢(3) 7385113 60.45 275.04 6.6%66 6594.68 2,8939 -1,31634 5,971.86213 548.062.04 41.41 -1,81.54 MWD (3) 7,410]] A9P6 259]8 6,69212 6.595,12 2220.07 -1,34256 5.971.865.62 648,832.83 52.04 -1,255,78 MWD(3) ].444]5 8285 245,00 6097.98 6,595.88 2,21805 -13505 5,971,856.41 5468.A1 49.13 -0,53]2 MD (3) ],4]4.17 8868 =,Si! 6698.80 65%80 2,203,42 -1,400.87 5,971,84061 5467]9]0 49.55 -1.207]0 MWO(3) 7,509.84 89.5 22497 669952 6,597,52 2,179.45 4,427.5 5,8]1616.4] 548753.4] is," 4173.03 MOVE) (3) 758.87 90.05 2=.60 6fitA69 6,597.69 215921 -1,446.65 5.971N6b 5487N22 892 -1,14881 MND(3) 7,589.15 9135 25.= 6.69030 8597.30 2135,76 -1,46]34 59]1.7]251 548.713.69 865 -1,115.95 MhD(3) ]5992] 91.44 21]]8 isiMn 57 6,595,57 2,11236 -1,407.5 5,9]1.]48.99 540.694% 8.10 -1.808.21 MWD (a) 7,62890 9178 214.12 669].]3 6,595]3 2,018.47 -1,50360 5,9]1,8199 54$6]]55 low -1,056.]] MD (3) ],6590] 94.40 21117 8696.11 6.59411 2081.49 .1,52062 5,9]16911% W.66080 tees -1,OW.n MAD (3) 7.68992 9461 21021 6,69376 6,591.76 205.00 -1,53630 5,9]1,6]439 548,64539 880 A95,86 MOD(3) ],]18.98 94.18 Mat 6.69146 6,589.46 2,01165 4,55922 5,9]164].88 548631.65 1620 .7]04 MOND (3) ]]52% 94113 202.37 6,681 6,5%]9 1.980.70 -1,56332 5,97161861 546.816.16 8.90 113337 MND(3) 7784,W 94.67 19687 6.80614 fi584.14 1,950.89 -1,5]6.1] 5,9]1,585.95 540,50]11 10.61 -001.94 MID (3) 792383 94.92 1%94 6602.89 6500.89 1,91392 -1.586.83 5,971,50,90 5411595.]0 7,53 -064.09 MID (3) 7054.33 9563 19120 868098 sense 1,804,0 4,59475 59715ffi54 548587.98 644 .344 MND(3) 7 H4.93 9393 19211 6.6853 6.575,53 1054.91 -160189 5,97149060 540,58124 679 ,3555 MND (3) �ER i u0cH%s Annotation TIP KOP Intaryolatad Azimuth Inhryclatel Azimuth Inkryalalad Azimuth 2H4WO19 8'4896AM Pa v 3 COMPASS 500014 SeW 650 C0 oc0 P 11lf1p5 ConmoPhillips Definitive Survey Report Company'. Conocolohi0lps Alaska Inc Kup9mk Local Co-ordinate Reference: M111&16 Protect: Kupamk River unit TVD Reference: 1B-16®102.00usR(1&16) Site: Kupamk I Pad MD Reference: iB-16@102.00usR(1&16) Well: 18-16 North Reference: Tme Wellbore: 19-16A Survey Calculation Method: Minimum Curvature Design: 18-IGA Databaoe: EDT 14 Naska Production Survey Annotation ER 1 U�Gl�ff6 VTU D19 848064M Page 4 COMPASS Soo0. 14 Buil 851) Map Map Vertical AND Iz AN TVD 1VOS6 .WS •GjM Northing EGO,°D". OLS Section Survey Tool Name IMM" 1°1 t% (usRl IusR) IusR) tusR IRI IR) 1 1 (R) 7,915.60 so," 19310 6fi7626 6,574.28 182684 -1607.59 5,97146070 540.57554 1221 -16.57 7000(3) ).946.77 9055 186,32 6,67592 6,57392 1.794.00 -1.612.04 50]1.429.83 548,57129 1215 -0263 MD (3) 7,975.53 92.64 18574 6,675.12 6,573.12 1.765.41 -1,615.0 5,9]1.40123 54055947 7,54 -02136 MD (3) 8.005.16 9147 18469 6.624.05 6.5]3.05 123593 -1617,76 5971,3)1.)3 548.565.97 5.30 -694A8 MWO(3) 6,04.0 90.95 18750 6.623.43 6,521.43 1206]6 .1,621.80 5,921.34255 548.56303 10.01 567.0 MWD(3) 8.04.19 Mae 18942 6.6]2.93 65]1.93 1,622.41 -1,62528 5,921313.16 546550th 6.37 540.0 MWD(3) 604..4 89.12 18063 6.622.89 6,520.89 1647.86 446M 52 5,92106356 W.650n 2.16 -611.83 NAND (3) 8,124.10 new 193.42 6,623.46 6,52146 1,616.62 -1,63625 5,921,25431 548,54726 042 {03.39 MMD(3) 8.INA 88,16 19520 6,624.8 652229 1SMA3 -1.844,19 5,921.225,02 548.54651 fi15 554,39 MJJO(3) 8,18395 Sew 196.05 6675.00 6,523.00 156696 -1,652.69 5.921.1055 54053220 1602 S25A9 MNO(3) 8.214.18 9015 2018 662521 6,52331 1,53242 -1,02.62 5821.16795 54852242 621 495.81 MD (31 8,244.52 9130 2018 6.624.65 8.57285 1.504.32 -1,674.15 592163..62 548.511.13 13,95 46525 MWD (3) 6.95.31 09411 208 6,674.67 6.5]1.62 1.426.42 .1,687.0 5921.11119 548.49041 612 43509 MWD (3) 8.370.40 85,99 20.36 6,625.56 6.57356 1,453.24 -lS9G70 5,971 M&M 546495.94 9M 70,09 MVVD(3) 6333.66 M." 203,42 6,627.29 65758 1423.56 -1,212.00 5.971 D58.77 548,47374 108 176a0 MUM) (3) 8.301.30 66a6 20013 6.879.11 652711 130.35 -12835 5.921.033.49 548,482.0 100 446.74 VNND(3) 0,394.19 S9@ 1.an 6680.00 6,5]888 1367.26 -1,73351 5921,002.33 548,45269 871 31733 MND(3) 6423.M Sam 19702 66&340 6,520.40 13859 -1,74270 59M.92460 54644369 600 -280.77 MD (3) 645393 09.92 193.64 66050 6.57650 1,310.11 -1]5080 5,920945.02 54043559 1140 -25119 MWD (3) 640391 9085 190,01 668034 6,520,34 1,280.91 -1.257.12 5970,915.83 548,42966 10@ -23074 MWD(3) 0.514.31 9203 1.,15 &AMS, 6,97.54 1,25093 8762.67 5,9M.805.82 546424.31 4.15 -8200 MWD(3) 8.543.82 93 fig 18950 6.828.0 6,57007 1,22184 -1767.73 oSM,656.20 548,41945 5.94 -17430 AYD(3) 8.02.93 934, 18056 6.676.50 6,574.58 1198.17 -171176 5,82003301 546tl5.58 1.38 45172 M (3) 8=63 93.0 191.47 6,624.50 8,57250 110.10 -1527.22 5,8708N.W 5464070 5.0 -120.98 Wive) (3) 0,68,93 0.23 193.54 667162 6,57067 1,132.55 -1504.10 5,970.22231 54040364 2.41 ..,a MND(3) 0008 94,21 195.46 667051 6,50.21 1110.12 -1791.19 5,970.740.84 548,3070 052 -eS.W MWD(3) 8.0955 95.05 19693 660.65 6,566.05 1,08041 -1,80039 5970,715.07 54838774 11.13 3547 MWD (3) 0,Ti605 8301 19667 6665.98 6,03.98 1,052.74 -1,809.81 5,970.687.34 50.328.51 692 &80 MWD (3) 8.74385 908 1%.02 6665.8 60336 1,029.15 -1.618.04 5970,66350 546,3M43 11.0 1775 "D (3) 8,77349 91,01 203.01 Sant 93 6562.93 100157 -1,828.06 5920636.04 548.35920 11.04 20 MWD (3) 8808.43 910 204.20 6664.14 656214 96962 -184299 597060480 54034528 5.09 8156 MND(3) Annotation ER 1 U�Gl�ff6 VTU D19 848064M Page 4 COMPASS Soo0. 14 Buil 851) Annotation �1 UGME8 9 21742019 848:06AM Paga5 COMPASS 5000.14 BWtl 850 ConocoPhillips �. Cono[oPlllllps Definitive Survey Report Co.,.., ConocoPhillips Als.ka lnc Kupamk Local CooMlnate Release.: Well 1&16 Project: K.Pa7uk River Dnit TVD Relemn.: iB-16a 10200us0(1&16) Slle: Kupamk I Pad MO Reference: iB-16®102.00..%(1&16) Well: 113,16 North Reference: T.. Wellbore: 113-16A Survey Calculation Method Minimum Curvalum Design 1B-i6A Dnobae: EDT 14 Alaska Production survey Map Map Vertical MD IM Ab TVD TVD88 414E ♦Hiy Northing Ea.tlhg DES Section go,ay Test Name (u.D) PI M loan (-am (.ant (ush) (n) (n) (.1190.) (D) 8,036.76 9335 204.22 .,.,.a 6.56093 943.85 y054,71 S,970,578 17 54a.334.34 6.54 109.95 MW0(3) 88[9.55 8390 203.75 6.66192 6558.02 914.87 -1 Wan 5,970.549.10 548.321.64 327 141.50 MWD(3) 8899.11 9298 200.82 6.659.08 6557.00 Mad -1,879.17 5,970,520.80 548,31¢26 Itt. 17173 MRD(3) 8938.70 9025 15606 8.55825 6,555.25 u50.E0 -1,808.53 5,970,492.64 548.301[9 18.48 200.69 MJN(3) 8959.17 9000 194.00 6,65818 6,556.10 829.10 -1.09643 5,970483.22 540.293.39 680 230.13 MAD(3) 8.98867 90.46 19261 685828 6,556.07 800A7 -1,90322 5,970.434.47 548,28879 496 258.39 MD (3) 9.01631 92.34 192.81 6657,34 8,555.34 771.56 -1,90914 5,970405.53 540,28045 630 286.68 MD (3) 9,04662 90.85 195.54 6,655.54 6,554.54 74219 -1,917.16 5,970,376.11 5462n,24 1054 315.82 NAND (3) 9,070.57 9175 Into 6.655.91 6,55391 713.53 -1.92582 5,970.347.39 548.264.77 9.23 34490 MWD(3) 9.108.74 e187 199,43 8654.93 655293 684.96 -1,93552 5,910.310]0 548.255.27 450 37455 MWD(3) 9.138.88 93.91 1&140 6.653.38 6,551.38 Sass. -1,945.53 5.970.290.33 548.N5.46 644 404.14 MJ4D(3) 9.16643 94.74 Mn 6.651.15 6.549.15 628.92 -1855.65 5,970,M,59 546.23552 547 433.16 MWD(3) 9,199.06 94.N 204.20 6.64876 6.546.76 600.72 -1,96733 5970,22072 546X4.03 11]2 463.42 MD (3) 9,243.00 "..N 204.20 6,64551 6.541.51 560.74 -1,985.29 5,970.194.X 54820633 000 W7.03 PRWECTEDto TD Annotation �1 UGME8 9 21742019 848:06AM Paga5 COMPASS 5000.14 BWtl 850 `I ConocoPhillips ConocoPhillips (Alaska) Inc.-Kupl Kuparuk River Unit Kuparuk 1B Pad 1 B-16APB1 50-029-22457-70 Baker Hughes INTEQ Definitive Survey Report 28 December, 2018 BAKER JUGHES GE,,,,,, f2282018 658:47PM Page t COMPASS 501148udd 85O Conocolphillips t1�GH6s 0 Conoi Survey Report Definitive Company.. ConocoPhillips (Alaska) Inc: Kupl Local Coorcmate Reference: We111B-16 Project: Kupamk River Unit TVD Reference: 18-16@102.00usg(18-16) Site: Kupamk I Pad MD Reference: 1B-16®102.00u,f1(16-18) Well. 1&16 Nunn Reference-. True Wellbom: i&16 Survey Calculation Method: Minimum Curvabre Design: 18.18 Database: EDT 14 Alaska Production Project Kupamk River Unit, North Slope Alaska, United States Map System: US Slate Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Da a m: NAD 1927 (NADCON CONUS) Using Well Rehrence Paint Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1&16 Well Position 'Ni 0.00 can Northing: 5,969,64681 Lamude: TO. IT 40.243N ♦HAV 0.90 us8 aiding: 550,191 Longibds: 149°35-34,510W Position Uncertainty 0,00.ag Wellhead Elevation: led Ground Level: 0.00 urn Wellbom IBA6APB1 Magnetics Madel Name Sample Dab Declination We Ad& Field Strangm N 11) (nT) OGGM2018 21112019 16]8 8088 57,420 Design 1B-16APB1 Audit Nates: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,02300 Vemcai Section: Depth Finale (M) N45 aV.W Direction (.aft) 1-111 (use) (1) 102.00 0.00 0.00 210.00 Survey Pmgmm Data From To Survey Survey d.S) (.an) Survey ".1fin n) Trial Name Description Students End Date 19359 6,823.00 1B -i6(1 B-16) MWD MWD -Standard 8252000 7,046.00 7.102.72 1B-16APB1 MW&INO(I&16AP81) 11 ONLY MWD -INC ONLY FILLER 121162010 121172010 7,130.20 7,436.17 1B-16APB1 MM(1&16APB1) MWD MWD -Standard 121172010 12120@010 f2282018 658:47PM Page t COMPASS 501148udd 85O �, 3 COMNSS 5000.14 Build 850 121182018 6'S8:4)PM ConocoPhillips .. CO(l000P11��IP5 Definitive Survey Report Oompary. Project: Site: Well: Wellbore: Devgn: OonocoPhl8lps(Meska) Kupamk River Unit Kupamk 10 Pad 1&16 18-16 19-16 Inc:Kupt Local Do<rdimes Referenu: TMD Refevn4a: MO Refarenoe: NorM Rafenuaa: a.., cakoleflon MalheE: Databaea: Well 18-16 1&16®1D2,00usfl(I B -I6) 1B-16 ® 102.O0usN (1&16) Tnuo Minimum Curvature EDT 14 Melia Production Survey MO (ueNl 6923.03 7046.00 7071.00 71028 7,13020 7160.41 7,190.51 7220.37 7250.66 7,280,60 7,310.32 70100 7370.95 7400.85 7.438.17 747800 Inc I'1 21.40 18.99 23.43 34,45 44.21 56.15 60.&1 78.51 80.22 99.00 103.07 100.43 103.8 99.07 96.00 %,W AL I°1 336.00 33720 33100 310.30 307.33 Il.71 300.25 290.71 A712 20.18 200.00 275.M ffi28 200.31 234.00 2M.00 1V0 (daft) 6,395.M 660561 6,6H69 6656.70 6677.97 6597.28 6.711.86 672149 8.85.49 8.83.41 679.59 6.71130 6705.W 6.700.64 8,695.90 669161 TVDSS (u -M 6,294.34 5503.61 6,527.fi9 6.554.70 6,575.97 6,69528 6,609.W 661848 6623.49 662171 6615.59 6.000.30 6.603.80 6590.64 6,593.90 6,58961 •0144 (USM 1.99118 2,06261 ?070.98 4083.12 2,004.96 2.108.54 2,12261 2,136.49 2,150.47 ?163,90 2,174.50 2189.45 2,180.06 2.18.20 ?156.89 2,132.44 Map .0m earthed (..ft) IN) -0,04379 5,971,53L39 -1 MINI 5.971.702.00 4.078.00 5,97171035 -1,08&fi5 5971,82.43 -1059,20 5971)34.18 -1118.04 5971,74764 -1.14034 5,97176156 -1,1".01 5,97177537 -1,19131 5,971,78907 -1,21&13 5,971002.40 -1,245.01 5,971.012.92 .1,27450 5.971,010.49 -1,30.79 5.971,81791 -1,332.38 58T1010.W -1.36321 5,971 ]94.35 -1,358.87 5.971.769.67 Map Eaatin0 IN) 549,13815 549.107.53 549103.35 549.094.69 54900197 MM 063 549.040.94 54901618 540.90969 548.962.0 548935.73 546,90521 546,07692 540.048.38 540.81785 54678,1.17 LS I,o 6n,1 0.24 1.09 19.8 3929 46.28 4007 3469 36.66 3914 3796 33,Y2 36.17 42.00 41P 4660 0.00 n Winniai Section Survey Tool Tool Name IN) A203.41 M D-iNC ONLY (2) -1,249.30 M INC ONLY(2) -1,25049 MW NC ONLY(2) -1360.71 M l0.$HC_ONLY(2) -1 S4.fi4 MNoi3) 4.287.03 MD (3) A260.12 MAD(3) 4.267.85 MvW(3) 4.266]5 MD (3) -1365.00 OND (3) -126on MWo(3i -125107 MWD (3) -1.239.09 MIND (3) -121500 MuND(3) A 186.32 MD -1,148.31 PROJECTED to TD Annotation TIP KOP Inhry0latedNemeth Interyolated ALimuth �, 3 COMNSS 5000.14 Build 850 121182018 6'S8:4)PM STATE OF ALASKA ALAbr A OIL AND GAS CONSERVATION COMMIT. .JN REPORT OF SUNDRY WELL OPERATIONS W1 IVEC E. St EE' 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown El Performed: Suspend ❑ ,0 V I vPerforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill erforate New Pool ❑ Repair Well ❑ Re-enter Soap Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development p Exploratory ❑ Stratigraphic❑ Service ❑ 218-155 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: Lq( µG- 99510 50-029-22457-86-'00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU IB -16A ADL 25648 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7,450 feet Plugs measured None feet true vertical 6,991 feet Junk measured None feet Effective Depth measured 7,240 feet Packer measured 6,666 feet true vertical 6,790 feet true vertical 6,250 feet Casing Length size MD TVD Burst Collapse CONDUCTOR 80 feet 16 121' MD 121' TVD SURFACE 4,383 feet 9 5/8 " 4,424' MD 4165' TVD PRODUCTION 7,402 feet 7x5" 7,441' MD 6983' TVD Perforation depth: Measured depth: 6778-6838. 6900-6908, 6918-6926, 7124-7158 at True Vertical depth: 6354-6410. 6468-6476, 6485-6493. 6680-6712 feet Tubing (size, grade, measured and true vertical depth) 4X3.5 J-55 6,704' MD 6,286' TVD Packers and SSSV (type, measured and true vertical depth) PACKER- BAKER FBA PERMENANT PACKER 6,666' MD 6,250' TVD SSSV -CAMCO TRDP-4A SAFETY VLV 1,893' MD 1,825' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 6778-7158 Treatment descriptions including volumes used and final pressure: Cement Squeeze: 30 bbls 15.8 Cement (20 bbls w/CemNet) 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 106 211 3902 1319 296 Subsequent to operation: 1128 1216 262 808 152 14. Attachments (required Per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations D Exploratory ❑ Development Service ElStratigraphic E] Copies of Logs and Surveys Run ❑ 16. Well Status after work: p Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSPEI SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318.576 ,/ nn,� o me: William Lon Name: ��( � ST AR8SA g Authorized games Ohlin er ( Iw Contact Email: William. R. Long@cop.com GTP 21le:eLrr Authorized Title: Staff CTD r IZ O -- Contact Phone: (907) 263-4372 Authorized Si nature: Date: ,3 C VTL 3/P/ / 19 �j� Form 10-404 Revised 4/2017 �(/ /�� (� Submit Original Only 16-16 Final CTD Schematic 16" 62# H-40 shoe @ 121' MD 9-5/8" 40# L-80 shoe @ 4424' MD III KOP @ 7026' MD 1KOP @ 7046' MD 3-1/2" x 5" TTWS 3-1/2"x 5" TTWS A -sand perfs 7:124'- 7158' MD 7" x 5" shoe @ 7441' MD 3-1/2" Cameo TRDP-4A Safety Valve @ 1893' MD Locked Out: 812/2017 4" 11# J-55 Tubing 4104' MD to surface Cross-over 4"x3.5" @ 4104' MD 3-1/2" Cameo gas lift mandrels @ 2624', 41391, 5204', 5967', & 6620' MD Baker FB -1 packer @ 6666' MD (4.0" ID) Baker SBE @ 6670' MD 3-1/2" Camco D landing nipple @ 6688' MD (2.80" min ID, Milled Out) 3-1/2" Cameo SOS @ 6700' MD 3-1/2" x 2-3/8" Northern Solutions Liner Top Paker @ 6682' MD 1B-16AL1PB1 TO @ 8886' MD Billet @ 8149' MD V16APB1 @ 7478' MD 1 B-16AL1 TD @ 9693' MD Liner @ 9069' MD To of Liner 6690' MD 1 B-1 6A TO @ 9243' MD Billet @ 7205' MD IWI ConomPhillips Alaska, Inc. +a+a z/Nl�teea41zu4 Last Tag -_ VeMvltllmoee lzx®11 ,lnndetlon I DepNmke) I End wh I Yhalnrt W[Medey Last Tag: RKB(Tagged Fiji in5"Closing) I6,9116.0 lillue2ing 18-16 lVshlblue, Last Rev Reason NPNGER se. AnnoteDon End Dom WNIGxe Last Molloy Rev Reason: Installed GLV'S B Set Llcer Top Packer 27612019 1B-16 zembaej [ Cashg Strings easing oeso,ptmn oo pest ID (in) rop mese) sal oemxlNee) sM oepu (rvo1... wuLm p... casae Top T"' CONDUCTOR ifi 15p6 410 12ro 121.0 6250 H-00 WELDED Lninp DezcmmmoD Int mIm, Tap(n") Se lepMet.1 SNDMx(ND) WSLen(L.. Daae TopTMW SURFACE 9518 883 40.8 4,424.1 4,1645 40.00 L-80 BTC LONDUCTON;tl.6R1.0 Lasanp Desceiption 006n) 10(ml Top Im, a[ in ltly9l SH DepM jND)... WbLen n_ Gnd¢ Top Threat PRODUCTION ) 828 36.9 7,441.1 6,982.5 26.00 L-80 BTC MOD 7'x5" 2 6690' Tubing Strings searm Tubing Descriple string Ma..IDllnl Top (nKB) Set Depth ln.Sn Depth OVD) T -IM Ddnl GMe Top Connmlion TUBING 4"x3.5" 4 3.48 38.8 6,]04.4 6,286.0 11.p0 7-55 BTC MOD Completion Details ELMLIFT:0.6IDs Top(ND) Top,- Nominal TopIMBI hi O Ice. Dam Com ID lin) 38.8 388 0.05 HANGER MCEVOY GEN IV HANGER 4.000 1,893.1 1,825.3 2323 SAFETVVLV CAMUOTRDP-4A A ETY VALVE 3.312 (LOCKED OUT TROP 8-24017) 4,104.1 3,866.9 21.93 Ro REDUCING CROSSOVER4x3.5, 1D2992,R93,T9,EUEBRDM0D 3,500 -70§3-3 W UFT;a13R3 6,249] 21.61 SF_ALASSY BAKER GBH-MLOCATOR wl1PSEALASSEMBLY 3.00D 8,666 2 6,250.4 21.61 PACKER BAKER FB -1 PERMENANT PACKER 4.000 06696 62538 2160 BBE SEAL BORE EXTENSION 4.000 0687.6 6,270.4 21.58 NIPPLE CAMCO D NIPPLE NO GO. (MILLED OUT TO A 280) 2.800 SURFACE easa,W.+ - 6,703.6 02852 21.56 SOB I CAMCO PE 500 SHEAR OUT SUB 3DW GAs LIFT; a,zm.s OMer In Hole (Mreline retrievable plugs, valves, pumps, fish, eta") TopfTwl rop ucl We uFr, Mess. Top mice) We) (•) Des cam Run Date In (n) 6,662.0 6,265.1 21.58 LINER TOP 72 "NOM.,. SOfmlens Li0e1t0P packerwl 1.781" R- 262019 1381 PACKER Profle Nipple(10 GAL) cAs un; e,Mae J,D25.0 6,585.6 19.22 WHIPSTOCK BAKERGEN2 DELTA WHIPSTOCK, .' GAL, 2 RA TAGS AT 70323. 0 DEGREE HIGH SIDE 1/162019 Dow ORIENTATION sE/,LAsBY; e,eeaa 7,045.0 6,604.] 19.00 WHIPSTOCK 2.63 GO BAKER GEN 2, AL,9.55'TRAY, S FROM TOW TO RA TAG, 33T ROHS ORIENTATION 1232018 0.000 ..a: a8M3 seE; e.e�a perforations a$lofs LINER TOP PALIPACKER8,8920 NIPPLE; effi LINERALI COMPLETION Top mK3) atm I(g m ) TopINO) (RNB) aM (IVO) (RKM Link"trine Dam S: Den Dammeat I ) Tylle Com 6,778.0 6,8380 03540 0410.3 UNI - 3,19-18 lian994 6.0 IPERF 1 "Enerje49 deg putting 45 deg orient cm:ama3s,lmo 8,900. 0908.0 8,468.2 6.g5.J G1, 1B-1 6/102008 fi.0 APERF . "PJ HSL, 60 ep random 8,918. 6,9260 6,465. 6,492.6 C -1,18-t W1D2006 6.0 APERF "PJ HBD, 60 deg random sot: aTLVe 7,124.0 ],158.0 06]9.6 6,711.9 A-0,10-1 81511994 40 1PERF "H D SGGuns, deg phasing Mandrel inserts IPFRG,BPB p6m9.p _ n rn Tdp(NO) Vanne UKl Pon S® TRO Run N Top We) InKa) seeks I Model I DD (in) Sm Time Type (In) hed) Run name, Co. 2,8235 2,4990 MERIA jTMPD 1 1 GAS LIFT GLV BK2 0.156 1, 11.0 252019 APERF;gmaoasTs.p- 2 4,139.3 3,898.5 CAMCO KBUG 1 GAB LIFT GLV BTRIP 0.188 -TWO122&1999 strip fiehin PPERF:BpW.Da�p� g ek 3 5,2035 4,8901 CAMCO DRUG 1 G45 LIFT OV BK 0250 0.0 252019 4 5,986.9 5,62 0 CAMCO KBUG i GAS LIFT pMY BK O.DDO 0.0 811411999 5 6,619.8 62073 CAMCO MMM 112 GAB LIFT DMY RK 0000 00 8/1311999 Notes: General a Safety Eno oma Annammn 22712009 NOTE: EST. 132' RATHOLE BELOW BOTTOM PERF POST FCO wNmsrpcK; T.psS. WW2010 NDI E: View BDhemalip mf AW. Schema6c9.0 WHIPSTOLKT,MMO 2202019 NOTE: View SChiment, W Alaska SchumagL10.0 IPENF:7,+3C0-7,+A0 PROgICTILNM'® 6E a9.B-T,N11 �� AOGCC Well History Report al IB-16 Daily Operations Start Date End Date AFE/RFE Last 24hr Sum 3/3/2019 15:00 3/3/2019 20:00 10412348 BRUSH n' FLUSHED SSSV @ 1893' RKB. SET 3.312" DB LOCK W/ K-VALVE (S#2949529-2 1290 PSI DOME) @ 1893' RKB; OBTAIN GOOD CLOSURE TEST & LRS OPEN BACK UP. JOB COMPLETE. 2/6/2019 06:00 2/7/2019 01:00 10412348 DRIFT W/ DMY NORTHERN SOLUTIONS LTP DRIFT TO TOP OF LINER @ 6689' RKB; SET 2.72" NS LTP W/ R-PLUG @ SAME & UNABLE TO OBTAIN TBG TEST; SET HOLEFINDER ON TOP OF LTP & OBTAIN GOOD TBG TEST; SET NS LTP TEST TOOL & UNABLE TO OBTAIN TBG TEST (SUSPECT ELEMENT ON LTP IS IN MILLED D-NIPPLE); PULLED NS LTP (FISHED ELEMENT), BRUSH n' FLUSHED LINER TOP & SET 2.72" NS LTP W/ EXTENSION & R-PLUG (10.75" OAL W/ 1.781" R- NIPPLE) @ 6689' RKB; OBTAIN GOOD TBG TEST & PULLED 1.781" R-PLUG SEAL ASSEMBLY. JOB COMPLETE. 2/5/2019 06:00 2/5/2019 18:30 10412348 TAG LINER TOP @ 6689' RKB & MEASURED BHP @ 6679' RKB (2734 psi); SET CATCHER @ 6687' RKB; PULLED DV & SET OV @ 5203' RKB; PULLED DV & SET GLV @ 2623' RKB; OBTAIN GOOD TBG TEST W/ HOLEFINDER @ 6600' RKB & PULLED CATCHER @ 6687' RKB. IN PROGRESS. 1/18/2019 06:00 1/18/2019 12:00 10412348 MASTER VALVE POSITIVE PRESSURE TEST(PASSED), MASTER VALVE DDT (PASSED), SSV POSITIVE PRESSURE TEST (PASSED), SSV DDT(PASSED). 1/17/2019 08:00 1/17/2019 23:59 10412348 RIH WITH BDJSN, TAG WHIP STOCK, PU CORRECT DEPTH TO 7025' RKB PAINT WHIT FLAG, BULLHEAD 44.4 BBLS DIESEL DOWN THE TUBING, LINE UP DOWN THE COIL, PUMP 30 BBLS SW, START INJECTION TEST, .5 BPM WHIP 949, IAO, OA 0, 1 BPM WHIP 1034, IAO, CA 1.5 BPM WHIP 1126, IA 0, OA 0, HOLD PJSM FOR CEMENT, BATCH UP 15.8 PPG CEMENT, PARK COIL AT 6695' RKB BULLHEAD 25 BBLS CEMENT INTO FORMATION, 5 BBLS NEAT FOLLOWED BY 20 BBLS WITH FIBER IN IT. LAID THE LAST 5 BBLS OF NEAT CEMENT IN TUBING, PU TO SAFETY, 6,000' RKB, BRING PRESSURE UP TO 2000 PSI, PRESSURE WOULD FALL OFF AS SOON AS WE CAME OFFLINE. DID 3 HESITATION SQUEEZES BEFORE GETTING PSI TO START STABILIZING. DROPPED .75" BALL, CIRCULATED TO THE NOZZLE WHILE HOLDING 1300 PSI AT CHOKE. SHUT CHOKE IN BUILD PRESSURE TO 2000 PSI, HELD PSI FOR 30 MIN, RIH CLEANED OUT DOWN TO WHIP STOCK. PU CONTAMINATING CMT CLEANING ACROSS PERFS. GOT UP TO 5500' GET BOTTOMS UP. SHUT CHOKE IN, BROUGHT PRESSURE UP TO 1867 PSI HELD FOR 30 MIN, ENDING PSI 1844 PSI, CONTINUE TO POOH CLEANING ACROSS ALL GLM. AT SURFACE TRAP 1,000 PSI ON WELL. .75" BALL RECOVERED. READY FOR DHD. JOB IN PROGRESS 1/16/201915:00 1/16/2019 22:30 10412348 SET TOP OF WHIPSTOCK @ 7025', 0" ROHS, CCL TO TOP OF WHIPSTOCK = 14.9', CCL STOP DEPTH = 7010.1', LOG CORRELATED TO SLB CBL DATED MARCH 26, 1994. 1/16/2019 06:00 1/16/2019 14:00 10412348 TAGGED MILLED NIPPLE @ 6688' RKB. DRIFT W/ 2.69" X 20' DMY WHIP STOCK DOWN TO 7053' RKB. READY FOR E-LINE. 1/14/201906:00 1/14/201914:30 10412348 RIH WITH DOWN JET NOZZLE, START CLEAN OUT FROM 6700' CLEAN OUT DOWN TO HARD TAG AT 7045' RKB, WELL READY FOR SLICKLINE. JOB IN PROGRESS. 1/13/2019 07:00 1113/201917:30 10412348 TRAVEL OVER FROM DEAD HORSE, SPOT UNIT, PERFORM WEEKLY BOP TEST, MAKE UP TOOLS, STACK BACK FOR THE NIGHT. JOB IN PROGRESS. 1/11/2019 06:00 1/11/201919:00 10412348 SET DV @ 2623' RKB; PULLED OV & SET DV @ 5203' RKB; MITT TO 2500 PSI (PASS); PULLED SLIP STOP CATCHER (RECOVERED OV FROM 119) & K-3 PLUG @ 6678' RKB. JOB COMPLETE & READY FOR CTU (fco). 1/10/2019 06:00 1/10/2019 21:30 10412348 LRS LOADED IA W/ 100 BBLS OF DIESEL; DRIFT 2.84" GAUGE RING & TAG D-NIPPLE @6687' RKB; ATTEMPT DMY WHIPSTOCK DRIFT & UNABLE TO GET PAST 6917' RKB (TOW SET DEPTH 7025' RKB); RAN 2.5" BAILER AND WORKED FROM 6927'-6958' RKB (BAILER FULL OF FILL); SET K-3 PLUG W/ SLIP STOP CATCHER ON TOP @ 6678' RKB; PULLED GLV @ 2623' RKB AND ATTEMPT TO SET DV @ SAME. IN PROGRESS. 12131201810:00 12/3/2018 19:30 10412348 SET TOP OF WHIPSTOCK @ 7045', WHIPSTOCK ORIENTATION @ 330° ROSH. CCL TO TOP OF WHIPSTOCK = 14.9', CCL STOP DEPTH = 7030.1' LOG CORRELATED TO SLB CBL DATED 26- MARCH-1994. 11/26/2018 06:00 11/26/2018 18:00 10412348 RIH WITH LH MOTOR AND MILL. MILLED NIPPLE AT 6687' TO 2.80", GAUGE MILL TO 2.80" GO, 2.79" NO GO, .5" BALL RECOVERED, WELL FREEZE PROTECTED, READY FOR ELINE. 11/23/2018 06:00 11/23/201817:45 10412348 PULLED 2.75" CSV @ 6688' RKB, MEASURED BHP @ 7000' RKB. WELL READY FOR COIL. SBHP OF 2,773 PSI MEASURED. JOB COMPLETE 11/22/2018 06:00 11/22/201817:15 10412348 SET GLV @ 2624' RKB, MADE MULTIPLE ATTEMPTS TO PULL GLV @ 4139' RKB. IN PROGRESS 11/21/2018 06:00 11/21/201819:45 10412348 SET OV @ 5204' RKB, MADE MULTIPLE ATTEMPT TO PULL GLV @ 4139' RKB (TOOLS LATCH BUT SLIP OFF VALVE, POSSIBLE STRIPPED FISHNECK,1 HR TOTAL JAR TIME ON VALVE), PULLED GLV @ 2624' RKB. IN PROGRESS 11/20/2018 06:00 11/201201819:00 10412348 PULLED 3.312' DB LOCK W/ K-VALVE @ 1893' RKB, BRUSH n FLUSHED TBG TO 7281' RKB, DRIFTED TO TD @ 7289' RKB W/2-5/8" x 15' DUMMY WHIPSTOCK (no issues), SET 2.75" CSV @ 6688' RKB, PULLED OV @ 5204' RKB. IN PROGRESS 11/3/2018 06:00 11/3/2018 18:00 10412348 TIFL (PASSED), MV-DDT (PASSED), MV-PPT (PASSED), SSV-DDT (PASSED), SSV-PPT (PASSED), SV-DDT (PASSED), SV-PPT (PASSED). 11/2/2018 06:00 11/2/2018 18:00 10412348 TORQUE TAND IC LDS TO 450 FLBS T POT PASSED T PPPOT PASSED RE ENERGIZE IC PO COMPLETE IC POT PASSED IC PPPOT PASSED MITOA PASSED TO 1800 PSI IN PROGRESS. Page 1/1 Report Printed: 3/4/2019 Operations Summary (with Timelog Depths) 113-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Agivily Code Time P -T -X Oparadon Start Depth (fiKB) End Depen (fiKB) 12/13/2018 12/13/2018 1.50 MIRU MOVE RURD P Break down TT hard-line, secure BOP, 0.0 0.0 21:00 22:30 continue RD checklist 12/13/2018 12/14/2018 1.50 MIRU MOVE RURD P Disconnect PUTZ lines, chain off reel, 0.0 0.0 22:30 00:00 move mats away from rig, complete RD check list, Peak trucks arrive on pad 12/14/2018 12114/2018 2.00 MIRU MOVE RURD P RU & move shop & half -way house to 0.0 0.0 00:00 02:00 1 1 2A -Pad 12/14/2018 12/14/2018 3.00 MIRU MOVE RURD P Truck back on site, rig up to sows, pull 0.0 0.0 02:00 05:00 sub & pits off well 12/14/2018 12/14/2018 6.50 MIRU MOVE MOB P Move from 2T -Pad to 1B -Pad 0.0 0.0 05:00 11:30 12/14/2018 12/14/2018 1.50 MIRU MOVE MOB P On 1B pad, Remove jeeps from units. 0.0 0.0 11:30 13:00 Check tree status, Rig up cellar herculite 12/14/2018 12/1412018 1.50 MIRU MOVE MOB P Spot modules 0.0 0.0 13:00 14:30 12114/2018 12/14/2018 3.00 MIRU MOVE RURD P Crew change, PJSM, Safe out 0.0 0.0 14:30 17:30 location, Build scaffolding in cellar, Start working rig up check lists 12/14/2018 12/14/2018 1.50 MIRU MOVE NUND P MU PUTZ, NU BOPE, continue RU 0.0 0.0 17:30 19:00 checklist " Rig Accept 19:00 hrs 12/14/2018 12/14/2018 2.50 MIRU MOVE RURD P Grease swab & tango valves, 0.0 0.0 19:00 21:30 harmmer up flanges, swap out riser, engergize koomy 12/1412018 12/14/2018 2.10 MIRU MOVE RURD P Grease HCR's (change out bad 0.0 0.0 21:30 23:36 pump), complete RU checklsit 12/14/2018 12/15/2018 0.40 MIRU WHDBOP DISP P Line up valves, begin fluid packing 0.0 0.0 23:36 00:00 lines 12/15/2018 12/15/2018 0.20 MIRU WHDBOP DISP P Complete fluid packing lines, displace 0.0 0.0 00:00 00:12 coil to freshwater 12/15/2018 12/15/2018 0.30 MIRU WHDBOP PRTS P Shell test, good 0.0 0.0 00:12 00:30 12/1512018 12/15/2018 1.30 MIRU WHDBOP BOPE P Begin BOP test (witness waive by 0.0 0.0 00:30 01:48 Adam Earl ofAOGCC), "Low 250 psi, high 3500 psi 12/15/2018 12/15/2018 1.00 MIRU WHDBOP BOPE T Difficulty holding low test #5 (Charlie 0.0 0.0 01:48 02:48 7), grease valve, good test 12/15/2018 12115/2018 6.70 MIRU WHDBOP BOPE P Continue BOP test, install test joint, 0.0 0.0 02:48 09:30 continue test, No other failures. Test PVT & gas detectors - all good, 9 hour test 12/15/2018 12/15/2018 1.90 MIRU WHDBOP PRTS P Fluid pack CT and pressure test inner 0.0 0.0 09:30 11:24 reel valve. Unstab injector, PT TT line and PDL's 12/15/2018 12/15/2018 0.60 PRODi WHPST CTOP P Change out upper quick conned and 0.0 0.0 11:24 12:00 1 irehead E -line 12/15/2018 12/15/2018 1.50 PROD1 WHPST PULD P PJSM, M/U and deploy BHA#1 0.0 74.2 12:00 13:30 Window milling BHA with 2.81 mill, 2.8 string reamer, and .6° AKO motor 12/15/2018 12/15/2018 1.00 PRODi WHPST PULD T Unable to accuate master valve, Call 74.2 74.2 13:30 14:30 out valve crew. Valve is pressure locked 12115/2018 12/1512018 0.80 PRODt WHPST PULD P Master open. WHP=525, Continue 74.2 74.2 14:30 15:18 with deployment, Make up coil to BHA and surface test - Good. Stab on injector. Tag up and set counters 12/15/2018 12115/2018 1.60 PROD'I WHPST TRIP P RIH BHA#1 to mill window. On 74.2 6,655.0 15:18 16:54 I seawater returns to Tiger tank Page 1122 Report Printed: 2/2812019 Operations Summary (with Timelog Depths) F 113-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth start Time End Time Durh (C Phase Op cme Acbvity Code Time P -T -X Operation (RKB) End Depth(ftKB) 12/15/2018 12/15/2018 0.10 PRODt WHPST DLOG P Log K1 for+1.5' correction 6,655.0 6,684.0 16:54 17:00 12/15/2018 12/15/2018 1.20 PROD1 WHPST DISP P Continue RIH, flush well w/ seawater, 6,684.0 6,760.0 17:00 18:12 unable to establish returns, bull -head seawater to window (2 bpm, 200 psi WHP) 12/15/2018 12/1512018 0.40 PROD1 WHPST DISP P Displace coil to DuoVis 6,760.0 6,760.0 18:12 18:36 12/15/2018 12/15/2018 2.30 PROD1 WHPST WAIT P Await building 50 bbl 150K LSRV pill, 6,760.0 6,760.0 18:36 20:54 coordinate trucks & fluids for possibility of no returns should pill not help Obtain SBHP while waiting on pill: MD = 6760', TVD sensor = 6296.9', BHP = 2717 psi, EMW = 8.3 ppg 12/15/2018 12/15/2018 2.00 PROD1 WHPST DISP P Bullhead 50 bbl 150K LSRV pill 6,760.0 6,760.0 20:54 2254 followed by DuoVis down to Paris (pushing away seawater), WHP climbs from 150 psi to -850 psi at parts, then begins to drop (100 bola away, 40 bbl squeezed into perfs) 12/15/2018 12/15/2018 0.60 PROD? WHPST TRIP P Pump attempting to get returns, 6,760.0 7,049.3 22:54 23:30 returns start @ 40% , quickly demininish to -21 %, decision made to close choke & mill window, PUW = 41 K, RIH, dry tag WS pinch point @ 7049.8', PUH, bring on pumps 12/15/2018 12/16/2018 0.50 PRODi WHPST WPST P Tag WS pumping @ 7049.3', FS = 550 7,049.3 7,050.0 23:30 00:00 psi @ 1.9 bpm,, CWT = 24.6K, WOB = 0.3K, BHP = 2866 psi, circ = 3567 psi 12/16/2018 12/1612018 3.50 PROD1 WHPST WPST P Continue milling window, CWT = 7,050.0 7,052.8 00:00 03:30 21.4K, WOB = 1.8K, BHP = 2906 psi, circ = 3324 psi, closed choke, 1.87 bpm 12/16/2018 12/16/2018 1.50 PROD? WHPST WPST P Continue milling window, CWT= 7,052.8 7,054.7 03:30 05:00 22.8K, WOB = 2K, BHP = 2933 psi, circ = 3272 psi Pre -load build BHA 12/16/2018 12/16/2018 2.60 PRODi WHPST WPST P Milling window, WOB = 2.5K, BHP = 7,054.7 7,057.3 05:00 07:36 2952 psi, circ = 3364 psi, WHIP = 12 psi TF=30R 12116/2018 12/16/2018 2.00 PROD1 WHPST WPST P Called BOW @ 7056.3, Reamer out 7,057.3 7,071.0 07:36 09:36 @ 7057.3. Drill rathole. 1.9 BPM @ 3400 PSI FS, BHP=2993 12116/2018 12/16/2018 2.00 PROD1 WHPST REAM P TO Rathole, start reaming passes. As 7,071.0 7,071.0 09:36 11:36 drilled, 30L, 30R, and 180° out of as drilled tool face. Dry drift window - Good. 12116/2018 12/16/2018 1.20 PROD1 WHPST TRIP P POOH, PUW=36K 7,071.0 74.0 11:36 12:48 12/16/2018 12/16/2018 1.00 PROD1 WHPST PULD P At surface, Tag up and space out. 74.0 0.0 12:48 13:48 Flow check well. PJSM. Well dead. Static losses - 20 BPH. Lay down BHA#1. Mill and string reamer out @ 2.79 No Go 12/16/2018 12/16/2018 1.20 PRODi DRILL PULD P P/U BHA #2, was pre loaded in PDL. 0.0 72.2 13:48 15:00 Make up to coil and surface test, Check pack offs 12/16/2018 12/1612018 1.30 PROD1 DRILL TRIP P RIH BHA #2 72.2 6,650.0 15:00 16:18 Page 2122 ReportPrinted: 212 812 01 9 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activtty Cove Time P -T -X Operation (ftKB) End Depm (ftKB) 12/16/2018 12/16/2018 0.20 PROM DRILL DLOG P log K1 for+.5', PUW=36K, Close EDC 6,650.0 6,670.0 16:18 16:30 12/16/2018 12/16/2018 0.20 PROD1 DRILL TRIP P Continue in well. Clean pass through 6,670.0 7,071.0 16:30 16:42 window 12/16/2018 12/16/2018 1.40 PROD1 DRILL DRLG P 771', Drill, 1.9 BPM (03 3214 PSI FS, 7,071.0 7,160.0 16:42 18:06 BHP=2950, Choke shut, WHP=O, RIW=19.2K, DHWOB=1.5, Bleed IA down from 1070, crew change, PUW = 40K 12/16/2018 12/16/2018 1.20 PROD1 DRILL DRLG P Drilling, FS = 530 psi @ 1.9 bpm, 7,160.0 7,215.0 18:06 19:18 closed choke, CWT = 21 K, WOB = 1.4K, BHP = 3050 psi, circ = 3404 psi, WHIP = 0 psi Difficulty achieving 45o DLS, reduce rate to 1.5 bpm & increase WOB per DD request, geo's confer w/town geology 12/16/2018 12/16/2018 0.30 PRODt DRILL WAIT P Geo/DD wiper, allow geo's time to 7,215.0 7,215.0 19:18 19:36 discuss deeper build landing, PUW = 40K, decision made to continue drilling 12/16/2018 12/16/2018 1.50 PROD1 DRILL DRLG P Drilling, CWT = 19K, WOB = 3.5K, 7,215.0 7,267.0 19:36 21:06 BHP =3091 psi, WHP=33 psi, circ= 2820 psi Continue at 1.5 bpm & increase WOB in attempt to achieve higher DLS, PUW = 38K 12/16/2018 12/17/2018 2.90 PROM DRILL DRLG P Drilling, FS = 550 psi @ 1.9 bpm, 7,267.0 7,378.0 21:06 00:00 CWT =17.6K, WOB =4K, BHP= 3134 psi, WHIP = 62 psi, varialbe ROP (12 fph - 115 fph), PUW = 40K, begin pulling 46K & -3 WOB 12/17/2018 12/17/2018 0.30 PROM DRILL WPRT P Continue wiper to window, pull up past 7,378.0 6,640.0 00:00 00:18 1 1 1 Paris at 6788' 12/17/2018 12/17/2018 0.30 PROD1 DRILL DLOG P Log K1 for +1' correction, continue in- 6,640.0 7,090.0 00:18 00:36 hole, log RA @ 7053' TOWS = 7046', TOW = 7048', BOW = 7056, RA = 7053 12/17/2018 12/17/2018 0.20 PROD1 DRILL WPRT P Wiper in-hole, RIW = 20K, weight 7,090.0 7,378.0 00:36 00:48 bobbles at 7277'& 7355'(—1 K WOB) 12/17/2018 12/17/2018 1.40 PROD1 DRILL DRLG P Drilling, FS = 568 psi Q 1.9 bpm, 7,378.0 7,470.0 00:48 02:12 CWT =19.8K, WOB =1.8K, BHP= 3229 psi, WHIP = 120 psi, circ = 3602 psi, dosed choke, drill to called EOB 7470 Work PDL's to avoid freeze-up 12/17/2018 12/17/2018 1.80 PROD1 DRILL TRIP P POOH, PUW = 40K, pull heavy 7,470.0 71.0 02:12 04:00 through 7365', 7342'& 7242 (up to - 4K WOB), open EDC, tag up, flow check, have flow 12/17/2018 12/17/2018 0.90 PROD1 DRILL PULD P PUD BHA#2, pumping managed 71.0 0.0 04:00 04:54 pressure 12/17/2018 12/17/2018 2.00 PROD1 DRILL PULD P PD BHA#3 "A" Lateral Assembly 0.0 78.0 04:54 06:54 (NOV Agitator, 0.5° AKO motor, RB HYC A2 bit), slide in cart, check pack - offs, MU to coil, tag up 12/17/2018 12/17/2018 1.20 PROM DRILL TRIP P Trip in hole, BHA#3 A lateral section, 78.0 6,655.0 06:54 08:06 1 Shallow test agitator 12/17/2018 12/17/2018 0.20 PROD1 DRILL DLOG P Log K1 for+.5', PUW=37K 6,655.0 6,680.0 08:06 08:18 Page 3122 Report Printed: 2128/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depm Start Time End Time Dur hr ( ) Plisse Op Catle Activity Cotle Time P -T -X aPeratiart (fl Ke) End Depth (flKB) 12/1712018 12/17/2018 0.20 PROD1 DRILL TRIP P Continue in well, Clean trip through 6,680.0 7,478.0 08:18 08:30 window. Clear to bottom @ 7478 12/17/2018 12/17/2018 0.50 PROD1 DRILL TRIP T 7478 PUH. Tight spots with pack offs 7,478.0 6,608.0 08:30 09:00 and high negative weight on bit. Hole in poor condition. Get up to cased hole. Jet 5 1/2 tubing in preparation for Polyswell pill. 12/17/2018 12/17/2018 2.40 PROD1 DRILL CIRC T Poly Swell material coming for 6,608.0 6,608.0 0900 1124 1 1 1 Deadhorse. recip 5 112 tubing 12/17/2018 12/17/2018 2.00 PROD1 DRILL CIRC T Stand by for polly swell 6,608.0 6,655.0 11:24 13:24 12/17/2018 12/17/2018 0.10 PROD1 DRILL DLOG T Log K1 for +3' correction 6,655.0 6,682.0 13:24 13:30 12/17/2018 12/17/2018 0.10 PROD1 DRILL TRIP T Trip in hole 6,682.0 6,700.0 13:30 13:36 12/17/2018 12/17/2018 0.20 PROD1 DRILL CIRC T Line up to pump down back side for 6,700.0 6,700.0 13:36 13:48 baseline pressures for poly swell job, 1 BPM Pump=315 PSI, BHP=2928, 1.5 BPM Pump=475PSI, BHP=3001, WHP=420, 2 BPM Pump=600PS1, BHP=3083, 2.5 BPM, Pump=700PSI, BHP=3137, 3 BPM Pump=800PSI, BHP=3177, 12/17/2018 12117/2018 1.30 PROD1 DRILL CIRC T PJSM to mix and pump poly swell 6,700.0 6,715.0 13:48 15:06 12/17/2018 12/17/2018 0.50 PROD1 DRILL CIRC T Pump 20 BBI poly swell pill down back 6,715.0 6,715.0 15:06 15:36 side, 3 BBI/Min, Pump Pressure 1100 PSI, WHP=25 PSI. 12/17/2018 12/17/2018 0.10 PROD1 DRILL TRIP T 6715 At 60 BBIs pumped down back 6,715.0 6,096.0 15:36 15:42 side Pull up hole out of pill, PUW=38K 12/17/2018 12/17/2018 1.00 PROD1 DRILL OTHR T 6096, out of pill. Wait for poly swell to 6,096.0 6,096.0 15:42 16:42 activate. 12/1712018 12117/2018 0.20 PROD1 DRILL CIRC T Start pumping down back side .5 6,096.0 6,096.0 16:42 16:54 BPM, WHP=23PSI, No change dudn pumping, BHP=2745 12/17/2018 12/17/2018 0.80 PROD1 DRILL OTHR T Shut down pump. No pressure build 6,096.0 6,096.0 16:54 17:42 up, Batch up second 20 BBL pill of poly swell 12/17/2018 12/17/2018 0.40 PROD1 DRILL CIRC T Pump 20 BBI pill of poly swell down 6,096.0 6,714.0 17:42 18:06 back side follow with duo vis RIH to below TT 12/17/2018 12/17/2018 2.40 PROD1 DRILL OTHR T At 6714. Wait on poly swell to activate, 6,714.0 6,714.0 18:06 20:30 1 1 12 Hrs 12/17/2018 12/17/2018 1.00 PRODt DRILL CIRC T Online with pump down back side .5 6,714.0 6,714.0 20:30 21:30 BPM, BHP=2830, Climbed slowly to 3210 12/17/2018 12117/2018 0.60 PROD1 DRILL TRIP T Trip in hole, Start prepping 3rd Poly 6,714.0 6,094.0 21:30 22:06 pill, 30 BBIs 12/1712018 12/17/2018 0.50 PROD? DRILL CIRC T Pump 30 BBI poly pill down back side 6,094.0 6,094.0 22:06 22:36 at 2 BPM under displace pill 30 Pill and 20 BBIs duo vis. 2 BPM BHP=3210 12/17/2018 12/18/2018 1.40 PROD1 DRILL WAIT T Pill spotted, PUH out of pill to 4000', 6,094.0 4,000.0 22:36 00:00 1 1 1 lWait 2 hours for swelling action 12/18/2018 12/18/2018 1.20 PROD1 DRILL WAIT T Continue to allow poly swell pill swell 4,000.0 4,000.0 00:00 01:12 time, estimate 35 bbl above parts Page 4122 Report Printed: 2/28/2019 c ° Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Til" End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation Staff Depth (ftKB) End oepm(W13) 12/18/2018 12/18/2018 0.70 PROW DRILL DISP T Pump 0.5 bpm down back -side, bit 4,000.0 4,000.0 01:12 01:54 depth = 4000', (attempting to achieve 1500 psi over stabalized annular pressure of 2750 psi) Annular quickly rises to 2600 psi, 2 bbl away, annular = 2750 psi 5 bbl away, annular = 3000 psi 10 bbl away, annular = 3217 psi 15 bbl away, annular = 3387 psi 17.5 bbl away, annular = 3412 psi (up to 13.7 ppg, and began to flatten) Shutdown pumps, pressure drops to -2600 psi relatively quickly, then began to slow 12/18/2018 12/18/2018 1.10 PROD? DRILL WAIT T Confer w/ town on plan forward 4,000.0 4,000.0 01:54 03:00 12/18/2018 12/18/2018 3.20 PROD1 DRILL DISP T Decision made to pump away 4,000.0 4,000.0 03:00 06:12 remaining 8.5 bbl Poly Swell, maintaining 11.4 ppg at window (2650 psi annular @ bit depth of 4000') Began pumping, annular quickly jumps to 3200 psi, allow to drop to 2650 psi, shut down pumps, continue pumping small ammounts and shutting down pump to maintain 11.4 ppg. (-1100 psi WHIP), swap to managed pressure in attempt to reduce annular fluctuations, rate in began to increase quickly from nominal to hold 11.4 ppg to .45 bpm, difficulty holding 11.4 ppg at window Begin prepping for 4th Poly Swell pill should it be required (30 bbl) 12/18/2018 12/18/2018 1.00 PRODt DRILL DISP T Begin circulating down coil, unable to 4,000.0 6,715.0 06:12 07:12 hold 11.4 ppg at window, confer w/ town, decision made to build & pump 4th Poly Swell pill (30 bbl) 12/18/2018 12/18/2018 0.60 PRODt DRILL DISP T 50 bbl bullhead away 30 bbl Poly 6,715.0 3,826.0 07:12 07:48 Swell follow by 20 bbl Duo Vis, reduce rate & PUH to 3826' pumping pipe displacement, PUW = 38K, (-26 bbl Poly Swell above perfs in cased hole) 12/18/2018 12/18/2018 2.00 PROD1 DRILL WAIT T Wait on swell time, pumps off (9.0 ppg 3,819.0 3,819.0 07:48 09:48 1 1 atvvindow) 12/18/2018 12/18/2018 0.70 PROD1 DRILL DISP T Squeeze 22 bbl away attempting to 3,819.0 3,819.0 09:48 10:30 hold 12.4 ppg at window, begin pumping at 1.8 bpm to build to 11.76 ppg ppg, 10 bbl away, reduce rate to .5 bpm attempting to build to 12.4 ppg, unable to achieve 12.4 ppg, drop to 10.4 ppg 12/18/2018 12/18/2018 2.00 PROM DRILL WAIT T Confer w/ town, MI formulating plan 3,819.0 78.0 10:30 12:30 forward w/ FORM-A-BLOK pill (recipe & volume requirements), perform lab tests w/ product on dg, PUH, tag up in prep for pumping 12/18/2018 12/18/2018 2.20 PROD1 DRILL WAIT T Await super sucker to clear pits, super 78.0 78.0 12:30 14:42 sucker arrives on site Coordinate w/ facilites for 3C-08 pre - dg work, begin RDMO paperwork should that become plan forward Page 6122 Report Printed: 2/28/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime Endf nme our (hr) Phase Dp Code AMIty Code Time P -T -x Operation (aKB) End Depth^8) 12/18/2018 12/18/2018 1.00 PRODI DRILL CLEN T Suck out pits, wash down & clean of 78.0 78.0 14:42 15:42 all polymer 12/1812018 12/18/2018 2.80 PROD1 DRILL CIRC T Build 10 bbl KCI spacers & 23 bbl 78.0 78.0 15:42 18:30 FORM-A-BLOK pill (40 ppb product) 12/18/2018 12/18/2018 0.80 PROD1 DRILL CIRC T PJSM, Pump 5 bbl KCL spacer, @ 3 78.0 78.0 18:30 19:18 bpm, Pump 20 bbis Form-A-Blok from 3-0.25 bpm, lots of issues pumping, lost C pump pressure, Triplex jacking off, purr - 1.0 bbl duovis, unable to initially catch prirme with KCL, swap to KCL once pump lined up, Pump 5 bbls KCL @ 3 bpm, Swap to duovis displacement, chase LCM to parts @ 3 bpm, CT 650 psi, WH 612 psi, 12/18/2018 12/18/2018 0.30 PRODI DRILL CIRC T Al 77 bbls total treatment away, with 78.0 78.0 19:18 19:36 Form-A-Blok at the parts reduce rate to 0.5 bpm, pump 10 bbls of Form-A- Blok to the formation, CT 195 psi, WH fell from 596 psi to 165 psi @ 5 bbls away, then climbed slowly to 179 psi at 10 bbls away 12118/2018 12/1812018 3.70 PROD1 DRILL CIRC T SID for 30 min, On line, - 1 bbl away 78.0 78.0 19:36 23:18 to fit hole / catch pressure. Squeeze away 1.8 bbls ( total away 89.8 bbls) well head climbed to 137 psi then broke over, SID for 30 min, WH fell to 0 psi Catch pressure with 1 bbl away, squeeze 1 bbl, WH climbed to 140 psi. SID for 30 min. WH fell to 0 psi Catch pressure imeditly squeeze 1 bbl away, WH climbed to 183 psi. SID for 30 min. WH fell to 3 psi Catch pressure imeditly, squeeze 1 bbl away, WH climbed to 218 psi. SID for 30 min. WH fell to 33 psi Catch pressure imeditly, squeeze 1 bbl away, WH climbed to 245 psi. S/D for 30 min. WH fell to 50 psi Catch pressure imeditly, squeeze 1 bbl away, WH climbed to 290 psi. SID for 30 min. WH fell to 83 psi 12/18/2018 12/19/2018 0.70 PROD1 DRILL CIRC T Move pipe, RIH 100 feet, POOH, 78.0 96.8 23:18 00:00 bump up, space out PJSM, Start batching 50 bbls of Pro V, 40 bbls water, 3 sacks viscosifyer, and Pro V plus LCM pill 12119/2018 12/19/2018 3.00 PROD1 DRILL CIRC T Complete building 52 bbls pill of Pro 96.8 96.8 00:00 03:00 V+ LCM pill, (92 Ib/bbl). 12/19/2018 12119/2018 2.10 PRODI DRILL CIRC T Lead in with duovis - mud, establish 96.8 96.8 03:00 05:06 injection 1 bpm WH 350 psi, swap to Pro V, pump 9.8 bbls, lock up Pump #1, troubleshoot issues. Swap to pump #2, get 7.6 bbls away lost pump #2. Pull apart pump # 1, LCM packing off and Floating the valves. Tear down and clean Pump#1. "Prov = 9.32 ppg Page 6/22 Report Printed: 2/2812019 Operations Summary (with Timelog Depths) 113-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SMO Depen Start Time End Time our (hr) Phase Op Code AdivKy Code Time P-T-X Operation (tIKB) End Depth (ftKB) 12/19/2018 12/19/2018 0.80 PROD1 DRILL CIRC T Back on line, estimate 17.4 bbls of 96.8 96.8 05:06 05:54 plug on the backside, meter indicated - 33 bbls on restat due to clearing lines. Ignoring fallout lead of plug at perfs with 92.6 bbls away end of plug is 110 bbls away. Displace at 2 bpm, WH 610 pi. WH broke trend Q 76 bbls, cut rate to 1 bpm @ 81 bbs away. WH increased to 720 psi then broke back, reduced rate to 0.5 bpm. WH climbed and started to break over. Shut down trapping 555 psi on the WH 12/19/2018 12/19/2018 1.30 PRODi DRILL CIRC T Wait on dehydration 96.8 96.8 05:54 0712 12/19/2018 12/19/2018 0.70 PRODt DRILL CIRC T Discussed w/ Procor rep, decision 96.8 78.0 07:12 0754 made to squeeze away all 5.75 bbl & attempt again w/ more volume (ie the remaining 45 bbl in pits), Squeeze away bbl 11.4 bbl, WHIP climbs to 785 psi, WHP w/ pumps off drops to 69 psi Shut 2-3/8" rams to isolate EDC, trap 105 psi WHP to ensure rams & checks are holding, pump down MP line, DPS is below rams (so will see dp, though is not affecting EDC) 12/19/2018 12/19/2018 1.20 PROD1 DRILL CIRC T PJSM, discuss w/ Procor rep method 78.0 78.0 07:54 09:06 of getting LCM in-hole given earlier packed off pump issue, decision made to pump remaing -45 bbl of Pro V, 5 bbl Pro V followed by -2 bb DuoVis (both in-hole), chase 60 bbl "pill' w/ puovis 72 bbl away, Pro V @ Paris (Note: 132 bbl total pumped will be tail of Pro V pill through the parts) 12/19/2018 12/19/2018 0.30 PROD1 DRILL CIRC T Squeeze away 20 bbl @ 1 bpm (92 78.0 78.0 09:06 09:24 total pumped), WHP climbs to 850 psi 12/19/2018 12/19/2018 1.00 PROD1 DRILL CIRC T Wait, WHP drops to 79 psi @ 1 hr 78.0 78.0 09:24 10:24 12/19/2018 12/19/2018 0.20 PROD1 DRILL CIRC T Squeeze 12 bbl, WHP = 875 psi, 78.0 78.0 10:24 10:36 103.75 bbl total pumped, 28.25 bbl pill remains 12/19/2018 12/19/2018 0.50 PROD1 DRILL CIRC T Wait, WHP drops tol97 psi 78.0 78.0 10:36 11:06 12/19/2018 12/19/2018 1.50 PROD1 DRILL CIRC T Pump at .1-.2 bpm until WHP = 600 78.0 78.0 11:06 12:36 psi, wait 20 min, WHP drops to 210 psi, (pumped 110 bbl total, 22 bbl remain) 12/19/2018 12/19/2018 0.70 PRODi DRILL CIRC T Pump al .1-.2 bpm until WHP = 650 78.0 78.0 12.36 13:18 psi, wait 20 min, WHP drops to 221 psi,(pumped 113.7 bbl total, 19 bbl remain) 12/19/2018 12/19/2018 0.80 PROD1 DRILL CIRC T Pump at -.3 bpm until WHP begins to 78.0 78.0 13:18 14:06 plateaus @ 888 psi, WHP quickly w/ pumps off, (pumped 125.8 bbl total, 6.2 bbl remain) 12/19/2018 12/19/2018 0.50 PROD? DRILL CIRC T Pump remaining 6.2 bbl at .5 bpm, 78.0 78.0 14:06 14:36 WHP climbs to 962 psi, with tail out petfs WHP drops to 856 psi, then climbs to 990 psi (142 bbl total pumped) Page 7122 Report Printed: 2/28/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth start Time End Time Dur (h) Phew DP Curie Adivdy Code Time P -T -X Operation ntK8) End Depth (ftKB) 12/19/2018 12/19/2018 1.10 PROD1 DRILL CIRC T Line up down coil, RIH to 2000', 78.0 78.0 14:36 15:42 pumping 1.3 bpm, At 2000' " 1.8 bpm, 1 -for -1 returns at holding 9.7 ppg at window " 1.8 bpm, 11.2 ppg. 72% returns, WHIP = 818 psi 12/19/2018 12/19/2018 1.00 PROD1 DRILL TRIP T Continue RIH, pumping .75 bpm, 78.0 6,620.0 15:42 16:42 1 holding 11.2 ppg 12/19/2018 12/19/2018 0.40 PRODi DRILL DLOG T Difficulty finding K1, PUH to 6620'& re 6,620.0 6,676.0 16:42 17:06 -log, PUW = 34K 12/19/2018 12/19/2018 2.00 PROD1 DRILL CIRC T Continue in-hole, slow through tubing- 6,676.0 6,676.0 17:06 19:06 tail & down to TOWS Make two down passes jeting max rate @ 20 ft/min from 6723' to 7035'. 12/19/2018 12/19/2018 1.50 PROD1 DRILL TRIP T POOH 6,676.0 83.0 19:06 20:36 12/19/2018 12/19/2018 1.20 PROD1 DRILL PULD T PJSM, atempt to bleed WH and lay 83.0 0.0 20:36 21:48 down over a dead well, presure built to 18psi. PUD BHA#3. 12/19/2018 12/19/2018 0.50 DEMOB WHDBOP PULD P Pick up a nozzle, stab back on. 0.0 0.0 21:48 22:18 12/19/2018 12/20/2018 1.70 DEMOB WHDBOP DISP P Bullhead 220 bbls seawater 1.9 BPM, 0.0 0.0 22:18 00:00 CT 4047 psi, WH 774 psi. LR on location, PJSM, confirm customer valve clear with air, RU, PT to 4 k psi, good. 12/20/2018 12/20/2018 0.20 DEMOB WHDBOP DISP P Complete bullheading 180 bbls 0.0 0.0 00:00 00:12 seawater 1.9 BPM, CT 4047 psi, WH 774 psi. LR on location, PJSM, confirm customer valve clear with air, RU, PT Ito 4 k psi, good. 12/20/2018 12/20/2018 1.00 DEMOB WHDBOP DISP P LRS, Bullhead 30 bbls diesel FP 1.0 0.0 0.0 00:12 01:12 BPM, CT 1400 psi, WH 454 psi. "' S/I well with 490 psi on the tubing 12/20/2018 12/20/2018 1.00 DEMOB WHDBOP CIRC P Pop off, install jet nozzle, stab back 0.0 0.0 01:12 02:12 on, Jet stack. 12/20/2018 12/20/2018 1.00 DEMOB WHDBOP CTOP P Pop off, install night cap flush lines, 0.0 0.0 02:12 03:12 blow down. 12/20/2018 12/20/2018 1.00 DEMOB WHDBOP CTOP P Pop off, vac stack, Bore O scope BOP 0.0 0.0 03:12 04:12 I I istack. 12/20/2018 12/20/2018 4.80 DEMOB WHDBOP RURD P Work dg down checklist, NO BOP 0.0 0.0 04:12 09:00 **Rig Released: 12/20/18 @ 09:00 hrs 1/19/2019 1/19/2019 3.00 MIRU MOVE RURD P Continu to work RD checklist. 0.0 0.0 00:00 03:00 1/19/2019 1/19/2019 1.00 MIRU MOVE RURD P Peak tmck(trackor/ trailer for shops) 0.0 0.0 03:00 04:00 broke down in middle of acces pad road just off pad. Crew towing truck to pad so sows can access the rig. PJSM 1/19/2019 1/19/2019 2.00 MIRU MOVE RURD Pull pits & sub off well, pull flow -block, 0.0 0.0 04:00 06:00 gate valve, & adapter flange from tree, clear pad, perform environmental walk around 1/19/2019 1/19/2019 2.50 MIRU MOVE RURD P Jeep up, load shop & pull shop mats 0.0 0.0 06:00 08:30 I Page 8122 Report Printed: 2/28/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start �p� DO startrma EM Imre drt h ( r) Phase Op Code Activit' Corse Time P -T -X operation (WB) Ena Depth (flKa) 1/19/2019 1/19/2019 4.50 MIRU MOVE MOB P Move from 3H pad to 1B pad 0.0 0.0 08:30 13:00 1/19/2019 1/19/2019 6.00 MIRU WHDBOP RURD P "• Rig Accept 20:00 0.0 0.0 13:00 19:00 adjust scaffold, and stack riser. Capture RKBs. Grease valves, complet RU check list, good up 1/19/2019 1/19/2019 2.70 MIRU MOVE MOB P Arrive at 1B -Pad, de -jeep, lay 0.0 0.0 19:00 21:42 herculite, spot sub 8 pits, lay mats Note: 38 minutes to place mats for sub 8 pits 1/19/2019 1/20/2019 2.30 MIRU WHDBOP RURD P Begin RU checklist, get COMMS on- 0.0 0.0 21:42 0000 line, lower stairs & landings, MU PUTZ, bring on steam, began building scaffolding around tree, unlock reel & injector. Shop and 1/2 way house spotted at entrance to the pad. Make up managed pressure line, stab BOP stack. Spot tiger tank, d in same. 1/20/2019 120/2019 4.20 MIRU WHDBOP BOPE P "` BOP test start 0:00 0.0 0.0 00:00 04:12 Shell test, 250 low, 3500 psi high good test. AOGCC witness waived by Austin McLeod R1 leaking, replace R1 Got test 5 Test against R1, with upper swab shut, open a the night cap, fluid apears to be going through the master, dump SSV, same, call valve crew. Contiune to trouble shoot, close lower blinds, held, not going through master, swab2 is leaking, fluid a the nigh cap. 1/20/2019 1/20/2019 2.80 MIRU WHDBOP BOPE P Valve crew sevice swab 2 Nabors 0.0 0.0 04:12 07:00 crew regressed stack valves, continue w/ BOP test 1/20/2019 1/20/2019 1.80 MIRU WHDBOP BOPE T Difficulty w/ high on test 8, trouble- 0.0 0.0 07:00 08:48 shoot, change out test pump bleeder valve, re-teset, continue trouble- shooting, eliminate choke maniford, track to Romeo2, grease R2, test, good 1/20/2019 1/20/2019 0.90 MIRU WHDBOP BOPE T Continue w/ BOP test, difficulty 0.0 0.0 08:48 09:42 holding low on test 9, re -grease Romeo 3, test, pass 1/20/2019 12012019 2.30 MIRU WHDBOP BOPE P Continue w/ BOP test, install test 0.0 0.0 09:42 12:00 joint, draw down test, LD test jnt, test complete 1/20/2019 1/20/2019 1.00 MIRU WHDBOP CIRC P Slide in cart, stab on, line up to 0.0 0.0 12:00 13:00 seawater, pump slack forward (1.5X coil volume @ 2 bpm) 1/202019 1/20/2019 1.00 MIRU WHDBOP PRTS P Reverse circulate, test inner reel 0.0 0.0 13:00 14:00 valve. PT tiger -tank line to 2500 psi & blow down 1/20/2019 1/20/2019 0.80 MIRU WHDBOP PRTS P Pop off injector, break off nozzle, 0.0 0.0 14:00 14:48 install pressure plate, PT CTC to 4000 psi, install UQC checks, PT PDL's 1/20/2019 1/20/2019 1.70 SLOT WELLPR OTHR P Valve crew opens grease locked 0.0 0.0 14:48 16:30 master valve (quite difficult to open), pressure up above SSV (588 psi), open SSV, no change in pressure 1/20/2019 1/20/2019 1.40 PROD1 WHPST PULD P PD BHA #4 Window Milling Assembly 0.0 74.0 16:30 17:54 (0.6" AKO motor, 2.79" string reamer, 8 2.80" DSM) Page 9122 Report Printed: 22812019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Mme End Mme Our (M Phase Op Code Activity Code Tune P -T -X Operation Start Depth (rt KB) End Depth (flKB) 1/20/2019 1/20/2019 3.30 PROD1 WHPST PULD T Test MWD - Short! 0.0 74.0 17:54 21:12 Unstab, break off, test meg 0. Cut lead off & troubleshoot. 9.1Mega ohm from office to whip, 8.7 Mega Ohm from whip to office. Test surface lines from office to coil - good. Call out electrician, found some water in collector, pulled anchor, cut wire back same issue, cut back coil on whip end -5' same issue. 1/20/2019 1/20/2019 1.80 PROD1 WHPST PULD T Organize new string (# 52795) to be 0.0 74.0 21:12 23:00 loaded and staged @ peak yard for morning move. SLB N2 crews hour'd out will mobilize from deadhorse to rig Q 04:00 Install anchor and rehead CTC, pull test 35 k lbs, good. PT CTC and inner reel iron to 2,500 psi - good. Skid cart back 1/20/2019 1/21/2019 1.00 PROD1 WHPST PULD T Grab lunch, PUD BHA *4, LD tools. 0.0 74.0 23:00 00:00 1/21/2019 1/21/2019 1.50 PRODi WHPST PULD T Continue to PUD & LD BHA ff4. 0.0 0.0 00:00 01:30 1 Struggle with frozen lugger line. 1/21/2019 1/21/2019 1.50 PROD1 WHPST CTOP T Skid cart, torque up nozzle, stab 0.0 0.0 01:30 03:00 injector, RIH, POOH to change coil position on reel in preparation to unstab. S/I master with 1000 psi trapped below. 1/21/2019 1/21/2019 4.00 PROD1 WHPST CTOP T Prep for reel blow down and unstabing 0.0 0.0 03:00 07:00 1 coil while wailing on N2. 1/21/2019 1/21/2019 2.20 PROD? WHPST CTOP T SLB arrives at dg, PJSM, PT customer 0.0 0.0 07:00 09:12 line to 3500 psi, lock -out reel & MU pressure bulk -head, pump 15,000 SCF N2 (100° F), bleed down coil 1/21/2019 1/21/2019 2.30 PROD1 WHPST CTOP T Unlock reel, pop off, disassemble 0.0 0.0 09:12 11:30 inner -reel iron, install grapple 121/2019 1/21/2019 2.00 PROD1 WHPST CTOP T PJSM, Pull test grapple/CTC to 900 0.0 0.0 11:30 13:30 psi, check grapple connection, unstab coil & secure 1/21/2019 1/21/2019 1.00 PROD1 WHPST CTOP T PJSM, lower whip end of pipe w/ 0.0 0.0 13:30 14:30 tugger from goose -neck to rig floor, prep to out coil at reel end 1/21/2019 1/21/2019 1.70 PROD1 WHPST CTOP T Cul pipe on rig floor, prep reel for 0.0 0.0 14:30 16:12 removal, remove saddle clamps, reel in slings 1/212019 1/21/2019 1.30 PROD? WHPST CTOP T Reel arrives on pad, PJSM, pick reel 0.0 0.0 16:12 17:30 from rig, pick & set new reel (# 52795) 1/21/2019 1/212019 1.00 PROW WHPST CTOP T Safety Stand -down meeting w/ all 0.0 0.0 17:30 18:30 personnel on rig, followed by pre lour for night crew 1/21/2019 1/21/2019 2.50 PROD1 WHPST CTOP T Complete cutting coil & clear pipe from 0.0 0.0 18:30 21:00 rig floor, Gear snow from new reel & heat w/ steam, connect TT soft line to rig, begin changing out brass 121/2019 1/21/2019 1.50 PROD1 WHPST CTOP T Reel set down in saddle, begin MU 0.0 0.0 21:00 22:30 saddle clamps, re -assemble injector, test wire in reel - Good. 1/212619 122/2019 1.50 PRODt WHPST CTOP T String grapple line, MU grapple, prep 0.0 0.0 22:30 00:00 to stab pipe 1/22/2019 122/2019 2.80 PROD1 WHPST CTOP T PJSM, Pull test grapple to 900 psi - 27 0.0 0.0 00:00 02:48 k lbs - good. Pull pipe past horses head, lock out reel, damp coil in head, unlock reel, stab pipe into gripper blocks. Page 10122 Report Printed: 2128/2019 Operations Summary (with Timelog Depths) 113-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Time Duf (hr) Phase Op Code Activity Code Time P -T -x Operabon (ftKB) End Depth (W) 1/22/2019 1/22/2019 3.20 FROM WHPST CTOP T Skid cart forward, cut pipe install CTC, 0.0 0.0 02:48 06:00 install inner reel iron. 1/22/2019 1/22/2019 4.00 FROM WHPST CTOP T complete inner tell iron, install 0.0 0.0 06:00 10:00 pressure bulkhead 1/22/2019 1/22/2019 0.40 PROD1 WHPST CTOP T Electrical test 68.8 Ohms > 2k M 0.0 0.0 10:00 10:24 Ohms, polarity good, Unlock reel LRS on location, PJSM, RU, PT 1/22/2019 1/22/2019 1.10 PROD1 WHPST CTOP T Pull test to 35 k lbs, MU upper Quick - 0.0 0.0 10:24 11:30 no flaots, Test UQC, 66.2 ohms >2 K M Ohms, make up rh =le, skid cart and stab on 1/22/2019 1/22/2019 2.00 FROM WHPST CTOP T Line up to LRS, Pump 5 bible neat 0.0 0.0 11:30 13:30 MetOH. Check pack offs, Line up to seawater, fluid pack the reel. Find leak in 90 ° , inner reel iron, S/D and lock out rig. Hammer up iron, unlock reel, Circ MethOH to the tiger tank. 1/22/2019 1/22/2019 2.50 FROM WHPST CTOP T Leak manifest its self again, locked 0.0 0.0 13:30 16:00 out reel, hammered up double wing under HP bulkhead. Pumped slack forward @ 2.2 bpm & 4256 psi. Drip healed as fluid warmed up. Pressure test & chat inner reel valve to 4400 psi - god. PT CTC to 4200 psi good. Test upper quick, install checks, 1/22/2019 1/22/2019 1.30 FROM WHPST PULD T PD BHA#5, miling asembly PT tiger 0.0 85.0 16:00 17:18 tank line. test tool - good 1/22/2019 1/22/2019 0.20 FROM WHPST PULD P Continue to PD BHA #5 0.0 85.0 17:18 17:30 1/22/2019 1/22/2019 1.35 FROM WHPST TRIP P RIH, with window milling BHA #5 85.0 6,625.0 17:30 18:51 1/22/2019 1/22/2019 0.60 FROM WHPST DLOG P Logging K1 marker, missed it, PBUH 6,625.0 6,684.3 18:51 19:27 to start logging higher, start logging 6,625', correction of plus 25.5'. PUW 34 k 1/22/2019 1/22/2019 0.25 PRODt WHPST TRIP P Continue RIH, flushing well with SW 6,684.3 6,792.0 19:27 19:42 1/22/2019 1/22/2019 1.00 FROM WHPST CIRC P Set down 10 k Top of pert section, 6,792.0 6,699.0 19:42 20:42 PUW 41 k, continue circulating SW flush from well, swap to milling fluid 1/22/2019 1/22/2019 0.75 FROM WHPST TRIP P Inspect and torque up Hub Bolts, suck 6,699.0 6,699.0 20:42 21:27 out tiger tank 1/22/2019 1/22/2019 2.00 FROM WHPST TRIP P Continue IH, mill past pert intervals, 6,699.0 6,750.0 21:27 23:27 6,790', 6,810', 6,810', and 6,904' with HIS TF. PUW's 36-38 k, PUH to above initial set down to 6,750', RBIH 1/22/2019 1/22/2019 0.25 FROM WHPST TRIP P Dry tag TOWS @ 7,029', PUH obtain 6,750.0 7,029.0 23:27 23:42 pumping parameters 1/22/2019 1/23/2019 0.31 PROM WHPST WPST P OB milling window @ 7,029', 1.9 bpm 7,029.0 7,029.3 23:42 00:00 at 4,430 psi, Diff --460 psi, WHP=592, BHP= -4,016, IA=618, OA=2 1/23/2019 1/23/2019 4.50 FROM WHPST WPST P OB milling window exit, 1.87 bpm at 7,029.3 7,033.2 00:00 04:30 4,423 psi, Diff --450 psi, WHP=610, BHP=4,033, IA=630, OA=1 1/23/2019 1/23/2019 4.00 FROM WHPST WPST P OB milling window exit, 1.87 bpm at 7,033.2 7,037.2 04:30 08:30 4,423 psi, Diff --450 psi, WHP=610, BHP=4,033, IA=630, OA=1 1/23/2019 1/23/2019 2.20 PROD1 WHPST WPST P Drillig ahead, CT Wt 17 k Its, Ct 4440 7,037.2 7,051.0 08:30 10:42 1 psi @ 1.88 bpm in 1.88 bpm out, WOB 1.84 6.5 ft/hr. Page 11122 ReportPrinted: 2/28/2019 Operations Summary (with Timelog Depths) 113-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SWA Time End Time our hr ( ) Phase Op Code Acevay Code Time P-T-X Operation Start Depth (rt De End mepm (flKa) 1/23/2019 1/23/2019 1.60 PROD1 WHPST REAM P TD rat hole @ 7051' PU 38 klbs, 7,051.0 7,051.0 10:42 12:18 perform reaming passes, HS, 30 L 30 R and LS. Dry drift clean. Tag bottom, pump 5 x 5 TD sweep, 1/23/2019 1/23/2019 0.50 PROD1 WHPST CIRC P PUH slowly waiting for sweeps to exit. 7,051.0 6,977.0 12:18 12:48 1/23/2019 1/23/2019 1.60 PROD1 WHPST TRIP P Open EDC, POOH 6,977.0 79.0 12:48 14:24 1/23/2019 1/23/2019 1.00 PRODi WHPST PULD P PUD BHA#5 bot mil and string renter 79.0 0.0 14:24 15:24 came out 2.79" NG 1/23/2019 1/23/2019 1.40 PRODt DRILL PULD P PD BHA #6, PT tiger tank line, re- 0.0 72.0 15:24 16:48 torque the upper Quick, Check pack of -good 1/23/2019 1/23/2019 1.40 PROD1 DRILL TRIP P RIH 72.0 6,635.0 16:48 18:12 1/23/2019 1123/2019 0.20 PROD1 DRILL DLOG P Logged the K1 marker correction of 6,635.0 6,639.0 18:12 18:24 plus 6.0', close EDC, PUW 34 k 1/23/2019 1/23/2019 0.20 PROD1 DRILL TRIP P RIH 6,639.0 7,051.0 18:24 18:36 1/23/2019 1/23/2019 0.25 PROD1 DRILL DRLG P OBD, 1.87 bpm at 4,274 psi, Diff-606, 7,051.0 7,065.0 18:36 18:51 WHP=570, BHP=4,114, IA=810, OA=2 1/23/2019 1/23/2019 0.15 PROD1 DRILL DRLG P Stall, PUW 36 k, pumping 1.86 bpm at 7,065.0 7,078.0 18:51 19:00 4,300 psi, Diff--606, WHP=570, BHP=4,114, IA=810, OA=2 1/23/2019 1/23/2019 1.00 PRODi DRILL DRLG P Stall, PUW 35 k, pumping 1.88 bpm at 7,078.0 7,135.0 19:00 20:00 4,365 psi, Diff--693, WHP=601, BHP=4,142, IA=814, OA=2 1123/2019 1/23/2019 2.30 PROD1 DRILL DRLG P Stacking weight, PUH, PUW 45 k, 7,135.0 7,363.0 20:00 22:18 1.88 bpm at 4,432 psi, Diff--684, WHP=601, BHP=4,142, IA=814, OA=2 1/23/2019 1/23/2019 0.20 PROD1 DRILL WPRT P 1 00'wiper up hole, PUW 42 k 7,363.0 7,363.0 22:18 22:30 1/23/2019 1/24/2019 1.50 PROD1 DRILL DRLG P Set down 7,354' work to bottom, drill 7,363.0 7,439.0 22:30 00:00 _ ahead 1.82 bpm at 4,296 psi, Diff-687, WHP=601, BHP=4,142, IA=814, OA=2 1/24/2019 1/24/2019 0.25 PRODi DRILL DRLG P OBD, 1.82 bpm at 4,296 psi, Diff=687, 7,439.0 7,480.0 00:00 00:15 WHP=601, BHP=4,142, IA=814, OA=2 1/24/2019 1/24/2019 0.50 PROD1 DRILL WPRT P TO Build section, (avg digs 38.9°), 7,480.0 7,025.0 00:15 00:45 PUW 38 k, chase sweep up hole, RBIH to confirm hole is dean. Pull up hole to window. 1/24/2019 1/24/2019 0.25 PROD1 DRILL WPRT P Perform jog back in hole to above WS 7,025.0 7,004.0 00:45 01:00 w/sweep, open EDC 1/24/2019 1/24/2019 1.35 PRODi DRILL TRIP P POOH to surface chasing 10x10 7,004.0 72.2 01:00 0221 1 1 sweep 1/24/2019 1/24/2019 1.20 PROD1 DRILL PULD P At surface, space out, PUD build 72.2 0.0 02:21 03:33 assembly 1/24/2019 1/24/2019 1.20 PROD1 DRILL PULD P PD lateral drilling assembly 0.0 72.0 03:33 04:45 1/24/2019 1/24/2019 1.50 PROD1 DRILL TRIP P RIH, close EDC, Shallow test agitator, 72.0 6,640.0 04:45 06:15 1156 Delta p @ 1.88 bpm. Continue to RIH 1/24/2019 1/24/2019 0.10 PROD1 DRILL DLOG P Tie int the K1 for a +4' correction 6,640.0 6,674.0 06:15 06:21 1/24/2019 1/24/2019 0.10 PROD1 DRILL TRIP P PU Wt 36 k lbs, continue to RIH 6,674.0 7,050.0 06:21 06:27 1 1/24/2019 1/24/2019 0.20 PROD? DRILL TRIP P Log the RA tag 7033.3" 7,050.0 7,080.0 06:27 06:39 1 Page 12122 ReportPrinted: 2/28/2019 Operations Summary (with Timelog Depths) IB -16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time ow(hr) Phase Op Code Activity Code Time PJ4 Operation Start Depth (%KB) End Depth(hKB) 1/24/2019 1/24/2019 0.20 PROM DRILL TRIP P Continue to RIH 7,080.0 7,480.0 06:39 06:51 1/24/2019 1/24/2019 2.00 PROD1 DRILL DRLG P On bottom drilling, New mud at the bit 7,480.0 7,830.0 06:51 09:39 7480'. Once new mud all the wy aroud picked up to reaquire numbers, PU 36 k Ibs. RBIH CT 4765 psi at 1.90 bm in, 1.90 bpm out, Delta P 1011 psi, Annular 4125 psi, WH 500 psi, IA 409 psi, CA psi. CT Wt 16 k lbs, WOB 1-2 k lbs, ROP 100-200 ft/ hr, losses started at 7536', healed quickly to loosing 0.1 bpm. 7829' PU 35 k lbs ROP 125 ft/hr 1/24/2019 1/24/2019 0.30 PROM DRILL WPRT P PU 40 K lbs, short wiper -400'to end 7,830.0 7,830.0 09:39 09:57 of build, RBIH Swap from pump #2 to Pump #1 - packing leak 1/24/2019 1/24/2019 3.80 PROD1 DRILL DRLG P Ct 4803 psi @ 1.88 bpm in and 1.80 7,830.0 8,311.0 09:57 13:45 bpm out, delta P 1007 psi, BHP 4164 11.8 EMW, WH 588 psi, 11.9 CT Wt, 2+ k bs WOB. 8057' PU 35 k lbs 8198' PU 38 k lbs ROP = 126 fl/hr 1/24/2019 1/24/2019 0.30 PROM DRILL WPRT P PU 38 k lbs, short wiper -300'to 8,311.0 8,311.0 13:45 14:03 8032', RBIH 1/24/2019 1/24/2019 1.60 PROD1 DRILL DRLG P Ct 4877 psi @ 1.89 bpm in and 1.73 8,311.0 8,527.0 14:03 15:39 bpm out, delta P 1004 psi, BHP 4185 psi 11.8 EMW, WH 540 psi, 9.7 CT Wt, 1.8 k bs WOB. Start snubbing -8450' 8481' Pu 37 k lbs ROP = 135 ft/hr 1/24/2019 1/24/2019 0.50 PROD1 DRILL WPRT P PU 38 k lbs, Long wiper for tie in 8,527.0 7,649.0 15:39 16:09 1/24/2019 1/24/2019 0.10 PROM DRILL DLOG P Tie into the R4 tag for +1' correction 7,649.0 7,086.0 16:09 16:15 1/24/2019 1/24/2019 0.20 PROD1 DRILL WPRT P RBIH from wiper trip 7,086.0 8,527.0 16:15 16:27 *** Note, had to reduce rate to get past 8470' 1/24/2019 1/24/2019 1.55 PROD1 DRILL DRLG P Ct 4893 psi @ 1.91 bpm in and 1.81 8,527.0 8,612.0 16:27 18:00 bpm out, delta P 1037 psi, BHP 4217 psi 11.8 EMW, WH 573 psi, 1.7 CT Wt, 1.9 k bs WOB. 1/24/2019 1/24/2019 2.00 PROM DRILL DRLG P OBD, 1.82 bpm at 4,296 psi, Diff=687, 8,612.0 8,768.0 18:00 20:00 WHP=601, BHP=4,142, IA=814, OA=2 1/24/2019 1/24/2019 0.50 PROM DRILL WPRT P Short wiper up hole, PUW 42 k, hard 8,768.0 7,904.0 20:00 20:30 time working back to bottom 8,470', continue wiper up hole to 7,904' 1/24/2019 1/24/2019 0.70 PROD? DRILL WPRT P 800', Wiper back in hole, lowering 7,904.0 8,768.0 20:30 21:12 pump rate to 1.3 bpm 1/24/2019 1/25/2019 2.80 PROM DRILL DRLG P BOBD, 1.9 bpm at 5,050 psi, 8,768.0 8,904.0 21:12 00:00 Diff --1,143 psi, WHP=595, IA=754, OA=B 1/25/2019 1/25/2019 2.00 PROD1 DRILL DRLG P OBD, 1.9 bpm at 5,202 psi, Diff=1,147 8,904.0 9,015.0 00:00 02:00 psi, WHP=572, BHP=4,249, IA=887, OA=12 Page 13122 Report Printed: 212 812 01 9 Operations Summary (with Timelog Depths) 113-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time Ertl Time our (hr) Phase Op Cotle Activity Cptle Time P -T -X Opealron Start Depth(110) End Depth (WB) 1/25/2019 1/25/2019 1.00 PROD1 DRILL DRLG P OBD, 1.91 bpm at 5,142 psi, 9,015.0 9,055.0 02:00 03:00 Diff --1,030 psi, WHP=553, BHP=4,249, IA=917, OA=13, Zero Coil Weight, 1.5 k=DHWOB, ROP 20- 74 fph 1/25/2019 1/25/2019 0.20 PROD1 DRILL DRLG P OBD, 1.91 bpm at 5,142 psi, 9,055.0 9,058.0 03:00 03:12 Diff --1,030 psi, WHP=553, BHP=4,249, IA=917, OA=13, Minus 5.0 k=CTSW, 1.3 k=DHWOB, ROP=30 fph 1/25/2019 1125/2019 0.30 PROD1 DRILL WPRT P Wiper up hole, PUW 38 k, pulled 9,058.0 8,059.0 03:12 03:30 heavy from 8,436-8,411', work pipe up hole, PUW's 40-62 k 1/25/2019 125/2019 1.35 PROD1 DRILL WPRT P Wiper back in hole, RIW 8-11 k, set 8,059.0 8,400.0 03:30 04:51 down 8,459' PUW 49 k, PUH to 8,400', continue IH, working pipe through tight spot 8,411'-8,721', pull back up hole to 8,400'. 1125/2019 125/2019 0.60 PRODI DRILL WPRT P Wiper back in hole, set down 8,453', 8,400.0 9,052.0 04:51 05:27 1 1 work pipe down hole, 1/2512019 1/25/2019 5.00 PROD? DRILL DRLG P CT 5082 psi, @ 1.9 bpm in , 1.7 bpm 9,052.0 9,238.0 05:27 10:27 out, delta P 1040 psi, BGP 4251 psi, 567 psi WH, Ct Wt -5 k lbs, 1.1 k WOB. Struggle with weight transfer and ankerite, bottoms up from 9090 - 40% ankerite. Build pill out of active mud with 212% 776/Low Torque. Able to put 3.7 k WOB. Break out, drill ahead til next ankerite lens, TD called early by town. 1/25/2019 1/25/2019 3.10 PROD1 DRILL WPRT P Pump TD sweeps, PU Wt 44 k lbs, 9,238.0 72.0 10:27 13:33 followed by sweeps staged to exit before the trouble spot at 8,430'. Drive by RAtag, +11', Jog 5", continue out of hole on wiper trip. 1/25/2019 1/2512019 1.70 PROD1 DRILL TRIP P Tag up, reset counters, RBIH. 72.0 6,655.0 13:33 15:15 14:24 - 4452', slowed running speed to - 27 ft/min possible bonitron issues. Continued in hole. 1/25/2019 1/25/2019 0.20 PRODI DRILL DLOG P Tie into the Ki for a+l l'correction. 6,655.0 6,994.0 15:15 15:27 1/25/2019 1/25/2019 0.20 PROD1 DRILL DLOG P Park at 6999' MD/ 6516' TVD Trap 6,994.0 6,999.8 15:27 15:39 11.8 EMW, 4015 psi and observe pressure fall to 3782 psi in 4 minutes, back on the pump. BHP less than 11.16 ppg EMW PU Wt 40 k lbs 1/25/2019 1/252019 3.00 PROD1 DRILL TRIP P RIH, window clean, confirmed TD 6,999.8 9,243.0 15:39 18:39 9,243', completed building Liner Running pill 12512019 125/2019 1.87 PRODI DRILL TRIP P POOH, laying in beaded 11.8 ppg 9,243.0 78.2 18:39 20:31 LRP, painting EDP flags at 7,160' (yellow), and 4,800' (white) 1/25/2019 1/25/2019 0.50 PRODI DRILL PULD P At surface, check well for flow, PJSM 78.2 78.2 20:31 21:01 1/2512019 1/25/2619 0.75 PRODI DRILL PULD P LD drilling BHA on a dead well. 78.2 0.0 21:01 21:46 1/252019 1/2512019 0.30 COMPZI CASING PUTB P RU RF for liner ops, Crew Change, 0.0 0.0 21:46 22:04 PJSM 1125/2019 1/262019 1.93 COMPZI CASING P PU A Lateral 2-3/8" slotted liner0.0 1,188.8 22:04 00:00 713 completion 40 joints and 7.47' pup joint Page 14122 Report Printed: 2128/2019 Operations Summary (with Timeiog Depths) IB -16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stall Tune End Time D Dur (hr) Phase Op Gatle Activity Code Tim P -T -X Operation (flKB) End Depth (ftK8) 1/26/2019 1/26/2019 0.75 COMPZ1 CASING PUTB P Continue PU A slotted 2-3/8" liner 1,188.8 2,015.7 00:00 00:45 completion (28 jts) 1/26/2019 1/26/2019 0.50 COMM CASING PUTS P RD, liner equipment, PJSM 2,015.7 2,015.7 00:45 01:15 1/26/2019 1/26/2019 0.75 COMPZ1 CASING PULD P PU/MU CoilTrak tools, roll cart 2,015.7 2,077.1 01:15 02:00 forward, MU tools, perform surface test (good -test) 1/26/2019 1/26/2019 1.00 COMPZ1 CASING RUNL P RIH, w/A liner assembly 2,077.1 6,878.7 02:00 03:00 1/26/2019 1/26/2019 0.15 COMM CASING RUNL P Correct to the EOP flag correct minus 6,878.7 6,877.1 03:00 03:09 1.6', PUW 40 k CTSW, minus 5.Ok DHWOB 1/26/2019 1/26/2019 1.00 COMPZ1 CASING RUNL P Continue IH, Work pipe towards 6,877.1 8,599.0 03:09 04:09 bottom, set down 8,599' PUW 55k, 8,620' PUW 54k, 8,939' PUW 50k, 9,053' PUW 55k, 9,132' PUW 55k, continued IH, setting down on bottom 9,243', bring pump up to 1.5 bpm 4,366 psi, 1,265 psi diff, PUW 38k, remove liner length from counters 1/26/2019 1/26/2019 1.40 COMPZ1 CASING TRIP P POOH 8,599.0 72.0 04:09 05:33 1/26/2019 1/26/2019 1.40 COMPZ1 CASING TRIP P LD BH# 8, A lateral completion 72.0 0.0 05:33 06:57 running BHA over a dead well. 1/26/2019 1/26/2019 0.50 PROD2 STK BOPE P Performe BOPE Function test - good. 0.0 0.0 06:57 07:27 1/26/2019 1/26/2019 0.50 PROD2 STK PULD P Pick up BHA#9, AL1 KO / turn drilling 0.0 72.0 07:27 07:57 assembly, install checks, check pack offs- good. 1/26/2019 1/26/2019 1.00 PROD2 STK PULD T Attempt to open EDC, error message, 0.0 72.0 07:57 08:57 Pop off, swap top coil track, stab injector, bump up. 1/26/2019 1/26/2019 1.20 PROD2 STK PULD P RIH 72.0 6,650.0 08:57 10:09 1/26/2019 1/26/2019 0.20 PROD2 STK DLOG P Tie in for a +4' correction. 6,650.0 6,678.0 10:09 10:21 1/26/2019 1/26/2019 1.20 PROD2 STK DISP P Continue to displace tubing an well to 6,678.0 6,993.0 10:21 11:33 drilling fluid. PU Wt 34 ME, Close EDC. 1/26/2019 1/26/2019 0.10 PROD2 STK TRIP P Continue in hole, window clean, dry 6,993.0 7,205.5 11:33 11:39 tag TOB @ 7,205' 1/26/2019 1/26/2019 2.40 PROD2 STK KOST P PU Wt 37 k lbs, CT 4600 psi @ 1.88 in 7,205.5 7,208.0 11:39 14:03 XX bpm out, delta P 580 psi, BHP 4130 psi, 11.8 ppg EMW, WH 520 psi, IA483 psi, OA7 psi. CT RIH Wt 20 k lbs, WOB and motor work 7205.5' start timed side track from liner top billet. V@ 1 ft/hr, V@ 2 ft/hr - Stall @ 7207', PU 39 k lbs. RESET, Delta P 472 psi, RBIH and restart 7206.8' V@3 ftlhr 1/26/2019 1/26/2019 1.60 PROD2 DRILL DRLG P Drilling ahead. 7,208.0 7,460.0 14:03 15:39 CT 4648 psi, 1.85 bpm in 1.83 bpm, annular 4137 psi, Ct Wt 17 k lbs, WOB 1.75 k lbs, drill to 7305' PU 40 klbs, RBIH, dry drift billet - dean. ROP 158 ft/hr, 1/26/2019 1/26/2019 1.10 PROD2 DRILL TRIP P TD tum, PU Wt 40 k lbs, POOH 7,460.0 72.0 15:39 16:45 1/26/2019 1/26/2019 1.92 PROD2 DRILL PULD P PUD BHA #9. 72.0 0.0 16:45 18:40 Page 16122 ReportPrinted: 2/28/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code AaA Jty Code Tme RT -X Operation (W13) End De" (W13) 1/26/2019 1/26/2019 0.17 PROD2 DRILL PULD P Reconfigure BHA 0.0 0.0 18:40 18:50 1/26/2019 1/26/2019 1.10 PROD2 DRILL PULD P PD Lateral Drilling Assembly BHA #10 0.0 78.3 18:50 19:56 1/26/2019 1/26/2019 1.20 PROD2 DRILL TRIP P Tag up re -set counter depths, inspect 78.3 6,678.6 19:56 21:08 pac-offs, RIH, surface test agitator (good -test) 1/26/2019 1/26/2019 0.20 PROD2 DRILL DLOG P Log the K1 marker correction of plus 6,678.6 6,680.6 21:08 21:20 1 1 2.0' 1/26/2019 1/26/2019 0.60 PROD2 DRILL TRIP P Continue IH 6,680.6 7,460.0 21:20 21:56 1/26/2019 1/26/2019 0.20 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 4,681 psi, 7,460.0 7,487.0 21:56 2208 Diff=800 psi, WHP=541, BHP=4,527, IA=563, OA=15 `"` Note: New mud system #2 at the bit 7,465' 1/26/2019 1/26/2019 0.20 PROD2 DRILL WPRT P Plug off choke, PUH 35 k, line up to 7,487.0 7,487.0 22:08 22:20 choke "B" 1/26/2019 1/26/2019 0.20 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 4,292 psi, 7,487.0 7,527.0 22:20 22:32 Diff --4,175 psi, WHP=683, BHP=4,193, IA=538, OA=15 1/26/2019 1/26/2019 0.15 PROD2 DRILL WPRT P PUH, PUW 41 k, Mud system #2 at 7,527.0 7,527.0 22:32 22:41 surface, obtain new pump parameters. 1/26/2019 1/27/2019 1.32 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 4,325 psi, 7,527.0 7,822.0 22:41 00:00 Diff ---882, WHP=721, BHP=4,175, IA=533, 0A=15 1/27/2019 1/27/2019 0.75 PROD2 DRILL DRLG P OBD, 1.9 bpm at4,341 psi, Diff --900, 7,822.0 7,860.0 00:00 00:45 WHP=730, BHP=4,165. IA=508, OA=18 1/27/2019 1/27/2019 0.20 PROD2 DRILL WPRT P 820', wiper up to the bottom of the 7,860.0 7,020.0 00:45 00:57 billet, PUW 41 k 1/27/2019 1/27/2019 0.15 PROD2 DRILL WPRT P Wiper back in hole, RIW 7,020.0 7,860.0 00:57 01:06 1/27/2019 1/27/2019 0.90 PROD2 DRILL DRLG P OBD, 1.91 bpm at 4,385 psi, 7,860.0 8,003.0 01:06 02:00 Diff -4,141, WHP=732, BHP=4,144, A=548, 0A=1 6, DD unable to drop in section, PU and set back down 5 times to initiate drop. Continue Drilling ahead. Note: Fault Crossing Q 7,940' 1/27/2019 1/27/2019 0.50 PROD2 DRILL DRLG P OBD, 1.88 bpm at 4,385 psi, Diff=864, 8,003.0 8,060.0 02:00 02:30 WHP=714, BHP=4,186, IA=548, OA=16 1/27/2019 1/27/2019 0.42 PROD2 DRILL WPRT P Geo wiper up hole, PUW 42 k 8,060.0 8,060.0 02:30 02:55 1/27/2019 1/27/2019 0.65 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 4,432 psi, 8,060.0 8,176.0 02:55 03:34 Diff -900, WHP=701, BHP=4,149, IA=632, OA=16 1/27/2019 1/27/2019 0.15 PROD2 DRILL WPRT P Stacking weight, PUH and restarrt, 8,176.0 8,176.0 03:34 03:43 1 1 IPLIW 38 k 1/27/2019 1/27/2019 0.15 PROD2 DRILL DRLG P BOBD, 1.91 bpm at 4,740 psi, 8,176.0 8,196.0 03:43 03:52 Diff -1, 100 psi, WHP=707, BHP=4,176, IA=649, OA=16 1/27/2019 1/27/2019 0.15 PROD2 DRILL WPRT P Stacking weight, PUH and restart, 8,196.0 8,196.0 03:52 04:01 PUW 48k 1/27/2019 1/27/2019 0.20 PROD2 DRILL DRLG P BOBD, 1.91 bpm at 4,740 psi, 8,196.0 8,260.0 04:01 04:13 Diff=1,100 psi, WHP=707, BHP=4,176, IA=649, 0A=16 1/27/2019 1/27/2019 0.30 PROD2 DRILL WPRT P Wiper to the EOB, PUW 38 k 6,260.0 7,460.0 04:13 04:31 Page 16122 Report Printed: 2128/2019 Operations Summary (with Timelog Depths) IB-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth startiim End In" our(h) Phase Op Code Activity Code Time P-T-X OpereGon (ftKB) End Depth(IIKB) 1/27/2019 1/27/2019 0.25 PROM DRILL WPRT P Wiper back in hole, RIW 15 k 7,460.0 8,260.0 04:31 04:46 1/27/2019 1/27/2019 2.10 PROD2 DRILL DRLG P BOBD, 1.91 bpm at 4,736 psi, 8,260.0 8,425.0 04:46 06:52 Diff=1,226 psi, WHP=723, BHP=4,143, IA=679, 0A=11 1/27/2019 1/27/2019 1.00 PROD2 DRILL WPRT P PU Wt 43 k lbs, PUH on early long 8,425.0 6,546.0 06:52 07:52 wiper to the K1 for tie in. Cahsed 5x5 off bottom, jogged below build @ 7460' to allow second sweep out. Chase out of hole. 1/27/2019 1/27/2019 0.10 PROD2 DRILL DLOG P Tie into the Kl for a +3.5' correction 6,546.0 6,573.0 07:52 07:58 1/27/2019 1/27/2019 0.70 PROD2 DRILL WPRT P RBIH, window and billet clean, WOB 6,573.0 8,406.0 07:58 08:40 spikes around 7960-800'. Was oriented low side though. 1/27/2019 1/27/2019 0.70 PROD2 DRILL DRLG P SID 8406, PU 43 k lbs, RBIH work 8,406.0 8,506.0 08:40 09:22 through trouble spot -150 API gamma, with reduced pump rate 1.5 bpm. Drill ahead, CT 4609 psi, 1.9 bpm in, 1.9 bpm out, BHP 4167 psi, WH 700 psi, CT 4.8 k lbs, WOB 1.3 k lbs 127/2019 1/27/2019 0.80 PROD2 DRILL WPRT P PU Wt 45 k lbs, Pull above trouble 8,506.0 8,506.0 09:22 10:10 spot, turn around at 8380', RBIH. some WOB spikes, Running past trouble spot @ 1.5 bpm and 30 ft/min 1/27/2019 1/27/2019 0.90 PROD2 DRILL DRLG P CT 4516 psi @ 1.87 bpm in nd 1.84 8,506.0 8,540.0 10:10 11:04 bpm out, dela P 866 psi, BHP 4165 psi - 11.8 ppg EMW at the window. Ct Wt 3.6 k lbs, WOB 2.1 k lbs, ROP 90 1/27/2019 127/2019 0.30 PROD2 DRILL DRLG P CT 4516 psi @ 1.87 bpm in and 1.83 8,540.0 8,553.0 11:04 11:22 bpm out, delta P 839 psi, BHP 4131 psi - 11.8 ppg EMW at the window. Ct Wt 2 k lbs, WOB 0.87 k lbs, ROP 110 PU W146 k lbs, Pull above trouble spot, tum around at 8443', RBIH. WOB spikes, stack some coil Wt @ 8470'. Running past trouble spot @ 1.5 bpm and 30 ft/min 1272019 1/27/2019 0.30 PROD2 DRILL WPRT P Struggle to get restarted, PU 47 k lbs, 8,553.0 7,490.0 11:22 11:40 drug up to 50 k lbs, Short time on bottom until pick up required, PUH on wiper, pump 5x5 Ct Wt 40 to 36 k lbs. 1/27/2019 1/27/2019 0.20 PROD2 DRILL WPRT P RBIH, 2.8 k lbs WOB spike @ 8438', 7,490.0 8,553.0 11:40 11:52 bounced through. 1/27/2019 1/272019 1.90 PROD2 DRILL DRLG P CT 4540 psi @ 1.90 bpm in and 1.83 8,553.0 8,633.0 11:52 13:46 bpm out, delta P 1000 psi, BHP 4162 psi - 11.8 ppg EMW at the window. Ct Wt k lbs, WOB 0.87 k lbs, ROP 110 1/27/2019 1/27/2019 0.20 PROD2 DRILL WPRT P Geo wiper after sudden drop in 8,633.0 8,633.0 13:46 13:58 gamma @ 8599'. RBIH, WOB spikes @ 8410' and 8513' 1/27/2019 1/27/2019 4.50 PROD2 DRILL DRLG P C14479 psi @ 1.9 bpm in 1.90 bpm 8,633.0 8,886.0 13:58 18:28 out, delta P 846 psi, BHP 4195 psi, CT W12.1 k lbs, WOB 1.6 k lbs. Reaquire the A4 pay @ 8780'. Pump 54 sweep. 1/27/2019 1/27/2019 0.40 PROD2 DRILL WPRT P Chase sweeps out of hole on 1000' 8,886.0 7,876.0 18:28 1852 wiper #2 PU 42 k Ibs @ 8570' pull into 53 k CT Wt, -6 k lbs WOB. RIH SID 2 k WOB, PU, 4 k continue to PUH. more minor neg MOB spikes @ 8460'. Page 17/22 Report Printed: 212812019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Time Dur (hn Phase Op Code Activity Code Tame P -T -X Operation (ftKB) End Depth (WB) 1/27/2019 1/27/2019 1.30 PROM DRILL WPRT P RBH, Start spiking WOB @ 8400', 7,876.0 8,811.0 18:52 20:10 8480', 84981, 8522, and multiple limes at 8,550'. PU weights 46k lbs. Reduce rale to 1.2 bpm ran through. Stuggled again up to 8764'. 1/27/2019 1/27/2019 1.60 PROM DRILL WPRT P PU, 46, pump 10 bbl High vis, PUH, 8,811.0 8,370.0 20:10 21:46 pulling heavy and packing off, pulled above trouble zones 8400'. Small amount of gas a the shaker from pack off event. launch 5x5, consult w town engineering.clean out to 8370' chase sweeps up hole. 1/27/2019 1/27/2019 1.25 PROM DRILL WPRT T PUH chasing sweeps out of the well. 8,370.0 78.2 21:46 23:01 Billet and window dean. Large unload of cuttings, flakes of sift and metal. 1/27/2019 1/28/2019 0.99 PROD2 DRILL PULD T At surface, PUD drilling BHA#10 78.2 0.0 23:01 00:00 1/28/2019 1/28/2019 0.25 PROD2 DRILL PULD T Continue PUD drilling BHA 0.0 0.0 00:00 00:15 1/28/2019 1/28/2019 0.30 PROD2 DRILL PULD T Reconfigure BHA 0.0 0.0 00:15 00:33 1/28/2019 1/28/2019 1.00 PROD2 STK PULD T PD Open Hole Anchored Billet 0.0 72.7 00:33 01:33 1/28/2019 1/28/2019 1.50 PROD2 STK TRIP T RIH, w/Open Hole Anchored Billet 72.7 6,655.0 01:33 03:03 BHA#11, 80 fpm as per BOT rep. 1/28/2019 1/28/2019 0.20 PROD2 STK DLOG T Log the K1 marker plus 3.0' 6,655.0 6,678.0 03:03 03:15 1/28/2019 1/28/2019 0.80 PROD2 STK TRIP T Continue IH 6,678.0 8,161.8 03:15 04:03 1/28/2019 1/28/2019 0.15 PROD2 STK WPST T PUW 39 k, RBIH to setting depth, 8,161.7 8,150.0 04:03 04:12 PUH to neutral weight, bring pump on line 1.3 bpm to shear 4,800 psi, set down 5.0 k, PUH, PUW 35 k 1/28/2019 1/28/2019 1.50 PROM STK TRIP T POOH, following MP 8,150.0 72.7 04:12 05:42 1/28/2019 1/28/2019 1.20 PROD2 STK PULD T PUD, setting tools 72.7 0.0 05:42 06:54 1/28/2019 1/28/2019 1.20 PROD2 STK PULD T PD, kickoff/drilling assembly, surface 0.0 78.3 06:54 08:06 test CoilTrak tools (good -test) 1/28/2019 1/28/2019 1.40 PROD2 STK TRIP T Tag up, reset counters, RIH w/Drilling 78.3 6,655.0 08:06 09:30 BHA#12 1/28/2019 1/28/2019 0.20 PROD2 STK DLOG T Log the K1 marker correction of plus 6,655.0 6,675.0 09:30 09:42 2.0' 1/28/2019 1/28/2019 0.50 PROD2 STK TRIP T Continue IH, close EDC, PUW 39 k 6,675.0 8,150.0 09:42 10:12 1/28/2019 1/28/2019 0.30 PROD2 STK TRIP T Dry drift billet @ 8,150' 8,150.0 8,150.0 10:12 10:30 1/28/2019 1/28/2019 3.80 PROD2 STK KOST T PUH, bring pump on-line 1.89 bpm at 8,150.0 8,153.0 10:30 14:18 4,717 psi, Diff=1,135 psi ,WHP=643, BHP=4,186, IA=398, OA=8, time mill off billet 3.0' 1/28/2019 1/28/2019 1.00 PROD2 DRILL DRLG T Drill ahead, 1.89 bpm at 4,717 psi, 8,153.0 8,257.0 14:18 15:18 Diff -1,050 psi ,WHP=643, BHP=4,186, IA=398, OA=8 1/28/2019 1/28/2019 0.20 PROD2 DRILL WPRT T PUH to drift window area (clean), 8,257.0 8,257.0 15:18 15:30 RBIH 1/28/2019 1/28/2019 1.80 PROD2 DRILL DRLG T Drill ahead, 1.87 bpm at 4,717 psi, 8,257.0 8,550.0 15:30 17:18 Diff -1,050 psi ,WHP=625, BHP=4,173, IA=756, OA=8 1/28/2019 1/28/2019 0.90 PROM DRILL WPRT T 8550', Wiper trip to 7488, PUW=42K 8,550.0 8,550.0 17:18 18:12 Page 18122 Report Printed: 212812019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P-T-X Operation (RKB) End Dept (RKB) 1/28/2019 1/28/2019 2.70 PROD2 DRILL DRLG T 8550', Drill, 1.87 BPM @ 469OPSI FS, 8,550.0 8,840.0 18:12 20:54 BHP=4235 1/28/2019 1/28/2019 0.10 PROD2 DRILL WPRT T 8840', BHA Wiper, PUW=45K 8,840.0 8,840.0 20:54 21:00 1/28/2019 1/28/2019 0.20 PROD2 DRILL DRLG T 8840', Drill, 1.87 BPM @ 4690 PSI 8,840.0 8,886.0 21:00 21:12 FS, BHP=4225 1/28/2019 1/28/2019 0.70 PROM DRILL DRLG P 8886. reached TO before billet, Off T 8,886.0 8,950.0 21:12 21:54 1 1 time 1/28/2019 1/28/2019 0.70 PROM DRILL WPRT P Wiper to billet @8150, PUW=43K 8,950.0 8,950.0 21:54 22:36 1/28/2019 1/2912019 1.40 PROD2 DRILL DRLG P 8950', drill, 1.88 BPM @ 4320 PSI FS, 8,950.0 9,114.0 22:36 00:00 BHP=4200, New mud at bit 9012'. Old system out @ 2288' drilled, 0.85% drill solids 1/29/2019 1/29/2019 3.50 PROD2 DRILL DRLG P 9114', Drill, 1.89 BPM @ 4320 PSI FS, 9,114.0 9,310.0 00:00 03:30 BHP=4180 1/29/2019 1/29/2019 0.10 PROD2 DRILL WPRT P BHA Wiper, PUW=49K 9,310.0 9,310.0 03:30 0336 1/29/2019 1/29/2019 0.30 PROD2 DRILL DRLG P 9310', Drill, 1.85 BPM @ 4360 PSI 9,310.0 9,350.0 03:36 03:54 FS, BHP=4150 1/29/2019 1/29/2019 1.20 PROD2 DRILL WPRT P Wiper trip to window with 5 X 5 9,350.0 7,035.0 03:54 05:06 sweeps, PUW=48K 1/29/2019 1/29/2019 0.20 PROD2 DRILL DLOG P Log the RA marker correction of plus 7,035.0 7,060.0 05:06 05:18 7.0' 1/29/2019 1/29/2019 1.20 PROD2 DRILL WPRT P Continue wiper back in hole, set down 7,060.0 9,350.0 05:18 06:30 9,122', PUH lowered pump rate 1.2 bpm, continued IH 1129/2019 1/29/2019 2.20 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 4,636 psi, 9,350.0 9,650.0 06:30 08:42 Diff--964, WHP=964, BHP=4,302, IA=424, OA=5, started lossing -24 bbVhr 1/29/2019 1129/2019 0.60 PROM DRILL WPRT P 1000', wiper up hole, PUW 48 k 9,650.0 8,650.0 08:42 09:18 1/29/2019 1/29/2019 1.00 PROD2 DRILL WPRT P Wiper back in hole, set down x 3 @ 8,650.0 9,650.0 09:18 10:18 9,157', and 9,249', lower pump rate to 1.2 bpm made it through 1/29/2019 1/29/2019 1.15 PROM DRILL DRLG P BOBD, 1.89 bpm at 4,693 psi, 9,650.0 9,694.0 10:18 11:27 Diff-938, WHP=635, BHP 4,693, IA=407, OA=5 1/29/2019 1/2912019 3.30 PROD2 DRILL WPRT P TO called early, pump 10x10 sweep, 9,694.0 78.3 11:27 14:45 chase sweeps to surface, performing og from 1/29/2019 1/29/2019 0.20 PROD2 DRILL TRIP P Tag up, reset counters 78.3 78.3 14:45 14:57 1129/2019 1/29/2019 1.10 PROD2 DRILL TRIP P RIH 78.3 6,655.0 14:57 16:03 1/29/2019 1/29/2019 0.20 PROD2 DRILL DLOG P Log the Ki marker correction of plus 6,655.0 6,678.0 16:03 16:15 0.5' 1/29/2019 1/29/2019 0.20 PROD2 DRILL TRIP P Continue IH, perform static pressure 6,678.0 7,010.0 16:15 16:27 surface above window area 1/29/2019 1/29/2019 0.20 PROD2 DRILL TRIP P Perform static pressure surface above 7,010.0 7,010.0 16:27 16:39 window area Sensor depth 6,423.8', Annular pressure 3,762, 11.8 ppg down to 11.1 ppg, PUW 39 k 1/29/2019 1/29/2019 0.30 PROD2 DRILL TRIP P Continue IH, set down x 3 @ 9,112', 7,010.0 7,112.0 16:39 16:57 PUH to log the Ki 1/29/2019 1/29/2019 0.20 PROD2 DRILL TRIP P PUH, to log the Kt 7,112.0 6,655.0 16:57 17:09 1/29/2019 1/29/2019 0.20 PROD2 DRILL DLOG P Log the K1 correction plus 0.5', 6,655.0 6,677.0 17:09 1721 Page 19122 Report Printed: 2/2812019 Operations Summary (with Timelog Depths) 113-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Start Time End Tme our hr ( ) Phase OP Catla Activity Catle Tim P -T -X Operetion (NDB) End Depen (WS) 1/29/2019 1/29/2019 1.10 PROD2 DRILL TRIP P POOH 6,677.0 92.0 17:21 18:27 1/29/2019 1/29/2019 1.50 PROD2 DRILL PULD P At surface, Tag up and space out, 92.0 0.0 18:27 19:57 PUD BHA#12, Lay down tools.Bit out @ 1-1. Change motor AKO from 1 to 1.25° 1/29/2019 1/29/2019 0.90 PROD2 DRILL PULD T PD BHA#13 with D-331 mill, 1.25° 0.0 68.4 19:57 20:51 AKO motor, no USR. Make up o coiltrak and surface test 1/29/2019 1/29/2019 1.40 PROD2 DRILL TRIP T RIH BHA #13, Surface test agititalor 68.4 6,650.0 20:51 22:15 1/29/2019 1/29/2019 0.10 PROD2 DRILL DLOG T Log K1 for+1 foot correction 6,650.0 6,677.0 22:15 2221 1/29/2019 1/29/2019 0.20 PROD2 DRILL TRIP T Continue in hole. Clean pass through 6,677.0 7,112.0 22:21 22:33 window. Dry tag @ 7112. PUH 1/29/2019 1/29/2019 0.10 PROW DRILL REAM T PUH to 7100, Bring on pumps 1.9 7,112.0 7,114.0 22:33 22:39 BPM @ 4761 PSI FS. Start working down @ 1 FPM. Start sweeps down CTSee motor work and WOB @ 7112. Start to speed up @ 7114. Stall motor 1/29/2019 1/29/2019 0.50 PROD2 DRILL REAM T PUH ater stall, restart. See torque and 7,114.0 7,180.0 22:39 23:09 vibration @ 7111. Maintain reaming @ - 1.5 FPM to 7120 then go to 5 FPM down to 7140. Recip up at 1.86 BPM up to 7098. Initial sweeps at shaker. Nothing coming across shaker. RBIH to 7180 mostly clean at higher speed 1/29/2019 1/29/2019 0.70 PROD2 DRILL REAM T PUH to 7097. Turn around clean trip 7,180.0 7,180.0 23:09 23:51 down. To 7180. Pump another seris of sweeps and recip area. Little to no material on shaker 1/29/2019 1/30/2019 0.15 PROD2 DRILL REAM T 7180, Line up to go past billet @ 7205. 7,180.0 7,194.0 23:51 00:00 Stack ou @ 7188 when we reduced rate to pass billet. PUH to 7166. 1/30/2019 1/30/2019 1.10 PROD2 DRILL TRIP T Run in hole, set down @ 8668' work 7,194.0 8,682.0 00:00 01:06 pipe down o 8682 1/30/2019 1/30/2019 0.80 PROD2 DRILL TRIP T Pump Sweeps, PUH to 8177, 8,682.0 8,177.0 01:06 01:54 PUW=45K 1/30/2019 1/30/2019 0.20 PROD2 DRILL TRIP T RBIH, 1.5 BPM set down @ 8704 8,177.0 8,735.0 01:54 02:06 work to 8735 1/30/2019 1/30/2019 0.10 PROD2 DRILL TRIP T 8735, PUH to 8590, 1.8 BPM 8,735.0 8,590.0 02:06 02:12 1/30/2019 1/30/2019 0.10 PROD2 DRILL TRIP T 8590 RBIH, 1.5 BPM @ 8783 set 8,590.0 8,783.0 02:12 02:18 down. 1/30/2019 1/30/2019 0.10 PROD2 DRILL TRIP T 8783', PUH to 8570, 1.8 BPM, 8,783.0 8,570.0 02:18 02:24 PUW=46K 1/30/2019 1/30/2019 0.20 PROD2 DRILL TRIP T 8570', RIH to setdown @9088', 1 8,570.0 9,088.0 02:24 0236 BPM, Choppy going 1/30/2019 1/30/2019 0.10 PROD2 DRILL TRIP T 9088', PUH, PUW=44K, 1.8 BPM 9,088.0 8,970.0 02:36 02:42 1/30/2019 1/30/2019 1.20 PROD2 DRILL TRIP T 8970, RBIH to 9157' recip 3 times. 8,970.0 9,157.0 02:42 03:54 1 Hard setdowns 1/30/2019 1/3072019 0.40 PROD2 DRILL TRIP T 9157. Get through 9157 at redused 9,157.0 9,693.0 03:54 04:18 rate 1/30/2019 1/30/2019 0.60 PROD2 DRILL TRIP T 9693, PUH slowly waiting on sweeps, 9,693.0 7,010.0 04:18 04:54 Continue up hole, Poor hole conditions @ 9290 up to 9050 with overpulls some with negaive WOB. Max pull 60K. Hard to get running back in hole. Cleared up above 9000' 1/3012019 1/30/2019 2.75 PROD2 DRILL WPRT T Jog the 5" with multiple sweeps 7,010.0 6,850.0 04:54 07:39 Page 20/22 Report Printed: 2128120191 - Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur (hr) Phase Op Cage AQivity Code Time P-T-X Operation Sten Depth (MKS) End Depth (MKB) 1/30/2019 1/30/2019 0.30 PROD2 DRILL TRIP T RIH, to logging depth 6,650.0 6,655.0 07:39 07:57 1/30/2019 1/30/2019 0.20 PROD2 DRILL DLOG P Log the Kt marker correction of plus 6,655.0 6,683.0 07:57 08:09 7.5' 1/30/2019 1/30/2019 1.00 PROD2 DRILL TRIP P RIH, through window (clean), continue 6,683.0 9,071.0 08:09 09:09 RIH to 9,070' 1/30/2019 1/30/2019 0.75 PRO02 DRILL CIRC P Send 11.8 ppg completion fluid down 9,071.0 9,071.0 09:09 0954 1 coil 1/30/2019 1/30/2019 2.00 PROD2 DRILL TRIP P POOH, laying in beaded liner running 9,071.0 68.0 09:54 11:54 pill, painting EOP flags, liner pill up into tuing @ 5,400' 1/30/2019 1/30/2019 0.50 PROD2 DRILL PULD P At surface check well for flow. 68.0 68.0 11:54 12:24 1/30/2019 1/30/2019 0.60 PROD2 DRILL PULD P LD cleanout BHA#13 66.0 0.0 12:24 13:00 1/30/2019 1/30/2019 0.50 COMPZ2 CASING PUTS P Prep RF for iner ops 0.0 0.0 13:00 13:30 1/30/2019 1/30/2019 2.65 PROD2 CASING PUTB P PU/MU slotted liner (68 jts) 0.0 1,971.2 13:30 16:09 1/30/2019 1/30/2019 0.60 PROD2 CASING PUTB P PU/MU solid liner (13 jts) 1,971.2 2,373.0 16:09 16:45 1/30/2019 1/30/2019 1.10 PROD2 CASING PULD P PU/MU CoilTrak tools. M/U to coil and 2,373.0 2,425.2 16:45 17:51 perform surface test (good-test). Check packoffs. Change out checks in UQC. 1/30/2019 1/30/2019 1.00 PROD2 CASING RUNL P RIH, w/AL1 liner completion 2,425.2 6,931.0 17:51 18:51 1/30/2019 1/30/2019 0.10 PROD2 CASING DLOG P Correct to flag for-5.55', PUW=45K 6,931.0 6,925.0 18:51 18:57 1/30/2019 1/30/2019 0.80 PROD2 CASING RUNL P Continue in hole,Clean through 6,925.0 9,069.6 18:57 19:45 window. Set down @ 8792 then run to set depth 1/30/2019 1/30/2019 0.10 PROD2 CASING RUNL P At set depth. Pumps on 1.5 BPM, 9,069.6 6,674.0 19:45 19:51 PUW=34K PUH to 9055 and remove liner length left in hole. Open EDC 1/30/2019 1/30/2019 3.30 DEMOB WELLPR WAIT T Waiting on seawater, Static 6,674.0 6,674.0 19:51 23:09 BHP=3689 PSI, Sensor depth 6660', TVD 6135' 1/30/2019 1/31/2019 0.85 DEMOB WELLPR TRIP P Circulate seawaer down coil. Displace 6,674.0 6,100.0 23:09 00:00 well to seawater, start out of hole 1/31/2019 1/31/2019 1.80 DEMOB WELLPR TRIP P Continue trip out, Freeze protect well 6,100.0 41.2 00:00 01:48 with 30 BBIs diesel 1/31/2019 1/31/2019 1.30 DEMOB WELLPR PULD P Tag up and space out, PJSM, PUD 41.2 0.0 01:48 03:06 BHA# 13, Lay down tools, FSITP=620 PSI 1/31/2019 1/31/2019 1.00 DEMOB WELLPR CIRC P Stab on injector, Displace CT back to 0.0 0.0 03:06 04:06 WMud 1/31/2019 1/31/2019 0.50 DEMOB WELLPR CIRC P Drilling WMud around, start takeing 0.0 0.0 04:06 04:36 baseline pressures .5 BPM @ 830 PSI, 1 BPM @ 1280 PSI, 1.5 BPM @ 1940 PSI, 1.75 BPM @ 2320 PSI, 2 BPM @ 2780 PSI, 2.25 BPM @ 3250 PSI, 2.5 BPM @ 3710 PSI, 2.75 BPM @ 4250 PSI, 3 BPM @ 4920. Unstab to make up NS liner release tool 1/31/2019 1/31/2019 0.20 DEMOB WELLPR CIRC P PJSM, M/U NS release tool and stab 0.0 0.0 04:36 04:48 back on well Page 21/22 Report Printed: 2/28/2019 Operations Summary (with Timelog Depths) 113-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime End Time our(hd Phase Op Corte Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 1/31/2019 1/31/2019 1.50 DEMOB WELLPR CIRC P Start Flow tests with tool on. .5 BPM 0.0 0.0 04:48 06:18 @ 950 PSI, 1 BPM @ 2000 PSI, 1.5 BPM @ 3700 PSI, Heard tool shift @ 1.73 BPM. unstab injector to verify. Tool has shifted. Test over. Lay down tool 1/31/2019 1/31/2019 6.00 DEMOB MOVE DMOB P Work on rig move check list, 0.0 0.0 06:18 1218 disconnect tiger tank line, remove fluid from tank, call out DTH to move tiger tank, remove all fluids and clean pits. 1/31/2019 1/31/2019 3.70 DEMOB MOVE DMOB P Proactively change out lower blind 0.0 0.0 12:18 16:00 shear rams, remove 4-1/16" valves and installed blind flange onto well. 1/31/2019 1/31/2019 0.00 DEMOB MOVE DMOB P RIG RELEASE @ 1600 furs, standby 0.0 0.0 16:00 16:00 for trucks Page 22122 Report Printed: 2/28/2019 BA EROQ FUGHES PRINT DISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1B -16A FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider�hes com STATUS Final COMPANY 2 18 155 3041 7 se sign and return one copy of this transmittal form to: ocoPhillips Alaska, Inc. I Osterkamp (WNS Petroleum Technician) G Street. horage, Alaska 99510 LOG TYPE GR - RES LOG DATE January 25, 2019 TODAYS DATE February 26, 2019 Revision Replacement: No Details: ADDRESS (FEDEX WILL NOT OELI9ER TO P.O. BOX) PERSON ATTENTION V 1 BP North Slope. EOA, PBOC. PRB-20 (Office 109) D&G WO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage. Alaska 99508 Requested by: --- FIELD I FINALCD/DVD Attn: Ricky Elgarico FINAL ATO 708 PRELIM LOGS chis, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) 3201 C Street, Suite 505 # OF PRINTS Anchorage, AK 99503 # OF COPIES J#OFCOPIES # OF COPIES 4 4 4 4 IG 4 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 C Street Anchorage, AK 99510 FEBB 2 8 2019 3 ExxonMobil, Alaska Attn: Lynda M. Vaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska -AOGCC 1 1 Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas *** 1 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 -"Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, IR2-1 900 E. Benson Blvd ,Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 BATER a GE company Date: February 25, 2019 Abby Bell AOGCC 333 West 71h Ave, Suite 100 Anchorage, Alaska 99501 X19155 30404 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 1B -16A 1B-16ALlPB1 1B-16AL1 RECEIVED FEB 2 6 2019 AOGCC (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Harvey Finch, Baker Hughes, Wellplanner Harvey.Finch@BakerHughes.com ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1B Pad 1 B -1 6A 50-029-22457-01 Baker Hughes INTEQ Definitive Survey Report 14 February, 2019 BA ER hUGHES a GE company 30404 ConocoPhillips BAKKl1�GME5 ry.E�wm C0nocoPh111117s Definitive Survey Report Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1B Pad Well: 18-16 Wellbore: 1B -16A Design: 1B -16A Project Kupamk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1B-16 1B-16 @ 102.00usft(1 B-16) 1B-16 @ 102.00usft (1B-16) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor II Well 1B-16 Well Position +N/ -S 0.00 usft Northing: 5,969,646.83 usft Latitude: 70° 19'40.243 N +E/ -W 0.00 usft Easting: 550,195.14usft Longitude: 149" 35'34.518 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1B -16A i Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°I (°I (nT) BGGM2018 2/1/2019 16.78 80.88 57,428 Design 1B -16A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,823.00 I ' Vertical Section: Depth From (TVD) +N/S +El -W Direction _ (usft) (usft) (usft) (1) 102.00 0.00 0.00 210.00 I Survey Program Date 2/13/2019 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 193.59 6,823.00 18-16(1 B-16) MWD MWD -Standard 8/25/2000 7,026.00 7,114.59 10-16A MWD -INC (I B -16A) MWD-INC—ONLY MWD-INC—ONLY—FILLER 1/23/2019 1/23/2019 7,145.11 9.199.05 1B -16A MWD (I B -16A) MWD MWD - Standard 1/23/2019 1/23/2019, 21142019 8:48:06AM Page 2 COMPASS 5000.14 Build 850 ConocoPhillips BA ER ConocoPhillips Definitive Survey Report Vp5� Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kupamk River Unit Site: Kuparuk 1B Pad Well: 1B-16 Wellbore: 1 B -16A Design: 1B -16A Survey��^__. ...�.�. Local Go -ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1B-16 1 B-16 @ 102,00usft (1 B-16) 1 &16 @ 102.00usft (1 B-16) True Minimum Curvature EDT 14 Alaska Production Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 21142019 8 48:06AM Page 3 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc Azi TVD TVDSS •N/ -S iEi-W OLS (usft) V) (1) (usft) (usft) (usft) (usft) Northing Eatift)ng ('1100') Section Survey Tool Name (ft) (( (ft) 6,823.00 21.40 336.64 6,396.34 6,294.34 1,991.70 -1043.79 5,971,63739 549,138.15 0.24 -1,203.03 MWD -INC _ONLY (2) 7,026.00 19.21 337.22 6,586,71 6,484.71 2,056.58 -1,071.41 5,971,695.99 549,110.10 1.08 -1,245.34 MWD -INC _ONLY (2) 7,054.26 24.81 325.80 6,612.91 6,510.91 2,065.78 -1,076.55 5,971,705.16 549,104.90 24.86 -1,250.74 MWD -INC _ONLY (2) 7,084.49 38.97 319.49 6,638.52 6,536.52 2,078.32 -1,086.34 5,971,717.63 549,095,02 48.06 -1,256.70 MWD-INC_ONLY(2) 7,114.59 49.17 315.49 6,660.13 6558.13 2,093.68 -1,100.52 5,971,732.90 549,080.75 35,11 -1,262.92 MWD-INC_ONLY (2) 7,145.11 57.74 312.56 6,678.28 6,576.28 2,110.68 -1,118.15 5,971,749.77 549,06300 29.12 4,268.82 MWD (3) 7,174.95 70.37 308.84 6,691.32 6,589.32 2,128.10 -1,138.48 5,971,76706 549,042.56 43.78 -1,273.75 MWD (3) 7,20527 84.68 306.54 6,697.85 6,595.85 2,146.14 -1,161.85 5,971,784.94 549,019.07 47,77 -1,277.68 MWD (3) 7,235.11 92.46 300.82 6,698.59 6,596.60 2,162.66 -1,186.65 5,971,801.29 548,994.17 32.35 -1,279.59 MWD (3) 7,265.00 91.84 30769 6,697.47 6,595.47 2,179.46 -1,211.32 5,971,817.93 548,969.39 23.06 -1,281.81 MWD (3) 7,295.06 86.81 308.55 6,697.63 6,595.83 2,198.01 -1,234.96 5,971,836.32 548,94562 16.98 -1,286.05 MWO(3) 7,325.25 88.07 294.21 6,699.18 6,597.18 2,213.67 -1,260.64 5,971,851.80 548,919.84 4763 -1,286.78 MWD (3) 7,354.30 95.97 286.18 6,698.16 6,596.16 2,223.68 -1,287.84 5,971,861.63 548,892.58 38.75 -1,281.84 MWD(3) 7,38543 89.45 275.04 6,696.68 6,594.68 2,229.39 -1,318.34 5,971,867.13 548,862.04 4141 -1,271.54 MWD (3) 7,414.77 88.86 259.78 6,697.12 6,595.12 2,228.07 -1,347.56 5,971,865.62 548,832.83 52.04 -1,255.78 MM (3) 7,444]5 87.85 245.08 6,697.98 6,595.98 2,219.05 -1,376.05 5,971,856.41 548,804.41 49.13 -1,233.72 MWD (3) 7,474.17 88.68 230.52 6,698.88 6,596.88 2,203.42 -1,400.87 5,971,840.61 548,779.70 49.55 -1,207.78 MWD(3) 7,509.84 89.26 224.97 6,699.52 6,597.52 2,179.45 -1,427.26 5,971,816.47 548,753.47 15.64 -1,173.83 MWD (3) 7,537.87 90.06 222.60 669969 6,597.69 2,159.21 -1,446.65 5,971,796.11 548,734.22 892 -1,146.61 MWD (3) 7,569.15 91.35 220.22 6,699.30 6,597.30 2,135.76 -1,467.34 5,971,772.51 548,713.69 8.65 -1,115.95 MWD(3) 7,59927 91.44 217.78 6698.57 6,596.57 2,112.36 -1,486.29 5,971,748.99 548,694.90 8.10 -1,086.21 MWD (3) 7,628.90 91.78 214.72 6697.73 6,595.73 2,088.47 -1,503.80 5,971,724.99 548,677.55 10.39 -1,056.77 MWD (3) 7,659.07 94.40 213.17 6,696.11 6,594.11 2,063.49 -1,520.62 5,971,699.90 546660.90 1009 -1,026.72 MWD (3) 7,689.02 94.61 210.21 6,693.76 6,591.76 2,038.08 -1,536.30 5,971,674.39 548,645.39 9.88 -996.88 MWD (3) 7,718.98 94.18 205.36 6,69146 6,589.46 2,011.66 -1,550.22 5,971,647.88 548,631,65 16.20 -%7.04 MM (3) 7,752.95 94.83 202.37 6,688.79 6,58679 1,980.70 -1,563.92 5,971,616.83 548,618.16 8.98 -933.37 MW) (3) 7,784.92 94.67 198.97 6,686.14 6,584.14 1,950.89 -1,575.17 5,971,586.95 548,607.11 10.61 -901.94 MWD (3) 7,823.83 94.92 196.04 6,682.89 6,580.89 1,913.92 -1,586.83 5,971,549.90 548,595.70 7.53 -864.09 MM (3) 7,854.33 95.63 194.20 6,680.08 6,578.08 1,884.60 -1,594.75 5,971,520.54 548,587.98 6.44 -834.74 MWD (3) 7,684.93 93.93 192.11 6677.53 6,575.53 1.854.91 -1,60169 5,971,490.80 548,581.24 8.79 -805.55 MWD (3) Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 21142019 8 48:06AM Page 3 COMPASS 5000.14 Build 850 ConocoPhillips oA E €T FWHES ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit Site: Kupamk 1 B Pad Well: 18-16 Wellbore: 1 B -16A Design: 1B -16A Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1B-16 18-16 @ 102.00usft (18-16) 1 B-16 @ 102.00usn (1 B-16) True Minimum Curvature EDT 14 Alaska Production Annotation 2/142019 8:48.06AM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name (ft) (ft) (ft) 7915.60 90.77 190.10 6,676.28 6,574.28 1,824.84 -1607.59 5,971,460.70 548,575.54 12.21 -776.57 MWD (3) 7,946.77 90.55 186.32 6,675.92 6,573.92 1]99.00 -1,61204 5,971,429.83 548,571.29 12.15 -747.63 MWD (3) 7,975.53 92.64 185.74 6,675.12 6,573.12 1,765.41 -1,615.06 5,971,401.23 548,568.47 7.59 -721.36 MM (3) 8,005.16 91.47 184.69 6,674.05 6,572.05 1,735.93 -1,617.75 5,971,371.73 548,565.97 5.30 694.48 MWD (3) 8,034.50 90.95 187.58 6,673.43 6,571 43 1,706.76 -1,620.88 5,971,342.55 548,563.03 10.01 -667.66 MM (3) 8,064.19 90.98 189.47 6,672.93 6,570.93 1,67741 -1,625.28 5,971,313.16 548,558.83 6.37 640.03 MWD (3) 8,094.20 89.17 190.63 6,672.89 6,570.89 1,647.86 -1,630.52 5,971,283.58 548,553.79 7.16 611.83 MWD(3) 8,124.10 88.68 193.42 6,673.46 6,571.46 1,618.62 -1,636.75 5,971,254.31 548,547.76 9.47 683.39 MWD (3) 8,154.24 88.16 195.20 6,674.29 6,572.29 1,589.43 -1,644.19 5,971,22507 548,540.51 6.15 -554.39 MWD (3) 8,183.96 89.08 198.05 6,675.00 6,573.00 1,560.96 -1,652.69 5,971,196.55 548,532.20 10.07 525.49 MWD (3) 8,214.18 90.15 200.29 6,675.21 6,573.21 1,532.42 -1,662.62 5,971,167.95 548,522.47 8.21 495.81 MWD (3) 8,244.52 91.20 204.39 6,674.85 6,572.85 1,504.37 -1,674.15 5,971,139.82 548,511.13 13.95 465.75 MWD(3) 8,275.31 89.48 205.20 6,674.67 6,572.67 1,476.42 -1,68TW 5,971,111.79 548,498.41 6.17 435.09 MM (3) 8,304.40 86.93 206.36 6,675.56 6,573.56 1,450.24 -1,699.70 5,971,085.52 548,485.94 9.44 406.09 MWD (3) 8,333.86 86.28 203.42 6,67729 6,575.29 1,423.56 -1,712.08 5,971,058.77 548,47374 10.25 -376.80 MWD (3) 8,364.30 86 W 200.13 6,679.11 6,577.11 1,395.35 -1,723.35 5,971,030.49 548,462.66 10.96 -346.74 MWD (3) 8,394.19 89.42 199.66 6,660.08 6,578.08 1,367.26 -1,733.51 5,971,00233 548,45269 8.71 317.33 MWD (3) 8,423.35 89.35 197.07 6,680.40 6,578.40 1,339.59 -1,742.70 5,970,97460 548,44389 8.88 -288.77 MWD (3) 8,453.93 89.97 19364 6,680.58 6,578.58 1,310.11 -1,750.80 5,970,995.07 548,435.79 11.40 -259.19 MM (3) 8,483.81 90.95 190.81 6,680.34 6,578.34 1,280.91 -1,757.12 5,970,915.83 598,429.66 10.02 -230.74 MWD(3) 8,514.31 92.03 190.15 6,679.54 6,577.54 1,250.93 -1,762.67 5,970,885.82 548,424.31 4.15 -202.W MM (3) 8,543.87 9369 189.58 6,678.07 6,576.07 1,221.84 -1,767.73 5,970,856.70 548,419.45 5.94 -174.28 MWD (3) 8,56793 93.41 189.76 6,676.58 6,574.58 1,196.17 -1,771.76 5,970,833.01 548,415.58 1.38 -151.77 MWD (3) 8,600.63 93.90 191.47 6,674.50 6,572.50 1,166.10 -1,777.77 5,970,800.90 548,40978 543 -120.98 MVV) (3) 8,629.93 93.23 193.54 6,672.67 6,570.67 1,137.55 -1,784.10 5,970,77231 548,403.64 7.41 -93.10 MWD (3) 8,658.33 94.71 195.46 6,670.71 6,568.71 1,110.12 -1,791.19 5,970,74484 548,396.73 8.52 65.80 MWD (3) 8,689.55 95.05 198.93 6,668.05 6,566.05 1,080.41 -1,800.39 5,970,715.07 548,387.74 11.13 -35.47 MWD(3) 6,71885 93.04 198.67 6,665.98 6,563.98 1,052.74 -1,809.81 5,970,687.34 548,378.51 6.92 6.80 MWD (3) 8,74385 90.28 199.82 6,66526 6,56326 1,029.15 -1,818.04 5,970,663.70 548,370.43 11.96 17.75 MWD (3) 8,773.49 91A1 203.01 6,664.93 6,562.93 1,001.57 -1,828.86 5,970,636.04 548.359.80 11.04 47.05 MWD (3) 8,808.43 9156 20470 6,664.14 6,562.14 96962 -1,842.99 5,970,60400 548,345.88 5.09 81.78 MWD (3) Annotation 2/142019 8:48.06AM Page 4 COMPASS 5000.14 Build 85D 1; ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well 18-16 Project: Kuparuk River Unit TVD Reference: 18-16 @ 102.00usR (1B-16) 1 Site: Kuparuk 1B Pad MD Reference: 18-16 @ 102.00usR (1 B-16) :Well: 1B-16 North Reference: True Wellbore: 1B -16A Survey Calculation Method; Minimum Curvature Design: 18-16A Database: EDT 14 Alaska Production Survey _ I MD Inc Azl TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (waft) (°I (°) (uaR) (usR) (usR) (usR) Northing Easting V11130') Section Survey Tool Name (R) (R) (R) 8,836.76 93.35 204.22 6,662.93 6,560.93 943.86 -1,854.71 5,970,578.17 548,334.34 6.54 109.95 MWD (3) 8,868.55 93.90 203.75 6,660.92 6,558.92 91487 -1,867.61 5,970,549.10 548,321.64 2.27 141.50 MM (3) 1 8,899.11 92.98 200.82 6,659.08 6,557.08 88665 -1,879.17 5,970,520.80 548,310.26 10.03 171.73 MWD (3) 8,928.70 9025 196.08 6,658.25 6,556.25 85860 -1,888.53 5,970,492.69 548,301.09 18.48 20069 MWD (3) 8,959.17 9000 194.00 6,658.18 6,556.18 829.18 -1,896.43 5,970,46322 548,293.39 6.88 230.13 MM (3) 8,988.67 90.46 19261 6,658.05 6,556.07 800.47 -1,903.22 5,970,434.47 548,286.79 4.96 258.39 MWD (3) i 9,018.31 92.34 192.81 6,657.34 6,555.34 771.56 -1,909]4 5,970,405.53 548,280.46 6.38 286.68 MWD (3) 9,048.62 90.68 195.54 6,656.54 6,554.54 742.19 -1,917.16 5,970,376.11 548,273.24 1054 315.82 MWD (3) 1 9,078.57 91.75 198.09 6,655.91 6,553.91 713.53 -1,925.82 5,970,347.39 548,264.77 9.23 344.98 MWD (3) 9,108.74 91.97 199.43 6,654.93 6,552.93 684.98 -1,935.52 5,970,318.78 548,255.27 4.50 374.55 MWD (3) 9,138.88 93.91 199.40 6,653.38 6,551.38 656.59 -1,945.53 5,970,290.33 548,245.46 6.44 404.14 MWD (3) 9,168.43 94.74 200.79 6,651.15 6,549.15 628.92 -1,955.65 5,970,262.59 548,235.52 5.47 433.16 MWD (3) 9,199.05 94.24 20420 6,648.76 6,546.76 600.72 -1,967.33 5,970,234.32 548,224.03 11.22 463.42 MWD (3) 9,24300 94.24 204.20 6,645.51 6,543.51 560.74 -1,985.29 5,970,19423 548,206.33 0.00 507.03 PROJECTED to TO BA ER f�WHES Annotation 211412019 8:48 06AM Page 6 COMPASS 5000.14 Build 85D BAN( GHES PANT DISTRIBUTION LIST 1 aGEcompany COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1B-16APB1 FIELD Greater Kuparuk Area COUNTY North Slope Borough 218155 30 25 3 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 Ito acknowledge receipt of this data. LOG TYPE GR - RES BHI DISTRICT Alaska --- LOG DATE December 17, 2018 AUTHORIZED BY Patrick Rider EMAIL Patrick.Ridera akerhughes. com TODAYS DATE January 14, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- �0/ ADDRESS (FEDEX WILL WT DELIVER TO P.O. BOX) PERSON ATTENTION I BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker& Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarice ATO 708 700 G Street Anchorage, AK 99510 3 F,xxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 ,Anchorage, Alaska 99501 FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las, diks, PDF, META, I SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS0 Ur rKIIN # OF GUM ES 1# OF COPIES 1# OF COPIES 4 4 lu !l a a JAN 16 2019 5 DNR - Division ofOil & Gas *** 1 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 61 BP Exploration (Alaska) Inc. Petrotechnical Data Center, I112-1 '1900 E Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 BA (ER 0 F�UGHES a GE company fo: Date: January 4, 2019 Abby Bell AOGCC 333 West 71^ Ave, Suite 100 Anchorage, Alaska 99501 21 81 55 30196 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 lease find enclosed the directional survey data for the following weII(s): 1B-16APB1 (1) Total print Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.Soper@BakerHuahes.com ,-' ConocoPhillips ConocoPhillips (Alaska) Inc.-Kupl Kuparuk River Unit Kuparuk 1B Pad 1 B-16APB1 50-029-22457-70 Baker Hughes INTEQ Definitive Survey Report 28 December, 2018 BAT UGHES a GE company 21 81 55 30 19 6 Project Kuparuk River Unit, North Slope Alaska, United States Map System: ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc.-Kup1i Local Co-ordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kupamk 1B Pad MD Reference: Well: 1B-16 North Reference: Wellbore: 18-16 Survey Calculation Method: Design: 1B-16 Database: Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well _. iB-16 _... _ Well Position -NI-S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 1B-16APB1 - Magnetics Model Name Sample Data Well 1B-16 1 B-16 @ 102.00usft(1 B-16) 18-16 @ 102.00usft (1 B-16) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,969,646.83usft 550,195.14usft usft Declination 1678 Tie On Depth: 6,823.00 +N/ -S (usft) 0.00 Tool Name MWD MWD-INC_ONLY MWD +EbW (usft) 000 Description MWD - Standard MWD-INC—ONLY—FILLER MWD - Standard Latitude: Longitude: Ground Level: Dip Angle (I 80.88 Direction (°) 210.00 Survey Start Date 6/25/2000 12/16/2018 12/17/2018 &SS 0 70° 19'40.243 N 149° 35'34.518 W 0.00 usft Field Strength (nT) 57,428 i Survey i End Data 12/17/2018 12/20/2018 - 12/28/1018 6:58:47PM Page 2 COMPASS 5000.14 Build 85D BGGM2018 2/1/2019 Design 1B-16APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 10200 Survey Program Date From To (usft) (usft) Survey(Wellbore) E 193.59 6,823.00 1B-16(1 B-16) E 7,046.00 7,102.72 1B-16APB1 MWD -INC (1B-16APB1) 7,130.20 7,436.17 1B-16APB1 MWD(1B-16APB1) Well 1B-16 1 B-16 @ 102.00usft(1 B-16) 18-16 @ 102.00usft (1 B-16) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,969,646.83usft 550,195.14usft usft Declination 1678 Tie On Depth: 6,823.00 +N/ -S (usft) 0.00 Tool Name MWD MWD-INC_ONLY MWD +EbW (usft) 000 Description MWD - Standard MWD-INC—ONLY—FILLER MWD - Standard Latitude: Longitude: Ground Level: Dip Angle (I 80.88 Direction (°) 210.00 Survey Start Date 6/25/2000 12/16/2018 12/17/2018 &SS 0 70° 19'40.243 N 149° 35'34.518 W 0.00 usft Field Strength (nT) 57,428 i Survey i End Data 12/17/2018 12/20/2018 - 12/28/1018 6:58:47PM Page 2 COMPASS 5000.14 Build 85D iSurvey MD ConocoPhillips Azi ConocoPhillips Definitive Survey Report +N/ -S $$ Company: ConocoPhillips (Alaska) Inc.-Kupl Local Co-ordinate Reference: Well 18-16 Project: Kuparuk River I !� TVD Reference: 1 B-16 @ 102.00usft (1B-16) i Site: Kuparuk 1B Pad MD Reference: 1B-16 @ 102.00usft (1B-16) Well: 18-16 North Reference: True r Welli 1 B-16 Survey Calculation Method: Minimum Curvature Design: 1B-16 Database: EDT 14 Alaska Production iSurvey MD Inc Azi TVD NDSS +N/ -S +E/ -W Map Map Vertical Will) (1 (1) (usft) (usft) NMI) (usft) Northing Easdng (.1100 ) Section Survey Tool Name (tt) (ft) (ft) 6,823.00 21.40 336.64 6,396.34 6,294.34 1,991.78 -1,04379 5,971,631.39 549,138.15 0.24 -1,203.03 MWD-INC_ONLY (2) 7,046.00 18.99 337.28 6,605.61 6,503.61 2,062.61 -1,073.94 5,971,702.00 549,107.53 1.09 -1,249.30 MWD -INC ONLY(2) 7,071.83 23.43 331.00 6,62969 6,527.69 2,070.98 4,078.06 5,971,710.35 549,103.36 1929 -1,254.49 MWD-INC_ONLY (2) 7,10212 34.45 320.30 6,656.70 6,554.70 2,083.12 -1,086.65 5,971,722.43 549,094.69 3929 -1,260.71 MWD -INC _ONLY (2) 7,130.20 44.21 307.33 6,677.97 6,575.97 2,094.96 .1,099.28 5,971,734.18 549,081.97 46.28 -1,264.64 MWD(3) 7,16041 56.15 304.71 6,697.28 6,595.28 2,108.54 -1,118.04 5,971,747.64 549,063.13 40.07 -1,267.03 MWD(3) 7,190.51 65.84 300.25 6,711.86 6,609.86 2,12261 -1,140.24 5,971,761.56 549,040.84 34.69 -1,268.12 MWD (3) 7,220.37 76.51 29831 6,721.48 6,619.48 2,136.49 -1,16481 5,971,775.27 549,016.18 36.06 -1,267.85 MWD (3) 7,250.56 88.22 297.12 6,725.49 6,623.49 2,150.47 -1,191.21 5,971,789.07 548,989.69 39.14 -1,266.76 MWD(3) 7,280.80 99.66 296.18 6,723.41 6,621.41 2,163.98 -1,218.13 5,971,802.40 548,962.68 37.96 -1,265.00 MWD (3) 7,310.32 103.07 286.80 6,717.59 6,615.59 2,174.58 -1,245.01 5,971,81282 548,935.73 33.22 -1,260.73 MWD (3) 7,341.08 100.43 275.76 6,711.30 6,609.30 2,18(1.45 .1,274.50 5,971,818.49 548,9D621 WA7 -1,251.07 1(3) 7,370.95 100.72 26273 6,705.80 6,603.80 2,180.06 -1,303.79 5,971,817.91 548,876.92 42.89 -1,236.09 MWD (3) 7,400.86 99.07 250.31 6,700.64 6,598.64 2,173.20 -1,332.38 5,971,810.66 548,848.38 41.27 -1,215.86 MWD (3) '',.. 7,436.17 96.00 234.00 6,695.98 6,593.98 2,156.89 -1,363.21 5,971,794.35 548,817.66 46.60 -1,186.32 MWD (3) 7478.00 96.00 234.00 6,691.61 6,589.61 2,132.44 -1,396.87 5,971,769.67 548,784.17 0.00 -1,148.31 PROJECTED to TO DA (LR UGRES Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth 12282018 6.'58:47PM Page 3 COMPASS 5000.14 Build 85D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS gn AAc 95 9Rn 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: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory 1:1 Development ❑✓ Stratigraphic ❑ Service ❑ 248.1'13 - %S 3. Address: 6. API Number: . PO Box 100360, Anchorage AK 99510 50-029-22457-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1 B-1 6A Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25648 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): 7450 6991 7240 6790 2883 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 121' 16" 121' 121' Surface 4423' 9-5/8" 4423' 4163' Intermediate Production 7438' 7" x 5" 7438' 6979' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6778-6838,6900-6908,6918- 6354-6410,6468-6476,6485- 6926,7124-7158 6493,6680-6712 4"x 3-1/2" J-55 6704' Packers and SSSV Type: Baker FB -1 Permanent Packer Packers and SSSV MD (ft) and TVD (ft): 6666 MD / 6251 TVD 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: N/A (Operations Shutdown) OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 20 -Dec -18 Commission Representative: Victoria Loepp GINJ ❑ Op Shutdown Q Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: William Long 'rte Authorized Title: Staff CTD Engineer Contact Email: William. Rlon COP.COm 01/01' / U Contact Phone: 263-4372 Y 101101'11g Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ` _ LIP, Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other:�71M r'r vrl R✓`� o� we O Gr -R y"y im-S Lir-!d /oq5 j -D ei2�Y U ,fVm Q 7-7'(6) p�C9CrK'l7- l0 p�03 T� I�eSun t� w� e ru w � /�' O//JtYet ��'ytS a✓ 7'Io'1` I"tfvrnC e+� 7n !2 n� � rJ roc<r'q/ J Post Initial Inject(on MIYReq'd? Yes ❑ No t-0 a blq -7ci' 7 O 11--fP l net 7y 27/}/t -C Z77— Spacing Exception Required? Yes ❑ No y Subsequent Form Required: 10-404 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: V7Z /LO1/oZ9//� 9'e i Cr 1, o In 1 Form 10-4o3R60� DEp?o�$�licat rr r li r o the date of approval. Submit Form and Attachments in Duplicate A'-14.11. 17-(zq-/J8 J6 155 1)I -B, KRU 1 B -16A (PTD #218-115f CTD Summary for Sundry (Operations Shutdown) A thru tubing whipstock was set in KRU well 1 B-16 (194-037) at 7046' MD. Returns could not be established on the well. A window was cut in the 5" casing and the build section of lateral well 1B -16A (218-115) was drilled to 7848' MD with full losses. After tripping to change from the build BHA to the lateral drilling BHA, pack offs and over pulls occurred in the lateral. The BHA was pulled back up into cased hole to establish returns and build pressure to maintain MPD on the open hole. Multiple LCM pills were pumped but sufficient pressure could not be built up to maintain MPD and establish sufficient returns to clean out the lateral. ConocoPhillips Alaska currently anticipates developing a plan to cement up the C -Sand perforations in 1 B-16 with service coil. After the pre -CTD cement job, CDR3 will make another attempt to cut a window and drill the 1 B-1 6A (24'8'I -+5T lateral. The current lateral will be renamed to 1 B-16APB1. A subsequent Application for Sundry Approvals will be submitted once plans are finalized. o?ly—JSj _A Page 1 of 1 12/20/2018 Long, William R From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, December 20, 2018 9:21 AM To: Long, William R Subject: [EXTERNAL]KRU 1B-16A(PTD 218-155) CTD Operations Shutdown William, Approval is granted for an Operations Shutdown. Please submit a 10-403 as soon as possible. A 10-403 will be required to resume drilling operations. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeoola7alaska.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)7931247 or Victoria.Loeoo®aloska.cLov From: Long, William R <WiIlia m.R.Long@conocophillips.com> Sent: Wednesday, December 19, 2018 8:13 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Starck, Kai<Kai.Starck@conocophillips.com>; Ohlinger, lames J <James.J.Ohlinger@conocophillips.com>; Herring, Keith E <Keith.E.Herring@conocophillips.com>; McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com>; Nabors CDR3 Company Man <NaborsCDR3CompanyMan@conocophillips.com> Subject: 1B-16 CTD Operations Shutdown Victoria, CDR3 is currently rigged up on KRU 16-16 (194-037) and has been attempting to drill the A lateral (218-155). We were initially unable to establish any returns on this well. We were successful in milling the window and drilling the build section of the lateral to 7479' MD with full losses. After tripping to change from the build BHA to the lateral drilling BHA we began experiencing pack offs and over pulls in the lateral. We pulled back up into cased hole and have been attempting to establish returns and build pressure to maintain MPD on the open hole. We have pumped multiple LCM pills but have been unable to establish sufficient returns and MPD to cleanout the lateral or drill ahead. CDR3 plans to rig down and move off this well. We will plan to submit a Sundry Request for Operations Shutdown. We believe a cement squeeze of the old perforations with service coil will help establish full returns and allow us to apply MPD drilling practices to help stabilize the wellbore and successfully drill the original project scope. We will plan to submit a subsequent Sundry Request for Plug for Redrill and Whipstock prior to beginning the service coil cement I i squeeze. After service coil has ,yueezed perforations we will return with CDn3 to mill a backup window and drill the original project scope. Please let me know if you would like any further information, or us to use any different forms to document these operations. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372(office) 281-723-6000 (cell) William.R.Long@ConocoPhillips.com . Time Log & Summary Report [AOGCC] IB -16 . Well Name: 1B-16 Rig Name: NABORS CDR3-AC Job type: DRILLING SIDETRACK Rig Accept : 12/14/2018 Rig Release: 12/20/2018 Time Log our Stan Depth End Depth Time P Stars Time End Tare (hr) (kKB) (hKB) Ph.. Op Code Adbi Code -T-X Operation 12/13/2018 12/13/2018 1.50 0.0 0.0 MIRU MOVE RURD P Break down TT hard-line, secure BOP, continue 21:00 22:30 RD checklist 12/13/2018 12/14/2018 1.50 0.0 0.0 MIRU MOVE RURD P Disconnect PUTZ lines, chain off reel, move 22:30 00:00 mats away from rig, complete RD check list, Peak trucks arrive on pad 12/14/2018 12/14/2018 2.00 0.0 0.0 MIRU MOVE RURD P RU & move shop & half -way house to 2A -Pad 00:00 02:00 12/14/2018 12/14/2018 3.00 0.0 0.0 MIRU MOVE RURD P Truck back on site, rig up to sows, pull sub & pits 02:00 05:00 off well 12/14/2018 12/14/2018 6.50 0.0 0.0 MIRU MOVE MOB P Move from 2T -Pad to 1B -Pad 05:00 11:30 12/14/2018 12/14/2018 1.50 0.0 0.0 MIRU MOVE MOB P On 1B pad, Remove jeeps from units. Check 11:30 13:00 tree status, Rig up cellar herculite 12/14/2018 12/14/2018 1.50 0.0 0.0 MIRU MOVE MOB P Spot modules 13:00 14:30 12/14/2018 12/14/2018 3.00 0.0 0.0 MIRU MOVE RURD P Crew change, PJSM, Safe out location, Build 14:30 17:30 scaffolding in cellar, Start working rig up check lists 12/14/2018 12/14/2018 1.50 0.0 0.0 MIRU MOVE NUND P MU PUTZ, NU BOPE, continue RU checklist 17:30 19:00 "Rig Accept 19.00 hrs 12/14/2018 12/14/2018 2.50 0.0 0.0 MIRU MOVE RURD P Grease swab& tango valves, harmmer up 1900 21:30 flanges, swap out riser, engergize koomy 12/14/2018 12/14/2018 2.10 0.0 0.0 MIRU MOVE RURD P Grease HCR's (change out bad pump), complete 21:30 2336 RU checklsit 12/14/2018 12/15/2018 0.40 0.0 0.0 MIRU WHDBOP DISP P Line up valves, begin fluid packing lines 23:36 00:00 12/15/2018 12/15/2018 0.20 0.0 0.0 MIRU WHDBOP DISP P Complete fluid packing lines, displace coil to 00:00 00:12 freshwater 12/15/2018 12/15/2018 0.30 0.0 0.0 MIRU WHDBOP PRTS P Shell test, good 00:12 00:30 12/15/2018 12/15/2018 1.30 0.0 0.0 MIRU WHDBOP BOPE P Begin BOP test(witness waive by Adam Earl of 00:30 01:48 AOGCC), "Low 250 psi, high 3500 psi 12/15/2018 12/15/2018 1.00 0.0 0.0 MIRU WHDBOP BOPE T Difficulty holding low test #5 (Charlie 7), grease 0148 0248 valve, good test 12/15/2018 12/15/2018 6.70 0.0 0.0 MIRU WHDBOP BOPE P Continue BOP test, install test joint, continue 02:48 0930 test, No other failures. Test PVT & gas detectors - all good, 9 hour test 12/15/2018 12/15/2018 1.90 0.0 0.0 MIRU WHDBOP PRTS P Fluid pack CT and pressure test inner reel valve. 09:30 11:24 Unstab injector, PT TT line and PDL's 12/15/2018 12/15/2018 0.60 0.0 0.0 PROD1 WHPST CTOP P Change out upper quick connect and rehead E- 11:24 12:00 1 line 12/15/2018 12/15/2018 1.50 0.0 74.2 PROD1 WHPST PULD P PJSM, MN and deploy BHA#1 Window milling 12:00 13:30 BHAwith 2.81 mill, 2.8 string reamer, and .6° AKO motor 12/15/2018 12/15/2018 1.00 74.2 74.2 PROD1 WHPST PULD T Unable to accuate master valve, Call out valve 1330 14:30 crew. Valve is pressure locked 12/15/2018 12/15/2018 0.80 74.2 74.2 PRODi WHPST PULD P Master open. WHP=525, Continue with 14:30 15:18 deployment, Make up coil to BHA and surface test - Good. Stab on injector. Tag up and set counters 12/15/2018 12/15/2018 1.60 74.2 6,655.0 PROD1 WHPST TRIP P RIH BHA#1 to mill window. On seawater returns 15:18 16:54 1 1 1 1 to Tiger tank 12/15/2018 12/1512018 0.10 6,655.0 6,684.0 PROD1 WHPST OLOG P Log K1 for +1.5' correction 1654 17:00 12/15/2018 12/15/2018 1.20 6,684.0 6,760.0 PROD1 WHPST DISP P Continue RIH, flush well w/ seawater, unable to 1700 18:12 establish returns, bull -head seawater to window (2 bpm, 200 psi WHIP) Page 117 Report Printed: 12/20/2018 Time Log & Summary Report [AOGCC] 1B-16 . Well Name: 1B-16 Rig Name: NABORS CDR3-AC Job type: DRILLING SIDETRACK Rig Accept: 12/14/2018 Rig Release : 12/20/2018 Time Log our Sten Depth End Depth Tme P Start Time End Time (hr) rem) ^B) Phase Op Code Activity Code -T-X Operation 12/15/2018 12/15/2018 0.40 6,760.0 6,760.0 PROD1 WHPST DISP P Displace coil to DuoVis 1812 1836 12/15/2018 12/15/2018 2.30 6,760.0 6,760.0 PROD1 WHPST WAIT P Await building 50 bbl 150K -SRV pill, coordinate 18:36 20:54 trucks & Fluids for possibility of no returns should pill not help Obtain SBHP while waiting on pill: MD = 6760', TVD sensor = 6296.9', BHP = 2717 psi, EMW = 8.3I_P9 12/15/2018 12/15/2018 2.00 6,760.0 6,760.0 PROD1 WHPST DISP P Bullhead 50 bbl 150K LSRV pill followed by 20:54 22:54 DuoVis down to parts (pushing away seawater), WHP climbs from 150 psi to -850 psi at perts, then begins to drop (100 bbls away, 40 bbl squeezed into perfs) 12/15/2018 12/15/2018 0.60 6,760.0 7,049.3 PROW WHPST TRIP P Pump attempting to get returns, returns start @ 2254 2330 40%, quickly demininish to -21%, decision made to close choke & mill window, PUW = 41 K, RIH, dry tag WS pinch point @ 7049.8', PUH, bring on pumps 12/15/2018 12/16/2018 0.50 7,049.3 7,050.0 PRODt WHPST WPST P Tag WS pumping @ 7049.3', FS = 550 psi @ 1.9 23:30 00:00 bpm, CWT =24.6K, WOB =0.3K, BHP =2866 psi, circ = 3567 psi 12/16/2018 12/16/2018 3.50 7,050.0 7,052.8 PROD1 WHPST WPST P Continue milling window, CWT = 21.4K, WOB= 00:00 0330 1.8K, BHP = 2906 psi, circ= 3324 psi, closed choke, 1.87 bpm 12/16/2018 12/16/2018 1.50 7,052.8 7,054.7 PRODi WHPST WPST P Continue milling window, CWT = 22.8K, WOB = 03:30 05:00 2K, BHP = 2933 psi, circ = 3272 psi Pre -load build BHA 12/16/2018 12/16/2018 2.60 7,054.7 7,057.3 PROD1 WHPST WPST P Milling window, WOB =2.5K, BHP =2952 psi, 05:00 07:36 circ = 3364 psi, WHP = 12 psi TF=30R 12/16/2018 12/16/2018 2.00 7,057.3 7,071.0 PROD1 WHPST WPST P Called BOW @ 7056.3, Reamer out @ 7057.3. 0736 09:36 Drill rathole. 1.9 BPM @ 3400 PSI FS, BHP=2993 12/16/2018 12/16/2018 2.00 7,071.0 7,071.0 PROD1 WHPST REAM P TD Rathole, start reaming passes. As drilled, 0936 11:36 30L, 30R, and 180° out of as drilled tool face. Dry drift window - Good. 12/16/2018 12/16/2018 1.20 7,071.0 74.0 PROD? WHPST TRIP P POOH, PUW=36K 11:36 12:48 12/16/2018 12/16/2018 1.00 74.0 0.0 PRODi WHPST PULD P At surface, Tag up and space out. Flow check 12:48 1348 well. PJSM. Well dead. Static losses - 20 BPH. Lay down BHA#1. Mill and string reamer out @ 2.79 No Go 12/16/2018 12/16/2018 1.20 0.0 72.2 PROD1 DRILL PULD P P/U BHA #2, was pre loaded in PDL. Make up to 13:48 1500 coil and surface test, Check pack offs 12/16/2018 12/16/2018 1.30 72.2 6,650.0 PROD1 DRILL TRIP P RIH BHA#2 15:00 16:18 12/16/2018 12/16/2018 0.20 6,650.0 6,670.0 PROD1 DRILL DLOG P log K1 for +.5', PUW=36K, Close EDC 16:18 16:30 12/16/2018 12/16/2018 0.20 6,670.0 7,071.0 PRODI DRILL TRIP P Continue in well. Clean pass through window 16:30 16:42 12/16/2018 12/16/2018 1.40 7,071.0 7,160.0 PRODt DRILL DRLG P 771', Drill, 1.9 BPM @ 3214 PSI FS, BHP=2950, 16:42 1806 Choke shut, WHP=O, RIW=19.2K, DHWOB=1.5, Bleed IAdown from 1070, crew change, PUW = 40K 12/16/2018 12/16/2018 1.20 7,160.0 7,215.0 PROD1 DRILL DRLG P Drilling, FS = 530 psi @ 1.9 bpm, closed choke, 18:06 19:18 CWT = 21 K, WOB = 1.41K, BHP = 3050 psi, circ = 3404 psi, WHP = 0 psi Difficulty achieving 45" DLS, reduce rate to 1.5 bpm & increase WOB per DO request, geo's confer wttown geology Page 2f7 Report Primed: 12/20/2018 Time Log & Summary Report [AOGCC] 113-16 ag Well Name: 1B-16 Rig Name: NABORS CDR3-AC Job type: DRILLING SIDETRACK Rig Accept : 12/14/2018 Rig Release: 12/20/2018 Time Log Dur Start Depth End Depth Tme P Start Time End Tune (hr) (11m) (WO) Phase on code ACWit, Code -T-X Operation 12/16/2018 12/16/2018 0.30 7,215.0 7,215.0 PROD1 DRILL WAIT P Geo/DD wiper, allow geo's time to discuss 19:18 1936 deeper build landing, PUW = 40K, decision made to continue drilling 12/16/2018 12/16/2018 1.50 7,215.0 7,267.0 PROM DRILL DRLG P Drilling, CWT= 19K, WOB = 3.5K, BHP = 3091 19:36 21:06 psi, WHIP = 33 psi, circ = 2820 psi Continue at 1.5 bpm & increase WOB in attempt to achieve higher DLS, PUW = 38K 12/16/2018 12/17/2018 2.90 7,267.0 7,378.0 PROM DRILL DRLG P Drilling, FS = 550 psi @ 1.9 bpm, CWT = 17.6K, 21:06 00:00 WOB =4K, SHIP =3134 psi, WHIP =62 psi, varialbe ROP (12 fph - 115 fph), PUW = 40K, begin pulling 46K & -3 WOB 12/17/2018 12/17/2018 0.30 7,378.0 6,640.0 PRODt DRILL WPRT P Continue wiper to window, pull up past perfs at 00:00 00:18 6788' 12/17/2018 12/17/2018 0.30 6,640.0 7,090.0 PROD1 DRILL DLOG P Log K7 for+1' correction, continue in-hole, log 0018 00:36 RA@7053' TOWS = 7046', TOW = 7048', BOW = 7056, RA = 7053 12/17/2018 12/17/2018 0.20 7,090.0 7,378.0 PROM DRILL WPRT P Wiper in-hole, RIW = 20K, weight bobbles at 00:36 00:48 7277'& 7355' (-1 K WOB) 12/17/2018 12/1712018 1.40 7,378.0 7,470.0 PROM DRILL DRLG P Drilling, FS = 568 psi @ 1.9 bpm, CWT = 19.8K, 00:48 02:12 WOB = 1.8K, BHP = 3229 psi, WHIP = 120 psi, circ = 3602 psi, closed choke, drill to called EOB @ 7470 Work PDL's to avoid freeze-up 12/17/2018 12/17/2018 1.80 7,470.0 71.0 PRODt DRILL TRIP P POOH, PUW =40K, pull heavy through 7365', 02:12 0400 7342'& 7242 (up to 4K WOB), open EDC, tag up, flow check, have flow 12/17/2018 12/17/2018 0.90 71.0 0.0 PROD1 DRILL PULD P PUD BHA#2, pumping managed pressure 04:00 04:54 12/17/2018 12/17/2018 2.00 0.0 78.0 PROM DRILL PULD P PD BHA#3 "A" Lateral Assembly (NOV Agitator, 04:54 06:54 0.5° AKO motor, RB HYC A2 bit), slide in cart, check pack -offs, MU to coil, tag up 12/17/2018 12/17/2018 1.20 78.0 6,655.0 PROM DRILL TRIP P Trip in hole, BHA#3 A lateral section, Shallow 0654 08:06 1 1 test agitator 12/17/2018 12/17/2018 0.20 6,655.0 6,680.0 PROM DRILL DLOG P Log K1 for+.5', PUW=37K 0806 08:18 12/17/2018 12/17/2018 0.20 6,680.0 7,478.0 PROD1 DRILL TRIP P Continue in well, Clean trip through window. 08:18 08:30 1 1 Clear to bottom @ 7478 12/17/2018 12/17/2018 0.50 7,478.0 6,608.0 PROD1 DRILL TRIP T 7478 PUH. Tight spots with pack offs and high 08:30 09:00 negative weight on bit. Hole in poor condition. Get up to cased hole. Jet 5 1/2 tubing in preparation for Polyswell pill. 12/17/2018 12/17/2018 2.40 6,608.0 6,608.0 PROD1 DRILL CIRC T Poly Swell material coming for Deadhorse. reap 09:00 11:24 1 5 1/2 tubing 12/17/2018 12/17/2018 2.00 6,608.0 6,655.0 PROD1 DRILL CIRC T Stand by for polly swell 1124 1324 12/1712018 12/17/2018 0.10 6,655.0 6,682.0 PROD1 DRILL DLOG T Log K1 for +3'correction 1324 1330 12/17/2018 12/17/2018 0.10 6,682.0 6,700.0 PROD1 DRILL TRIP T Trip in hole 13.30 1336 12/17/2018 12/17/2018 0.20 6,700.0 6,700.0 PROD1 DRILL CIRC T Line up to pump down back side for baseline 13:36 13:48 pressures for poly swell job, 1 BPM Pump=315 PSI, BHP=2928, 1.5 BPM Pump=475PSI, BHP=3001, WHP=420, 2 BPM Pump=600PSI, BHP=3083, 2.5 BPM, Pump=700PS1, BHP=3137, 3 BPM Pump=800PSI, BHP=3177, 12/17/2018 12/17/2018 1.30 6,700.0 6,715.0 PROM DRILL CIRC T PJSM to mix and pump poly swell 13:48 1506 1 I Page 317 Report Printed: 12/20/2018 ft- !�k Time Log & Summary Report [AOGCC] A a 1B-16 Well Name: 1B-16 Rig Name: NABORS CDR3-AC W Job type: DRILLING SIDETRACK Rig Accept: 12/14/2018 Rig Release :12/20/2018 Time Log Dur Start Depth emi Depth Time P Start Time End Mme (M) (fiR6) (fiKB) Phase Op Code Acbvtly Code -T-% Operetbn 12/17/2018 12/17/2018 0.50 6,715.0 6,715.0 PROM DRILL CIRC T Pump 20 BBI poly swell pill down back side, 3 15:06 15:36 BBI/Min, Pump Pressure 1100 PSI, WHP=25 PSI. 12/17/2018 12/17/2018. 0.10 6,715.0 6,096.0 PROD1 DRILL TRIP T 6715 At 60 BBIs pumped down back side Pull up 1536 15:42 hole out of pill, PUW=38K 12/17/2018 12/17/2018 1.00 6,096.0 6,096.0 PROD? DRILL OTHR T 6096, out of pill. Wait for poly swell to activate. 15:42 16:42 12/17/2018 12/17/2018 0.20 6,096.0 6,096.0 PROD1 DRILL CIRC T Start pumping down back side .5 BPM, 16:42 16:54 WHP=23PS1, No change duan pumping, BHP=2745 12/17/2018 12/17/2018 0.80 6,096.0 6,096.0 PROM DRILL OTHR T Shut down pump. No pressure build up, Batch 1654 1742 up second 20 BBL pill of poly swell 12/17/2018 12/17/2018 0.40 6,096.0 6,714.0 PROW DRILL CIRC T Pump 20 BBI pill of poly swell down back side 1742 18:06 follow with duo vis RIH to below TT 12/17/2018 12/17/2018 2.40 6,714.0 6,714.0 PROM DRILL OTHR T At 6714. Wait on poly swell to activate, 2 Hrs 18:06 20:30 12/17/2018 12/17/2018 1.00 6,714.0 6,714.0 PROM DRILL CIRC T Online with pump down back side .5 BPM, 20:30 21:30 BHP=2830, Climbed slowly to 3210 12/17/2018 12/17/2018 0.60 6,714.0 6,094.0 PROD1 DRILL TRIP T Trip in hole, Start prepping 3rd Poly pill, 30 BBIS 21:30 22:06 12/17/2018 12/17/2018 0.50 6,094.0 6,094.0 PROD1 DRILL CIRC T Pump 30 BBI poly pill down back side at 2 BPM 2206 22:36 under displace pill 30 Pill and 20 BBIs duo vis. 2 BPM BHP=3210 12/17/2018 12/18/2018 1.40 6,094.0 4,000.0 PROD? DRILL WAIT T Pill spotted, PUH out of pill to 4000', Wait 2 2236 00:00 hours for swelling action 12/18/2018 12/18/2018 1.20 4,000.0 4,000.0 PROM DRILL WAIT T Continue to allow poly swell pill swell time, 00:00 01:12 estimate 35 bbl above perfs 12/18/2018 12/18/2018 0.70 4,000.0 4,000.0 PROM DRILL DISP T Pump 0.5 bpm down back -side, bit depth = 01:12 01:54 4000', (attempting to achieve 1500 psi over stabalized annular pressure of 2750 psi) Annular quickly rises to 2600 psi, 2 bbl away, annular = 2750 psi 5 bbl away, annular = 3000 psi 10 bbl away, annular= 3217 psi 15 bbl away, annular= 3387 psi 17.5 bbl away, annular = 3412 psi (up to 13.7 ppg, and began to flatten) Shutdown pumps, pressure drops to -2600 psi relatively quickly, then began to slow 12/18/2018 12/18/2018 1.10 4,000.0 4,000.0 PROD1 DRILL WAIT T Confer w/ town on plan forward 01:54 03:00 12/18/2018 12/18/2018 3.20 4,000.0 4,000.0 PROD1 DRILL DISP T Decision made to pump away remaining 8.5 bbl 03:00 06:12 Poly Swell, maintaining 11.4 ppg at window (2650 psi annular @ bit depth of 4000') Began pumping, annular quickly jumps to 3200 psi, allow to drop to 2650 psi, shut down pumps, continue pumping small ammounts and shutting down pump to maintain 11.4 ppg. (-1100 psi WHP), swap to managed pressure in attempt to reduce annular fluctuations, rate in began to increase quickly from nominal to hold 11.4 ppg to .45 bpm, difficulty holding 11.4 ppg at window Begin prepping for 4th Poly Swell pill should it be required (30 bbl) 12/18/2018 12/18/2018 1.00 4,000.0 6,715.0 PROD? DRILL DISP T Begin circulating down coil, unable to hold 11.4 06:12 07:12 1 1 I I ppg at window, confer w/ town, decision made to build & pump 4th Poly Swell pill (30 bbl) Page 4/7 Report Printed: 12/20/2018 Time Log & Summary Report [AOGCC] (IL IB -16 . . . Well Name: 1B-16 Rig Name: NABORS CDR3-AC Job type: DRILLING SIDETRACK Rig Accept: 12/14/2018 Rig Release: 12/20/2018 Time Log Dur Start Depth End Depth Time P Start rme End Time (hr) (Wa, (WB) Phase Op Code Activity Code -LX Opetatbn 12/18/2018 12/18/2018 0.60 6,715.0 3,826.0 PROD1 DRILL DISP T 50 bbl bullhead away 30 bbl Poly Swell follow by 07:12 0748 20 bbl DuoVis, reduce rate & PUH to 3826' pumping pipe displacement, PUW = 38K, (-26 bbl Poly Swell above perfs in cased hole) 12/18/2018 12/18/2018 2.00 3,819.0 3,819.0 PR0D1 DRILL WAIT T Wait on swell time, pumps off (9.0 ppg at 07:48 0948 window) 12/18/2018 12/18/2018 0.70 3,819.0 3,819.0 PRODI DRILL DISP T Squeeze 22 bbl away attempting to hold 12.4 09:48 1030 ppg at window, begin pumping at 1.8 bpm to build to 11.76 ppg ppg, 10 bbl away, reduce rate to .5 bpm attempting to build to 12.4 ppg, unable to achieve 12.4 ppg, drop to 10.4 ppg 12/18/2018 12/18/2018 2.00 3,819.0 78.0 PROD1 DRILL WAIT T Confer w/town, MI formulating plan forward w/ 1030 12:30 FORM-A-BLOK pill (recipe & volume requirements), perform lab tests w/ product on rig, PUH, tag up in prep for pumping 12/18/2018 12/18/2018 2.20 78.0 78.0 PR0D1 DRILL WAIT T Await super sucker to clear pits, super sucker 1230 14:42 arrives on site Coordinate w/ facilites for 3C-08 pre -rig work, begin RDMO paper work should that become plan forward 12/18/2018 12/18/2018 1.00 78.0 78.0 PR0D1 DRILL CLEN T Suck out pits, wash down & clean of all polymer 14:42 15:42 I 12/18/2018 12/18/2018 2.80 78.0 78.0 PR0D1 DRILL CIRC T Build 10 bbl KCI spacers & 23 bbl FORM -A- 15:42 18:30 BLOK pill (40 ppb product) 12/18/2018 12/18/2018 0.80 78.0 78.0 PRODI DRILL CIRC T PJSM, Pump 5 bbl KCL spacer, @ 3 bpm, Pump 18.30 19:18 20 bbls Form-A-Blok from 3-0.25 bpm, lots of issues pumping, lost C pump pressure, Triplex jacking off, pum - 1.0 bbl duovis, unable to initially catch prirme with KCL, swap to KCL once pump lined up, Pump 5 bbls KCL @ 3 bpm, Swap to duovis displacement, chase LCM to perfs @ 3 bpm, CT 650 psi, WH 612 psi, 12/18/2018 12/18/2018 0.30 78.0 78.0 PROD1 DRILL CIRC T At 77 bbls total treatment away, with Form -A- 1918 19:36 Blok at the perfs reduce rate to 0.5 bpm, pump 10 bbls of Form-A-Blok to the formation, CT 195 psi, WH fell from 596 psi to 165 psi @ 5 bbls away, then climbed slowly to 179 psi at 10 bbls away 12/18/2018 12/18/2018 3.70 78.0 78.0 PR0D1 DRILL CIRC T SID for 30 min, On line, -1 bbl away to fl hole / 19:36 2318 Catch pressure. Squeeze away 1.8 bbls ( total away 89.8 bbls) well head climbed to 137 psi then broke over, S/D for 30 min, WH fell to 0 psi Catch pressure with 1 bbl away, squeeze 1 bbl, WH climbed to 140 psi. S/D for 30 min. WH fell to 0 psi Catch pressure imeditly, squeeze 1 bbl away, WH climbed to 183 psi. S/D for 30 min. W H fell to 3 psi Catch pressure imeditly, squeeze 1 bbl away, WH climbed to 218 psi. SID for 30 min. WH fell to 33 psi Catch pressure imeditly, squeeze 1 bbl away, WH climbed to 245 psi. S/D for 30 min. WH fell to 50 psi Catch pressure imeditly, squeeze 1 bbl away, WH climbed to 290 psi. S/D for 30 min. WH fell to 83 psi 12/18/2018 12/19/2018 0.70 78.096.8 PRODI DRILL CIRC T Move pipe, RIH 100 feet, POOH, bump up, 23:18 0000 space out PJSM, Start batching 50 bbls of Pro V, 40 bbls water, 3 sacks viscosifyer, and Pro V plus LCM pill Page 517 Report Printed: 12/2012018 ,I Time Log & Summary Report [AOGCC] IB-16 Well Name: 1B-16 Rig Name: NABORS CDR3-AC Job type: DRILLING SIDETRACK Rig Accept: 1211412018 Rig Release: 12/20/2018 Time Log Start Time End Time Dw (ho Start Depth (fiKa) EM Depth Me) Phase Op Code Actively Code note P -T-X Operation 12/19/2018 12/19/2018 3.00 96.8 96.8 PROD1 DRILL CIRC T Complete building 52 bbls pill of Pro V+ LCM pill, 00:00 03:00 (92 lb/bbl). 12/19/2018 12/19/2018 2.10 96.8 96.8 PROD? DRILL CIRC T Lead in with duovis - mud, establish injection 1 0300 05:06 bpm WH 350 psi, swap to Pro V, pump 9.8 bbls, lockup Pump #1, troubleshoot issues. Swap to pump #2, get 7.6 bbls away lost pump #2. Pull apart pump # 1, LCM packing off and floating the valves. Tear down and dean Pump#1. "ProV = 9.32 ppg 12/19/2018 12/19/2018 0.80 96.8 96.8 PROD1 DRILL CIRC T Back on line, estimate 17.4 bbls of plug on the 05:06 0554 backside, meter indicated - 33 blots on restat due to Gearing lines. Ignoring fallout lead of plug at parts with 92.6 bbls away end of plug is 110 bbls away. Displaceat 2 bpm, WH 610 pi. WH broke trend @ 76 bbls, cut rate to 1 bpm @ 81 bbs away. WH increased to 720 psi then broke back, reduced rate to 0.5 bpm. WH climbed and started to break over. Shut down trapping 555 psi on the WH 12/19/2018 12/19/2018 1.30 96.8 96.8 PROD? DRILL CIRC T Wait on dehydration 05:54 07:12 12/19/2018 12/19/2018 0.70 96.8 78.0 PROM DRILL CIRC T Discussed w/ Procor rep, decision made to 07:12 07:54 squeeze away all 5.75 bbl & attempt again wl more volume (ie the remaining 45 bbl in pits), Squeeze away bbl 11.4 bbl, WHP Climbs to 785 psi, WHP w/ pumps off drops to 69 psi Shut 2-3/8" rams to isolate EDC, trap 105 psi WHP to ensure rams & checks are holding, pump down MP line, DPS is below rams (so will see dp, though is not affecting EDC) 12/19/2018 12/19/2018 1.20 78.0 78.0 PROD? DRILL CIRC T PJSM, discuss w/ Procor rep method of getting 07:54 09:06 LCM in-hole given earlier packed off pump issue, decision made to pump remaing -45 bbl of Pro V, 5 bbl Pro V followed by -2 bb DuoVis (both in- hole), chase 60 bbl "pill" w/ DuoVis 72 bbl away, Pro V @ peris (Note: 132 bbl total pumped will be tail of Pro V pill through the perfs) 12/19/2018 12/19/2018 0.30 78.0 78.0 PROD? DRILL CIRC T Squeeze away 20 bbl @ 1 bpm (92 total 09:06 0924 pumped), WHP climbs to 850 psi 12/19/2018 12/19/2018 1.00 78.0 78.0 PROW DRILL CIRC T Wait, WHP drops to 79 psi @ 1 hr 09:24 1024 12/19/2018 12/19/2018 0.20 78.0 78.0 PROM DRILL CIRC T Squeeze 12 bbl, WHP = 875 psi, 103.75 bbl total 10:24 1036 pumped, 28.25 bbl pill remains 12/19/2018 12/19/2018 0.50 78.0 78.0 PROD1 DRILL CIRC T Wait, WHP drops tol97 psi 10:36 11:06 12/19/2018 12/19/2018 1.50 78.0 78.0 PROD? DRILL CIRC T Pump at .1-.2 bpm until WHP = 600 psi, wait 20 11:06 12:36 min, WHP drops to 210 psi, (pumped 110 bbl total, 22 bbl remain) 12/19/2018 12/19/2018 0.70 78.0 78.0 PROW DRILL CIRC T Pump at.1-.2 bpm until WHP= 650 psi, wait 20 12:36 13:18 min, WHP drops to 221 psi,(pumped 113.7 bbl total, 19 bbl remain) 12/19/2018 12/19/2018 0.80 78.0 78.0 PROD1 DRILL CIRC T Pump at-.3 bpm until WHP begins to plateaus 13:18 1406 @ 888 psi, WHP quickly w/ pumps off, (pumped 125.8 bbl total, 6.2 bbl remain) 12/19/2018 12/19/2018 0.50 78.0 78.0 PROD1 DRILL CIRC T Pump remaining 6.2 bbl st.5 bpm, WHP climbs 14:06 14:36 to 962 psi, with tail out perfs WHP drops to 856 psi, then climbs to 990 psi (142 bbl total pumped) Page 6!7 Report Printed: 12120/2018 Time Log & Summary Report [AOGCC] 113-16 . Well Name: 1B-16 Rig Name: NABORS CDR3-AC Job type: DRILLING SIDETRACK Rig Accept : 12/14/2018 Rig Release : 12/20/2018 Time Log Dur Start Depth End Depth Tme P Start Time End Time (hr) (ftKB) (ftKB) Phase Op Cade Activity Code -T-% Operation 12/19/2018 12/19/2018 1.10 78.0 78.0 PROD1 DRILL CIRC T Line up down coil, RIH to 2000', pumping 1.3 14:36 15:42 bpm, At 2000' .' 1.8 bpm, 1-for-1 returns at holding 9.7 ppg at window •• 1.8 bpm, 11.2 ppg, 72% returns, WHP = 818 psi 12/19/2018 12/19/2018 1.00 78.0 6,620.0 PROD1 DRILL TRIP T Continue RIH, pumping .75 bpm, holding 11.2 15:42 16:42 pPg 12/19/2018 12/19/2018 0.40 6,620.0 6,676.0 PROD1 DRILL DLOG T Difficulty finding K1, PUH to 6620'& re-log, PUW 16:42 17:06 = 34K 12/19/2018 12/19/2018 2.00 6,676.0 6,676.0 PROD1 DRILL CIRC T Continue in-hole, slow through tubing-tail & 17:06 19:06 down to TOWS Make two down passes jeting max rate @ 20 ft/min from 6723' to 7035'. 12/19/2018 12/19/2018 1.50 6,676.0 83.0 PRODi DRILL TRIP T POOH 19:06 20:36 12/19/2018 12/19/2018 1.20 83.0 0.0 PROW DRILL PULD T PJSM, atempt to bleed WH and lay down over a 20:36 21:48 dead well, presure built to 8 psi. PUD BHA#3. 12/19/2018 12/19/2018 0.50 0.0 0.0 DEMOB WHDBOP PULD P Pick up a nozzle, stab back on. 21:48 22:18 12/19/2018 12/20/2018 1.70 0.0 0.0 DEMOB WHDBOP DISP P Bullhead 220 bbls seawater 1.9 BPM, CT 4047 2218 0000 psi, WH 774 psi. LR on location, PJSM, confnn customer valve clear with air, RU, PT to 4 k psi, good. 12/19/2018 12/19/2018 0.20 0.0 0.0 DEMOB WHDBOP DISP P Complete bullheading 180 bbls seawater 1.9 00:00 00:12 BPM, CT 4047 psi, WH 774 psi. LR on location, PJSM, confirm customer valve clear with air, RU, PT to 4 k psi, good. 12/19/2018 12/19/2018 1.00 0.0 0.0 DEMOB WHDBOP DISP P LRS, Bullhead 30 bbls diesel FP 1.0 BPM, CT 00:12 01:12 1400 psi, WH 454 psi. "` S/I well with 490 psi on the tubing 12/19/2018 12/19/2018 1.00 0.0 0.0 DEMOB WHDBOP CIRC P Pop off, install jet nozzle, stab back on, Jet 01:12 02:12 stack. 12/19/2018 12/19/2018 1.00 0.0 0.0 DEMOB WHDBOP CTOP P Pop off, install night cap flush lines, blow down. 02:12 03:12 12/19/2018 12/19/2018 1.00 0.0 0.0 DEMOB WHDBOP CTOP P Pop off, vac stack, Bore 0 scope BOP stack. 03:12 04:12 12/19/2018 12/19/2018 4.80 0.0 0.0 DEMOB WHDBOP KURD P Work rig down checklist, ND BOP 04:12 09:00 1 I I "Rig Released: 12/20/18 @ 09:00 Firs Page 70 Report Printed: 12/20/2018 1 B-16 CTD Schematic 16" 62# H-40 shoe @ 121' MD 9-5/8" 40# L-80 shoe @ 4424' MD C -sand perfs 6778'- 6838' MD 6900'- 6908' MD KOP @ 7046' MD 3-1/2" x 5" TTWS JA -sand pe rfs 7124' - 7158' MD 7" x 5" shoe @ 7441' MD 3-1/2" Cameo TRDP-4A Safety Valve @ 1893' MD Locked Out: 8/2/2017 4" 11# J-55 Tubing 4104' MD to surface Cross-over 4"x3.5" @ 4104' MD 3-1/2" Cameo gas lift mandrels @ 2624', 4139', 5204', 5987'. & 6620' MD Baker FB -1 packer @ 6666' MD (4.0" ID) Baker SBE @ 6670' MD 3-1/2" Camco D landing nipple @ 6688' MD (2.80" min ID, Milled Out) 3-1/2" Cameo SOS @ 6700' MD 1 BD-16APB1 TIB @ 7848' MD Loepp Victoria T (DOA) From: Long, William R <William.R.Long@conocophillips.com> Sent: Thursday, December 20, 2018 10:06 AM To: Loepp, Victoria T (DOA) All Cc: Ohlinger, James J Subject: RE: [EXTERNAL]KRU 1 B-16A(PTD 218-155) CTD Operations Shutdown Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you. I have been working on generating the paperwork this morning. I will try to get everything signed and delivered before the end of the day today. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372(office) 281-723-6000 (cell) William. R.Long@ConocoPhillips.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, December 20, 2018 9:21 AM To: Long, William R<WiIlia m.R.Long@conocophillips.com> Subject: [EXTERNAL]KRU 1B-16A(PTD 218-155) CTD Operations Shutdown William, Approval is granted for an Operations Shutdown. Please submit a 10-403 as soon as possible. A 10-403 will be required to resume drilling operations. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil 8 Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria LoeooCadalaska.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)7931247 or Victoria Loeoo@alaska aov From: Long, William R <William R.Long@conocophillips.com> Sent: Wednesday, December 19, 2018 8:13 PM To: Loepp, Victoria T (DOA) <victoria loepp@alaska.gov> Cc: Starck, Kai <Kai.Starck(cDconocophillips.com>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Herring, Keith E <Keith.E.Herring@conocophillips.com>; McLaughlin, Ryan <Ryan McLaughlin@conocophillips.com>; Nabors CDR3 Company Man<NaborsCDR3CompanyMan@conocophillips.com> Subject: 1B-16 CTD Operations Shutdown Victoria, CDR3 is currently rigged up on KRU 1B-16 (194-037) and has been attempting to drill the A lateral (218-155). We were initially unable to establish any returns on this well. We were successful in milling the window and drilling the build section of the lateral to 7479' MD with full losses. After tripping to change from the build BHA to the lateral drilling BHA we began experiencing pack offs and over pulls in the lateral. We pulled back up into cased hole and have been attempting to establish returns and build pressure to maintain MPD on the open hole. We have pumped multiple LCM pills but have been unable to establish sufficient returns and MPD to cleanout the lateral or drill ahead. CDR3 plans to rig down and move off this well. We will plan to submit a Sundry Request for Operations Shutdown. We believe a cement squeeze of the old perforations with service coil will help establish full returns and allow us to apply MPD drilling practices to help stabilize the wellbore and successfully drill the original project scope. We will plan to submit a subsequent Sundry Request for Plug for Redrill and Whipstock rior to beginning the service coil cement squeeze. After service coil has squeezed perforations we wi�rn with CDR3 to mill a backup window and drill the original project scope. Please let me know if you would like any further operations. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372 (office) 281-723-6000 (cell) William R Long@ConocoPhillips.com or us to use any different forms to document these THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1B -16A ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-155 Surface Location: 501' FNL, 244' FEL, SEC. 9, TI IN, R10E, UM Bottomhole Location: 52' FNL, 2245' FEL, SEC. 9, TI IN, R10E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 vvvrov.aogcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair k% DATED this day of December, 2018. RECEIVED STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 2 6 2018 PERMIT TO DRILL 2n AAC 25 005 A Tv i•a .-. Ia. Type of Work: Drill ❑ Lateral ❑ Redrill ❑✓ ' Reentry ❑ 1b. Proposed Well Class: Exploratory - Gas ❑ Stratigraphic Test ❑ Development - Oil ❑Q Exploratory - Oil ❑ Development - Gas ❑ Service - WAG Service - Disp ❑ ' Service - WIN ❑ Single Zone R1 • Service -Supply ❑ Multiple Zone ❑ 1C. Speci i r. Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: Conoco Phillips Alaska, Inc. 5. Bond: Blanket 0 • Single Well ❑ Bond No. 5952180. 11. Well Name and Number: KRU 16-16A 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 9300' TVDt 6532' 12. Field/Pool(s): Kuparuk River Pool / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 501' FNL, 244' FEL, Sec 9, Tl l N, R10E, UM Top of Productive Horizon: 1561' FSL, 1314' FEL, Sec 4, T11 N, Fit OE, UM Total Depth: 52' FNL, 2245' FEL, Sec 9, T11 N, R10E, UM 7. Property Designation: it ADL 25648 • �( 8. DNR Approval Number: LONS 79-016 13. Approximate Spud Date: 12/3/2018 9. Acres in Property: 2560 14. Distance to Nearest Property: 18,500' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 550195 • y- 5969647 • Zone- 4 10. KB Elevation above MSL (ft): 102 GL / BF Elevation above MSL (ft): 61 15. Distance to Nearest Well Open to Same Pool: 1907' (1 B-02) 16. Deviated wells: Kickoff depth: 7045 • feet Maximum Hole Angle: 100 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 3513 • Surface: 2883 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 2050' 7250' 6612' 9300' 6532' Slotted 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): 7450 6991 N/A Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 7240 6790 N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 121' 16" 200 sx All 121' 121' Surface 4423' 9-5/8" 1000 sx ASIII, 420 sx Class G 4423' 4163' Production 7438' 7" x 5" 350 sx Class G 7438' 6979' Perforation Depth MD (ft): 6778-6838, 6900-6908, 6918-6926, 7124-7158 Perforation Depth TVD (ft): 6354-6410, 6468-6476, 6485-6493, 6680-6712 5839'- 5852' Hydraulic Fracture planned? Yes❑ No 7 20. Attachments: Properly Plat ❑ BOP Sketch Divertter Sketch 8 Drilling Report Dril ng Fluid Program Shallow Hazard Analysis e 20 AAC 25.050 require 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: William Long Authorized Name: James Ohlinger Contact Email: Willlam.R.Lon COP.Com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4372 Authorized Signature: Date: Commission Use Only Permit to Drill r^ Number: ��—(•�� API Numbper: �f 50-O;r S•r �(�� Permit Approval Date: ( See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methan , gas hydrates, or gas contained in shales: Other: 8/�0P �� f 35-00 �r Samples req'd: Yes No Mud log req'd: Yes ❑ No� q/� y7H2SS measures: Yes � No❑ Directional svy req'd: Yes �No,❑/ r/ ki /-1 v Cl / tJ 1—t Vr'n fts"7T$ t '� ZSgi�g eXEepf n req'd: Yes ❑ No� Inclination -only svy req'd: Yes ❑ No L��• /- Post initial injection MIT req'd: Yes F-1 No[R APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: V7 L la17l t KSubmit Form and Form 10-401 Revised 5/2077 T r permit is valid for�lntn�tlM F.1 1it r�tgpf approval per 20 AAC 25,00 65 ),/G Aflachm is in Duplicate,/g ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 26, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock and applications for permits to drill two laterals out of the KRU 1 B-16 (PTD# 194-037) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in December 2018. The objective will be to drill two laterals KRU 1 B - 16A and 1 B-16AL1 targeting the Kuparuk A -sand interval. The CTD completion is planned to isolate the IB -16 perforations mechanically. ConocoPhillips requests a variance to the requirements of 20 AAC 25.112(c) for the alternate plugging method to isolate/abandon 1 B-16 with a swell packer and liner -top packer in the final lateral CTD completion. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the sundry application are the following documents: - 10403 Sundry Application for KRU IB -16 - Operations Summary in support of the 10-403 sundry application - Proposed CTD Schematic - Current Well Bore Schematic Attached to permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 1 B-1 6A and 1 B-16AL1 - Detailed Summary of Operations - Directional Plans for 1 B -16A and 1 B-16AL1 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 1 B-1 6A and 1 B-16AL1 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary .......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4)) ............. . _..... _................... __.................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 ............................................................................. (Requirements of 20 AAC 25.005(c)(5)) ............... _... _. _. _..... _.. ... ..........................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 7. Diverter System Information ..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))..........................................................................................................................--.................. 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................ 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 1B -16A and 1 B-16ALl laterals................................................................................6 Attachment 2: Current Well Schematic for 1 B-16............................................................................................................6 Attachment 3: Proposed Well Schematic for 1 B -16A and 1 B-16AL1 laterals..................................................................6 Page 1 of 6 November 26, 2018 PTD Application: 1131-16A & 1 B-16AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(x) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1 B -16A and 1 B-16AL1. The laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1 B -16A and 1 B-16AL1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3 500 psi. Using the maximum formation pressure in the area of 3513 psi at the datum in 1A -04A (i.e. 10.7 ppg EMW), the maximum potential surface pressure in 1 B-16, assuming a gas gradient of 0.1 psi/ft, would be 2883 psi. Seethe "Drilling Hazards Information and Reservoir Pressure" section for more details. The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 113-16 was measured to be 2607 psi at the datum (8.0 ppg EMW) on 7/7/2016. The maximum downhole pressure in the 1B-16 vicinity is the 1A -04A at 3513 psi at the dataum (10.7 ppg EMW) measured on 7/10/2017. ' Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 1 B-16 have injected gas, so there is a possibility of encountering free gas while drilling the 1 B-16 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 1 B-16 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 B-16 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 November 26, 2018 PTD Application: 1B -16A & 1B-16AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 16" 62.5 H-40 WELDED 41' 2-3/8", 4.7#, L-80, ST -L slotted liner; IB -16A 7250 9300 6612 6532 aluminum billet on to 40 L-80 BTC 40.8' 4423' 2-3/8", 4.7#, L-80, ST -L slotted liner; 1 B-16AL1 7040 9900 6498 6540 with seal bore deployment sleeve on L-80 BTC MOD 38.9' 7438' 38.9' to Existing Casingkiner Information Category OD Weight Opt) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 WELDED 41' 121' 41' 121' 1640 670 Surface 9-5/8" 40 L-80 BTC 40.8' 4423' 40.8' 4163' 5750 3090 Production 7" x 5" 26 L-80 BTC MOD 38.9' 7438' 38.9' 6979' 7240 5410 Tubing4" x 3-1/2" 11 x-55 9.3 BTC MOD 38.9' 6704' 38.9' 6286' 6300 5750 7. Diverter System Information (Requirements of 20 AA C 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission.. Description of Drilling Fluid System - Window milling operations: Chloride -based PowerVis mud (8.6 ppg) - Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically ✓ overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. - Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and shale stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 1B-16 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 November 26, 2018 PTD Application: 1B -16A & 1B-16AL1 Pressure at the 1B-16 Window 7045' MD, 6605' TVD Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 1 B-16 is a Kuparuk A and C Sand producer equipped with 4" x 3-1/2" tubing and 7" x 5" production casing. The CTD sidetrack will utilize two laterals to target the A -sands to the north and south of 1 B-16. The laterals will improve recovery and target resource not produced by the existing wellbore. Wireline will set a thru-tubing mechanical whipstock inside the 5" casing at the planned kick off point of 7045' MD pre -rig. CDR3-AC will cut a window in the 1B-16 production casing and drill the 1131-16A lateral. The lateral will be completed with 2-3/8" slotted liner from TD up to the AL1 lateral kick off point with an aluminum billet for kicking off. The AL1 lateral will be kicked off from the A lateral and drilled to TD. It will be completed with 2-3/8" slotted liner from TD to outside of the window. Solid liner, a swell packer, and a seal bore deployment sleeve with liner top ✓' packer will be used to isolate the existing perforations in the ..1_B-16 wellbore. The liner top packer will be run with slickline after CDR3-AC has ngge own and moved off. CTD Drill and Complete 1B-16 Laterals: Pre -CTD Work 1. RU Slick -line: Pull K -Valve. Conduct dummy whipstock drift. Install new gas lift design. 2. RU Service Coil: Mill out "D" nipple. 3. RU E -line: Set thru-tubing whipstock in 5" casing. 4. Prep site for Nabors CDR3-AC. Page 4 of 6 November 26, 2018 Pumps On 1.8 bpm) Pumps Off A -sand Formation Pressure 8.0 2706 psi 2706 psi Mud Hydrostatic 8.6 2909 psi 2909 psi Annular friction i.e. ECD, 0.08psi/ft) 564 psi 0 psi Mud + ECD Combined no chokepressure) 3473 psi Overbalanced -767psi) 2909 psi Overbalanced -203psi) Target BHP at Window 11.8 3991 psi 3991 psi Choke Pressure Required to Maintain Target BHP 518 psi 1082 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 1 B-16 is a Kuparuk A and C Sand producer equipped with 4" x 3-1/2" tubing and 7" x 5" production casing. The CTD sidetrack will utilize two laterals to target the A -sands to the north and south of 1 B-16. The laterals will improve recovery and target resource not produced by the existing wellbore. Wireline will set a thru-tubing mechanical whipstock inside the 5" casing at the planned kick off point of 7045' MD pre -rig. CDR3-AC will cut a window in the 1B-16 production casing and drill the 1131-16A lateral. The lateral will be completed with 2-3/8" slotted liner from TD up to the AL1 lateral kick off point with an aluminum billet for kicking off. The AL1 lateral will be kicked off from the A lateral and drilled to TD. It will be completed with 2-3/8" slotted liner from TD to outside of the window. Solid liner, a swell packer, and a seal bore deployment sleeve with liner top ✓' packer will be used to isolate the existing perforations in the ..1_B-16 wellbore. The liner top packer will be run with slickline after CDR3-AC has ngge own and moved off. CTD Drill and Complete 1B-16 Laterals: Pre -CTD Work 1. RU Slick -line: Pull K -Valve. Conduct dummy whipstock drift. Install new gas lift design. 2. RU Service Coil: Mill out "D" nipple. 3. RU E -line: Set thru-tubing whipstock in 5" casing. 4. Prep site for Nabors CDR3-AC. Page 4 of 6 November 26, 2018 PTD Application: 1B -16A & 1B-16AL1 Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1B -16A Lateral a. Mill 2.80" window at 7045' MD. b. Drill 3" bi-center lateral to TD of 9300' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 7250' MD. 3. 113-16AL1 Lateral a. Kick off the aluminum billet at 7250' MD. b. Drill 3" bi-center lateral to TD of 9900' MD. c. Run 2-3/8" slotted liner from TD to outside the window. d. Run swell packer, 2-3/8" solid liner, and seal bore deployment sleeve with top of liner set in the tubing tail. 4. Freeze protect, ND ROPE, and RDMO Nabors CRD3-AC. Post -Rig Work 1. RU Slick -line: Record SBHP, Set Liner Top Packer. 2. Return to production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA un -deployment, the steps listed above are observed, only in reverse. Liner Running — The 1 B-16 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids" section for more details. — While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. Page 5 of 6 November 26, 2018 PTD Application: 1B -16A & 1B-16AL1 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. . • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral NameDistance 16-16A 18,500' 1 B-16AL1 16,050' - Distance to Nearest Well within Pool Lateral Name Distance Well 1 B-1 CA 1907' 1 B-02 1B-16AL1 985' 1B-09 16. Attachments Attachment 1: Directional Plans for 1B -16A and 1B-16AL1 laterals Attachment 2: Current Well Schematic for 1B-16 Attachment 3: Proposed Well Schematic for IB -16A and 1 B-16AL 1 laterals Page 6 of 6 November 26, 2018 ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 1 B Pad 113-116 1 B-1 6A Plan: 1 B-16A_wp04 Standard Planning Report 20 November, 2018 BA UGHES a GE company 'P, ConocoPhillips BA, KER Conoco Phillips Planning Report �j IGHES aGEcompany Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kupamk 18 Pad Well: 1B-16 Wellbore: 1 B-1 6A Design: 1B-16A_wp04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1B -i6 Mean Sea Level 18-16 (M i02.00usft (18-16) True . Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) • System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kupamk 1 B Pad 1B-16 Turn Site Position: Northing: 5,969,646.72 usft Latitude: 70' 19'40.290 N From: Map Easting: 549,457.39 usft Longitude: 149' 35'56.057 W Position Uncertainty: 0.00 usft Slot Radius: 0,000in Grid Convergence: 0.38 ' ' Well 1B-16 Turn Rate Magnetics Model Name Sample Date Well Position +NI -S 0.00 usft Northing: 5,969,646.83 usft Latitude: 70° 19'40.243 N (nT) +E/ -W 0.00 usft Easting: 550,195.14 usft Longitude: 149° 35'34.518 W Position Uncertainty (°) 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1B -16A Turn Rate Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°1100usft) TVD Below 1°) n (nT) Inclination BGGM2018 2/1/2019 -1.08 16.78 80.88 57,428 Design 1B -16A wp04 (°) (I 45.00 Audit Notes: (usft) (usft) 6,823.00 21.40 Version: Phase: PLAN Tie On Depth: 6,823.00 Vertical Section: Depth From (TVD) +N/4 +E/ -W Direction 2,062.30 (usft) (usft) (usft) (°) -2.45 0.00 0.00 0.00 210.00 Plan Sections Build Turn Rate Rate Rate Measured (°/100usft) (°/100usft) (°1100usft) TVD Below 0.00 0.00 Depth Inclination Azimuth -1.08 System +N/ -S +E/ -W (usft) (°) (I 45.00 (usft) (usft) (usft) 6,823.00 21.40 336.64 270.00 6,294.34 1,991.78 -1,043.79 7,045.00 19.00 337.28 -6.97 6,502.67 2,062.30 -1,073.81 7,075.00 22.73 331.84 -2.45 6,530.70 2,071.92 -1,078.44 7,253.34 100.00 301.82 7.00 6,611.05 2,164.20 -1,187.81 7,400.00 94.05 235.49 260.00 6,590.85 2,160.41 -1,324.97 7,600.00 92.00 221.63 6,580.24 2,028.54 -1,474.30 7,850.00 90.41 204.19 6,574.93 1,819.51 -1,609.56 8,050.00 95.60 191.17 6,564.41 1,629.72 -1,670.12 8,250.00 90.71 178.03 6,553.37 1,431.15 -1,686.03 8,550.00 87.45 198.78 6,558.26 1,136.07 -1,729.59 8,800.00 90.55 216.00 6,562.66 915.00 -1,844.16 9,300.00 96.17 181.38 6,532.42 449.73 -2,002.06 Dogleg Build Turn Rate Rate Rate TFO (°/100usft) (°/100usft) (°1100usft) (°) 0.00 0.00 0.00 0.00 1.09 -1.08 0.29 175.04 14.00 12.44 -16.13 330.00 45.00 43.33 -16.84 330.00 45.00 4.06 45.22 270.00 7.00 -1.02 -6.93 262.00 7.00 -0.64 -6.97 265.00 7.00 2.59 -6.51 292.00 7.00 -2.45 -6.57 250.00 7.00 -1.09 6.92 99.00 7.00 1.24 6.89 80.00 7.00 1.12 -6.92 260.00 Target 1120/2018 6: 17.4 IPM Page 2 COMPASS 5000.14 Build 85D ConocoPhillipsBA_ ICER ConocoPhillips Planning Report UGHES a GEcompany Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1 B-16 Company: _Con=Phillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 B-16 Q 102.00usft (18-16) Site: Kuparuk 1 B Pad North Reference: True Well: 18-16 Survey Calculation Method: Minimum Curvature Wellbore: 10-16A Design: 18-16A_Wp04 TVD Below Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/3 +E/ -W Section Rate Azimuth Northing Easting (usft) (•) (_) (usft) (usft) (usft) (usft) (°1100usit) V) (usft) (usft) 6,823.00 21.40 336.64 6,294.34 1,991.78 -1,043.79 -1,203.03 0.00 0.00 5,971,631.39 549,138.15 TIP 6,900.00 20.57 336.85 6,366.23 2,017.11 -1,054.68 -1,219.53 1.09 175.04 5,971,656.64 549,127.09 7,000.00 19.49 337.14 6,460.18 2,048.63 -1,068.07 -1,240.13 1.09 174.85 5,971,688.07 549,113.49 7,045.00 ' 19.00 337.28 6,502.67 2,062.30 -1,073.81 -1,249.10 1.09 174.57 5,971,701.70 549,107.66 KOP 7,075.00 22.73 331.84 6,530.70 2,071.92 -1,078.44 -1,255.12 14.00 -30.00 5,971,711.29 549,102.97 End 14 tills, Start 46 dig 7,100.00 32.93 321.51 6,552.79 2,081.53 -1,084.97 -1,260.18 45.00 -30.00 5,971,720.85 549,096.38 7,200.00 76.46 306.52 6,609.41 2,134.49 -1,144.02 -1,276.51 45.00 -20.82 5,971,773.41 549,036.98 7,253.34 100.00 301.82 6,611.05 2,164.20 -1,187.81 -1,280.35 45.00 -11.46 5,971,802.83 548,992.99 4 7,300.00 99.33 280.52 6,603.12 2,180.70 -1,230.45 -1,273.32 45.00 -90.00 5,971,819.04 548,950.25 7,400.00 94.05 235.49 6,590.85 2,160.41 -1,324.97 -1,206.48 45.00 -93.62 5,971,798.12 548,855.88 End 45 dis, Start 7 dls 7,500.00 93.05 228.55 6,584.65 2,099.03 -1,403.59 -1,116.02 7.00 -98.00 5,971,736.22 548,777.67 7,600.00 92.00 221.63 6,580.24 2,028.54 -1,474.30 -1,019.62 7.00 -98.43 5,971,665.26 548,707.45 6 7,700.00 91.38 214.65 6,577.28 1,949.97 -1,535.99 -920.73 7.00 -95.00 5,971,586.29 548,646.29 7,800.00 90.74 207.68 6,575.43 1,864.47 -1,587.69 -820.83 7.00 -95.21 5,971,500.45 548,595.16 7,850.00 90.41 204.19 6,574.93 1,819.51 -1,609.56 -770.97 7.00 -95.33 5,971,455.36 548,573.60 7 7,900.00 91.72 200.95 6,574.00 1,773.36 -1,628.74 -721.40 7.00 -68.00 5,971,409.08 548,554.73 6,000.00 94.32 194.44 6,568.73 1,678.28 -1,659.08 -623.90 7.00 -68.06 5,971,313.81 548,525.03 8,050.00 95.60 191.17 6,564.41 1,629.72 -1,670.12 -576.32 7.00 -68.40 5,971,265.18 548,514.32 a 8,100.00 94.39 187.87 6,560.06 1,580.60 -1,678.35 -529.66 7.00 -110.00 5,971,216.01 548,506.42 8,200.00 91.94 181.30 6,554.52 1,481.13 -1,686.32 439.54 7.00 -110.29 5,971,116.50 548,499.11 8,250.00 90.71 178.03 6,553.37 1,431.15 -1,686.03 -396.40 7.00 -110.65 5,971,066.53 548,499.74 9 8,300.00 90.16 181.48 6,552.99 1,381.16 -1,685.82 -353.22 7.00 99.00 5,971,016.55 548,500.29 8,400.00 89.06 188.40 6,553.68 1,281.60 -1,694.42 -262.69 7.00 99.03 5,970,916.94 548,492.35 8,500.00 87.98 195.32 6,556.27 1,183.83 -1,714.95 -167.75 7.00 98.98 5,970,819.04 548,472.48 8,550.00 87.45 198.78 6,558.26 1,136.07 -1,729.59 -119.07 7.00 98.80 5,970,771.19 548,458.15 10 8,600.00 88.06 202.23 6,560.22 1,089.28 -1,747.09 -69.80 7.00 80.00 5,970,724.29 548,440.97 8,700.00 89.30 209.12 6,562.53 999.23 -1,790.37 29.83 7.00 79.86 5,970,633.97 548,398.30 8,800.00 90.55 216.00 6,562.66 915.00 -1,844.16 129.66 7.00 79.71 5,970,549.39 548,345.08 11 8,900.00 91.76 209.11 6,560.64 830.79 -1,897.93 229.48 7.00 -80.00 5,970,464.82 548,291.88 9,000.00 92.95 202.20 6,556.52 740.78 -1,941.17 329.05 7.00 -80.14 5,970,374.54 548,249.25 9,100.00 94.09 195.28 6,550.39 646.32 -1,973.22 426.88 7.00 -80.42 5,970,279.87 548,217.83 9,200.00 95.17 188.34 6,542.31 548.82 -1,993.62 521.52 7.00 -80.85 5,970,182.25 548,198.09 9,300.00 1 96.17 181.38 6,532.42 • 449.73 -2,002.06 611.55 7.00 -81.41 5,970,083.12 548,190.31 Planned TD at 9300.00 11/202018 6.17:41PM Page 3 COMPASS 5000.14 Build 85D `, ConocoPhillips ER ConocoPhillips Planning Report BF UGHES affcompany Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1 B Pad Well: IB -16 Wellbore: 1 B-16A Design: 113-16A wp04 Casing Points Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 18-16 Mean Sea Level 1B-16 @ 102.00usft(1 B-16) True Minimum Curvature Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,300.00 6,532.42 2 318" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NIS +El -W (usft) (usft) (usft) (usft) Comment 6,823.00 6,294.34 1,991.78 -1,043.79 TIP 7,045.00 6,502.67 2,062.30 -1,073.81 KOP 7,075.00 6,530.70 2,071.92 -1,078.44 End 14 dls, Start 45 dls 7,253.34 6,611.05 2,164.20 -1,187.81 4 7,400.00 6,590.85 2,160.41 -1,324.97 End 45 cls, Start 7 dls 7,600.00 6,580.24 2,028.54 -1,474.30 6 7,850.00 6,574.93 1,819.51 -1,609.56 7 8,050.00 6,564.41 1,629.72 -1,670.12 8 8,250.00 6,553.37 1,431.15 -1,686.03 9 8,550.00 6,558.26 1,136.07 -1,729.59 10 8,800.00 6,562.66 915.00 -1,844.16 11 9,300.00 6,532.42 449.73 -2,002.06 Planned TO at 9300.00 112012018 8.17:41PM .Page 4 COMPASS 5000.14 Build 85D `- ConocoPhillipsBAi(ER ConocoPhillips Travelling Cylinder Report 11GHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1B Pad Site Error. 0.00 usft Reference Well: 18-16 Well Error: 0.00 usft Reference Wellbore 1B -16A Reference Design: 1 B-16A_wpG4 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 B-16 1B-16 @ 102.00usft(i B-16) 1 B-16 @ 102.O1 (1 B-16) True Minimum Curvature 100 sigma EDT 14 Alaska Production Offset Datum Reference 1 B-1 6A wp04 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200" 100/1000 of reference From Interpolation Method: MD Interval 100.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,119.80 usft Error Surface: Pedal Curve Survey Tool Program Date 11/20/2018 From To Reference Offset (usft) (usft) Survey (Weighers) Tool Name Description 193.59 6,823.00 18-16(1846) MWD MWD - Standard Deviation 6,823.00 9,300.0018-16A_wp04(16-16A) MWD MWD- Standard Distance Casing Points from Plan Offset Well - Wellbore - Design (usft) Measured vertical (usft) Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 2,700.00 9.300.00 6.634.42 2 3/8" 61.12 2.375 3.000 Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1 B Pad 1 B-03 - 1 B-03 - 1 B-03 2,624.12 2,700.00 130.84 61.12 84.86 Pass - Major Risk 1 B-05 - 1 B-05 - 1 B-05 1,217.25 1,200.00 257.26 30.61 226.80 Pass - Major Risk 1 B-06 - 1 B-06 - 1 B-06 605.47 600.00 140.15 8.54 131.61 Pass - Major Risk 1 B-07 - 1 B-07 - 1 B-07 407.64 400.00 19.16 7.68 11.48 Pass - Major Risk 18-08 - 1 B-08 - 1 B-08 507.07 500.00 101.15 7.81 93.34 Pass - Major Risk 1 B-08 - 1 B -08A- 1 B -08A 508.06 500.00 101.17 7.83 93.34 Pass - Major Risk 1B-08-1B-08AL1-1B-08AL1 508.06 500.00 101.17 7.83 93.34 Pass - Major Risk 1B-08-1B-08ALI-01-1B-08ALl-01 508.06 500.00 101.17 7.81 93.36 Pass - Major Risk 1B-08-1B-08AL1-01-1B-08ALl-01 wp07 508.06 500.00 101.17 7.81 93.36 Pass - Major Risk 1B-08-1B-08AL1 PB1-1B-08ALl PB1 508.06 500.00 101.17 7.83 93.34 Pass - Major Risk 1 B-101 - 1 B-101 - 1 B-101 313.63 300.00 33.65 4.41 29.23 Pass - Major Risk 1 B-101 - 18.101 L1 - 1 B-101 1-1 313.63 300.00 33.65 4.41 29.23 Pass - Major Risk 1B -101-1B-101 PBI -1B-101 Pat 313.63 300.00 33.65 4.26 29.39 Pass - Major Risk 1B -102-1B-102-18-102 213.75 200.00 54.87 2.73 52.14 Pass - Major Risk 1B-11 - 1B-11 - 1B-11 2,308.56 2,400.00 207.53 64.07 151.41 Pass- Major Risk 1 B-12 - 1 B-12 - 1 B-12 499.22 500.00 72.17 9.85 62.32 Pass - Major Risk 1B -12 -Plan: 1B-12A-1B-12A(wp01) 499.22 500.00 72.17 9.95 62.22 Pass - Major Risk 18-13 - 1B-1311 - 18-131-1 1,319.72 1,300.00 352.56 23.24 329.34 Pass- Major Risk 18 -14 -1B -14-1B-14 1,827.64 1,800.00 194.28 41.98. 152.35 Pass - Major Risk 1B -15 -1B -15-1B-15 299.41 300.00 241.63 3.22 238.42 Pass - Major Risk 1B -15 -1B -15A -1B -15A 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk 1B-15-1B-15AL1-1B-15AL1 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk 1B-15-1B-15AL2-1B-15AL2 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk 1B-15-1B-15AL2PB1-1B-15AL2PB1 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk 1B-15-1B-15AL2PB2-1B-15AL2PB2 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk 1B-15-1B-15AL3-1B-15AL3 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk 1B-15-1B-15AL3PB1-1B-15A1-3PB1 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk 18 -16 -1B -16-1B-16 7,167.86 7,200.00 59.48 11.64 52.57 Pass - Major Risk 1 B-16 - 1 B-16ALI - 1 B-16AL1_wp03 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1120/2018 5:38:08PM Page 2 COMPASS 5000.14 Build 85D �, ConocoPhillips BA ER ConocoPhillips Travelling Cylinder Report FUGHES aGEcompany Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Coordinate Reference: Well 18-16 Project: Kuparuk River Unit TVD Reference: 1B-16@102.00usft(1 B-16) Reference Site: Kuparuk 1 B Pad MO Reference: IB -16 @ 102.00usft (1 B-16) Site Error: 0.00 usft North Reference: True Reference Well: 1 B-16 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1 B -16A Database: EDT 14 Alaska Production Reference Design: 1 B-16A_wp04 Offset TVD Reference: Offset Datum Summary Kuparuk I Pad- 16 -03 -1B -03-1B-03 Reference Offset Centre to N"o Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1 B Pad Veftmod Measured Vertical Reference Offset Toolface+ 1 B-17 - 1 B-17 - 1 B-17 597.89 600.00 91.23 13.39 77.86 Pass - Major Risk 1 B-17 - 1 B-171-1 - 1 B-1711 597.89 600.00 91.23 13.39 77.86 Pass - Major Risk 1 B-17 - 1 B-171-2 - 1 B-1712 597.89 600.00 91.23 13.39 77.86 Pass - Major Risk 1 B-17 - 1 B-171-2-01 - 1 B-1712-01 597.89 600.00 91.23 13.39 77.86 Pass - Major Risk 1B -17 -IB -1712-01 Pal -1B-171-2-01 PB1 597.89 600.00 91.23 13.39 77.86 Pass - Major Risk 1 B-18 - 1 B-18 - 1 B-18 399.50 400.00 47.89 4.70 43.20 Pass - Major Risk 1B -18 -1B -18A -IB -18A 399.50 400.00 47.89 4.70 43.20 Pass - Major Risk IB-18-IB-18AL1-1B-18AL7 399.50 400.00 47.89 4.70 43.20 Pass - Major Risk 1B-18-IB-18AL2-IB-1 BAL2 399.50 400.00 47.89 4.70 43.20 Pass - Major Risk 1B-18-IB-18AL3-1B-18AL3 399.50 400.00 47.89 4.70 43.20 Pass - Major Risk 1 B-18 - 1 B-18AL3-01 - 1 B -1 8A1-301 399.50 400.00 47.89 4.70 43.20 Pass - Major Risk 1B-18-1B-18AL3PB1-1B-18AL3PB1 399.50 400.00 47.89 4.70 43.20 Pass - Major Risk 1B -19 -1B -19-1B-19 299.64 300.00 108.70 3.31 105.40 Pass -Major Risk 1 B-19 - 1 B-1911 - 1 B-191-1 299.64 300.00 108.70 3.31 105.40 Pass - Major Risk 1 B-19 - 1 B-1911-01 - 1 B-1911-01 299.64 300.00 108.70 3.31 105.40 Pass - Major Risk IB -19 -1B -19L1 -02 -IB -19L1-02 299.64 300.00 108.70 3.31 105.40 Pass - Major Risk WSW -0I -WSW -OI -WSW -01 1,216.76 1,200.00 94.51 20.80 73.81 Pass - Major Risk WSW -02 -WSW -02 -WSW -02 1,017.31 1,000.00 110.65 19.06 92.23 Pass - Major Risk WSW -03 -WSW -03 -WSW -03 1,039.07 1,000.00 161.22 19.65 143.20 Pass - Major Risk WSW -04 -WSW -04 -WSW -04 1,315.78 1,300.00 70.13 34.13 36.31 Pass - Major Risk WSW -05 -WSW -05 -WSW -05 1,112.32 1,100.00 185.09 27.64 157.45 Pass - Major Risk WSW -06 -WSW -O6 -WSW -06 1,498.98 1,400.00 273.93 33.91 245.36 Pass - Major Risk WSW -O8 -WSW -08 -WSW -O8 1,472.02 1,400.00 327.81 38.99 288.96 Pass -Major Risk Offset Design Kuparuk I Pad- 16 -03 -1B -03-1B-03 ortser site Error. 0.00 use Survey P".: IO FINDER -MS Rule Asia ad: Melot Risk Mae, Well E.I. 0.00 use Reference Othet Semi Major Axis Measured Veftmod Measured Vertical Reference Offset Toolface+ Offset WBshere Centre Cesirg- ce. to No Go Allowehle Wamiry Depth Depth Depth Depth Affinuth a1M16 ♦EI4M RoleBW Centre car... 0.1sien (usft) (usft) (usft) uerm (usft) (usft) PI (reel !usft) (in) (usft) (use) (usft 10200 102.00 94.00 94.00 000 0.00 -8960 346 -497.19 3.000 497.20 025 496.95 Pass - Major Risk 107.90 107.90 100.00 100.00 0.00 0.00 -89.80 3.46 497.19 3.000 497,20 033 498.87 Pass - Major Risk 206.51 206.51 200.00 20000 0.07 0.14 -89.63 3.46 497.19 3.000 497.39 1,82 495.57 Pass. Major Risk 306.68 306.66 300.00 300.00 0.18 0.27 .89.82 3.46 497.19 3.000 497.63 345 491.17 Pass -Major Risk 405.61 405.47 400.00 400.00 0.30 0.40 -90.37 3.46 -497.19 3.000 498.07 5.10 492,97 Pass -Major Risk 506.07 505.62 500.00 500.00 0.44 0.53 -91.28 3.46 -497.19 3.000 498.52 6.82 491.70 Pass - Major Risk 603.93 602.92 600.00 600.00 0.61 0.67 .92.50 3.46 -497.19 3.000 49920 0.58 490.62 Pass -Major Risk 701.88 700.00 700.00 700.00 0.81 0.80 -94.01 3.46 497.19 3.000 500.58 10.41 490.17 Pass - Major Risk 010.76 607.54 000.00 800.00 1.00 0.93 -9584 3.95 496.75 3.000 501.30 1249 488.02 Pass - Major Risk 950.61 944.56 90000 899.99 1.43 1.06 -98.40 5.00 495.98 3.000 495]7 15.17 481.60 Pass - Major Risk 1061.83 1,052.50 1000.00 999.99 1]0 1.2) -101.07 557 -495.66 3.000 487.57 17.54 470.03 Pass - Major Risk 1.158.40 1.145.10 1,100.00 1.099.97 2.15 1.32 -104.00 6.88 495att 3.000 478.67 19.83 450.85 Pass - Major Risk 1,252.68 1,233.82 1.200.00 1,199.93 2.60 1.43 -107.53 9.93 -495.70 3.000 471.21 22,27 448.94 Pa. - Major Risk 1,345]9 1,319.92 1.300.00 1,299.80 3.11 1.56 -111.63 14.75 494.58 3.000 46440 24.07 439.51 Pass -Major Risk 1439.82 1406.42 1.400.00 1,399.43 3.58 1.69 -115.79 22.67 491.51 3.000 457.26 27.44 429.83 Pass -Major Risk 1,535.55 1,494.86 1,500.0 1499]1 3.97 1.03 .119.67 33.94 -487.40 3.000 449.85 29.79 420.15 Pass - Major Risk 1,630.71 1,582.90 1,800,00 1,597.58 4.34 1.00 -12351 48.36 -403.40 3,000 442]4 32.12 41079 Pass - Major Risk 1,729.65 1,674.63 1,700.00 1,695.81 4.80 2.12 -128.61 66.40 -478.67 3,000 434.67 34.71 40D.26 Pass - Major Risk 1.829.82 1]57.11 1,80.00 1792.63 530 2.28 -130.25 8920 -465]7 3.000 42006 37.41 383.15 Pass - Major Risk CC - Min centre to canter distance or covergem point, SF - min separation factor, ES - min ellipse separation 11!202018 5.38.08PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillips Travelling Cylinder Report I 11 E a GEcompany Company: ConocclPhillips(Alaska) Inc.-Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1B Pad Site Error: 0.00 usft Reference Well: 1 B-16 Well Error: 0.00 usft Reference Wellbore 1B -16A Reference Design: 1B-16A_wp04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 B-16 1 B-16 @ 102.001(1 B-16) 1 B-16 @ 102.001(1 B-16) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference 1B-16A_wp04 91tertype: NO GLOBAL FILTER: Using user defined selection 8 filtering criteria Survey Tool Program nterpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 6,823.00 to 9,300.00usft Scan Method: Trev. Cylinder North Results Limited by: Maximum center -center distance of 1,119.80 usft Error Surface: Pedal Curve Summary KuparuklBPad- 1B-16-1B-16-iB-16 Survey Tool Program Date 11/20/2018 Reference Offset From To Allowable (usft) (usft) Survey (Wellbore) Tool Name Description Deviation 193.59 6,823.00 18-16(18-16) MWD MWD -Standard Distance 6,823.00 9,300.00 18-16A_wp04(1B-16A) MWD MWD - Standard (usft) Casing Points (usft) VMical (usft) Vertical Measured Vertical Offset Casing Hole Casing- Depth Depth No Go Diameter Diameter Depth (usft) (usft) Name (in) (in) 1 B-14 - 1 B-14 - 1 B-14 9,300.00 6,634.42 23/8" +EFW 2.375 3.000 Summary KuparuklBPad- 1B-16-1B-16-iB-16 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) VMical (usft) Vertical Kuparuk 1 B Pad Offset Toolfi Offset Wellbore Co.',. Casing- Centre to No Go 1 B-11 -1 B-11 - IB -11 Depth Depth Depth Depth Out of range 1 B-14 - 1 B-14 - 1 B-14 -NIS +EFW Hole 3iae Centre Distance Out of range 1B -16 -1B -16-1B-16 7,139.43 7,150.00 26.75 10.60 19.92 Pass - Major Risk 1 B-16 - 1 B-16AL1 - 1 B-16AL1_wp03 fusel lint (usft) (usft) (usft) Out of range Offset Design KuparuklBPad- 1B-16-1B-16-iB-16 Waal site Error. Doo mit survey Program: 194-MW3 Rule Assigned: Major Risk Offset Well Error. O.00 usft Reference Offset Semi Major Axis Measured VMical Measured Vertical Reference Offset Toolfi Offset Wellbore Co.',. Casing- Centre to No Go Annapolis Warning Depth Depth Depth Depth AaimuN -NIS +EFW Hole 3iae Centre Distance oeviatbn lural (usft) (usm lush) loan] (USn) (1) junk) fusel lint (usft) (usft) (usft) 6.825.00 6,398.20 682500 6398.20 0.01 001 -23.35 1992.45 -1p4408 3.000 C.90 a81 -0.27 FAIL - Major Risk 6850.00 6.421.50 6,850.00 6421.50 0.11 0.12 -141.43 2.000.77 -1.047.67 3.000 0.00 1.62 -1.05 FAIL - Major Risk 6,875.00 6,444.85 6,875.00 6,444.85 0.21 0.23 -141.43 2,000.99 -1,0.51.20 3.000 0.00 2.42 -ISO FAIL - Major Risk 6.900.00 8.488.23 6.900.00 6468.23 0.31 0.31 -141.42 2.017.11 .1cial68 3.000 0.00 3.22 -2.54 FAIL - Major Risk 6,925.00 6,491.88 6,925.00 6,491.66 0.40 0.46 -141.40 2,025.14 -1,050.11 3.000 0.00 3.99 -3.24 FAIL - Major Risk 6,950.00 6,515.13 6,950.00 6.515.13 0.48 0.57 -141.36 2,033.07 4,061.48 3.030 0.00 4.74 -3.95 FAIL - Major Risk 8,975.00 6,538.64 6,975.00 6,53&6,1 0.57 0.68 -141.33 2,040.90 -1.084.80 3.000 0.00 5.50 4.65 FAIL - Major Risk 7.000.00 6.562.18 7.000.00 8,562.18 0,65 0.79 -141.30 2.048.83 -1.06807 3.000 0.00 6.26 -5.35 FAIL - Major Risk 7,02500 6,585.77 7,025.00 8,5111 0.74 0.90 -65.75 2,055.9 -1,071.28 3.000 0.01 7.02 -5.19 FAIL Major RM 7,050.00 60439 7,050.00 6.609.40 0.02 1.01 132.59 2,063.80 -1,074.44 3.000 0.03 7]0. 4.78 FAIL - Major Risk 7,074.94 6.632.64 7.075.0 6,633.06 0.91 1.13 128.78 2,07114 -1.077.55 3.000 118 0.55 4.41 FAIL - Major Risk 7,098.97 6.653.92 7,100.00 6.61 1.02 1.24 124.93 2,078.50 -1,080.60 3.000 5.53 9.31 -0.72 FAIL - Major Risk 7,120.72 6.671.25 7.125.00 6,600.50 1.15 1.34 122.56 2.085.03 -1.083.60 3.000 14.31 9.96 7.68 Pass - Major Risk 7,139.43 6.684.28 7.150.00 8,704.26 1.28 1.44 121.02 2.093.01 -1,086.57 3.000 26.75 10.60 19.92 Pass- Major Risk, CC, ES, SF 7,155.03 6,693.61 7,175.00 6.728.05 1.40 1.54 119.86 2.100.14 -1,089.50 3.000 42.04 11.15 35.14 Paas - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11202018 5.38.57PM - Page 2 COMPASS 5000.14 Build 85D (ut/gsn OSE) (+)qualy(-)glnos N� E o J'n N C1 0 a c e r o c W N 8,5 m 0 a a � e 0 capes a or m QHY �"�ayONhmNANpA Q mN o��MQmOf MQOmN via uio ofd ro.66, NNNNOIT N[+f��(G a �<n '=1n moQo o o oo00000 (D N�mC �+000000000000 YJ000[V YlN0�00 2100 JN ��aM�]NNNNNOmN m .......... 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J N� mONO�Q�-N�AOM Q 1yfrn �AMNN QmN Ar 001 (V�COmQ)m-^m uim Q NNNNNf� j AmmN (gQrOID W .0 (n fhmAomNmQMNmQ � 01� QOM�rnmn ��n vmimM 825 ~��b[NO b[O� LQ a00 t�0 tmDd Z�'�`mNmmQm��oroM Q m Q N m M m r M m o m lA MMM�O'INN��N� UpOOIR C 0. -NSA r CQO��yyOOOQaOAQm� �O mOam�� O N�NOTQ�O Wi ♦ O 0 0 d'O o O O O O O O O ]50 Nf+]00000000 00000000000 No hOOmmmV]00 3 O � O ��..NMQmmAm010'N O N + 695 G (ui/gsn 5L) q;dad )eoivaA amy IS 1201 112: 1051 995 900 825 ]50 3 _ 695 O1 1-81 600 25 450 ]5 00 225 50 it 5 0 95 -150 -2zs -300 601 V9l' l -395 -450 -525 -600 -695 -)50 -825 Ec V91 8l -900 9]5 .105 Y -112 6 F u 49— .120 _ W _.__- ..__._: _....... .121 o x 1 .135 Y -142 .150 W -ISJ -165 97 (ui/gsn 5L) q;dad )eoivaA amy IS VI Q S a 0 0 c 0 V .: KUP PROD 1B-16 ConocoPhillips well1, t'ueates Max AngleBr) TD .fla$K•d ln6° welleore APIIVWI F,[IG Name wenC[r[smps 50@92245]00 KUPARUK RIVER UNIT WP R" ncl l°I mOnMe) Fn Dlm lrcNel 2363 2,23041 74500 K8'DedDO RI9 Release Gale 41.11 32511994 Comment NR (ppm) Odle SSSV: TROP 20 12129/2015 Annotation End 0418 Last P/O: 19.16, 969316156:52PM arpulx ma Annolalicn Oep1hd-I ErNOate An"-,--umdeny End Dalaie[ .......... OBSOLETE-IGNORE:DO Last Tag SLIM ],109.0 61512016 Rev Reason: TAG, M2S pproven 61612016 XANGER: S0a a5 ng mg6 Casln9 DescnPlian OD llpl ID lent Lop IflK81 SN DepIn IXK81 SetCepin ITVO1 WVLen 11... Grade Top TM1rW GONDUCTOR 16 15.060 41.0 1210 1210 82.50 H40 WELOED .Ing Oes[riglon OD lin) 1011n1 T -P IXKB)-"S."'NB) Se10m1n I, V0, --a 11... Grade Top Thrmd SURFACE 9518 8.835 40.8 4.424.1 4,1645 4000 L-60 BTC Casing De lotion Op lin) IDlinl ioo'no., Set Depen IXKO) set ..pan I. et,.. wuLen p... trio[ Top 'in.' MOD PRODUCTION ] 2'. 389 ],441.1 6982.5 2600 L-80 BTC MOO _ 7Y5"@6690' Tubing Strings Turing Wscnplion $Icing Ma.. IDlinl iopIXKO set Oepin lX.. set Dept IN011... W1110n9 Gm[a Top LonnMion TUBING4'k35" 4 34]6 38.9 6]044 6.2660 1100 J-55 BTC MOO CONDVCTOR: 410.1210 Completion Details Nominal lD TOP NKDI T,P(TVS(dKa) Topincll'I Item Oes Co. Nm 38.9 38.9 005 HANGER MCEVOY GEN N HANGER 4000 1,893.1 1,8253 23.23 SAFETY VLV CAMCO TROP -4A SAFETY VALVE 3.312 9AFEry Vtv;1033.1 4,104.1 3,8889 21.93 XO Reducing CROSSOVER 4 z 3.5. ID 2.992, 69.3, J-55, 3.500 EVEBROMOD 6.6654 6,2493 21.61 SEALASSY BAKER GBH -22 LOCATOR 1110SEAL ASSEMBLY 3.000 6.666.2 6$50.5 21.61 PACKER BAKER FB -1 PERMENANT PACKER 4.000 OASUFT;2SSS 6.6696 62536 2160 SSE SEAL BORE EXTENSION 4,000 6.6871 6,270A 21.58 NIPPLE CAMCO D NIPPLE NO GO 2.750 6,7038 6,2852 2156 SOS CASCO PE 500SHEAR OUT SUB 3000 Perforations 8 Slots snne Dene Tap a.(M)lsnolw GPS LIFT: 4.139) Tap 1.778 BM Ka) 16,3 (MBI ]Coin Dale 1) Type Gom 6.]]8.0 .MM)838 88380 6356.d 6410.3 UNITS Gd, 11O/1994 6.0 (PERF 2 PIP 90deg G3, 113-06 rising 5deg pleasing dS deg Odell 6,900.0 6,9080 6,468.2 6,4]5.] C-1,113-16 6t)SH108 6.0 APERF 2.5' PJ HSD, 60 deg random 6.918.0 6,926.0 6485.1 6,4926 C-1.1&16 61102008 6.0 APERF 2.5- PJ HSS 60 deg random SURFACE: 4064.24.1- ],124.0 7.1500 6,679.6 6,711.9 A4,iB-16 615/1994 4.0 IPERF 3 W HBO CEO Guns, 180 deg phasing GPB UIT', 520.5 Mandrel Inserts at Ge&LIPi',5P[6.9 N Top IN01 Valve Death Pon Slain TRO Run Top(.) IXKB) Maine Model OD tint 6av Type Type (in) Ips6 Run Ogle Com 1 2.623.5 2490.0 MERIA TMPD 1 GAS LIFT GLV BK2 0.156 1 261 122000 2 4.139.3 3,8996 CAMCA KBUG 1 GAS LIFT GLV BK 0.188 1,305.0 12/2811999 3 5.203.5 4.880.2 CAM0O KBUG 1 GAS LIFT OV BK 0.250 00 1212811999 GASL.P edt98 4 5.9869 56200 CAMCO KBUG 1 GAS LIR DMV BK 0.000 0.0 8114/1999 5 6619.8 6 207 3 CAMCO MMM 1112 GAS LIFT OMY RK 0.000 00 8/1311999 Notes: General & Safety End Annotation teAt-AS.A.Sai 212]12009 NOTE. EST 132' RATHOLE BELOW BOTTOM PERF POST FCO PACKEK6.E%2 61912010 NOTE.VI¢W SCh¢m91iC WlA dSkd 6Lh6ma11L9.0 69E:aW86 NIPPLE6077 SOS', 6,70.6 IPERF 6.]]908636 .0 APERF APER, IPERF,],1240.7159.0 MOOUCTN)N rE®� 6SHJ:39.aQul1 IB -16 Proposed CTD Schematic 16" 62# H-40 shoe @ 121' MD 9-5/8" 40# L-80 shoe @ 4424' MD �t{kIc C -sand perfs /2 6778'- 6838' MD 6900' - 6908' MD ZL • 7pTop@of99n00 @Mt 6690' MD rOP @ 7045' MD -1/2" x F TTWS A -sand Paris 7124'-7158'MID 7" x 5" shoe @ 7441' MD Modified by WRL 12 -Nov -2018 3-1/2" Camco TRDP-4A Safety Valve @ 1893' MD Locked Out: 81212017 4" 11# J-55 Tubing 4104' MD to surface Cross-over 4"x3.5" @ 4104' MD 3-1/2" Camco gas lift mandrels @ 2624', 4139', 5204', 5987'. & 6620' MD Baker FB -1 packer @ 6666' MD (4.0" ID) Baker SBE @ 6670' MD 3-1/2" Camco D landing nipple @ 6688' MD (2.75" min ID, No -Go) 3-1/2" Camco SOS @ 6704' MD 1,02 ZL • 7pTop@of99n00 @Mt 6690' MD f,B^!W fl 1 B -16t 'T_wp03 !/ 2L Ag TD @ 9300' MD Billet @ 7250' MD Davies, Stephen F (DOA) From: Long, William R <William.R.Long@conocophillips.com> Sent: Monday, November 26, 2018 5:24 PM To: Davies, Stephen F (DOA) Cc: Ohlinger, James J; Herring, Keith E Subject: RE: [EXTERNAL]KRU 1 B-16 (PTD 194-037; Sundry 318-522) Steve, The final lateral CTD completion is planned to isolate the 113-16 perforations mechanically. A swell packer will be ran outside the window and a liner -top packer will be installed at the top of the CTD completion. Solid liner will be ran between the two packers to prevent flow from the existing perforations. Please let me know if you would like any further information. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372(office) 281-723-6000 (cell) William.R.Long@ConocoPhillips.com From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Monday, November 26, 2018 4:33 PM To: Long, William R <William.R.Long@conocophiIlips. com> Subject: (EXTERNAL]KRU 113-16 (PTD 194-037; Sundry 318-522) William, I'm reviewing the Sundry Application to set a whipstock in KRU 18-16 and the two Permit to Drill Applications that accompanied it. I have a question: After setting the whipstock and drilling these two proposed wellbores, will the Kup C sand perforations in the original well KRU 16-16 remain open to the Kuparuk River Oil Pool? If the answer is no, then the proposed well names KRU 113-16A and 113-16AL1 are correct. (I13 -16A is the redrilled well, and 16-16AL1 is the first lateral drilled from that 113-16 redrill.) However, if the answer is yes, then both of the planned wellbores must be classified as lateral wellbores (because the original well is still open to the Kuparuk River Oil Pool), and they will instead be named KRU 113-161-1 and KRU 113-161-2. Which is correct? Thank you, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.daviesfda laska.gov. Remark: AOGCC Permit to Drill No. 218155 27 November 2018 INPUT OUTPUT Geographic, NAD27 State Plane, NAD27 5004 -Alaska 4, U.S. Feet KRU 1 B-1 BA Latitude: 70 19 40.24300 Longitude: 149 35 34.51800 1/1 NorthingN: 5969646. 866 Easting/X: 550195.144 Convergence: 0 22 59.95069 Scale Factor: 0.999902862 Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: 4.4_.5 PTD: Z/i5 - V/ Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: V ds't� POOL: k_�_Ktr �!T U Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50-_-_----. function the original (If last two digits Production should continue to be reported as a of in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception ) Operator order approving a spacing exception. (Company -Name assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company --Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#: 2181550 Company CONOCOPHILLIPS ALASKA INC Initial Class/rype DEV Well Name: KUPARUK RIV UNIT 1B -16A Program DEV Well bore seg ❑ / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven, gas conforms to AS31,05.030(j.1.A),0.2.A-D) . . . . . ...:. . . . . NA _ _ _ .... _ _ _ - - - Date: 1 Permit fee attached- -- - - - - - - - - - - - _ _ ... NA. S 2 Lease number appropriate_ _ _ .. _ _ _ - - - _ _ Yes _ _ _ Entire Well lies within ADL0025648....... . . . . . . . 3 Unique well name and number - - _ _ Yes ..... . .... . . . . ....... . 4 Well located in a. defined pool_ _ _ _ _ _ _ _ _ .. _ _ _ _ _ . _ Yes _ _ KUPARUK RIVER,-KUPARUK RIV OIL --490100 . . . . .... . . .... . . 5 .Well located proper distance from drilling unit. boundary _ _ _ _ Yes . - Kuparuk River Oil Pool, governed by Conservation Order No. 432D 6 Well located proper distance from other wells _ _ _ Yes _ _ Conservation Order No. 432D bas no interwell spacing restrictions. Wellbore will be more than 50V 7 Sufficient acreage available in drilling unit... _ Yes - _ _ - from an external property line_ where_ ownership or landownership. changes. As proposed,. well will. 8 If deviated, is wellbore plat included _ _ _ ... _ _ Yes _ _ conform to_spacing -requirements. 9 Operator only affected party- _ _ _ _ _ Yes 10 Operator has. appropriate bond in force . . ....... . . . . .... _ _ _ _ _ Yes_- Appr Date it Permit can be issued without conservation order- _ _ _ _ .. _ _ _ _ _ Yes SFD 11/27/2018 12 Permit can be issued without administrative. approval _ - _ - - . _ - _ - Yes 13 Can permit be approved before 15 -day wait _ _ _ _ _ _ _ _ _ _ Yes 14 Well located within area and strata authorized by Injection Order # (put, 10# in comments) (For NA 15 All wells within 114 mile area of review identified (For service well only) _ _ _ _ ___ NA_ _ . _ _ _ 16 Pre -produced injector; duration of pre -production less. than 3 months _(For service welt only) _ _ NA 18 Conductor stringprovided_ _ ____ _ _ _ _ _ ___ _ _ _ _ _ _ ______ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ Conductor set for KRU 1B-16 Engineering 19 Surface casing. protects all known.USDWS _ - - . _ . . . _ _ _ _ _ ___ NA _ .... .Surface casing set for KRU 1 B-16.. 20 CMT_vol adequate to circulate on conductor& surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ Surfers casing set and fully cemented _ 21 OMT.vol adequate to tie-in long string to surf csg. . . . . . . . . . . ....... . . ..... . . NA 22 CMT will cover all known productive horizons _ _ .... ... _ .. No... _ _ _ Productive_ interval will be completed with -uncemented slotted liner 23 Casing designs adequate for C. T, B 8 -permafrost _ _ _ _ _ _ _ _ _ _ _ _ _ . _Yes 24 Adequate tankage or reserve pit _ _ _ _ _ _ _ _ _ _ _ ___ _ _ _ _ _ _ _____ _ _ _ __ Yes _ _ _ _ Rig has steel tanks; all waste to approved disposal wells 25 Jf a_ re -drill, has a 10-403 for abandonment been approved _ .. .... Yes _ PTD 194 -037, -Sundry 318-522. 26 Adequate wellbore separation proposed.... _ _ .. _ _ Yes _ _� And collision analysis complete; no major risk failures _ 27 If_diverter required, does it meet regulations _ _ _ _ _ NA_ Appr Dale �29 28 Drilling fluid program schematic & equip list adequate_ _ _ _ .. _ _ - Yes .. Max formation_ pressure is 3513 psig(10.7 _) _ ppg EMW and maintain.overbal w/ MPD R �9( - RP9 EMW will drill w/ 8.6 VTL 12/5/2018 BOPEs, do they meet regWation _ _ _ _ . . . . .. . . . . ... . . . . .....Yes 30 BOPE press rating appropriate; test to_(put psig in comments)_ _ _____ _ _ _ _ __ _ _ _ Yes .... _ _ _ MPSP is 2883 psig; will test BOPs_to 3500 prig_ 31 Chokemanifold complies w/API_RP-53 (May 84) _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - - - - . 32 Work will occur without operation shutdown _ _ _ _ _ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 33 IS presence_of H?$ gas. probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .... Yes _ ... _ _ H2$ measures required. 34 Merhanical condition of wells within AOR verified (For service well only) _ _ .. _ _ _ .... NA 35 Permit can be issued w/o hydrogen sulfide measures ..... . . . . ....... . . . . .. . No.. _ .. _ Wells .on.16-Pad are. 1 -12S -bearing. H2S measures required._- Geology 36 Data presented on potential overpressure zones...... _ _ _ _ _ _ _ .... _ _ _ Yes _ _ _ _ _ _ . McArnum potential reservoir pressure.is 10.7 ppg.EMW;-expected reservoir pressure -is 6.0 ppg_ EMW. Appr Date 37 Seismic analysis of shallow gas.zones.. . . . ... . . . . ... _ _ ... _ _ _ .NA _ _ _ Well will be drilled using 8,6 ppg mud, a ooiled-tubing rig, and, managed pressure drilling SFD 11/27/2018 38 Seabed condition survey (if off -shore) _ _ _ __ _ _ _ __ _ _ _ _ _ NA _ _ - .. technique to control formation pressures and stabilize shale.sections. NOTE:. Chancy of 39 Contact name/phone for weekly.pfogress reports. [exploratory only _ _ - - - NA_ - - - - - _ _ encountering gas while drilling this -wellbore due to gas. injection performed in this area.. Geologic Engineering Public Commissioner: Date: Commissioner: Date Co Date SMC. �6c S 1 Zee Ile-