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Home My WebLink About219-104C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\5NH9KXKT\2025-06-09_24017_KRU_3R-111_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 24017 KRU 3R-111 50-029-23643-00 Caliper Survey w/ Log Data 09-Jun-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 219-104 T40544 6/11/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.11 11:50:28 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15959'feet None feet true vertical 3558' feet None feet Effective Depth measured 15959'feet 7912', 8423'feet true vertical 3558' feet 3610', 3641'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 8173'3625' Packers and SSSV (type, measured and true vertical depth)7912' 8423' 3610' 3641' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak 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: 2449' 2223' Burst CollapseCasing 3663'8883' 7512' 4-1/2" 15935' 3558' 2410' 142'Conductor Surface Intermediate 20" 13-3/8" 103' Liner 8844' measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 219-104 50-029-23643-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL355023, ADL 355024, ADL 373301 Kuparuk River Field/ West Sak Oil Pool KRU 3R-111 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) Shut-In Gas-Mcf MD 107 Size 142' 0 1270 323-605 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Paragon II BAKER MLZXP SSSV: None Elliot Tuttle elliott.tuttle@conocophillips.com (907) 263-4742 None Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov CTD/Workover Engineer By Grace Christianson at 1:56 pm, Jan 04, 2024 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O= Conoco Phillips, CN=Elliott Tuttle, E= elliott.tuttle@conocophillips.com Reason: I am the author of this document Location: Date: 2024.01.04 12:53:29-09'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle RBDMS JSB 011124 DSR-1/26/24 Page 1/7 3R-111 Report Printed: 1/3/2024 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) 12/3/2023 00:00 12/3/2023 04:00 4.00 MIRU, MOVE MOB P PJSM, Jack up rig and pull off 1J-137. Load rig mats from under rig onto trailer. Pull herculite from around tree 0.0 0.0 12/3/2023 04:00 12/4/2023 00:00 20.00 MIRU, MOVE MOB P Leave 1J Pad @ 04:00. Hold at Spine for crew change out. Cont move to 3R. At K Pad access road @ midnight. 0.0 0.0 12/4/2023 00:00 12/4/2023 03:30 3.50 MIRU, MOVE MOB P Cont rig move to 3R. Arrived on 3R @ 03:00AM. 0.0 0.0 12/4/2023 03:30 12/4/2023 08:30 5.00 MIRU, MOVE MOB P Hang new tree in cellar. Stage WH equipment behind well. Clear auxillary equipment to pull over the well. Set transition mats to crawl up on double mats. 0.0 0.0 12/4/2023 08:30 12/4/2023 10:30 2.00 MIRU, MOVE MOB P Spot rig over well. Tight clearance to 3R -11D and temporary wellhouse on ODS. 0.0 0.0 12/4/2023 10:30 12/4/2023 15:00 4.50 MIRU, MOVE RURD P Cont. to spot support equipment. Build cellar containment. Spot returns tanks and R/U hardline. Spot cuttings tank. Complete rig acceptance checklist. R/U circ manifold for well kill. Accept rig @ 15:00. Load 8.6# Seawater into Pits. 0.0 0.0 12/4/2023 15:00 12/4/2023 16:30 1.50 MIRU, MOVE RURD P LRS pump on location. PT hardline out to tanks to 2,500 psi. Initial Pressures (T/I/O) = 50 / 50 / 75 psi. Nordic 3 RKB to ULDS = 26.84'. 0.0 0.0 12/4/2023 16:30 12/4/2023 22:30 6.00 MIRU, MOVE COND P Heat Seawater truck to 120 deg F and build 100 BBL DeepClean pill. Heat 100 BBLS of Diesel onboard LRS Pump to 100 deg F. Suck out bleed trailer. Spot bleed trailer at OA. Unload 4 1/2" Tubing. Unload misc support equipment from 1J. 0.0 0.0 12/4/2023 22:30 12/5/2023 00:00 1.50 MIRU, WELCTL CIRC P PJSM. Bleed free gas from Tubing and IA. R/U LRS to tubing lined up to take returns out to tiger tank. PT lines to 2,500 psi. Pump 100 bbl hot diesel @ 2 BPM / 600 psi. R/D LRS. With rig pumps chase hot diesel with 140 bbl DeepClean Pill and 8.6# Seawater. Pump 100BBLS of Seawater @ 2 BPM and 130 psi, holding 60 psi back pressure. Monitor returns density at choke. 0.0 0.0 12/5/2023 00:00 12/5/2023 01:00 1.00 MIRU, WELCTL CIRC P Continue pumping cleaning fluids. S/D pumps. Stabilized pressure T=0, IA=60 PSI 0.0 0.0 12/5/2023 01:00 12/5/2023 01:36 0.60 MIRU, WELCTL KLWL P Start circulating well kill with 8.6 PPG seawater. Initial pressures T=0, IA=65, OA=20. Pump 100 BBls returned 51 BBls. S/D monitor pressures 0.0 0.0 12/5/2023 01:36 12/5/2023 02:00 0.40 MIRU, WELCTL KLWL P Initial S/D T=0, IA=118. IA down to 9 PSI 0.0 0.0 12/5/2023 02:00 12/5/2023 02:30 0.50 MIRU, WELCTL OWFF P Open up tubing & IA. Tubing on vac. IA sputtering diesel. 0.0 0.0 12/5/2023 02:30 12/5/2023 03:00 0.50 MIRU, WELCTL KLWL P Line up on tubing. Circ 100 BBls down tubing @ 2 BPM up annulas. Initial T=0, IA=20. Returned 20 BBls. Took 10 BBls to catch pressure in tubing, !0 more BBls to see pressure at choke 0.0 0.0 12/5/2023 03:00 12/5/2023 03:30 0.50 MIRU, WELCTL OWFF P S/D , T=0, IA=0. Open up tubing and IA in cellar. Reidual drip from IA 0.0 0.0 12/5/2023 03:30 12/5/2023 04:00 0.50 MIRU, WELCTL OWFF P Shut in IA for 10 minutes. Open up to slight drip - monitor 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 12/13/2023 Page 2/7 3R-111 Report Printed: 1/3/2024 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) 12/5/2023 04:00 12/5/2023 04:30 0.50 MIRU, WELCTL KLWL P Pump 100 BBls down tubing returns from IA. Catch tubing pressure at 9 BBls. Get returns to kill tank @ 13 BBls, T=0, IA=0 0.0 0.0 12/5/2023 04:30 12/5/2023 05:00 0.50 MIRU, WELCTL OWFF P Perform 30 Min No flow - good 0.0 0.0 12/5/2023 05:00 12/5/2023 07:00 2.00 MIRU, WELCTL RURD P Rig down kill lines 0.0 12/5/2023 07:00 12/5/2023 07:30 0.50 MIRU, WELCTL WWSP P Set BPV and test. Unable to get test from top down. Bleed off, shut in get good test 1000PSI / 10 minutes 0.0 0.0 12/5/2023 07:30 12/5/2023 09:30 2.00 MIRU, WELCTL NUND P Nipple down tree 0.0 0.0 12/5/2023 09:30 12/5/2023 13:00 3.50 MIRU, WELCTL WWSP P Bleed down SSSV line, R/U fill hose to IA. Loss rate 30 BBl/Hr. Start fill schedule @ 15 BBl / 30 min. Tree hand rigging off penetrations. Seal off injection line. Install 1/4 turn valve on SSSV line. Pressure up to 4500 PSI to maintain TRDP flapper valve open. Minor scaling on hanger threads 0.0 0.0 12/5/2023 13:00 12/5/2023 17:30 4.50 MIRU, WHDBOP NUND P Nipple up BOPE stack. Install flow nipple. 0.0 0.0 12/5/2023 17:30 12/5/2023 19:30 2.00 MIRU, WHDBOP RURD P Mobilized SLB & HES spooling unitis to RF and stage for pull. 0.0 0.0 12/5/2023 19:30 12/5/2023 20:30 1.00 MIRU, WHDBOP RURD P R/U BOPE testing equipment. R/U 4 1/2" TJ. Grease HCR and manual valves. Fill stack with fresh waster. 0.0 0.0 12/5/2023 20:30 12/6/2023 00:00 3.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's, w/ 4 1/2" test joints. Test blinds rams. Choke valves #2 to #5, #7 to 12, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 4 ½” EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Perform accumulator test. Initial pressure=2975 PSI, after closure=1800 PSI, 200 PSI attained 16 sec, full recovery attained =88 sec. UVBR's= 5 sec, Annular= 20 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2125 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Kam StJohn. Fillling hole w/ 15 Bbls every 30 Min. 0.0 12/6/2023 00:00 12/6/2023 02:15 2.25 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested choke valves #1, #6 & #13, Test manual and HCR choke valves. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Witness waived by AOGCC rep Kam StJohn. Continue filling hole w/ 15 Bbls every 30 Min. 0.0 0.0 12/6/2023 02:15 12/6/2023 02:30 0.25 MIRU, WHDBOP BOPE T Choke valves #9 & #6 failed initial test. Greased, functioned and passed retest. 0.0 0.0 12/6/2023 02:30 12/6/2023 03:00 0.50 MIRU, WHDBOP RURD P B/D, R/D testing equipment. Suck out stack. 0.0 0.0 12/6/2023 03:00 12/6/2023 03:30 0.50 MIRU, WHDBOP SVRG P Service rig, Inspect derrick. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 12/13/2023 Page 3/7 3R-111 Report Printed: 1/3/2024 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) 12/6/2023 03:30 12/6/2023 03:45 0.25 MIRU, WHDBOP MPSP P Pull tree test dart & BPV. Slight gas and fluid under BPV. 0.0 0.0 12/6/2023 03:45 12/6/2023 04:00 0.25 COMPZN, RPCOMP RURD P B/D, R/D circ hose off of IA. Close blinds and circ 15 Bbls down tubing w/ charge pump. Open up blinds, fluid falling in stack. 0.0 0.0 12/6/2023 04:00 12/6/2023 04:30 0.50 COMPZN, RPCOMP RURD P Make up landing joint. Engage hanger. Set down 10K. BOLDS. 0.0 0.0 12/6/2023 04:30 12/6/2023 05:00 0.50 COMPZN, RPCOMP PULL P Pull hanger T/ rig floor F/ 8174' T/ 8144'. Hanger off seat @ 100K. PUW=107K. 8,174.0 8,144.0 12/6/2023 05:00 12/6/2023 06:00 1.00 COMPZN, RPCOMP PULD P Terminate control lines. L/D hanger & landing joint. 8,144.0 8,144.0 12/6/2023 06:00 12/6/2023 07:30 1.50 COMPZN, RPCOMP RURD P Rig up Access sheave to outside spooler 8,144.0 8,144.0 12/6/2023 07:30 12/6/2023 09:00 1.50 COMPZN, RPCOMP CIRC P Circulate in tubing volume 2 BPM @ 25 PSI, pumped 235 lost 132 8,144.0 8,144.0 12/6/2023 09:00 12/6/2023 09:30 0.50 COMPZN, RPCOMP PULL P POOH F/8134 T/8015, PUW=100K 8,144.0 8,015.0 12/6/2023 09:30 12/6/2023 11:30 2.00 COMPZN, RPCOMP RURD P Pull lines over sheaves down to ground spooler and make up. Pump SSSV to 5000PSI to hold open 8,015.0 8,015.0 12/6/2023 11:30 12/6/2023 17:00 5.50 COMPZN, RPCOMP PULL P Pull old completion F/8013 T/4148. PUW=97K. Having problems with air line to spooler freezing up. Treating with airline antifreeze. First hole in joint 132 8,015.0 4,148.0 12/6/2023 17:00 12/6/2023 17:45 0.75 COMPZN, RPCOMP RURD P Cut gauge Tec wire, remove from spooler to accommodate remaining wire to be pulled from hole. 4,148.0 4,148.0 12/6/2023 17:45 12/6/2023 20:45 3.00 COMPZN, RPCOMP PULL P POOH w/ 4 1/2" completion spooling up control lines F/ 4148' T/ 2733', PUW=70K. 4,148.0 2,733.0 12/6/2023 20:45 12/6/2023 21:45 1.00 COMPZN, RPCOMP RURD P Bleed PSI off SSSV. Cut flat pack control line. Connect flat pack control line to SLB spooling unit on RF. Pressure up SSSV control line T/ 1800 PSI. Circ 5 Bbls down tubing to confirm SSSV is open. 2,733.0 2,733.0 12/6/2023 21:45 12/7/2023 00:00 2.25 COMPZN, RPCOMP PULL P POOH w/ 4 1/2" completion, spooling up control lines F/ 2733' T/ 935', PUW=63K. Large hole in joint #36 w/ ESP cable damage in same spot. @ 6479' In hole depth. 2,733.0 935.0 12/7/2023 00:00 12/7/2023 02:00 2.00 COMPZN, RPCOMP PULL P POOH w/ 4 1/2" completion, spooling up control lines F/ 935' T/ 209', PUW=47K. Joint #16 F/ 7281' T/ 7321' was completely collapsed. In hole depth. 935.0 209.0 12/7/2023 02:00 12/7/2023 04:00 2.00 COMPZN, RPCOMP PULL P POOH F/ 209' T/ surface. L/D motor shroud, ACP. Terminated ESP cable and lower to spooler on ground. ESP cable heavily corroded. L/D B profile, sliding sleeve, chemical injection mandrel & SSSV. Terminate control line and lower to spooling unit. L/D 192-47 seal assembly. Total of 199 cannon clamps, 12 half clamps, 4 motor clamps, 2 splice clamps & 414 pins recovered. 209.0 0.0 12/7/2023 04:00 12/7/2023 06:00 2.00 COMPZN, RPCOMP CLEN P Clean & clear RF. Remove spooling units and jewelry from RF & pipe shed. 0.0 0.0 12/7/2023 06:00 12/7/2023 07:30 1.50 COMPZN, RPCOMP RURD P Swap out spools from used cables to new cables. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 12/13/2023 Page 4/7 3R-111 Report Printed: 1/3/2024 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) 12/7/2023 07:30 12/7/2023 10:30 3.00 COMPZN, RPCOMP ELOG P Spot in SLB E-line. Load SLB tools. Mount sheaves. M/U tool string with SLB tractor and Read Cased hole 40 arm caliper 0.0 0.0 12/7/2023 10:30 12/7/2023 13:45 3.25 COMPZN, RPCOMP ELOG P RIH w/caliper, Start running tractor @ 3000 to 8153', Log up 35 FPM, PUW=1100 lbs 0.0 8,153.0 12/7/2023 13:45 12/7/2023 16:30 2.75 COMPZN, RPCOMP ELOG P Log up 35 FPM, PUW=1100 lbs. Close caliper arms. 8,153.0 0.0 12/7/2023 16:30 12/7/2023 17:00 0.50 COMPZN, RPCOMP RURD P R/D E-line. 0.0 0.0 12/7/2023 17:00 12/7/2023 22:30 5.50 COMPZN, RPCOMP RURD P Load completion equipment into shed. R/U GBR equipment & torque turn. Hang sheaves in derrick. Run ESP, flat pack & Tec wire over sheaves and secure on RF. Verify joint count and jewelry running order. Load clamps to pipe shed. 0.0 0.0 12/7/2023 22:30 12/7/2023 23:00 0.50 COMPZN, RPCOMP SFTY P PJSM w/ Access, Summit, HES, GBR & rig crew on running 4 1/2" completion w/ control lines & ESP. 0.0 0.0 12/7/2023 23:00 12/8/2023 00:00 1.00 COMPZN, RPCOMP PUTB P RIH w/ 4 1/2", 9.6#, L-80, Hyd 563 completion T/ 66'. Install chemical injection line. PT chem line T/ 400 PSI and hold while RIH. Hyd 563 torque turned T/ 3800 Ft/Lbs. Best O Life 2000 AG dope used. 0.0 66.0 12/8/2023 00:00 12/8/2023 03:15 3.25 COMPZN, RPCOMP PUTB P Cont RIH w/ 4 1/2", 9.6#, L-80, Hyd 563 completion F/ 66' T/ 142'. Connect PLE T/ ACP. Electrical check on PLE A=83.6, B=64.3, C=77. Cont RIH T/ 270'. Connect Opsis gauge. PT connection T/ 10000 PSI for 10 Min. Cont RIH T/ 300'. Hyd 563 torque turned T/ 3800 Ft/Lbs 4 1/2" Vam Top torque turned T/ 4440 Ft/Lbs 5 1/2" Vam FJL torque turned T/ 4270 Ft/Lbs 62.0 206.0 12/8/2023 03:15 12/8/2023 04:00 0.75 COMPZN, RPCOMP PUTB P Continue to RUH to 300' 206.0 300.0 12/8/2023 04:00 12/8/2023 07:30 3.50 COMPZN, RPCOMP RURD P Cut PLE, perform electrical check A=143, B=84.1, C=107.1. Splice PLE T/ ESP cable. Perform electrical check. 300.0 300.0 12/8/2023 07:30 12/8/2023 11:00 3.50 COMPZN, RPCOMP PUTB P Cont RIH w/ 4 1/2", 9.6#, L-80, Hyd 563 completion F/ 300' T/1459', RIW=57KPerforming electrical check every 1000'. 300.0 1,459.0 12/8/2023 11:00 12/8/2023 12:30 1.50 COMPZN, RPCOMP PUTB P ESP spooler hung up while RIH causing cable damage. Test cable. One leg of cable testing bad. Splice cable @ 1459' 1,459.0 1,459.0 12/8/2023 12:30 12/8/2023 16:30 4.00 COMPZN, RPCOMP PULL P POOH inspecting ESP line for damage 1,459.0 300.0 12/8/2023 16:30 12/8/2023 19:30 3.00 COMPZN, RPCOMP PULL P At PLE / ESP line splice. Trouble shoot On Joint #2, PLE to lug housing on BHA will not test. Continue out of hole disconnect PLE. Cont POOH T/ seals @ 31'. C/O ACP. L/D XN nipple w/ DFCV. Order out big bore DB nipple and send to SLB RHC plug installation. 300.0 0.0 12/8/2023 19:30 12/8/2023 19:45 0.25 COMPZN, RPCOMP CLEN P Clean and clear rig floor. Verify jewelry running order for modified completion run. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 12/13/2023 Page 5/7 3R-111 Report Printed: 1/3/2024 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) 12/8/2023 19:45 12/8/2023 20:00 0.25 COMPZN, RPCOMP SFTY P PJSM w/ Access, Summit, HES, GBR & rig crew on running 4 1/2" completion w/ control lines. 0.0 0.0 12/8/2023 20:00 12/9/2023 00:00 4.00 COMPZN, RPCOMP PUTB P RIH w/ 4 1/2", 9.6#, L-80, Hyd 563 completion T/ 83'. Install chemical injection line. PT chem line T/ 500 PSI and hold while RIH. Cont RIH T/ 163'. Connect PLE T/ ACP. Electrical check on PLE A=85.2, B=79.6, C=88.4. Cont RIH T/ 286'. Connect Opsis gauge. PT connection T/ 10000 PSI for 10 Min. Cont RIH T/ 320'. SOW=43K. Hyd 563 torque turned T/ 3800 Ft/Lbs. 4 1/2" Vam Top torque turned T/ 4440 Ft/Lbs 5 1/2" Vam FJL torque turned T/ 4270 Ft/Lbs Best O Life 2000 AG dope used. 0.0 320.0 12/9/2023 00:00 12/9/2023 01:45 1.75 COMPZN, RPCOMP RURD P Cut PLE, perform electrical check A=149.6, B=120, C=107.2. Splice PLE T/ ESP cable. Perform electrical check A=10.92, B=9.23, C=12.64. 320.0 320.0 12/9/2023 01:45 12/9/2023 04:45 3.00 COMPZN, RPCOMP PUTB P Cont RIH w/ 4 1/2" completion F/ 320' T/ 1334''. SOW=65K. Perform electrical check A=8.61, B=7, C=10.37. 320.0 1,334.0 12/9/2023 04:45 12/9/2023 14:45 10.00 COMPZN, RPCOMP PUTB P Cont RIH w/ 4 1/2" completion F/ 1334' T/ 7438''. SOW=62K. Perform electrical checks at 2440', 3456', 4482, 5446', 6426', & 7438, All tests in spec continue in well 1,334.0 7,438.0 12/9/2023 14:45 12/9/2023 17:30 2.75 COMPZN, RPCOMP PUTB P Cont RIH w/ 4 1/2" completion F/ 7438'' T/ 8127' Nordic 3 RKB. PUW=105, SOW=65K. 7,438.0 8,127.0 12/9/2023 17:30 12/9/2023 18:00 0.50 COMPZN, RPCOMP PUTB P M/U TD T/ joint 194, wash seals into SBE. Fully located @ 8166' Nordic 3 RKB. Filled IA verified no losses indicating seals are stung in. Pull seals out, fluid dropping in BOP @ 8145'. 8,066.0 8,166.0 12/9/2023 18:00 12/9/2023 19:00 1.00 COMPZN, RPCOMP HOSO P L/D joints # 194 & 193. M/U 3.78' space out pup below joint # 193. P/U landing joint. M/U to hanger. M/U hanger T/ string. Ran total of 199 Cross collar clamps, 1 Mid joint half clamp, 4 Motor clamps, 2 Spice clamps, 2 Upper GLM clamps, 3 Lower GLM clamps, 5 Mid joint clamps (217 clamps) & 1 SS super band. 8,166.0 8,120.0 12/9/2023 19:00 12/9/2023 23:30 4.50 COMPZN, RPCOMP RURD P Terminate flat pack CI line & gauge Tec wire through hanger. Perform electrical check on ESP A=9.84, B=8.99, C=11.45. Cut ESP cable and splice into Flat Tri Bore Pigtail. Feed through hanger. Perform electrical check on ESP A=10.19, B=9.35, C=11.6 Begin feeding well w/ 8.5 PPG Filtered CI seawater 15 Bbls every 30 Min. 8,120.0 8,120.0 12/9/2023 23:30 12/10/2023 00:00 0.50 COMPZN, RPCOMP CRIH P Circulating in 500 Bbls of filtered CI seawater. 8,120.0 8,120.0 12/10/2023 00:00 12/10/2023 02:00 2.00 COMPZN, RPCOMP CRIH P Complete pumping 500 Bbls filtered CI seawater in IA. R/D ESP sheave & Tec wire sheave. 8,120.0 8,120.0 Rig: NORDIC 3 RIG RELEASE DATE 12/13/2023 Page 6/7 3R-111 Report Printed: 1/3/2024 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) 12/10/2023 02:00 12/10/2023 03:45 1.75 COMPZN, RPCOMP PUTB P RIH tagged up on LTP @ 8133'. P/U, kelly up pump @ 1 BPM, 38 PSI. Tagged in same spot. Orient sting 180* out. Perform electrical check A=10.05, B=9.21, C=11.6. RIH, slid past LTP. Land hanger w/ seals @ 8172.76' ORKB. RILDS. 8,120.0 8,172.8 12/10/2023 03:45 12/10/2023 04:00 0.25 COMPZN, RPCOMP PRTS P PT hanger seal T/ 5000 PSI for 15 MIn. 8,172.8 8,172.0 12/10/2023 04:00 12/10/2023 04:45 0.75 COMPZN, RPCOMP RURD P R/U testing equipment for TGB & IA. R/D HES spooling unit. 8,172.0 8,172.0 12/10/2023 04:45 12/10/2023 06:00 1.25 COMPZN, RPCOMP PRTS P Attempt T/ PT tubing T/ 1500 PSI for 5 Min. Tubing not holding PSI. No pressure transfer observed to IA. 8,172.0 8,172.0 12/10/2023 06:00 12/10/2023 08:30 2.50 COMPZN, RPCOMP WAIT T MOB slick line to rig, Off load pipe shed. Clean rig floor and pipe shed. Install FOSV on hanger 8,172.0 8,172.0 12/10/2023 08:30 12/10/2023 09:30 1.00 COMPZN, RPCOMP SLKL T R/U HES Slick Line unit to floor valve with pump in sub and sensator. PT to 1800 PSI 8,172.0 8,172.0 12/10/2023 09:30 12/10/2023 10:30 1.00 COMPZN, RPCOMP SLKL T Latch up to ball and rod @ 2582 SLM. PUH. Bring pumps online at 1.5 BPM. Flush RHC plug. Set back down while pumping. Pressure up to 1800PSI. Shut down pump. Double block. Same pressure drop as before 8,172.0 8,172.0 12/10/2023 10:30 12/10/2023 11:00 0.50 COMPZN, RPCOMP SLKL T POOH. Recover ball and rod. No damage observed on ball 8,172.0 8,172.0 12/10/2023 11:00 12/10/2023 12:00 1.00 COMPZN, RPCOMP SLKL T Trip in with GR spear, Latch RHC @ 2589 SLM. Jar up to pull RHC. Sheared tool and release. Trip out 8,172.0 8,172.0 12/10/2023 12:00 12/10/2023 14:00 2.00 COMPZN, RPCOMP SLKL T Trip in well with GS spear, Latch RHC @ 2589 SLM. Jar RHC out of "Big Bore" DB nipple. Work to surface 8,172.0 8,172.0 12/10/2023 14:00 12/10/2023 15:30 1.50 COMPZN, RPCOMP SLKL T Start hand spanking wire. Hung up in tubing hanger. Able to get 700 Lb oil jar hits with 1250 LB straight pulls8174 8,172.0 8,172.0 12/10/2023 15:30 12/10/2023 17:30 2.00 COMPZN, RPCOMP SLKL T Shear off tool. Measure out and confirm RHC in tubing hanger. Group up rig team with SL crew and SL field supervisor discuss options. Consult town, configure non roller weight bar and spanks for use with rig tugger 8,172.0 8,172.0 12/10/2023 17:30 12/10/2023 18:00 0.50 COMPZN, RPCOMP SLKL T Start jarring with tugger, Pulled free on forth cycle. Recover RHC plug 8,172.0 8,172.0 12/10/2023 18:00 12/10/2023 19:30 1.50 COMPZN, RPCOMP SLKL T R/D tool string. Rig SL unit back. Run 3.80" drift 8,172.0 8,172.0 12/10/2023 19:30 12/10/2023 21:00 1.50 COMPZN, RPCOMP SLKL T R/D tool string. Rig SL unit back. Run 3.76" P2P RBP. Set RBP @ 2563'. Release, POOH. Stand back SL, 8,172.0 8,172.0 12/10/2023 21:00 12/10/2023 21:45 0.75 COMPZN, RPCOMP PRTS T PT TBG T/ 1500 PSI for 5 MIn. 8,172.0 8,172.0 12/10/2023 21:45 12/10/2023 22:45 1.00 COMPZN, RPCOMP RURD T R/D SL. R/U testing equipment T/ TBG & IA. 8,172.0 8,172.0 12/10/2023 22:45 12/10/2023 23:30 0.75 COMPZN, RPCOMP PRTS P Pressure up T/ 1500 PSI. SI TBG. PT IA T/ 2500 PSI for 30 Min. Dump tubing pressure, shear out SOV. Pump down IA @ 2 BPM 560 PSI. 8,172.0 8,172.0 12/10/2023 23:30 12/11/2023 00:00 0.50 COMPZN, RPCOMP RURD P R/D TBG testing equipment. L/D landing joint. 8,172.0 8,172.0 12/11/2023 00:00 12/11/2023 00:30 0.50 COMPZN, RPCOMP MPSP P Set HP BPV. 8,172.0 8,172.0 12/11/2023 00:30 12/11/2023 00:45 0.25 COMPZN, RPCOMP PRTS P PT BPV T/ 1000 PSI from below. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 12/13/2023 Page 7/7 3R-111 Report Printed: 1/3/2024 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) 12/11/2023 00:45 12/11/2023 01:30 0.75 COMPZN, WHDBOP RURD P R/D testing equipment. 0.0 0.0 12/11/2023 01:30 12/11/2023 03:30 2.00 COMPZN, WHDBOP NUND P Change LPR T/ 7" fixed for upcoming well. 0.0 0.0 12/11/2023 03:30 12/11/2023 05:00 1.50 COMPZN, WHDBOP NUND P N/D flow riser & flow nipple. N/D BOP. 0.0 0.0 12/11/2023 05:00 12/11/2023 12:00 7.00 COMPZN, WHDBOP NUND P Nipple up adapter and test void. HES terminate gauge wire and test, DH T=1443, DH T Temp=67.57°. DH Annular t+ 1621.17PSI, DH annular temp=.67.74° Summit terminated ESP cable. Final ESP cable readings A= 10.16 Gohm, B= 9.26 Gohm, C= 11.47 Gohm, Nipple up tree 0.0 0.0 12/11/2023 12:00 12/11/2023 14:30 2.50 COMPZN, WHDBOP RURD P Work rig down check list, R/D Geronimo line while waiting on broke down LRS Hot oil truck 0.0 0.0 12/11/2023 14:30 12/11/2023 15:15 0.75 COMPZN, WHDBOP RURD P LRS on location. MIRU, hold PJSM 0.0 0.0 12/11/2023 15:15 12/11/2023 16:00 0.75 COMPZN, WHDBOP PRTS P Flood lines Fill tree. PT tree to 4900 PSI. Good test. LRS pull vac. Drain stack. Pull BPV 0.0 0.0 12/11/2023 16:00 12/11/2023 17:00 1.00 COMPZN, WHDBOP CIRC P Circulate 172 BBls diesel down IA up tubing. Shut down. Blow lines down. 0.0 0.0 12/11/2023 17:00 12/11/2023 18:30 1.50 COMPZN, WHDBOP OTHR P Rig up U tube 0.0 0.0 12/11/2023 18:30 12/11/2023 20:00 1.50 COMPZN, WHDBOP RURD P Secure tree and cellar. Obtain final pressures T/IA/OA 0/100/0. 0.0 0.0 12/11/2023 20:00 12/12/2023 00:00 4.00 COMPZN, WHDBOP DMOB P Remove auxiliary equipment away from rig. Pull off of well, stage up on pad. Clean up around well. 0.0 0.0 12/12/2023 00:00 12/12/2023 12:00 12.00 COMPZN, WHDBOP DMOB P Perform planned modifications to choke and kill lines to remove grey lock type fittings. 0.0 0.0 12/12/2023 12:00 12/13/2023 00:00 12.00 DEMOB, MOVE DMOB T Perform planned modifications to choke and kill lines to remove grey lock type fittings. Repairing dump line from shakers to Pit #1. 0.0 0.0 12/13/2023 00:00 12/13/2023 04:30 4.50 DEMOB, MOVE DMOB T Repair flow line outside from shakers to pit #1 Rig released @ 04:30 Hrs. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 12/13/2023 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By LAST TAG:3R-111 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled DMY, set SOV 3R-111 1/1/2024rogerba Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR2018.65 39.3 142.3 142.3 154.34 65 SURFACE 13 3/8 12.42 79.8 2,499.0 2,222.7 68.00 L-80 Hyd 563 INTERMEDIATE 9 5/8 8.84 35.4 8,883.0 3,662.9 40.00 L-80 Hyd 563 LOWER LATERAL LINER 5.65 3.96 8,422.5 15,934.5 3,558.3 12.60 L-80 Hyd 563 SEAL BORE DIVERTER 4 1/23.89 8,341.98,457.03,642.812.60 L-80 Hyd 563 SRT / DSM L03 1/22.99 8,133.68,364.93,637.19.20 L-80 Vamtop Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 34.6 Set Depth … 8,172.8 String Max No… 4 1/2 Set Depth … 3,625.4 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection 4.5 ID (in) 3.96 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) 34.6 34.6 0.00 Hanger 13.440 Vault MB 242 13 5/8" x 4 1/2" tubing hanger (4.909 MCA Box Up) Vault MB 242 3.900 2,525.7 2,238.6 54.10 Mandrel – GAS LIFT 6.390 4-1/2" x 1" KBMG, GLM SLB KBMG 3.865 2,592.9 2,276.8 56.78 Nipple - DB 5.574 4 1/2" x 3.875" DB Nipple SLB DB Nipple 3.875 7,812.7 3,603.9 86.42 Mandrel – GAS LIFT 6.380 4-1/2" x 1" KBMG, GLM SLB KBMG 3.865 7,881.5 3,608.0 86.57 Gauge / Pump Sensor 6.041 HES Dual Opsis Gauge Mandrel (SN#:002804) HES Dual Opsis Gauge 3.913 7,947.7 3,612.0 86.53 Sliding Sleeve 5.500 5-1/2" GVSS, 4 1/2" Vamtop Box x 5 1/2", 23#, Vam FJL Box. Run in closed position. (OPENED ON 12/19/23) Access ESP Sliding Sleeve 3.910 7,951.63,612.286.53 Motor Shroud 5.500 Motor Shroud 9, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 7,956.4 3,612.5 86.54 Motor Centralizer 5.500 Motor Centralizer 8, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 7,958.23,612.686.54 Motor Shroud 5.500 Motor Shroud 8, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 7,963.03,612.986.54 Motor Centralizer 5.500 Motor Centralizer 7, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 7,964.7 3,613.086.55 Motor Shroud 5.500 Motor Shroud 7, 5 1/2" Vam FJL Box x Pin Access ESP 4.548 7,969.63,613.386.55 Motor Centralizer 5.500 Motor Centralizer 6, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 7,971.13,613.4 86.55 Motor Shroud 5.500 Motor Shroud 6, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 7,975.93,613.7 86.56 Motor Centralizer 5.500 Motor Centralizer 5, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 7,977.4 3,613.886.56 Motor Shroud 5.500 Motor Shroud 5, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 7,982.23,614.186.56 Motor Centralizer 5.500 Motor Centralizer 4, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 7,984.03,614.286.56 Motor Shroud 5.500 Motor Shroud 4, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 7,988.83,614.5 86.57 Motor Centralizer 5.500 Motor Centralizer 3, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 7,990.63,614.686.57 Motor Shroud 5.500 Motor Shroud 3, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 7,995.4 3,614.986.58 Motor Centralizer 5.500 Motor Centralizer 2, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 7,997.23,615.086.58 Motor Shroud 5.500 Motor Shroud 2, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,002.03,615.386.58 Motor Centralizer 5.500 Motor Centralizer 1, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,003.7 3,615.4 86.58 Motor Shroud 5.500 Motor Shroud 1, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,010.03,615.886.59 Annular Connection Port 5.500 ACP, 5", 18# Vam FJL Box x 4 1/2" 12.6# Vamtop Box Access ESP ACP 3.860 8,033.63,617.286.61 Profile Sub 4.500 B-Profile, 4 1/2", 12.6#, L-80 Vamtop Box x Box Access ESP B profile 3.913 8,047.23,618.086.62 No-go nipple 4.500 4 1/2" x 3.813" No-Go, 12.6# Vamtop Box x 4 1/2" Hyd 563 Box Access ESP No-go Nipple 3.813 8,061.33,618.886.61 Sliding Sleeve 5.510 3.813" NEXA-2 Sliding Sleeve, L-80, TSH BxP, Run in closed position. Baker CMU3.813 8,085.8 3,620.2 86.59 Mandrel 5.586 HES Chemical Injection Mandrel HES Chemica l Injection Mandrel 3.908 8,150.9 3,624.1 86.56 LOCATOR 5.220 Baker Mechanical locator, 5.22" OD No-Go BakerLocator 3.880 MULTIPLE LATERALS, 3R-111, 1/3/2024 11:18:14 AM Vertical schematic (actual) LOWER LATERAL LINER; 8,422.5-15,934.5 INTERMEDIATE; 35.4-8,883.0 SEAL BORE DIVERTER; 8,341.9-8,457.0 SRT / DSM L0; 8,133.6-8,364.9 SBR; 8,341.9 UPPER LATERAL LINER; 8,337.1-15,940.3 SRT / DSM L1; 8,133.0-8,379.5 Seal Assembly; 8,151.7 Mandrel; 8,085.8 Sliding Sleeve; 8,061.3 ESP MOTOR; 7,959.4 Sliding Sleeve; 7,947.7 ESP; 7,919.8 PACKER; 7,911.9 Mandrel – GAS LIFT; 7,812.7 Nipple - DB; 2,592.9 Mandrel – GAS LIFT; 2,525.7 SURFACE; 79.8-2,499.0 CONDUCTOR; 39.3-142.3 Hanger; 34.6 KUP PROD KB-Grd (ft) 39.34 RR Date 11/24/201 9 Other Elev… 3R-111 ... TD Act Btm (ftKB) 15,959.0 Well Attributes Field Name Wellbore API/UWI 500292364300 Wellbore Status PROD Max Angle & MD Incl (°) 97.08 MD (ftKB) 12,162.96 WELLNAME WELLBORE Annotation LAST WO: End DateH2S (ppm) 244 Date 10/4/2021 Comment Deep Set Downhole Operable … 3.813" Seal Bore IDLast TagLast Tag Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,151.7 3,624.2 86.56 Seal Assembly 4.740 Baker 192-47 GBH-22 Seal assembly, (spaced out 3.5') Baker 192-47 Seal Assembl y 3.880 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) 7,911.9 3,609.9 86.55 PACKER PARAGON II PACKER 3.76" OD, 2.0" ID, 4.31' LENGTH (CPP45037) HANG OFF XO 3.7" OD, 2" ID, .67' LENGTH EXTENSION 3.7" OD, 2" ID, .98' LENGTH STANDING VALVE 3.72" OD, 0" ID, 1.0' LENGTH SEAL STINGER 3.73" OD, 2.2" ID, .89' LENGTH (TOL= 7.85') Quadco 12/30/2023 2.000 7,919.8 3,610.3 86.55 ESP AccessESP Retrievable Pump Assembly includes: Polished Bore Receptacle, X-Over, Pump Discharge Head, Summit Upper Pump, Summit Lower Pump, and Upper Mating Unit OAL = 41.32' Summit 12/20/20230.000 7,959.4 3,612.7 86.54 ESP MOTOR AccessESP Retrievable ESP motor assembly includes: Lower Mating Unit, Upper Summit 338 Series Seal, Lower Summit 338 Series Seal, Access 375 250 HP Motor, Downhole Gauge, Plug Arm Assembly, and Motor Guide. OAL = 50.58' Access ESP/Bak er Hughes 12/20/20230.000 8,341.9 3,635.7 86.49 SBR 11/12/2019 2.705 8,350.0 3,636.2 86.49 WINDOW 10/29/2019 4.500 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) 2,525.7 2,238.6 54.10 1 ESP SOVBK 1 1/1/2024 2000 PSI TBG shear SLB KBMG 7,812.7 3,603.9 86.42 2 ESPDMYBK 1 12/10/2023SLB KBMG 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) 8,178.13,625.886.56 FLCV7.690 7'' FLCV, VamTop HC Box x Pin Bakre FLCV4.560 8,207.63,627.5 86.56SWIVEL 5.260 Baker Telescoping Swivel 4 1/2" Vamtop Box x Pin Baker Swivel Sub 3.980 8,221.83,628.4 86.56SRT 8.230 SRT 4 1/2" Vamtop box x 3 1/2" Vamtop Pin Baker SRT 8,251.13,630.186.55 SWIVEL 4.250Swivel Sub 3 1/2" Vamtop Box x Pin 2.950 8,283.6 3,632.1 86.53 NIPPLE 3.950 Nipple, 3-1/2" Camco, XN , 2.81" Profile,SN:???? HAL XN Nipple 2.750 8,409.6 3,639.8 86.47 2.60" No-go 4.500 2.60'' NO GO SUB, Hyd 563 Box x Pin 2.600 8,431.1 3,641.1 86.41 Anchor 7.390 7'' MLHR Production Anchor, 4 1/2" IBT-M Box x Pin TOP HALF Baker MLHR Prod Anch 3.940 8,435.4 3,641.4 86.39 Anchor 6.510 7'' MLHR Production Anchor, 4 1/2" IBT-M Box x Pin BOTTOM HALF (8435.4) BakerMLHR Prod Anch 3.940 8,457.03,642.886.274.730 8,422.5 3,640.686.46 PACKER 8.440 Baker MLZXP 7" x 9.625" Hanger Packer L-80 7" Hyd 563 pin Baker MLZXP 7.500 8,466.9 3,643.4 86.22 VALVE 7.000 7'' KOIV Isolation Tool, VamTop HC Box x Pin 4.770 8,469.8 3,643.6 86.20 VALVE 7.000 7'' C-2 Knock Out Isolation Valve, VamTop HC Box x Pin 5.190 8,947.9 3,665.8 87.80 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-9) 9 Baker Self Energize Packer 3.960 11,309.5 3,633.093.02 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-8) 8 Baker Self Energize Packer 3.960 11,698.4 3,598.7 95.85 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-7) 7 Baker Self Energize Packer 3.960 11,840.1 3,592.7 89.55 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-6) 6 Baker Self Energize Packer 3.960 12,272.3 3,578.1 91.89 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-5) 5 Baker Self Energize Packer 3.960 13,060.13,587.688.35 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-4) 4 Baker Self Energize Packer 3.960 13,327.9 3,579.8 94.46 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-3) 3 Baker Self Energize Packer 3.960 MULTIPLE LATERALS, 3R-111, 1/3/2024 11:18:19 AM Vertical schematic (actual) LOWER LATERAL LINER; 8,422.5-15,934.5 INTERMEDIATE; 35.4-8,883.0 SEAL BORE DIVERTER; 8,341.9-8,457.0 SRT / DSM L0; 8,133.6-8,364.9 SBR; 8,341.9 UPPER LATERAL LINER; 8,337.1-15,940.3 SRT / DSM L1; 8,133.0-8,379.5 Seal Assembly; 8,151.7 Mandrel; 8,085.8 Sliding Sleeve; 8,061.3 ESP MOTOR; 7,959.4 Sliding Sleeve; 7,947.7 ESP; 7,919.8 PACKER; 7,911.9 Mandrel – GAS LIFT; 7,812.7 Nipple - DB; 2,592.9 Mandrel – GAS LIFT; 2,525.7 SURFACE; 79.8-2,499.0 CONDUCTOR; 39.3-142.3 Hanger; 34.6 KUP PROD 3R-111 ... WELLNAME WELLBORE 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) 14,076.8 3,583.7 92.10 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-2) 2 Baker Self Energize Packer 3.960 14,469.7 3,550.395.21 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-1) 1 Baker Self Energize Packer 3.960 15,900.93,558.389.97 PBR 5.010 4 1/2'' Drillable Packoff Bushing, BTC Pin x Pin 2.375 MULTIPLE LATERALS, 3R-111, 1/3/2024 11:18:25 AM Vertical schematic (actual) LOWER LATERAL LINER; 8,422.5-15,934.5 INTERMEDIATE; 35.4-8,883.0 SEAL BORE DIVERTER; 8,341.9-8,457.0 SRT / DSM L0; 8,133.6-8,364.9 SBR; 8,341.9 UPPER LATERAL LINER; 8,337.1-15,940.3 SRT / DSM L1; 8,133.0-8,379.5 Seal Assembly; 8,151.7 Mandrel; 8,085.8 Sliding Sleeve; 8,061.3 ESP MOTOR; 7,959.4 Sliding Sleeve; 7,947.7 ESP; 7,919.8 PACKER; 7,911.9 Mandrel – GAS LIFT; 7,812.7 Nipple - DB; 2,592.9 Mandrel – GAS LIFT; 2,525.7 SURFACE; 79.8-2,499.0 CONDUCTOR; 39.3-142.3 Hanger; 34.6 KUP PROD 3R-111 ... WELLNAME WELLBORE C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-12-07_22575_KRU_3R-111_07-Dec-23_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22575 KRU 3R-111 50-029-23643-00 Caliper Survey w/ Log Data 07-Dec-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:219-104 T38221 12/12/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.12 10:42:55 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Kyle Karsten To:Regg, James B (OGC) Subject:Nordic 3 BOP test 3R-111 Date:Friday, December 8, 2023 9:13:55 AM Attachments:KUP 3R-111 AOGCC.xlsx You don't often get email from kyle.karsten@nordic-calista.com. Learn why this is important Good morning Jim. I sent this off but you were not in the email. Here you are sir. Kyle Karsten Nordic Rig 3 (907)670-6144 Rig (509)217-1478 Cell This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. .XSDUXN5LYHU8QLW5 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:3 DATE: 12/6/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2191040 Sundry #323-605 Operation: Drilling: Workover: xxx Explor.: Test: Initial: xxx Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1010 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 1P BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8"P Pit Level Indicators PP #1 Rams 1 2 7/8 x 5 1/2 P Flow Indicator PP #2 Rams 1 CSO P Meth Gas Detector PP #3 Rams 0 2 7/8 x 5 1/2 NA H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)2975 P Kill Line Valves 1 3 1/8"P Pressure After Closure (psi)1800 P Check Valve 0NA200 psi Attained (sec)16 P BOP Misc 2 2 1/16" 5000 P Full Pressure Attained (sec)88 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4@ 2106 P No. Valves 12 FP ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 1P Annular Preventer 20 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0NA #3 Rams NA #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:2 Test Time: HCR Choke 1 P Repair or replacement of equipment will be made within 0 days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/3/2023 21:09 Waived By Test Start Date/Time:12/5/2023 20:30 (date) (time)Witness Test Finish Date/Time:12/6/2023 2:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Nordic Tested on 4 1/2" test joint. Tested Gas alarms,PVT's and flow paddle. CM #6 and #9 intial fail,greased,passed. Karsten / Twedt CPAI Newell / Barr KRU 3R-111 Test Pressure (psi): igmanager.rig3@nordic-calista.co ic3.Companyman@conocophillips Form 10-424 (Revised 08/2022) 2023-1206_BOP_Nordic3_KRU_3R-111 9 9 9 999 9 9 9 9 9 9 9 -5HJJ CM #6 and #9 intial fail FP 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: West Sak Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 15959'1010 None Casing Collapse Conductor Surface Production Slotted Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Elliott Tuttle Contact Email: Contact Phone: 907-263-4742 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng KRU 3R-111 Other: Replace Tubing N/A Kuparuk River Field elliott.tuttle@conocophillips.com CTD/RWO Drilling Engineer Size West Sak Oil Pool 3558' Plugs (MD): 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Packer: 8423'MD/ 3641'TVD SSSV: 8127'MD/3623'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 355023, ADL 355024, ADL 373301 219-104 P.O. Box 100360, Anchorage, AK 99510 50-029-23643-00-00 ConocoPhillips Alaska, Inc Proposed Pools: L-80 TVD Burst 8174' MD 142' 2223' 142' 2449' 20" 13-3/8" 103' 2410' Perforation Depth MD (ft): None 8844' 4-1/2" None 3663'9-5/8" None15959' 3558' 11/25/2023 15935'7512' 4-1/2" 3558' Packer: Baker MLZXP SSSV: HES NE TRSV 8883' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O= Conoco Phillips, CN=Elliott Tuttle, E= elliott.tuttle@conocophillips.com Reason: I am approving this document Location: Date: 2023.11.06 20:01:35-09'00' Foxit PDF Editor Version: 12.1.2 Elliott Tuttle By Grace Christianson at 11:18 am, Nov 07, 2023 DSR-11/15/23 10-404 X SFD 11/13/2023VTL 11/16/2023 X BOP test to 2500 psig Annular preventer to 2500 psig *&:JLC 11/16/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.16 15:24:31 -09'00'11/16/23 RBDMS JSB 111723 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 6, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over 3R-111 (PTD# 219- 104). 3R-111 was drilled and completed in 2019 as a West Sak Producer. The well is a dual lateral ESP completion. A tubing leak has been identified at approximately 2,525’ RKB. A patch was run in the tubing; however, tubing by IA communication continued after setting the patch. Additional leak points may exist. The existing 4-1/2” tubing and ESP completion will be pulled from seals above the production packer. A new 4- 1/2” ESP completion will be run in the same configuration with new tubing. Plan is to re-run the Deep Set SSSV that is currently in hole after inspection, if it fails, the new completion will not have the SSSV and we understand that the well will have to continue passing a no flow test. If you have any questions or require any further information, please contact me at 907-252-3347. Elliott Tuttle Rig Workover Engineer CPAI Drilling and Wells Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN =Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am the author of this document Location: Date: 2023.11.06 20:02:07-09'00' Foxit PDF Editor Version: 12.1.2 Elliott Tuttle 3R-111 West Sak Producer Pull and Replace Tubing Procedure PTD: 219-104 Page 1 of 2 PPre-Rig Work Completed 1. Pull patch at 2,498’ RKB 2. Pull ESP retrievable components 3. Monitor DH Gauge 4. Set Test Packer at 7400’ CTMD, obtain CMIT to 2500psi, move up hole and fail @ 7000’CTMD. Lost drift and tagged tubing at 7310’ CTMD (10/14/2023) Remaining Pre-Rig Work 5. T-PPPOT and T-POT tests. 6. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3R-111. No BPV set for MIRU due to Nordic 3’s internal risk assessment. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Circulate KWF as needed. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 PSI. Test annular 250/2,500 PSI. Retrieve 4-1/2” Tubing and ESP 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing down to seal assembly at 8,153’ RKB. a. Set annular and circulate bottoms up. b. Send SSSV to vendor to perform inspection and pressure testing. Contingency Cleanout Run 6. Perform a cleanout run, based on tubing condition - if necessary. Install 4-1/2” Completion with ESP 7. Run 4.5” upper completion with seal assembly, chemical injection valve, sliding sleeve, rigless ESP, gas lift mandrel(s), and downhole gauge. RIH to depth, stab seal assembly into liner hanger and land tubing hanger. 8. Pressure test tubing to 1,500 psi 9. Pressure test IA to 2,000 psi for 30 minutes, Chart test. ND BOP, NU Tree 10. Confirm pressure tests, then shear out SOV with pressure differential. 11. Install BPV and test. ND BOPE. NU tubing head adapter assembly, NU tree and test tree to 5000 psi for 10 minutes. 12. Pull BPV and freeze protect well. 13. RDMO. 3R-111 West Sak Producer Pull and Replace Tubing Procedure PTD: 219-104 Page 2 of 2 PPost-Rig Work 1. Dummy off Sheared SOV in GLM(s) 2. Pull any plugs. 3. Install ESP General Well Information: Estimated Start Date: 11/25/2023. Current Operations: Shut in Well Type: Producer Wellhead Type: VetcoGray 4-1/16” 5M BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Static BHP: 1350 psi / 3,395’ TVD measured 7/25/2023 7.7ppg EMW, MPSP: 1010 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 4-1/2” completion from seals above the top packer, install a new 4-1/2” completion and rigless ESP system. Personnel: Workover Engineer: Elliott Tuttle (907-252-3347 / Elliott.tuttle@conocophillips.com) Reservoir Surveillance Engineer: Doug Valentine Production Engineer: Will Parker Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By LAST TAG:3R-111 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull P2P patches 2495' - 2555' & 2592' - 2622'3R-111 8/21/2023 praffer Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic 10.012/19/2019 jennalt Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR2018.65 39.3 142.3 142.3 154.34 65 SURFACE 13 3/8 12.42 79.8 2,499.0 2,222.7 68.00 L-80 Hyd 563 INTERMEDIATE 9 5/8 8.84 35.4 8,883.0 3,662.9 40.00 L-80 Hyd 563 LOWER LATERAL LINER 5.65 3.96 8,422.5 15,934.5 3,558.3 12.60 L-80 Hyd 563 SEAL BORE DIVERTER 4 1/23.89 8,341.98,457.03,642.812.60 L-80 Hyd 563 SRT / DSM L03 1/22.99 8,133.68,364.93,637.19.20 L-80 Vamtop Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 34.6 Set Depth … 8,174.3 String Max No… 4 1/2 Set Depth … 3,625.5 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd 563 ID (in) 3.96 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) 34.634.60.00 HANGER 13.375 VETCO/GE MB 242 13-1/2" x 4-1/2" tubing hanger (4.909 MCA Box Up) Vetco/ GE MB 242 13 1/2" x 4 1/2", PN: H46349 2-1, ser # 5321780 -1 3.900 2,583.4 2,271.5 56.36 GAS LIFT 6.437 4-1/2" x 1" Camco KBMG GLM w/ BEK latch SOV, Hyd 563 SN# 075AK03 Camco KBMG3.860 6,687.7 3,391.9 72.07 GAUGE 6.077 HES ROC-150 Annulus DHG + Mandrel SAP# 102818492 HES ROC- 150, HES SAP# 1028184 92 3.919 6,698.8 3,395.3 72.17 GAUGE 6.620 HES ROC-150 Discharge DHG + Mandrel SAP# 102818517 HES ROC- 150, HES SAP# 1028185 17 3.919 7,972.23,613.5 86.55 SLIDING SLEEVE 5.500 5-1/2" GVSS, 4 1/2" Vamtop Box x 5 1/2", 23#, Vam FJL Box. (CLOSED ON 10/1/23) Access ESP CMD Sliding Sleeve 3.910 7,976.23,613.7 86.56 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 3.893 7,980.63,614.086.56 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 7,982.13,614.186.56 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 3.893 7,986.63,614.4 86.57 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 7,988.1 3,614.4 86.57 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" Vam FJL Box x Pin Access ESP 3.893 7,992.5 3,614.7 86.57 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 7,994.0 3,614.8 86.57 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 3.893 7,998.5 3,615.1 86.58 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,000.0 3,615.2 86.58 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 3.893 8,004.4 3,615.4 86.58 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,005.9 3,615.5 86.58 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 3.893 8,010.4 3,615.8 86.59 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,011.93,615.986.59 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 3.893 8,016.33,616.186.59 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,017.83,616.286.60 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,023.5 3,616.5 86.60 ANNULAR CONNECTION PORT 5.950 ACP, 5", 18# Vam FJL Box x 4 1/2" 12.6# Vamtop Box Access ESP 3.853 MULTIPLE LATERALS, 3R-111, 11/6/2023 4:52:44 PM Vertical schematic (actual) LOWER LATERAL LINER; 8,422.5-15,934.5 INTERMEDIATE; 35.4-8,883.0 SEAL BORE DIVERTER; 8,341.9-8,457.0 SRT / DSM L0; 8,133.6-8,364.9 SBR; 8,341.9 UPPER LATERAL LINER; 8,337.1-15,940.3 SRT / DSM L1; 8,133.0-8,379.5 SSSV; 8,127.1 SSSV; 8,127.1 Chemical Injection Valve; 8,103.2 SLIDING SLEEVE; 8,078.5 NO GO NIPPLE; 8,063.7 ESP MOTOR; 7,977.8 SLIDING SLEEVE; 7,972.2 ESP; 7,930.5 OBSTRUCTION; 7,310.0 GAS LIFT; 2,583.4 LEAK - TUBING; 2,525.0 SURFACE; 79.8-2,499.0 CONDUCTOR; 39.3-142.3 HANGER; 34.6 KUP PROD KB-Grd (ft) 39.34 RR Date 11/24/201 9 Other Elev… 3R-111 ... TD Act Btm (ftKB) 15,959.0 Well Attributes Field Name Wellbore API/UWI 500292364300 Wellbore Status PROD Max Angle & MD Incl (°) 97.08 MD (ftKB) 12,162.96 WELLNAME WELLBORE Annotation LAST WO: End DateH2S (ppm) 244 Date 10/4/2021 Comment Deep Set Downhole Operable … 3.813" Seal Bore IDLast TagLast Tag Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,050.2 3,618.1 86.62 PROFILE SUB 4.500 B-Profile, 4 1/2", 12.6#, L-80 Vamtop Box x Box 3.985 8,063.7 3,618.9 86.61 NO GO NIPPLE 5.000 No-Go, 4 1/2" 12.6# Vamtop Box x 4 1/2" Hyd 563 Box 3.813 8,078.5 3,619.8 86.60 SLIDING SLEEVE 5.490 Camco W/ 3.813 X-nipple, 4 1/2" Hyd 563 PN 381NEXA27642, SN# 003 (CLOSED 9/30/23) Camco CMU Sliding Sleve w/ X-Profile P/N#381 NEXA27 642, S/N# 03 3.813 8,127.1 3,622.7 86.57 SSSV 6.620 HES NE TRSV, 6.62" x 3.813 X- nipple, TSH-Blue Box x Pin HES NE TRSV, HES SAP # 1027802 97 3.813 8,152.83,624.286.56 LOCATOR5.210 Mechanical locator (Collar 5.21" OD on top of Seal assembly) Baker 3.985 8,153.2 3,624.3 86.56 SEAL ASSY 4.730 Baker GBH-22 Seal assembly, 4 1/2" Hyd 563 Box Baker COMM No. H45301 0106, Trace # 1067386 42 3.958 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) 2,525.0 2,238.2 54.07 LEAK - TUBING TUBING LEAK BETWEEN 2525' - 2535' RKB, CTU TEST PKR 5/11/20233.990 2,600.0 2,280.6 57.09 LEAK TBG leak found with coil. 7/28/2022 3.992 7,310.0 3,545.3 79.57 OBSTRUCTI ON TUBING OBSTRUCTION SEEN BY COIL. Smallest toolstring attempted was a 2" nozzle with 2.13" toolstring. 10/14/2023 2.000 7,930.5 3,611.0 86.54 ESP Polish Bore, Pumps, Upper Mating Unit (OAL = 41 ft) 8/18/2022 0.000 7,977.8 3,613.8 86.56 ESP MOTOR lower mating unit, seals, motor, plug arm assembly, motor guaide (OAL=34.74) 12/26/2021 0.000 8,127.1 3,622.7 86.57 SSSV Deep Set Downhole Operable Valve HES NE Tubing- Retrievable Safety Valve 3.813" Seal Bore ID 11/23/20193.813 8,341.93,635.7 86.49SBR 11/12/2019 2.705 8,350.03,636.286.49 WINDOW 10/29/2019 4.500 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) 2,583.4 2,271.5 56.36 1 GAS LIFT SOV 1 0.0 7/30/2022 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,178.13,625.886.56 FLCV7.690 7'' FLCV, VamTop HC Box x Pin Bakre FLCV4.560 8,207.63,627.5 86.56SWIVEL 5.260 Baker Telescoping Swivel 4 1/2" Vamtop Box x Pin Baker Swivel Sub 3.980 8,221.83,628.4 86.56SRT 8.230 SRT 4 1/2" Vamtop box x 3 1/2" Vamtop Pin Baker SRT 8,251.13,630.186.55 SWIVEL 4.250Swivel Sub 3 1/2" Vamtop Box x Pin 2.950 8,283.6 3,632.1 86.53 NIPPLE 3.950 Nipple, 3-1/2" Camco, XN , 2.81" Profile,SN:???? HAL XN Nipple 2.750 8,409.6 3,639.8 86.47 2.60" No-go 4.500 2.60'' NO GO SUB, Hyd 563 Box x Pin 2.600 8,431.1 3,641.1 86.41 Anchor 7.390 7'' MLHR Production Anchor, 4 1/2" IBT-M Box x Pin TOP HALF BakerMLHR Prod Anch 3.940 8,435.4 3,641.4 86.39 Anchor 6.510 7'' MLHR Production Anchor, 4 1/2" IBT-M Box x Pin BOTTOM HALF (8435.4) Baker MLHR Prod Anch 3.940 8,457.03,642.886.274.730 8,422.5 3,640.686.46 PACKER 8.440 Baker MLZXP 7" x 9.625" Hanger Packer L-80 7" Hyd 563 pin Baker MLZXP 7.500 8,466.93,643.4 86.22 VALVE 7.000 7'' KOIV Isolation Tool, VamTop HC Box x Pin 4.770 8,469.8 3,643.6 86.20 VALVE 7.000 7'' C-2 Knock Out Isolation Valve, VamTop HC Box x Pin 5.190 8,947.9 3,665.8 87.80 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-9) 9 Baker Self Energize Packer 3.960 11,309.5 3,633.093.02 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-8) 8 Baker Self Energize Packer 3.960 11,698.4 3,598.7 95.85 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-7) 7 Baker Self Energize Packer 3.960 11,840.1 3,592.7 89.55 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-6) 6 Baker Self Energize Packer 3.960 MULTIPLE LATERALS, 3R-111, 11/6/2023 4:52:51 PM Vertical schematic (actual) LOWER LATERAL LINER; 8,422.5-15,934.5 INTERMEDIATE; 35.4-8,883.0 SEAL BORE DIVERTER; 8,341.9-8,457.0 SRT / DSM L0; 8,133.6-8,364.9 SBR; 8,341.9 UPPER LATERAL LINER; 8,337.1-15,940.3 SRT / DSM L1; 8,133.0-8,379.5 SSSV; 8,127.1 SSSV; 8,127.1 Chemical Injection Valve; 8,103.2 SLIDING SLEEVE; 8,078.5 NO GO NIPPLE; 8,063.7 ESP MOTOR; 7,977.8 SLIDING SLEEVE; 7,972.2 ESP; 7,930.5 OBSTRUCTION; 7,310.0 GAS LIFT; 2,583.4 LEAK - TUBING; 2,525.0 SURFACE; 79.8-2,499.0 CONDUCTOR; 39.3-142.3 HANGER; 34.6 KUP PROD 3R-111 ... WELLNAME WELLBORE 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) 12,272.3 3,578.1 91.89 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-5) 5 Baker Self Energize Packer 3.960 13,060.13,587.688.35 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-4) 4 Baker Self Energize Packer 3.960 13,327.93,579.894.46SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-3) 3 Baker Self Energize Packer 3.960 14,076.8 3,583.7 92.10 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-2) 2 Baker Self Energize Packer 3.960 14,469.7 3,550.3 95.21 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-1) 1 Baker Self Energize Packer 3.960 15,900.93,558.389.97 PBR 5.010 4 1/2'' Drillable Packoff Bushing, BTC Pin x Pin 2.375 MULTIPLE LATERALS, 3R-111, 11/6/2023 4:52:59 PM Vertical schematic (actual) LOWER LATERAL LINER; 8,422.5-15,934.5 INTERMEDIATE; 35.4-8,883.0 SEAL BORE DIVERTER; 8,341.9-8,457.0 SRT / DSM L0; 8,133.6-8,364.9 SBR; 8,341.9 UPPER LATERAL LINER; 8,337.1-15,940.3 SRT / DSM L1; 8,133.0-8,379.5 SSSV; 8,127.1 SSSV; 8,127.1 Chemical Injection Valve; 8,103.2 SLIDING SLEEVE; 8,078.5 NO GO NIPPLE; 8,063.7 ESP MOTOR; 7,977.8 SLIDING SLEEVE; 7,972.2 ESP; 7,930.5 OBSTRUCTION; 7,310.0 GAS LIFT; 2,583.4 LEAK - TUBING; 2,525.0 SURFACE; 79.8-2,499.0 CONDUCTOR; 39.3-142.3 HANGER; 34.6 KUP PROD 3R-111 ... WELLNAME WELLBORE 3R-111 Contingency RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 142 142 20" 18.65 154# - Welded Welded Surface 2499 2222 13 3/8" 12.415" 68# L-80 HYD563 HYD563 Intermediate 8883 3661 9 5/8" 8.835" 40# L-80 HYD563 HYD563 Upper Lateral 15940 3536 5.65" 3.96" 12.6# L-80 HYD563 HYD563 Lower Lateral 15934 3558 5.65" 3.96" 12.6# L-80 HYD563 HYD563 Tubing 8174 3625 4 1/2" 3.958" 12.6# L-80 HYD563 HYD563 Surface Casing Conductor Perfs Vault PC Vert MB 242 wellhead/ Tubing Hanger 4.909" MCA Box up 4-1/2" x 1" Camco KBMG GLM @ XXXX' RKB 4-1/2" HES Opsis Gauge @ XXXX' RKB 1/4" TEC AccessESP PCA (4 ea. Assy) @ XXXX' RKB No.4 ESP Cable 4-1/2" SLB NEXA Sliding Sleeve @ XXXX' RKB (3.812" ID) Chemical Injection Valve @ XXXX' RKB 3/8" x 1/4" Flat Pack Deep Set HES TRSV SSSV @ XXXX' RKB 3/8" x 1/4" Flat Pack 4-1/2" BKR Locator/ Seal Assembly @ 8152' RKB 7" x 9 5/8" SLZXP w/ 10' 7,375" Ext @ 8099.42' RKB 190-47 SBE (4.75" Seal Bore) @ 8136' RKB SRT (selective Re-entry Tool) @ 8192.42' RKB B Sand Lateral (Mainbore): 7" x 9 5/8" MLZXP Hanger Packer @ 8442.5' RKB 4.75" ID SBR @ 8450.78' RKB 4 1/2" x 6" RE Packer 4 1/2" 107 Micron Excluder Screen TD of Liner @ 15945' RKB Intermediate Casing D Sand Lateral (L1 Liner): RAM Hanger @ Top 8337.12' RKB 3.75" PBR for DSM @ 8373.85' RKB 4 1/2" x 6" RE Packer 4 1/2" 107 Micron Excluder Screen TD of Liner @ 16000.84' RKB RAM Hanger RAM SBD Selective Reentry Tool Dual Seal Module 3R-111 Contingency RWO Completion - Mo PPPL COETI NFDOM DM( O Ef KBt R) V. FLf KBt R) V. Of Kin. Momh Df Kin. Weigbt Kl/ GBt.radue Fbaedu Ktop. Fbaedu K/tm. ConuSctoa 142 142 20" 18.65 154# - Welded Welded PSaBdce 2499 2222 13 3/8" 12.415" 68# L-80 HYD563 HYD563 Dnteameuidte 8883 3661 9 5/8" 8.835" 40# L-80 HYD563 HYD563 Uppea I dteadl 15940 3536 5.65" 3.96" 12.6# L-80 HYD563 HYD563 Iowea Idteadl 15934 3558 5.65" 3.96" 12.6# L-80 HYD563 HYD563 FS/ ing 8174 3625 4 1/2" 3.958" 12.6# L-80 HYD563 HYD563 Surface Casing Conductor Perfs Vault PC Vert MB 242 wellhead/ Tubing Hanger 4.909" MCA Box up 4-1/2" x 1" Camco KBMG GLM @ XXXX' RKB 4-1/2" HES Opsis Gauge @ XXXX' RKB 1/4" TEC AccessESP PCA (4 ea. Assy) @ XXXX' RKB No.4 ESP Cable 4-1/2" SLB NEXA Sliding Sleeve @ XXXX' RKB (3.812" ID) Chemical Injection Valve @ XXXX' RKB 3/8" x 1/4" Flat Pack 4-1/2" BKR Locator/ Seal Assembly @ 8152' RKB 7" x 9 5/8" SLZXP w/ 10' 7,375" Ext @ 8099.42' RKB 190-47 SBE (4.75" Seal Bore) @ 8136' RKB SRT (selective Re-entry Tool) @ 8192.42' RKB V Pdnu I dteadl KEdin/oae.: 7" x 9 5/8" MLZXP Hanger Packer @ 8442.5' RKB 4.75" ID SBR @ 8450.78' RKB 4 1/2" x 6" RE Packer 4 1/2" 107 Micron Excluder Screen TD of Liner @ 15945' RKB Intermediate Casing f Pdnu I dteadl KI1 Iinea.: RAM Hanger @ Top 8337.12' RKB 3.75" PBR for DSM @ 8373.85' RKB 4 1/2" x 6" RE Packer 4 1/2" 107 Micron Excluder Screen TD of Liner @ 16000.84' RKB RAM Hanger RAM SBD Selective Reentry Tool Dual Seal Module C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-10-11_22565_KRU_3R-111_CaliperSurvey_LogData_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22565 KRU 3R-111 50-029-23643-00 Caliper Survey w/ Log Data Coil Flag 11-Oct-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 219-104 T38061 10/17/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.17 12:17:23 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch 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 15959'feet None feet true vertical 3558'feet None feet Effective Depth measured 15959'feet 7876', 7896', 11161'feet true vertical 3558'feet 4782', 4791', 6261'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 8174' MD 3625' TVD Packers and SSSV (type, measured and true vertical depth) 2495' MD 2555' MD 2592' MD 2622' MD 8422' MD N/A 2220' TVD 2256' TVD 2276' TVD 2292' TVD 3641' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 268 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Baker MLZXP Hanger Packer SSSV: None Jan Byrne jan.byrne@conocophillips.com (907) 659-7224Senior Well Integrity Specialist None None 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) 409 Gas-Mcf MD 260 Size 142' 1822 10182 1340 261808 255 measured TVD 9-5/8" 5.65" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 219-104 50-029-23643-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0355023, ADL0355024, ADL0373301 Kuparuk River Field/ West Sak Oil Pool KRU 3R-111 Plugs Junk measured Length Lower Lateral Liner 8848' 7512' Casing 3663' 3558' 8883' 15934' 2419' 142'Conductor Surface Intermediate 20' 13-3/8" 103' 2499' 2223' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov West Sak Oil Pool By Grace Christianson at 3:11 pm, Jun 12, 2023 Digitally signed by Jan Byrne DN: OU=Well Integrity, O=Conocophillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorge Alaska Date: 2023.06.12 09:07:14-08'00' Foxit PDF Editor Version: 12.1.2 Jan Byrne DTTMSTART JOBTYP SUMMARYOPS 5/5/2023 MAINTAIN WELL FREEZE PROTECT PUMPED 45 BBLS DSL DWN TBG PUMPED 5 BBLS DSL DWN FL 5/8/2023 REPAIR WELL RAN 4 1/2 TTS TEST TOOL DOWN TO 725' RKB RECOVER TOOLS COVERED IN HEAVY SCALE. SAMPLE RECOVERED & GIVEN TO LAB. JOB SUSPENDED FOR COIL. 5/10/2023 REPAIR WELL PERFORM WEEKLY BOP TEST. RAN 3.5" DJN, DRY TAG AT 1857' CTMD, WASH THRU EASILY TO PATCH AT 2575' CTMD, W/ SLICK SEAWATER. UNABLE TO GET RETURNS. 4.50" PIIP TEST TOOL TO TOP OF PATCH @ 2592' RKB. PUMP S. DIESEL TO VERIFY TUBING LEAK ABOVE 2592' RKB. START TESTING TUBING W/ TEST PACKER & S. DIESEL @ 2580' RKB. ****IDENTIFY TUBING X IA LEAK COMMUNICATING 2525' - 2535' RKB**** TUBING FREEZE PROTECTED W/ S. DIESEL. JOB SUSPENDED FOR PLAN FORWARD. 5/13/2023 REPAIR WELL SET 3.76" LOWER PIIP PACKER W/ MOE = 2558' RKB, CCL TO MOE = 11.2', CCL STOP = 2546.8' RKB, CORRELATED TO TUBING TALLY DATED 11/22/2019. JOB IS READY FOR SL SERIAL #: CPP45021 5/14/2023 REPAIR WELL SET 3.65'' PBR,SPACER PIPE,ANCHOR LATCH ASSEMBLY(OAL33.56') ON LOWER PACKER @ 2558'RKB. SET 3.76''P2P PACKER,SPACER PIPE,ANCHOR LATCH ASSEMBLY(OAL31.24') ME @ 2498'RKB. UNABLE TO OBTAIN A PASSING PT AGAINST SV IN PACK OFF BUT GOOD PRESSURE TEST TO 1000PSI WITH TEST TOOL IN UPPER PACKER. JOB COMPLETE. PBR: CPBR45002 ANCHOR LATCHES: CPAL 45015 & CPAL 45019 P2P: CPP45041 5/15/2023 REPAIR WELL SET 4-1/2" TTS TEST TOOL @ 2470' SLM, OBTAIN PASSING MITT TO 1500 PSI, PULL TEST TOOL, JOB COMPLETE. 6/3/2023 MAINTAIN WELL FREEZE PROTECT PUMPED 2 BBLS DSL DWN FL PUMPED 34 BBLS DSL DWN 3R-111 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By LAST TAG:3R-111 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set upper patch assembly.3R-111 5/14/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic 10.0 12/19/2019 jennalt 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 20 18.65 39.3 142.3 142.3 154.34 65 SURFACE 13 3/8 12.42 79.8 2,499.0 2,222.7 68.00 L-80 Hyd 563 INTERMEDIATE 9 5/8 8.84 35.4 8,883.0 3,662.9 40.00 L-80 Hyd 563 LOWER LATERAL LINER 5.65 3.96 8,422.5 15,934.5 3,558.3 12.60 L-80 Hyd 563 SEAL BORE DIVERTER 4 1/2 3.89 8,341.9 8,457.0 3,642.8 12.60 L-80 Hyd 563 SRT / DSM L0 3 1/2 2.99 8,133.6 8,364.9 3,637.1 9.20 L-80 Vamtop Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 34.6 Set Depth 8,174.3 Set Depth 3,625.5 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd 563 ID (in) 3.96 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) 34.6 34.6 0.00 HANGER 13.375 VETCO/GE MB 242 13-1/2" x 4-1/2" tubing hanger (4.909 MCA Box Up) Vetco/ GE MB 242 13 1/2" x 4 1/2", PN: H46349 2-1, ser # 5321780 -1 3.900 2,583.4 2,271.5 56.36 GAS LIFT 6.437 4-1/2" x 1" Camco KBMG GLM w/ BEK latch SOV, Hyd 563 SN# 075AK03 Camco KBMG 3.860 6,687.7 3,391.9 72.07 GAUGE 6.077 HES ROC-150 Annulus DHG + Mandrel SAP# 102818492 HES ROC- 150, HES SAP# 1028184 92 3.919 6,698.8 3,395.3 72.17 GAUGE 6.620 HES ROC-150 Discharge DHG + Mandrel SAP# 102818517 HES ROC- 150, HES SAP# 1028185 17 3.919 7,972.2 3,613.5 86.55 SLIDING SLEEVE 5.500 5-1/2" GVSS, 4 1/2" Vamtop Box x 5 1/2", 23#, Vam FJL Box. (Opened 12/4/19) Access ESP Sliding Sleeve 3.910 7,976.2 3,613.7 86.56 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 3.893 7,980.6 3,614.0 86.56 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 7,982.1 3,614.1 86.56 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 3.893 7,986.6 3,614.4 86.57 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 7,988.1 3,614.4 86.57 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" Vam FJL Box x Pin Access ESP 3.893 7,992.5 3,614.7 86.57 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 7,994.0 3,614.8 86.57 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 3.893 7,998.5 3,615.1 86.58 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,000.0 3,615.2 86.58 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 3.893 8,004.4 3,615.4 86.58 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,005.9 3,615.5 86.58 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 3.893 8,010.4 3,615.8 86.59 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,011.9 3,615.9 86.59 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 3.893 8,016.3 3,616.1 86.59 MOTOR CENTRALIZER 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,017.8 3,616.2 86.60 MOTOR SHROUD 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,023.5 3,616.5 86.60 ANNULAR CONNECTION PORT 5.950 ACP, 5", 18# Vam FJL Box x 4 1/2" 12.6# Vamtop Box Access ESP 3.853 MULTIPLE LATERALS, 3R-111, 6/8/2023 4:58:55 PM Vertical schematic (actual) LOWER LATERAL LINER; 8,422.5-15,934.5 INTERMEDIATE; 35.4-8,883.0 SEAL BORE DIVERTER; 8,341.9-8,457.0 SRT / DSM L0; 8,133.6-8,364.9 SBR; 8,341.9 UPPER LATERAL LINER; 8,337.1-15,940.3 SRT / DSM L1; 8,133.0-8,379.5 SSSV; 8,127.1 SSSV; 8,127.1 Chemical Injection Valve; 8,103.2 SLIDING SLEEVE; 8,078.5 NO GO NIPPLE; 8,063.7 ESP MOTOR; 7,977.8 SLIDING SLEEVE; 7,972.2 ESP; 7,930.5 PACKER; 7,922.6 PACKER - PATCH - LWR; 2,622.0 ANCHOR LATCH ON SPACER PIPE; 2,596.7 PACKER - PATCH - UPR; 2,592.0 GAS LIFT; 2,583.4 PACKER - PATCH - LWR; 2,555.0 PBR; 2,522.9 LEAK - TUBING; 2,525.0 SPACER PIPE; 2,500.0 SURFACE; 79.8-2,499.0 PACKER - PATCH - UPR; 2,495.0 CONDUCTOR; 39.3-142.3 HANGER; 34.6 KUP PROD KB-Grd (ft) 39.34 RR Date 11/24/201 9 Other Elev 3R-111 ... TD Act Btm (ftKB) 15,959.0 Well Attributes Field Name Wellbore API/UWI 500292364300 Wellbore Status PROD Max Angle & MD Incl (°) 97.08 MD (ftKB) 12,162.96 WELLNAME WELLBORE Annotation LAST WO: End DateH2S (ppm) 244 Date 10/4/2021 Comment Deep Set Downhole Operable 3.813" Seal Bore IDLast TagLast Tag Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,050.2 3,618.1 86.62 PROFILE SUB 4.500 B-Profile, 4 1/2", 12.6#, L-80 Vamtop Box x Box 3.985 8,063.7 3,618.9 86.61 NO GO NIPPLE 5.000 No-Go, 4 1/2" 12.6# Vamtop Box x 4 1/2" Hyd 563 Box 3.813 8,078.5 3,619.8 86.60 SLIDING SLEEVE 5.490 Camco W/ 3.813 X-nipple, 4 1/2" Hyd 563 PN 381NEXA27642, SN# 003 (Opened 12/1/19) Camco Sliding Sleve w/ X-Profile P/N#381 NEXA27 642, S/N# 03 3.813 8,127.1 3,622.7 86.57 SSSV 6.620 HES NE TRSV, 6.62" x 3.813 X- nipple, TSH-Blue Box x Pin HES NE TRSV, HES SAP # 1027802 97 3.813 8,152.8 3,624.2 86.56 LOCATOR 5.210 Mechanical locator (Collar 5.21" OD on top of Seal assembly) Baker 3.985 8,153.2 3,624.3 86.56 SEAL ASSY 4.730 Baker GBH-22 Seal assembly, 4 1/2" Hyd 563 Box Baker COMM No. H45301 0106, Trace # 1067386 42 3.958 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) 2,495.0 2,220.3 52.94 PACKER - PATCH - UPR Upper patch assembly P2P packer, xo, spacer pipe, & anchor latch. (OAL 31.24') TTS P2P CPP4 5041, CPAL 45019 5/14/2023 2.000 2,500.0 2,223.3 53.13 SPACER PIPE Spacer pipe CPAI 5/14/2023 2.000 2,522.9 2,236.9 53.99 PBR Set PBR assembly in lower packer. CPBR 45002 , CPAL 45015 5/14/2023 2.000 2,525.0 2,238.2 54.07 LEAK - TUBING TUBING LEAK BETWEEN 2525' - 2535' RKB, CTU TEST PKR 5/11/2023 3.990 2,555.0 2,255.5 55.20 PACKER - PATCH - LWR 3.76" PIIP PACKER W/ WLEG, MOE = 2558' RKB, OAL = 4.89' TTS PIIP CPP4 5021 5/13/2023 2.000 2,592.0 2,276.2 56.74 PACKER - PATCH - UPR 4.5" Upper Paragon II Packer (mid-element @ 2595.21') (total patch 30' mid-element to mid-element) Quadco CPP4 5011 8/22/2022 2.000 2,596.7 2,278.8 56.95 ANCHOR LATCH ON SPACER PIPE 4.5" Anchor Latch on Spacer Pipe Quadco CPAL 45018 8/22/2022 1.995 2,600.0 2,280.6 57.09 LEAK TBG leak found with coil. 7/28/2022 3.992 2,622.0 2,292.4 58.06 PACKER - PATCH - LWR 4-1/2" PARAGON II PACKER MID-ELEMENT AT 2625' RKB, 7200# RELEASE, OAL 4.89' CPP4 5027 8/21/2022 2.000 7,922.7 3,610.5 86.55 PACKER PARAGON II PACKER 3.76" OD, 2.0" ID, 4.31' LENGTH (CPP45037) HANG OFF XO 3.7" OD, 2" ID, .67' LENGTH EXTENSION 3.7" OD, 2" ID, .98' LENGTH STANDING VALVE 3.72" OD, 0" ID, 1.0' LENGTH SEAL STINGER 3.73" OD, 2.2" ID, .89' LENGTH (TOL= 7.85') CPP4 5037 8/19/2022 2.000 7,930.5 3,611.0 86.54 ESP Polish Bore, Pumps, Upper Mating Unit (OAL = 41 ft) 8/18/2022 0.000 7,977.8 3,613.8 86.56 ESP MOTOR lower mating unit, seals, motor, plug arm assembly, motor guaide (OAL=34.74) 12/26/2021 0.000 8,127.1 3,622.7 86.57 SSSV Deep Set Downhole Operable Valve HES NE Tubing- Retrievable Safety Valve 3.813" Seal Bore ID 11/23/2019 3.813 8,341.9 3,635.7 86.49 SBR 11/12/2019 2.705 8,350.0 3,636.2 86.49 WINDOW 10/29/2019 4.500 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) 2,583.4 2,271.5 56.36 1 GAS LIFT SOV 1 0.0 7/30/2022 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,178.1 3,625.8 86.56 FLCV 7.690 7'' FLCV, VamTop HC Box x Pin Bakre FLCV 4.560 8,207.6 3,627.5 86.56 SWIVEL 5.260 Baker Telescoping Swivel 4 1/2" Vamtop Box x Pin Baker Swivel Sub 3.980 MULTIPLE LATERALS, 3R-111, 6/8/2023 4:59:00 PM Vertical schematic (actual) LOWER LATERAL LINER; 8,422.5-15,934.5 INTERMEDIATE; 35.4-8,883.0 SEAL BORE DIVERTER; 8,341.9-8,457.0 SRT / DSM L0; 8,133.6-8,364.9 SBR; 8,341.9 UPPER LATERAL LINER; 8,337.1-15,940.3 SRT / DSM L1; 8,133.0-8,379.5 SSSV; 8,127.1 SSSV; 8,127.1 Chemical Injection Valve; 8,103.2 SLIDING SLEEVE; 8,078.5 NO GO NIPPLE; 8,063.7 ESP MOTOR; 7,977.8 SLIDING SLEEVE; 7,972.2 ESP; 7,930.5 PACKER; 7,922.6 PACKER - PATCH - LWR; 2,622.0 ANCHOR LATCH ON SPACER PIPE; 2,596.7 PACKER - PATCH - UPR; 2,592.0 GAS LIFT; 2,583.4 PACKER - PATCH - LWR; 2,555.0 PBR; 2,522.9 LEAK - TUBING; 2,525.0 SPACER PIPE; 2,500.0 SURFACE; 79.8-2,499.0 PACKER - PATCH - UPR; 2,495.0 CONDUCTOR; 39.3-142.3 HANGER; 34.6 KUP PROD 3R-111 ... WELLNAME WELLBORE 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) 8,221.8 3,628.4 86.56 SRT 8.230 SRT 4 1/2" Vamtop box x 3 1/2" Vamtop Pin Baker SRT 8,251.1 3,630.1 86.55 SWIVEL 4.250 Swivel Sub 3 1/2" Vamtop Box x Pin 2.950 8,283.6 3,632.1 86.53 NIPPLE 3.950 Nipple, 3-1/2" Camco, XN , 2.81" Profile,SN:???? HAL XN Nipple 2.750 8,409.6 3,639.8 86.47 2.60" No-go 4.500 2.60'' NO GO SUB, Hyd 563 Box x Pin 2.600 8,431.1 3,641.1 86.41 Anchor 7.390 7'' MLHR Production Anchor, 4 1/2" IBT-M Box x Pin TOP HALF Baker MLHR Prod Anch 3.940 8,435.4 3,641.4 86.39 Anchor 6.510 7'' MLHR Production Anchor, 4 1/2" IBT-M Box x Pin BOTTOM HALF (8435.4) Baker MLHR Prod Anch 3.940 8,457.0 3,642.8 86.27 4.730 8,422.5 3,640.6 86.46 PACKER 8.440 Baker MLZXP 7" x 9.625" Hanger Packer L-80 7" Hyd 563 pin Baker MLZXP 7.500 8,466.9 3,643.4 86.22 VALVE 7.000 7'' KOIV Isolation Tool, VamTop HC Box x Pin 4.770 8,469.8 3,643.6 86.20 VALVE 7.000 7'' C-2 Knock Out Isolation Valve, VamTop HC Box x Pin 5.190 8,947.9 3,665.8 87.80 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-9) 9 Baker Self Energize Packer 3.960 11,309.5 3,633.0 93.02 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-8) 8 Baker Self Energize Packer 3.960 11,698.4 3,598.7 95.85 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-7) 7 Baker Self Energize Packer 3.960 11,840.1 3,592.7 89.55 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-6) 6 Baker Self Energize Packer 3.960 12,272.3 3,578.1 91.89 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-5) 5 Baker Self Energize Packer 3.960 13,060.1 3,587.6 88.35 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-4) 4 Baker Self Energize Packer 3.960 13,327.9 3,579.8 94.46 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-3) 3 Baker Self Energize Packer 3.960 14,076.8 3,583.7 92.10 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-2) 2 Baker Self Energize Packer 3.960 14,469.7 3,550.3 95.21 SWELL PACKER 6.130 PACKER,SWELL,4 1/2 X 6.125",BAKER,HYD563 SN (003503-001-1) 1 Baker Self Energize Packer 3.960 15,900.9 3,558.3 89.97 PBR 5.010 4 1/2'' Drillable Packoff Bushing, BTC Pin x Pin 2.375 MULTIPLE LATERALS, 3R-111, 6/8/2023 4:59:04 PM Vertical schematic (actual) LOWER LATERAL LINER; 8,422.5-15,934.5 INTERMEDIATE; 35.4-8,883.0 SEAL BORE DIVERTER; 8,341.9-8,457.0 SRT / DSM L0; 8,133.6-8,364.9 SBR; 8,341.9 UPPER LATERAL LINER; 8,337.1-15,940.3 SRT / DSM L1; 8,133.0-8,379.5 SSSV; 8,127.1 SSSV; 8,127.1 Chemical Injection Valve; 8,103.2 SLIDING SLEEVE; 8,078.5 NO GO NIPPLE; 8,063.7 ESP MOTOR; 7,977.8 SLIDING SLEEVE; 7,972.2 ESP; 7,930.5 PACKER; 7,922.6 PACKER - PATCH - LWR; 2,622.0 ANCHOR LATCH ON SPACER PIPE; 2,596.7 PACKER - PATCH - UPR; 2,592.0 GAS LIFT; 2,583.4 PACKER - PATCH - LWR; 2,555.0 PBR; 2,522.9 LEAK - TUBING; 2,525.0 SPACER PIPE; 2,500.0 SURFACE; 79.8-2,499.0 PACKER - PATCH - UPR; 2,495.0 CONDUCTOR; 39.3-142.3 HANGER; 34.6 KUP PROD 3R-111 ... WELLNAME WELLBORE C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-07-27_21086_KRU_3R-111_LeakDetectionSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21086 KRU 3R-111 50-029-23643-00 Leak Detection Survey 27-Jul-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:219-104 T36834 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.29 09:01:35 -08'00' Transmittal #1271 Detail Date: 4/28/2020 To (External Party):From (CPAI Contact): Email*: abby.bell@alaska.gov Email*: richard.e.elgarico@conocophillips.com First Name*:Abby First Name*: Ricky Last Name*: Bell Last Name*: Elgarico Phone Number:(907) 793-1225 Phone Number: (907) 265-6580 Company: AOGCC Company: ConocoPhillips Address: 333 West 7th Ave.Address: 7 City: Anchorage City: Anchorage State: AK State: AK Zip Code: 99501 Zip Code: 99501 Transmittal Info Sent Via: FTP Tracking #: Justification: Data Detail Quantity*:Description*:Type*: 1 3R-111 LWD, Directional Survey, Mud Resistivity Digital 1 3R-111L1 LWD, Directional Survey, Mud Resistivity Digital 1 3R-111L1PB1 LWD, Directional Survey, Mud Resistivity Digital Attachments: Received By: ___________________________ Signature: ___________________________ Date: _________________ Approver: ___________________________ Signature: ___________________________ Date: _________________ PTD: 2191040 E-Set: 32779 Received by the AOGCC on 04/28/2020, to go with data received 04/23/2020 Abby Bell Abby Bell 04/28/2020 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23643-00-00Well Name/No. KUPARUK RIV UNIT 3R-111Completion Status1-OILCompletion Date11/23/2019Permit to Drill2191040Operator ConocoPhillips Alaska, Inc.MD15959TVD3558Current Status1-OIL4/23/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/Res/AZM RESNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC12/20/2019 Electronic File: 3R-111 EOW - NAD27.pdf31713EDDigital DataC12/20/2019 Electronic File: 3R-111 EOW - NAD27.txt31713EDDigital DataC12/20/2019 Electronic File: 3R-111 EOW - NAD83.pdf31713EDDigital DataC12/20/2019 Electronic File: 3R-111 EOW - NAD83.txt31713EDDigital Data0 0 2191040 KUPARUK RIV UNIT 3R-111 LOG HEADERS2191040 KUPARUK RIV UNIT 3R-111 LOG HEADERS31713LogLog Header ScansC4/23/2020130 15959 Electronic Data Set, Filename: 3R-111 Drilling Mechanics Depth Data.las32779EDDigital DataC4/23/20202419 8891 Electronic Data Set, Filename: 3R-111 OTK Memory 12.25 inch Section Drilling Data.las32779EDDigital DataC4/23/202087 2507 Electronic Data Set, Filename: 3R-111 OTK Memory 16inch Section Drilling Data.las32779EDDigital DataC4/23/20208861 15959 Electronic Data Set, Filename: 3R-111 OTK Memory 6.75 inch Section Drilling Data.las32779EDDigital DataC4/23/2020132 15959 Electronic Data Set, Filename: 3R-111 OTK Memory Drilling Data.las32779EDDigital DataC4/23/2020136 15959 Electronic Data Set, Filename: 3R-111 Realtime Drilling Data.las32779EDDigital DataC4/23/2020 Electronic File: 3R-111_BHGE_Mud Resistivity Report.xls32779EDDigital DataC4/23/2020 Electronic File: 3R-111 Drilling Mechanics Depth Log.cgm32779EDDigital DataC4/23/2020 Electronic File: 3R-111 2MD Memory Log.cgm32779EDDigital DataThursday, April 23, 2020AOGCCPage 1 of 43R-111 OTK,Memory Drilling Data.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23643-00-00Well Name/No. KUPARUK RIV UNIT 3R-111Completion Status1-OILCompletion Date11/23/2019Permit to Drill2191040Operator ConocoPhillips Alaska, Inc.MD15959TVD3558Current Status1-OIL4/23/2020UICNoC4/23/2020 Electronic File: 3R-111 2TVD Memory Log.cgm32779EDDigital DataC4/23/2020 Electronic File: 3R-111 5MD Memory Log.cgm32779EDDigital DataC4/23/2020 Electronic File: 3R-111 5TVD Memory Log.cgm32779EDDigital DataC4/23/2020 Electronic File: 3R-111 2MD Realtime Log.cgm32779EDDigital DataC4/23/2020 Electronic File: 3R-111 2TVD Realtime Log.cgm32779EDDigital DataC4/23/2020 Electronic File: 3R-111 5MD Realtime Log.cgm32779EDDigital DataC4/23/2020 Electronic File: 3R-111 5TVD Realtime Log.cgm32779EDDigital DataC4/23/2020 Electronic File: 3R-111 Drilling Mechanics Time Log Run01.cgm32779EDDigital DataC4/23/2020 Electronic File: 3R-111 Drilling Mechanics Time Log Run02.cgm32779EDDigital DataC4/23/2020 Electronic File: 3R-111 Drilling Mechanics Time Log Run03.cgm32779EDDigital DataC4/23/2020 Electronic File: 3R-111 Drilling Mechanics Time Log Run05.cgm32779EDDigital DataC4/23/2020 Electronic File: 3R-111 OTK Memory Drilling Data.dls32779EDDigital DataC4/23/2020 Electronic File: 3R-111 OTK Memory 12.25inch Section Drilling Data.dls32779EDDigital DataC4/23/2020 Electronic File: 3R-111 OTK Memory 16inch Section Drilling Data.dls32779EDDigital DataC4/23/2020 Electronic File: 3R-111 OTK Memory 6.75inch Section Drilling Data .dls32779EDDigital DataC4/23/2020 Electronic File: 3R-111 Realtime Drilling Data.dls32779EDDigital DataC4/23/2020 Electronic File: 3R-111 Drilling Mechanics Depth Log.pdf32779EDDigital DataC4/23/2020 Electronic File: 3R-111 2MD Realtime Log.pdf32779EDDigital DataC4/23/2020 Electronic File: 3R-111 2TVD Realtime Log.pdf32779EDDigital DataC4/23/2020 Electronic File: 3R-111 5MD Realtime Log.pdf32779EDDigital DataC4/23/2020 Electronic File: 3R-111 5TVD Realtime Log.pdf32779EDDigital DataC4/23/2020 Electronic File: 3R-111 2MD Realtime Log.pdf32779EDDigital DataC4/23/2020 Electronic File: 3R-111 2TVD Realtime Log.pdf32779EDDigital DataThursday, April 23, 2020AOGCCPage 2 of 4 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23643-00-00Well Name/No. KUPARUK RIV UNIT 3R-111Completion Status1-OILCompletion Date11/23/2019Permit to Drill2191040Operator ConocoPhillips Alaska, Inc.MD15959TVD3558Current Status1-OIL4/23/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:11/23/2019Release Date:8/15/2019C4/23/2020 Electronic File: 3R-111 5MD Realtime Log.pdf32779EDDigital DataC4/23/2020 Electronic File: 3R-111 5TVD Realtime Log.pdf32779EDDigital DataC4/23/2020 Electronic File: 3R-111_Drilling Mechanics Time Log_Run01.pdf32779EDDigital DataC4/23/2020 Electronic File: 3R-111_Drilling Mechanics Time Log_Run02.pdf32779EDDigital DataC4/23/2020 Electronic File: 3R-111_Drilling Mechanics Time Log_Run03.pdf32779EDDigital DataC4/23/2020 Electronic File: 3R-111_Drilling Mechanics Time Log_Run05.pdf32779EDDigital DataC4/23/2020 Electronic File: 3R-111_Final Surveys.pdf32779EDDigital DataC4/23/2020 Electronic File: 3R-111_Final Surveys.txt32779EDDigital DataC4/23/2020 Electronic File: 3R-111_Final Surveys.xls32779EDDigital DataThursday, April 23, 2020AOGCCPage 3 of 4 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23643-00-00Well Name/No. KUPARUK RIV UNIT 3R-111Completion Status1-OILCompletion Date11/23/2019Permit to Drill2191040Operator ConocoPhillips Alaska, Inc.MD15959TVD3558Current Status1-OIL4/23/2020UICNoComments:Compliance Reviewed By:Date:Thursday, April 23, 2020AOGCCPage 4 of 4M. Guhl4/23/2020 PTD 8117-/04 Loepp, Victoria T (CED) From: Regg, James B (CED) Sent: Friday, January 31, 2020 11:41 AM To: devin.kozak@conocophilliops.com; Valentine, Doug K Cc: AOGCC; Brooks, Phoebe L (CED); Loepp, Victoria T (CED) Subject: KRU 3R-111 (PTD 2191040) No -Flow Test Attachments: No -Flow KRU 3R-111 1-31-2020.pdf Follow Up Flag: Follow up Flag Status: Flagged Approval to operate 311-111 without a SCSSV is attached. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. THE STATE °'ALASKA GOVERNOR MIKE DI;NLEAVY January 31, 2020 Mr. Doug Valentine Senior DS Petroleum Engineer, GKA — CPF3 ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 RE: No -Flow Verification Kuparuk River Unit 3R-111 PTD 2191040 Dear Mr. Valentine: Alaska Oil and Gas Conservation Commission 333 West Seventh AVer1Ue Anchorage, Alaska 99501-3572 Main: 907.279.14.33 Fax: 907.276.7542 www.aogcc.alaska.gov On January 24, 2020 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Kuparuk River Unit 3R-111. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10- 004 — was rigged up on Kuparuk River Unit 3R-111 prior to the test including calibrated pressure gauges and flow meter with suitable range and accuracy. The test procedure called for a 3 -hour shut in followed by a flow monitoring period. Criteria used for determining a successful test were as stated in 20 AAC 25.265(1}(1): (A) The measured liquid production is not greater than 6.3 gallons per hour, and the measured gas production is not greater than 900 standard cubic feet per hour; or (B) Well pressure is discharged not later than 5 minutes after a 3 -hour charted pressure build-up period. The test failed the pressure discharge criteria, so the flow monitoring period was extended. After 30 minutes 30 seconds the gas flow rate declined below 900 standard cubic feet per hour; there were no liquids produced to surface. The time for gas flow to drop below the allowed limit is not typical of historic successful no -flow tests and was deemed a fail by the witnessing AOGCC Inspector. However, since AOGCC regulations do not state a specific time limit for the fluid flow rate monitoring period, AOGCC is considering the January 24, 2020 no -flow test result a conditional pass. Kuparuk River Unit 3R-111 may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. This approval to produce without a functioning subsurface safety valve expires January 31, 2022, if Kuparuk River Unit 3R-111 demonstrates the ability to flow to surface, or if the well undergoes any cleanout, perforating or other stimulation work, whichever occurs first. A subsequent passing no -flow test must be completed, or the subsurface safety valve must be returned to service. No -Flow Test —KRU 3R-1 I I January 31, 2020 Page 2 of 2 Sincerely, James B. Regg ( 1 Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors Devin Kozak (Bevin.kozakrii:conocophiIIips.co111) RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is tiled. Failure to act on it within 10 -days is a denial of reconsideration. if the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ``�� lel DATE: 1/24/2020 P. I. Supervisor FROM: Guy Cook SUBJECT: No Flow Test Petroleum Inspector KRU 3R-111 ConocoPhillips Alaska PTD 2191040 - 1/24/2020: 1 arrived on site and met with CPAI representative Brian Martin and looked over the rig up. The IA and Tubing were tied together via a tee into the flow meter skid and would be bled together. '/2" hoses were used pre -skid and 1" hoses to the bleed tank. It was decided by Kenneth Martin, CPF3 engineer with CPAI, to build pressure for 3 hours and bleed while monitoring gas flow and liquid production. If the well pressure bled off in 5 minutes it would pass, and if not, we could monitor both gas and liquid flow rates through the in-line test meter to determine if it would meet AOGCC criteria for a passing no -flow test. The well was shut in for 3 hours and then opened to bleed. The well pressure did not drop to 0 psi within 5 minutes, so the well was left open to monitoring the gas and liquid flow rates. At no time did the well produce any liquid. At 30 minutes and 30 seconds the gas flow dropped below 900 standard cubic feet per hour (899.9 scfh). After 1 hour of bleeding the well reached the original starting pressures and bleeding was stopped. The well was still producing gas (-470 scfh) as it was when the well was initially shut in to start the no -flow test pressure. It is my conclusion that the well did not meet the passing criteria to allow the well to be operated without a SSSV. The following table shows test details: Time Pressures' (psi) Flow Rate Remarks Gas — scf/hr Liquid—gal/hr 09:25 1/0/0 - - KRU 3R-111 Shut in 09:55 7/7/0 - - 10:25 12/12/0 - - 10:55 16/16/0 - - 11:25 19/19/0 - - 11:55 23/23/0 - - 12:25 26/26/0 1985.4 0 Oen to bleed " +1 Minute 1961.2 0 +2 Minutes 1924.8 0 +3 Minutes 1891.7 0 +4 Minutes 1862.5 0 +5 Minutes 22/22/0 1836.1 ✓ 0 2020-0124_No-Flow_KRU _3 R-111 _gc.docx Page 1 of 2 +10 Minutes 1727.2 0 +20 Minutes 1270.8 0 +30 Minutes 4/4/0 916.8 0 +30.5 Minutes 4/4/0 899.9 0 +35 Minutes 785.2 0 +40 Minutes 681.1 0 +45 Minutes 601.6 0 +50 Minutes 539.2 0 +55 Minutes 497.9 0 +60 Minutes 1/1/0 472.8 0 Bleed was closed - ' Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Supervisor's Addendum: Pass criteria are bleed to 0 psi in 5 minutes or rate decline to less than 900 scfm gas. The test clearly FAILS the pressure bleed criteria. 30 minutes to drop below the flow rate limit is atypical for no -flow tests performed to date so the result appears to be inconclusive.' However, since AOGCC has not set a limit for the time it takes the fluid flow rate to decrease below the allowed limit this test will be considered a "PASS". _J-E_f- Attachments: None ' 182 No Flow Tests 2011 through 2019; average time for flow rate to drop below allowed rate was 10 minutes (35 of 182 tests had initial flow rate > allowed limits). There have been just 3 approved no -flow tests that took 30 minutes or more for the flow rate to drop below allowed rate limits. 2020-0124_No-Flow_KRU_3R-1 11_gc.docx Page 2 of 2 I? TD �[7-lCg- Loepp, Victoria T (CED) From: Valentine, Doug K <Doug.K.Valentine@conocophillips.com> Sent: Friday, January 10, 2020 2:44 PM To: Loepp, Victoria T (CED) Cc: CPF3 Prod Engrs; Pedam, Sandeep; NSK Prod Engr Specialist Subject: KRU 3R-111 No Flow Test Procedure Attachments: 3R-111 No Flow Test Procedure.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please see the attached procedure for the KRU 3R-111 (PTD 219-104) no flow test for approval. The plan is to perform the test 1/24/2020. If we run into weather delays, we may move it up. Either way we will notify the AOGCC at least 48 hours in advance. Thanks, Doug Valentine Senior DS Petroleum Engineer I ConocoPhillips GKA — CPF3 I 3F,3A,3B,3J,3C,3K, 3R Westsak 0: 907-263-4146 1 C: 208-932-5280 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, August 7, 2019 1:37 PM To: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com>; Buck, Brian R <Brian.R.Buck@conocophillips.com> Cc: Regg, James B (CED) <km.reRR@alaska.ggov> Subject: [EXTERNAL]KRU 3R-111 and 3S/NUNA Completions: Regulation Requirements: SSSVs; No -flow test Sandeep, Brian, In our conversation today you mentioned that CPAI would perform a no -flow test after KRU 3R-111 was brought on production. If a no -flow test is conducted and the well passes, a SSSV will not be required in the well. 1. Reference AOGCC Guidance Bulletin 10-004 2. Up to a 30 day production period is acceptable prior to the no -flow test for this well 3. The no -flow test must be conducted within 30 days 4. A procedure must be submitted for AOGCC approval at least two weeks in advance. 5. CPAI must demonstrate that offset injectors have not been shut in prior to the no -flow test. That is provide a list of offset injectors with status and injection history for the past 6 months. 6. Should conditions change, such as increased reservoir pressure due to water injection, an updated no -flow test may be required. Let me know if this is how you plan to proceed for KRU 3R-111. I am reviewing the PTD at this time. 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. Loepp(o)alaska. gov Loepp, Victoria T (CED) From: Regg, James B (CED) Sent: Monday, January 27, 2020 10:01 AM To: Loepp, Victoria T (CED) Subject: FW: No -Flow KRU 3R-111 Attachments: KRU 3R-111 No -Flow 1-24-2020.docx Follow Up Flag: Follow up Flag Status: Flagged Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Cook, Guy D (CED) <guy.cook@alaska.gov> Sent: Friday, January 24, 2020 5:19 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Subject: No -Flow KRU 311-111 Jim, Here is the report for the no -flow I witnessed today on KRU 311-111. 1 have in the report that I do not believe the well passed due to the extended time it took to drop below 900 SCFH. The well did not produce any fluid and never bled to zero psi. The well was not dead when we started the buildup period either. Let me know what you think about my conclusion when you get a minute. If you have and questions please let me know as well. Thank you, Guy Cook Petroleum Inspector AOGCC 907-227-2614 guy.cook@a laska.gov CONFIDENTIALITY NOTICE: nis 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 Guy Cook at 907-227-2614 or guy.cook@alaska.gov. z MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 1/24/2020 P. I. Supervisor FROM: Guy Cook SUBJECT: No Flow Test Petroleum Inspector KRU 3R-111 Conoco/Phillips Alaska PTD - 2191040 1/24/2020: 1 arrived on site and met up with Brian Martin and looked over the rig up. The IA and Tubing were tied together via a tee into the flow meter skid and would be bled together. '/2" hoses were used pre -skid and 1" hoses to the bleed tank. It was decided by Kenneth Martin, CPF3 engineer with Conoco, to build pressure for 3 hours and bleed while monitoring gas flow and fluid production. If the well bled off in 5 minutes it would pass, and if not, we could monitor both gas and fluid to satisfy a pass if it met AOGCC criteria. The well was shut in for 3 hours and then opened to bleed. The gas flow did not drop below 900 SCFH in the five minutes required so we continued bleeding while monitoring the gas flow and watching for fluid. At no time did the well produce any fluid. At 30 minutes and 30 seconds the gas flow dropped below 900 SCFH (899.9 SCFH). After one hour of bleeding we had reached the original starting pressures (1/1/0) and bleeding was stopped, but the well was still producing gas as it was when the well was initially shut in to build pressure. It is my conclusion that the well did not meet the passing criteria to allow the well to be operated without a SSSV. The followina table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas — scf/hr Liquid — al/hr 09:25 1/0/0 - - Well was shut in to build pressure. 09:55 7/7/0 - - 10:25 12/12/0 - - 10:55 16/16/0 - - 11:25 19/19/0 - - 11:55 23/23/0 - - 12:25 26/26/0 1985.4 0 Well was o en to bleed 1 Minute 1961.2 0 [File Name] Page I of 2 2 Minutes 1924.8 0 3 Minutes 1891.7 0 4 Minutes 1862.5 0 5 Minutes 22/22/0 1836.1 0 10 1727.2 0 Minutes 20 1270.8 0 Minutes 30 4/4/0 916.8 0 Minutes 30:30 4/4/0 899.9 0 Minutes 35 785.2 0 Minutes 40 681.1 0 Minutes 45 601.6 0 Minutes 50 539.2 0 Minutes 55 497.9 0 Minutes 60 1/1/0 472.8 0 Bleed was closed. Minutes Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Attachments: None [File Name] Page 2 of 2 Loepp, Victoria T (CED) From: Valentine, Doug K <Doug.K.Valentine@conocophillips.com> Sent: Monday, January 27, 2020 9:09 AM To: Loepp, Victoria T (CED) Subject: KRU 3R-111(PTD 219-104), 3R-111 L1(PTD 219-105) No Flow Test Follow Up Flag: Follow up Flag Status: Flagged Good Morning Victoria, Guy Cook witnessed the test on Friday. He said he was submitting the results to you and Jim Regg for interpretation. The well is still SI waiting on an answer. Do you know when we might get an answer back? -Doug From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, January 27, 2020 8:57 AM To: Valentine, Doug K <Doug.K.Valentine@conocophillips.com> Subject: [EXTERNAL]KRU 3R-111(PTD 219-104), 3R-111L1(PTD 219-105) No Flow Test How did the NFT go? From: Valentine, Doug K <Doug.K.Valentine@conocophillips.com> Sent: Thursday, January 23, 2020 2:20 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3R-111(PTD 219-104), 3R-111L1(PTD 219-105) No Flow Test Procedure Thanks Victoria. We are planning on the no flow test tomorrow, (1/24/2020). The Kuparuk SVS techs on the slope are coordinating with the state inspectors up there. -Doug Doug Valentine Senior DS Petroleum Engineer I ConocoPhillips GKA — CPF3 13F,3A,3B,3J,3C,3K, 3R Westsak 0: 907-263-4146 1 C: 208-932-5280 From: Loepp, Victoria T (CED) <victoria_loepp@alaska.gov> Sent: Thursday, January 23, 2020 2:17 PM To: Valentine, Doug K <Doug.K.Valentine@conocophillips.com> Subject: [EXTERNAL]KRU 3R-111(PTD 219-104), 3R-111L1(PTD 219-105) No Flow Test Procedure Doug, Thank you for addressing the comment:, .nd questions. Your procedure is approve(.. What is the current status of the NFT timing? 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. Loepp(t!_)alaska. cIov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeop@alaska.gov From: Valentine, Doug K <Doug.K.Valentine@conocophillips.com> Sent: Tuesday, January 14, 2020 12:34 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: CPF3 Prod Engrs <n1223@conocophillips.com>; Pedam, Sandeep <Sandeep.Pedam@conocophillips.con-i>; NSK Prod Engr Specialist <n1139 conocophillips.com>; Regg, James B (CED) <jim.regg@alaska.gov> Subject:KRU 3R-111(PTD 219-104), 3R-111L1(PTD 219-105) No Flow Test Procedure Victoria, Thanks for the comments and questions. Here is the response: 1. We will have electronic instruments on the no flow rig that have been calibrated and can be read to < 1 psi as well as trended on our automation system. We have two, 100 psi and 60 psi, analog bourdon-tube gauges in stock if needed. The wellhead IA and OA have electronic instruments which are new and have calibration stickers. We intend to have the SVS techs digital on the tree cap and the one on the metering rig, essentially both on tubing pressure. 2. SI at the wing and IA valve at the time of test. 3. We will use Y2" high pressure hose during the test for flow to the meter and to the tank. 4. Inside diameter is 0.599". 5. We intend to pass the NFT on the flow criteria, however, we would like to reserve the right to pass on the second criteria, if needed. 6. The steps for the test, reflected in the procedure: Rig Up 1. Operations to shut in well prior to the test. 2. Operations to isolate the well from flowline. 3. Operations to bleed tubing and casing IA pressure to open top tank or bleed tank (atmospheric pressure) a. SVS Techs to verify well tubing and IA pressure is at 0 psig. 4. Rig test equipment up to a high point on a wellhead. (see equipment in figure 1 below) a. Low pressure gauge b. % turn full opening valve c. Flow meter d. Hose/line to atmospheric tank 5. Let well bleed through test equipment until inspector arrives No -Flow Test 1. Perform 3 hour witnessed test. 2. No Flow Test passes if: a. The well meets one of the following conditions: i. the measured liquid production is not greater than 6.3 gallons per hour, and the measured gas production is not greater than 900 standard cubic feet per hour, or ii. Well pressure is discharged not later than five minutes after a three-hour charted pressure build- up period, and b. The operator receives written confirmation from AOGCC that the No Flow Test results were accepted. Please see the attachments for more information. Please note regarding the water injection history. 3R-102 was shut in due to drilling in the offset wells 311-112 and 311- 111. Once rig release from 311-111, both 311-102 and 311-112 were put on full injection. 311-106 remains shut in for drilling of offset well, 311-107. A snapshot of rates is below. The complete daily injection data for all 3 injectors has been attached for review: 311 Infection History m :t r", "V l.3trc la 11 202D DATE -IN) i3 To your last question, 311-111 is equipped with a deep operable valve. If the NFT fails, we will demonstrate the equivalency of SSSV. Best Regards, Doug Valentine Senior DS Petroleum Engineer I ConocoPhillips GKA—CPF3 13F,3A,3B,3J,3C,3K, 311 Westsak 0: 907-263-4146 1 C: 208-932-5280 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, January 13, 2020 2:36 PM To: Valentine, Doug K <Doug.K.Valentine@conocophil�s.com> Cc: CPF3 Prod Engrs <n1223@conocophill ips.com>; Pedam, Sandeep <Sandeep.Pedam@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; Regg, James B (CED) <lim.regg@alaska.gov> Subject: [EXTERNAL]KRU 3R-111(PTD 219-104), 3R-111L1(PTD 219-105) No Flow Test Procedure Doug, We have reviewed the No Flow Test Procedure submitted for KRU 311-111 and have the following comments/questions: 1. Calibrated pressure gauges required for the tubing, IA and OA with suitable range and accuracy(1 psi increment for an analog pressure gauge) 2. Where will the well be shut in at? 3. Specify the size of the flowline from the tree cap and through the meter. 4. Specify the size of the orifice meter bore. 5. Which criteria will be used?: Fluid flow rate option or pressure discharge option? 6. Provide steps in procedure. 7. A surface schematic would be useful S. Provide a well bore schematic 9. Provide a list and status of offset injectors including injection history Is this well equipped with a deep set operable valve? If so and the well fails a NFT, an equivalency between the deep set operable valve and a SSSV must be demonstrated. 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. Loepp(aa)alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepp4alaska.aov From: Valentine, Doug K <Doug.K.Valentine@conocophillips.com> Sent: Friday, January 10, 2020 2:44 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: CPF3 Prod Engrs <n1223 conocophillips.com>; Pedam, Sandeep <Sandeep.Pedam conocophillips.com>; NSK Prod Engr Specialist <n139 conocophillips.com> Subject: KRU 311-111 No Flow Test Procedure Victoria, Please see the attached procedure for the KRU 311-111 (PTD 219-104) no flow test for approval. The plan is to perform the test 1/24/2020. If we run into weather delays, we may move it up. Either way we will notify the AOGCC at least 48 hours in advance. Thanks, Doug Valentine Senior DS Petroleum Engineer I ConocoPhillips GKA — CPF3 13F,3A,3B,3J,3C,3K, 311 Westsak 0: 907-263-4146 1 C: 208-932-5280 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, August 7, 2019 1:37 PM To: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com>; Buck, Brian R <Brian.R.Buck@conocophillips.com> Cc: Regg, James B (CED) <iim.regg@alaska.gov> Subject: [EXTERNAL]KRU 311-111 and 3S/NUNA Completions: Regulation Requirements: SSSVs; No -flow test Sandeep, Brian, In our conversation today you mentioned that CPAI would perform a no -flow test after KRU 3R-111 was brought on production. If a no -flow test is conducted and the well passes, a SSSV will not be required in the well. 1. Reference AOGCC Guidance Bulletin 10-004 2. Up to a 30 day production period is acceptable prior to the no -flow test for this well 3. The no -flow test must be conducted within 30 days 4. A procedure must be submitted for AOGCC approval at least two weeks in advance. 5. CPAI must demonstrate that offset injectors have not been shut in prior to the no -flow test. That is provide a list of offset injectors with status and injection history for the past 6 months. 6. Should conditions change, such as increased reservoir pressure due to water injection, an updated no -flow test may be required. Let me know if this is how you plan to proceed for KRU 3R-111. I am reviewing the PTD at this time. Thanx, Victoria 311-111 No Flow Test Procedure Revision 1 Summary: 311-111 was put on production on December 26th, 2019. Before January 25th, 2020 the well is required to pass a no flow test, or the SSSV be placed in operation and tested. To pass a no flow test the well is required to be one of the two following criteria. OR 1. Measured liquid production is not greater than 6.3 gallons per hour (GPH) and the measured gas production is not greater than 900 standard cubic feet per hour (SCFH). 2. Well pressure is discharged not later than five minutes after a 3 -hour charted pressure build period Both criteria one and criteria two requires the following third item be met as well. AND 3. Operator receives written confirmation from the AOGCC that the no -flow test results were accepted. The following procedure outlines how this will be accomplished. Any operations work should be charged to work order 22913159. Pre -Work • 72 hours prior to no flow test o Verify operability of low-pressure gauge, temperature transmitter and flow meter ■ Meter was verified to be at the 3B shop on 01 -Jan -2020 ■ Flow meter was calibrated on 29 -Oct -2019 by Frank Beathard ■ Meter has a 0.271" orifice plate inside it • dP calibration of -250 to 250" WC • Meter can read up to ± 16.15 SUM (970 SCFH) 48 hours prior to no flow test o Notify AOGCC of no flow test (NSK Production Technician) o Stage tanks for no flow test at 311 pad o Relocate meter to 3R and connect wireless gauge into SCADA ■ Verify tags are appropriately reading into IP.21 ■ Meter should be kept warm and protected • 24 hours prior to no flow test o Shut in well (CPF3 Operations) o Isolate well from flowlines with blinds or dropping pipe (CPF3 Operations) o Bleed tubing and IA pressures to open top tank (CPF3 Operations) ■ Leave flow path open to atmosphere if possible o Verify continuous flow path from tree cap to open tank ■ Keep continuous path from IA to open tank as well Page 1 of 4 311-111 No Flow Test Procedure Revision 1 Day of the test • Install test equipment to tree cap (NSK SVS Technicians) o Orifice flowmeter o Temperature transmitter o Low pressure local gauge off tree cap o % turn full open ball valve o Hose to atmospheric tank • Conduct pre job discussion in control room at DS3R 0 311-111 is under temporary hooch and room will not be available for multiple people o Personnel onsite: ■ Production Engineer ■ AOGCC Representative ■ SVS Technicians ■ Operations Representative • Confer with AOGCC representative prior to beginning test • Operations representative to close open path from IA to open tank o Only path to the tank is through calibrated meter • Monitor well and confirm whether test passed or failed o See above criteria • Perform preventative maintenance o 6,000# needle valve • If test passes: o BOL following normal 311-111 startup procedure o Normal up SVS system • If test fails: o Need to schedule testing for SSSV o BOL following normal 313-111 startup procedure o Normal up SVS system Page 2 of 4 3R-111 No Flow Test Procedure Images of No Flow Testing Equipment f 0. ri . . Y /j`/ttjgi� i Revision 1 Page 3 of 4 3R-111 No Flow Test Procedure Revision 1 Current Calibration Stickers of No Flow Testing Equipment Page 4 of 4 PTO Loepp, Victoria T (CED) From: Jones, Jeffery B (CED) Sent: Monday, December 30, 2019 1:04 PM To: Loepp, Victoria T (CED) Subject: Re: KRU 311-111 Follow Up Flag: Follow up Flag Status: Flagged Ok thanks. Sent from my iPhone > On Dec 30, 2019, at 10:20 AM, Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> wrote: > Jeff, > Yes, they may leave it(DSOV) locked out until they conduct the no flow test. > Thanx, > Victoria > Sent from my iPhone >> On Dec 30, 2019, at 9:32 AM, Jones, Jeffery B (CED) <jeff.jones@alaska.gov> wrote: >> Hi Victoria, >> I tested the SVS on new well 3R-111 this morning that has a "deep set operable valve" (DSOV)that is locked out and CPAI did not test it today because they had a email from you allowing a 30 day period to conduct a no -flow test, but it didn't say they don't have to test the "SSSV". >> So I just wanted to check with you that CPAI can leave the DSOV locked out and operate the well for 30 days and not test it while they attempt to no- flow test the well? >> Thanks, >>Jeff Jones >> AOGCC >> 907-744-4446 >> Sent from my iPhone DLB 04/17/2020 Baker Hughes Get Date: o: Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 2 19 104 31713 Letter of Transmittal December 20, 2019 From: Michael Soper Baker Hughes 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3R-111 3R-111L1PB1 3R -111L1 (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Michael Soper, Baker Hughes, Applications Engineer DEC 2 0 2019 Michael.Soper@bakerhughes.com �OGnC 00 v 0 CDU CD N 0 tD v� CA a��0 CD -h CD ■ j �� CD W /� o ` O O Q■ �, C V ♦♦D V ♦ r■r _ \Vmcn — ■ %<Z D M — CD JO cn 1 o n 13 2) _ A :.a N O (O v N < < D v 9 *2 m � * 9 C) 9 V v** m m n ca `" `° CD N — W - O '06 (A W N 3 m co 0 0 0 o m Cl) CD(D ". o o d 0 O ,Mm„ A 7 CI) O 0 3 n N 3 n O 7 3 n G W 0 7 W W W T� Ci V \ =r O o w G7 0 ww mm Z T1 D Z we �• o N s Z N N (D T G = 3 v ° 6 m m fD CD Z 0) m a( D o A DO v O N o p o Z Z Sn O O O O X T C .O. 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J a) OJ W W (A1) UWi (0 W J W o O O O N WW J W V N A V m g O O O A W N W W A W 0 O A O c m vY N A O O -A+ N W W (NP w (0 m N V N O O O O W W W UN W j V j V O N A O O O O) N A J O) N m A J W W O m m m 0) m m m m m 0) m 0) m m m P m Z 0 0 0 0 0 0 0 o O o 0 0 0 0 0 0 0 0 O sa 01 W W W W 01 W O) 01 01 O 01 m 0) y 7 A O W V W A W N N W N W N O t0 A v OD T N A ow V (O O 0) W m t0 IJ O O Ut A O N O Ui m V A N N W N m W O) V N Ut 0 N N N N N N N N N N N N N N N N N N- 0 O O O O O O O O O O O O O ,y d (o io a W CD �I J J J � rn rn rn m rn m rn W O O O V O4 O N O O p A N ID O) V 0) 0) 0) 0) O) O � J O N � N W (0 J W W O) V V m O � W (O O O 8 J J J J m m O) W V 0) O) O) W m W Ut O W O O 0) N A N N W O N N N N O O O (D 10 O do O G O N O O W N O N N ti JN O m V m W N m n (0 OD CD (O A 0 O 01 0) N D) j d O N N NO J A W A N O O O) du O O Ut N J du 0 N A M N Q1 O 0 O W W O G7 Gl G7 G7 G7 G7 G7 G7 G7 G7 G7 G7 G7 G7 G7 G7 G7 C to O O O O O O O O O O O O O O O O O C G1 G7 G7 L7n � L7 G1 L7 G7 G7 (,7nnn Gi Gl T `G M p Z Z Z 3 (D cn Z ui 0 07 00 N N -> _ W 00 A A N N C -n A A (Jl( (00 0 O O o 3 W A W W NPPN y m N 3. 3 00 00 A A 01 N .i O A A O m n � UJi cO0 (00 (D N 7 m A O _7 O '-t 0 O a co La Lo Lo Lo C.0 o. 3 CD (D � ,Zwl .ZWI .Zwl c c 0 a 0 d O 3<1 O N A W N C F F o O M 0) - - - r v W W N N T O A A ? 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(\ O A c O A [: C 00 N N (� O0 0 OG C O 7 O 7 GJ A A O c OZ -I 0 D m n � n (D 0 n (D N 7 m A O _7 O '-t MCD N D in O C 0 CD (D N � a 3 0 (D N 0 p N 'y c 3 D n m Z O OD O1 E3 + W + C w W O 7 A A ^ 1Cl A ^ \G A O A c O A [: (� O0 0 OG O 7 O 7 A A T N m a C + N ? 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T T m T T ZT T W A A A A A t0 A O A A W W A W A W A 00�� A N O O U V t0 (0 w m t0 t0 V m m U (O W m w (0 N > > A V (0 W W U m O A w A W A 0 M M ;1 M .17 n m m D � D N ' m m U m V V m A > t0 N O A m m A O U t0 m V m O W O J O m O V N N N N N N N N N N p O O + + U) m + + m m + CO m m m m m m m m m + + m m Z m + w + + w m + m + + w w + + w m + + + w w w + + m m p P7 d > D D D D D D D D D D D D D D D D r D D D D D D D D D D D D D D Z 7 O w G7 O O O Gl n O O O O L1 < w L7 O L7 G7 Gl n G7 L7 G7 G7 47 G7 C.1 d _ A A . + + cn 10 . + co N N N N N N N N N N N N N N N N N N N N N > >> > > >> >> C m m m m m m m m m m m U [li U m U A A A A A W W N N N > > O O c0 t0 tO m m m V �I m (n = A A A A A A A v A A N N N N N W W W W W W W m U W N OOo w A N V A Umn O O N O T 0 N U (D W m > U N A U m U V N m N W O p O A W U U W WmN O W Um m N m N O C w T D G N N U A N N A A N N N A N N A A N N W N N N W W N N N N > N N > >_ N > N> O W > t0 > > m m > > m m > > J V > m > > C m U fA OW W W W 0A� a AAA A N pAp A .UVO J U00 m A W .UUO U0 N N (J0 A W W (AP m W > V y W U U0 j t0 m j U W W m A W m W 0 8 J m m N m J m > O U (D O O U U w N (D A m m U w> O m N m U V m m m > O U m rn CL C + N ? (O (O m m J N m m m m m N m JA m O m W O A O m U A W y O tD m m V V U A W N N W A m U m J O A t0 O A J A O W V U W O A J A m U w m A U m m V m N m W N A N O A A O V U V U O A m O W m m m W U N A W > U A 0 (D O A U t0 0 m m m m m W V W m V + 0 r- - __________ U N U U N N U U N - U U - - U U U U U U U U U U U U U U U m U U NO y O -1O <O A A W N A W 1p00 m O 0 0 m m V V V N N > > > O O O .?zZ O N tJ0 (WJE t00 O N m O 10 A N 0 U O m O A m W O m W 0 N U Qv �2p �3 [D � W O O J m m A A 40 N > t0 W IJ D7 m N y n ^ \ / m W O W A OD W O m W m U> W A m V N N J O m A U J N N N A W N W m W J J t0 A N UD C7 Up C � A >3 � D D O C) ni n m n ° CD3 G m C 0) n rn rn rn rn rn rn rn rn rn rn m rn m rn m rn m m rn rn rn rn m rn rn m rn rn rn rn rn Z y F N m O o o o 0 D o o o o o o D o o o 0 0 o 0 0 0 0 0 0 0 0 0 o O o 0.50 0 ..+ ; c -� w w N N w w N N w N w w N N w w N N w w N N w w w N N N w�� N A w w w w w w w W w�� y �j (0 m COL � m ,D < U U U A A W W w N N> > > O O 0 0 0 0 W m m c Up w L m A (O tp O m m V N m m A m A O m N N m O O . 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(O O m Cl m m (ND O A m N m m (WO m m N g N N N O W A m N (0 m (O W N J A m N O m m O m m m m N m J N � N N A m V V A m N O W ()( m (0 N (0 N J A V W A m O O A m A (0 A N N V V W U m N N N m N U O 0 N m Ot N m m N m U (n m N N 0 N N m N w U N m + O (n z 3 i t N N W W N N N W W W N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N m w C O C O s m A A Ut m m J J J m m m m t0 (O t0 m m m m J V m m N N A W N W N O x CC D) C .1 C W W OD Ut Ot m m J IV m W m m O m m .Vmi m m .OAD m A CD S tMD M 3 V 0) O (P W (O m W J J m J 6 V m W O 6 m m A m W O N m W J A (0 O � W m V O D D DI N � v n c m ^ N C C C m (g) tD O(D n m rn rn rn rn rn rn rn m rn m rn rn rn rn rn rn rn m m rn rn rn rnO rnOm z ' "(D (•° O� OmA ON(O OAO Om O(O p ON O O O O O O O O O 0 Omm Om 0 _" Q O f°Di A W A WW WA A WW pW W W W W W W W W W WWNNNN I C t W m W (o (D 2 ' J(0 7 Dm0 N 0 O mN m J J mOm V m t0 mA A N O O O V Iv m WW A A A O �OWJ A m .. 0 (D N NOJ m N J mO N O V mmN AO m O N m N W m 0 O O AO N W W m O W W m V m O A (0 W W m W m N m W W (O J Ut m O m v O m i0 D7 m O O V A m N m A IV > O) N m N O m W IV W m m m (O A m � 8 N V N N A � m m m OS (O Ut A V m m (0 O m N m (0 V (O m N J O N N (0 m 0) lD A O V A A V (0 O O O A V O m m 00000 00000 00000 00000 00000 0 z xx + + T T + + + T T T + + T T + + + T T T + T + + T T + + T T + T + T + + T T + T + T + + + T T T + + + + + T T m + + m N N N N N N N N N N N N N N N N U m N N N m N U O 0 N m Ot N m m N m U (n m N N 0 N N m N w U N m N N W W N N N W W W N N W W N N N W W W N W N N W W N N W W N W N W N N W W N W N W N N W W W W W W N N N N N N W A A A N N N m Nm s m A A A W W N O (O (poD m m W (0 m O m (0 W m O N J A m O m O W W N A m (0 O m (((,TT A N W W OD Ut Ot m m J IV m W m m O m m .Vmi m m .OAD m A V m A -+ m Ja W V A O 3 CD m O m A O J J A m m W A Ut W J A O � W y 3 D D v n N C C C Q O m + co + I C W m W (o _ O A A cn m VW m(n V m t0 mA A N O O O V Iv m WW A A A O �OWJ A m .. 04 m. W m WWV m Wm OmW mmN O0 O@ @W NA N m W W CO m A W m N Ut A J Ut m O m v O m i0 D7 m O O V A m m A m Ut m A m m O m d - A A m O m m m O O m O m m J m J O N m m m (O Ut A V m m (0 O m N (O (p 00000 S3 00000 00000 00000 00000 00000 0 z xx + + T T + + + T T T + + T T + + + T T T + T + + T T + + T T + T + T + + T T + T + T + + + T T T + + + + + T T m + + m N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N Q `G O 'G + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + p (,� O O (n (n D D N (n m D D D W m D D N m co D D D co D W U) D D W N D D m D N D m w D D W D N D m N W D D D N W W w N D D D D D N W D D Z 7 7 G) 47 47 G7 G7 G7 G7 (.7 G1 d A A . . . . . . . . m� N O O W N O O1 0 (0 co N c0 W OD m m m m m m m m m m m m J V J V V V V V V V V m C N N W A A m N N t0 O O N W W A A ((,,nn m J m fD cD A O �n O N O O> A A W O V W c0 A O U N m A V A O � N t0 � O c0 A > U U m V V O A W N > N m V W m U m > V A O O m U m U O c0 IJ m m W t0 A t0 m O W A A m N W A W m c0 O U U V N O A W U W J m (D (O (0 c0 cp c0 m m m W m m m m m W m m m m m m m m m m J J V J J e 5 O O J V m V m m m U m m m m m m m m U W N O c0 m m N m m m v J j V j j v v v m m J J J J J m m _v J J m W (NO 00 (NO O O v° N c0 (0 (0 O O N O O O c0 c0 O O O O O t0 (0 P) 50 W m O A m O A W A N O W V V w A m m J A O U w m V N m O O W O m O A A 0 N O A A m W m W A J m N 0 W W W W W W W W W W W W W W W W W W W W W W W W W W (W� W W W W C �I (mIt N N N m m N m m m N N N 0 o W N N W W O O m m V N A N O mA (Alt evQ Q J m W U V U W p m m N m O A m W V N m O W A N m N A A m m O m m m N W m m IJ A T A U c0 N m O A U A O U U > > > Vt w c0 O m m A w N U N N W m O m W W m m m W A N V N c0 N WW W W W W W W W W W W W W W W W W W W W W W W W W W W W W W C G m m m m Ot m m m m m m m 0) (It 6 <n U in Ut (n U U W 0.f0 > A Q7 dD O) A N O O(D W V mAm UUU U NA VA ANA p cn p N J W 0 CA0 p y A V O U m N la LJ c0 W A c0 O <O A > U m J J J N J A O U m > m m 0 A V m A w 0 A N N 0 O m W m U m t W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W N Z U U U U U U U U (n (n <n Cn Cn U (n Zn (n (n U U U U U U U A A A W W N mA fAp O O p ,Am sp W W N N A A N W N A A r O W O J J W W cND N x A U IV W U O m m O A O A V U c0 V W W Ol A U A U J O m V N U W U A W U A V > m cD c0 A U U A m > m m> U m > U> > U U cp c0 N W A A U U m m <0 O O > N W A U m V m c0 O > > N W � C m lD (O m m J W V O W N O O N m m J m m U A W N O m m W C m A O A W A D7 A O O N (n V > A O W N (n m N U V V V U O N W m m U O m m W m A O O m V m CJ V c0 O m la (O c0 m J A A m m V V J U O m 4 3 A A O A A A m A A m O W J > O U M M M m m rn rn m rn rn m m m rn rn m rn rn m m rn rn rn m rn 0 M m M M m 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O,^ O U (n (n U (It U U Cn U (n Vf U U U U U U U U U U U U U U UU 0_ 7 m m m m m m m U U U U U U U U U U U U U m U U W N c00 m OW W colt O N W A A A N O c0 m J J V V cp c0 (0 c0 0 c0 (O O m N t0 O m J W A ON O W W V > (0 V A m m O U V A > > O N O w N W J U A O O � N W V U O m U c0 m N m V W 10 O O J V V m W A N U U U U U U U U U U U U U U U U U U U U U U U U U U U U U U U y N N N N N N N j OAmt0 OUN O O O O jV jV j j JN ,N NN NN NN NN NN NNV NNWNN cmp Nty ME> m J m c0 O O N W A m m w O Am c0 c0 3 mN Am>mOANNpmD(lW A A NO O W W m m W m W > J m m W V m W V O O m m O U U W m W O m w m U A U N N m O 10 w w (O m A W O O O O O W >> W N O N>> 0 0 O O O O N A A A w A W W w A W 0 y N m O W W > > w O 0 W m J m .... 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A N m v O W 7 d (0 A U O O O c0 W J U U N J o J N U m V (O A U m V m m m U O W W m W > A W (O > J U W O O (O -+ m A U V O m c0 U O O O > U (0 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 N g ` O 0 0 p 0 0 0 0 0 0 0 0 0 O O z + } } } } } + + + + } } + + } } } + + + + + + + + + + + + + T T T T T T T Tl Z T T T T T T T T T T T T T T T T T T T T T T N N N N N N N N I N N N N N N N N N N N N N N N N N N N N N N O l c m + + + + } } (] + + + + + + + + + + + + + } } } } } } } } } O > w m m w m w z w m m m m m w m m w w m m m m m m m m m w m D D D D D D D D r D D D D D D D D D D D D D D D D D D D D D D Z ' p + + + + + + + +z + + + } } } } } } } } } } + + + + + + + + 3 (n 9:z co cn u) cn 3 3 R:cn 3 9 3 3 3 3 3 3 3 3 3 3 3 3 3 3 m m m m cn m m m n w w m w m m w m m w w w w w w w m w m w m m v c) Ol m m Ol A A A A A A A .G A A d A a s A A A A A A A A N D m 0 w i M v 0 OZ N M A W ;Z A 'p n d Z CD O `C `C j cr O O y D 7 O m n ° m (D o � 3 M A A c p M d d 0 m o Q N w A � � o_ C N y N x j 10 C , "O d C m K : w w p C Z11 ,0 CD CD D p n N 0 G c N 0) d Z O CO m d <D + + C W W (D (D O ^^A ^^w \G 1G A A A A C C �x p p 0 0 O O 7 � A A 1J I 0 c OZ 0 <� n d CD O Dt `C .Z1 m 0 D 7 O m n ° m (D o � 3 M M 3 m o Q N m K : w w p C Z11 ,0 CD CD D p n N 0 G c N 0) d Z O CO m d <D + + C W W (D (D O ^^A ^^w \G 1G A A A A C C �x p p 0 0 O O 7 � A A 1J O_ 10 S+ W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W N 2 U A N O N U m O (O m O OD (0 O O (D m V � A N m J m m m (0 m A N O U 0) 0 O N O A m V m (O W (0 IJ A N m ON m m O A N O O U 10 W m N A U J m m N m A m N U m O O O m m C0 o cn v 0 3 -{ r N N N N N N N N N z �S Na3 N RI N C O 0 < O O m m J m U A W N O m m V V W IJ n N N N N N p) y Q N m N N J W W W (D A A A t0 U m U Q m O m (O m w O O V � O A N N W J W W V mV m O O V V m N m W N W W A N N m1 (� W (O (O W A t0 (0 N m (WJ) m N VNi J m N m N tm0 tU0 N m m N (0 m m m 0) `OG N " W U W W (O m (D U A m (0 m W N m m 0) m U O N V N O O N m m A J (D 0 O (p O O O A m m A W w 0 V m (O m m W m U N m m O m A m A W N A 0 D V (D A 7 Q (D O W W W m t0 (0 O t0 N (O (O V W m m m m 10 m 10 10 m U U 10 0 W W (O m m (O (O 0 O (0 N 0 w m N N (0 m m m (O m V m m V t0 0 N 0 0 0 (On j W N 9) rn ;L1 X ;0 C C O � m U W O W m A N O N A N (p (O J m rn m rn rn rn m rn Z 0 O o 0 0 0 0 0 U U o O W 0 0 U U W O 0 O m m O o 0 0 0 0 o O O o O 7 A w w U w U w w U U w w U U w w U U w w U (T w U w w U (T w w w U (1) (T w V) w U) w w (J) 0) w U w w U U w w U U w -w U U w w^ U U UrT 4 ;uN (D U m V V V V V V m m m m m J J J m m m J J J J J J V V G = O CD (O m m V V (0 W m V V A (O m m O O O p W m J m A J V J J V m m m m m J J V m m m V V V m V V V J J J J J O N W CO m N A �- N N 0 J W 0) m (D --+ N O W U O O O O O m A W m m (O O N W N W 0 m (0 fJ m p 0 0 O W O m O p O J w j O O m 0 V N m . 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C W D 3 n n N U A U W U O N N U O O N O O A N W O N N A V N m O N m A W V O J O W W U U w A m O- U m U K, W C N ^) (D (0 m N (O W A U W O W U m W W (0 A N A N m W J U O N m Cal N + + cn C (0 W W (O A A A A A A W W W W W W W W W W W W N N N N N N N N N N N N A O w A A A m V m m U A W N - CD pp O ((m�1 .� .Ar a V O n @ @ O m cpO W V O O (O W W O (UD W m w A V O (NO m (UO O A V W O N U W m m N (0 (UO N U N N A A J O (UP m m N A O A O m 7 0 W O A t0 N V U V O V m U A A (0 m J A O (0 w N A O m o O N V (O (O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 D o 0 0 0 v 0 v o 0 0 0 z x + + T T + T + + T T + + T T + + T T + + T T + T + + T T + + + T T T + T + T + + T T + T + + T T + + T T + + T T + + + T T T m Y` �7 m N N N m N N ,U m N N N m N N N N) N N N N N N N N N N N N N N N N N N N N 'G + + W m + W + + m co + + m W + + W m + + m m + co + + m m + + + fn m m + m + m + + W m + m + + m m + + W m + + (o W + + + W m (n p-1 p O 7 O 7 G) 0 + + G7 + G7 G) + + G) G) + + G) G) + + G) 0 + + G)n + + + G) C)n + + + nn + + 0 G)n + + + 0 0 + + 0 G7 + + G7G7 + + G7 G7 G7 + + + m N V 3 3 (n m 3 W 3 3 m W 3 m U) 3 3 W W 3 3 m W 3 m 3 3 W W 3 W m W 3 V) m W m 3 W 3 m m 3 m m 3 W W 3 3 W m m W rn rn rn rn rn rn rn m rn m m m m m rn m rn rn rn m rn rn rn rn m rn rn rn rn m rn + U U Cn U U U U <n U Cn (T U U U in V) Vt Cn Ui U U U U U U (T U) U U U U J N U W m O N W V m V O m m N N m N m O W A N N m O N O U m ^ + O (0 OD V O UA W IJ O O m m V m U A W N O p m J T N A W W N W W A U m j J m W O O N N W W A U 0) 0) V J m CO 0 W O N J A V W D1 W O (!) A m W 0 A p U (T W m W W W M U p p O w N O V A Up m m A m W U W m (O A m A O A U m U O J t0 O J A m m O J N ) rn rn m m rn rn rn rn rn rn m m m rn rn m m m m M rn m rn m rn rn m m rn 0 Z 0 0 0 0 0 0 0 o O o 0 0 0 0 0 o o o 0 0 0 o o o o o o 0 o 0 o 0 w w w w w w w w w w w w w w w w w w w w w w w w w w w w w w w^� y W U m m t0 p t0 m m m V m A W N O c0 A A A N O A (O N m m O � w A m O U O m U O A w W -+ m m W O 0 O m m U m m m m m A (O m m m A 0 A m W m m 0 c0 O N W A U m V m 0 O UA tJ0 WW A U U Nm N Wt0 N m WW m W U V �N N aA U 0 m m 0 O W A NWW m+AWWV , v O WJ NAmWA m V 0 O 8 O O O m 0 A m N O W W m V m W A U m W W A O N CD N (0 U O O 7' W N N W A N W A 7' 7' 7' 7' A W N ' U A A N N N O A N N C y N A W J a a W W m N W O O m U A A W m W N O m W V N W N m m A A U W m W m W V U U U U m N A m U a J O W m O m co < v m m m m m m m m m m U U U U U U U U U U U U A A A A A A n O W U V t0 N A m Jt0 W A m m �p W A m m t0 W J m O N " n (p V m A N m A N N m m N m Up m A W m J W m A N O m V W0 N W J (r N? m m N N O A 0 m m W U O A fJ A m m A tO W O m O 0 0 N m m A W U A m m W W V O V V m V N J m W (0 O t0 N m 0 0 0 0 0 0 0 0 0 00 0 B 7 v o d o d 7 7 7 d d d 0 0 o z ± ± ± ± + + + + + + + + + + + T T T T T T T T T T T T T T T T T T T T T T T T T T T T T T T v^ N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N O + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + p W W U) W U) m W m m Un U) W Cl) W m W N m Cl) Cl) W W 0 m m W W W 0 w 0 D D D D D D D D D D D D D D D D D D D D D D D D D D D D D D D Z + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + �3 U 3 3 3 C 3 3 3 3 3 C 3 3 3 3 3 C 3 3 3 3 3 3 3 3 3 3 3 3 C C (n W W W W W W W m m m m W W U) U) W N UA W W N W m m m W W W U) m rn rn m rn rn m m rn rn rn m rn m m rn rn m IT m m m IT m rn m ai 'T 'D -m 'T -m ° c OZ o ° i r O d a. v o 0 '< (n ° V7 '0 0 0 m n m N iD O C D D 0 U)CD D 3 O Q 2 N m m m p 3 N CD 3 m UJ (D 1D (7 0 O Q U U U U A A A AA A A A A A A W W W W W W W W W W W N N N N N C `G 7 O D ,nom W IV m J O (D W t0 m t0 W V O O m A CO N N N � O m m J m U A W N N C �� 3 C co m W A D7 W m O W A O U m m U U V m m m N m t0 W A m O O W O) W N (D U W W O m O W p co m W Q1 U A W A V W A A Q7 U W O A N U A W W W m (T j j m A C x c C x W W J O W A t0 m m V W W N m O W O N m A m m m M m O U W m = A m W N m m 0 w 0 W w t0 t0 tp (O O W W m m m m 0 W(0 m m (0 N m N m n� W W A W C C p ,Z7 ,Z] m O W (P W O A W (P A A m O U N) m N m m 0 U N J J O O W C C -j < S m m m m O) t0 m m (O O m N V O m m J J J (O tp O O N V O V V O O J m O Q7 J J O O V O V m m O O) V m m V J m m m COm m t0 �• O- C V m N N U O m W m N m m A V V m O W j0 N (D cD w N A U W O A V A J m m W t0 V W J m N (O m O m J V 0 t0 W A = ^ V) N 7 W W W W W W W W W W W W W W W WW W W W W W W W W W W W W C 10 7zd A W W W W W (W(O� (�) A A (Ul) V m m m m m m V V V m m m m m m m m J C 0) N (O 0) U U m W A m A W N O A J m W (O m m N (O (O m m V m N J V J W V N V J O ()1 O m m A O A m V V V U U A U V A J A U A U U U U m W m A A A N IV A m N m m O U Nm O t0 J N C F W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W JJ W C 0° ' t0 tD m V W O m m V U m U m t0 W W t0 t0 O N U V U A W W W W U J m W WW V A W N O J N W J W A A W O O V W W V V W W J W N U) m ••-' (n MW U N W m W m m J w A O U (0 m O W U W m V W O A W !20 W O A !a N � J U J J W O O � N O W m N A W V O U m U U m + U U Cn U U U U <n U Cn (T U U U in V) Vt Cn Ui U U U U U U (T U) U U U U J N U W m O N W V m V O m m N N m N m O W A N N m O N O U m ^ + O (0 OD V O UA W IJ O O m m V m U A W N O p m J T N A W W N W W A U m j J m W O O N N W W A U 0) 0) V J m CO 0 W O N J A V W D1 W O (!) A m W 0 A p U (T W m W W W M U p p O w N O V A Up m m A m W U W m (O A m A O A U m U O J t0 O J A m m O J N ) rn rn m m rn rn rn rn rn rn m m m rn rn m m m m M rn m rn m rn rn m m rn 0 Z 0 0 0 0 0 0 0 o O o 0 0 0 0 0 o o o 0 0 0 o o o o o o 0 o 0 o 0 w w w w w w w w w w w w w w w w w w w w w w w w w w w w w w w^� y W U m m t0 p t0 m m m V m A W N O c0 A A A N O A (O N m m O � w A m O U O m U O A w W -+ m m W O 0 O m m U m m m m m A (O m m m A 0 A m W m m 0 c0 O N W A U m V m 0 O UA tJ0 WW A U U Nm N Wt0 N m WW m W U V �N N aA U 0 m m 0 O W A NWW m+AWWV , v O WJ NAmWA m V 0 O 8 O O O m 0 A m N O W W m V m W A U m W W A O N CD N (0 U O O 7' W N N W A N W A 7' 7' 7' 7' A W N ' U A A N N N O A N N C y N A W J a a W W m N W O O m U A A W m W N O m W V N W N m m A A U W m W m W V U U U U m N A m U a J O W m O m co < v m m m m m m m m m m U U U U U U U U U U U U A A A A A A n O W U V t0 N A m Jt0 W A m m �p W A m m t0 W J m O N " n (p V m A N m A N N m m N m Up m A W m J W m A N O m V W0 N W J (r N? m m N N O A 0 m m W U O A fJ A m m A tO W O m O 0 0 N m m A W U A m m W W V O V V m V N J m W (0 O t0 N m 0 0 0 0 0 0 0 0 0 00 0 B 7 v o d o d 7 7 7 d d d 0 0 o z ± ± ± ± + + + + + + + + + + + T T T T T T T T T T T T T T T T T T T T T T T T T T T T T T T v^ N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N O + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + p W W U) W U) m W m m Un U) W Cl) W m W N m Cl) Cl) W W 0 m m W W W 0 w 0 D D D D D D D D D D D D D D D D D D D D D D D D D D D D D D D Z + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + �3 U 3 3 3 C 3 3 3 3 3 C 3 3 3 3 3 C 3 3 3 3 3 3 3 3 3 3 3 3 C C (n W W W W W W W m m m m W W U) U) W N UA W W N W m m m W W W U) m rn rn m rn rn m m rn rn rn m rn m m rn rn m IT m m m IT m rn m ai 'T 'D -m 'T -m ° c OZ o ° i r O d a. v o 0 '< O N 0 m n m N iD O C D D 0 U)CD D 3 O Q D o' n N N CD 3 m UJ 0 O Q O n tD m p w Zl w A N CD D 3 D D 0 i7 C) C 0 C N C � C co m a c m + Cl) m + w () O W p co A W A m A C x c C x 0 0 00 7 `OG A A O 3 O 0 V u m 0 �. O (D O Cl)O ° O G � CD 3 7C3 U O ;I W W W W W W W C coo cOo a0o 8i ocn cn m m m m m m m Z O Sa J O) W N N N (n 3 N N A m m V A A A A A A A S N v O) A t0 OD W N t0 0 o w o 0 o J O o cn O � cW0 V N tOD N cn < N cA0 A W fNn O 0- V70 d OWD O A cW0 � t00 T M 3 3 3 co O m N N N N N N O p + + + + + + p o D D D D D D Z X 0 0 0 0 O G7 m ztU) N V1 V1 U) W rn m rn rn rn rn a D N � - o x p O) (a O A 0003�0 O m 2 � D m :0 m n _O N n d A O � o A m N m n N n CD N = N O m 2 2 W Z11 W T7 m W D C 3 T m c� c cv m c � a C m co + co + n O co co m ^^A 1tY ^^A \G A co A co A C x A C cn O O O 7 O 3 N N A PTP a19-104- Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Monday, August 26, 2019 2:54 PM To: Tolman, Ben V Subject: KRU 3R-111 (PTD: 219-104): Intermediate Cement - No Sonic Required Approval Ben, Approval is granted to omit the sonic log for this producer. Please include this approval with the approved PTD. Thanx, Victoria Sent from my iPhone On Aug 26, 2019, at 2:31 PM, Tolman, Ben V <Ben.V.Tolman@conocophillips.com> wrote: Good afternoon Victoria, I wanted to send a follow-up note to an email we sent over last week and make sure you don't have any follow-up questions for us. Thanks. Ben Tolman Staff Drilling Engineer I ConocoPhillips, Alaska (907) 265-6828 (o) 1 (307) 231-3550 (m) From: Tolman, Ben V Sent: Tuesday, August 20, 2019 2:39 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Pov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Rohlfing, Jenaya J <Jenava.i.i of hi ng@conocophilli s.com> Subject: 311-111 (PTD: 219-104): Clarification on Intermediate Cement Condition of Approval Good afternoon Victoria, ConocoPhillips received the approved PTD package; thank you for your time and discussion on the upper completion. When reviewing the PTD, ConocoPhillips would like to receive clarification around the conditions of approval relating to the intermediate cement and the included documentation regarding approval to run sonic LWD for cement evaluation. The 311-111 is a producer that will not be fracture stimulated, for this reason, as noted in the operations summary with the permit, ConocoPhillips currently does not plan to run a cement evaluation log (either sonic LWD or more "conventional" CBL) on the intermediate cement job. ConocoPhillips has chosen this path due to: • Recent successes (2017 and 2019) of offset well intermediate cement jobs (311-102, 311-101, and 311-112); ConocoPhillips experienced no complications with the intermediate cement job. • Proper cement job planning and practices are incorporated to maximize the effectiveness and minimize problems during cementing (On every well ConocoPhillips executes: pre -job modeling, proper centralization, top and bottom plugs, spacer program, and excess volumes). As outlined in the PTC,, ConocoPhillips will perform a formation integrity test on the intermediate casing shoe (lower lateral) and window (upper lateral — PTD 219-105). ConocoPhillips understands that operations don't always go as planned, if this were to occur ConocoPhillips will follow 20AAC25.005 (d)(5), if indications of improper cementing exist, we will be contacting the AOGCC to outline and receive approval with our plan forward. ConocoPhillips anticipates the AOGCC would choose to review the specific situation, well details, and the plan to evaluate adequacy of the cement at that time (depending on circumstances, the best solution for cement evaluation may or may not be a sonic LWD tool). In previous PTD packages this condition has only been included when the permit to drill operations summary has specified that a sonic tool will be run for cement evaluation. From ConocoPhillips understanding of the regulations, prior AOGCC approvals of non -fracture stimulated producers, and adherence to our own internal industry leading operational standards, if there are no indications of improper cementing/isolation of the intermediate cement, it is not necessary to run a cement evaluation log for the intermediate cement job. With this understanding, a sonic pass for cement top confirmation is not required on the 311-111 well. Can you please confirm ConocoPhillips understanding of the regulation and also confirm that the operations summary without a sonic log provided with the submitted package for non -fracture stimulated producer well 312-111 is approved. Thanks, Ben Tolman Staff Drilling Engineer I ConocoPhillips, Alaska (907) 265-6828 (o) 1 (307) 231-3550 (m) s � OF T� THE STATE Alaska Oil and Gas 'ALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 3R-111 Conservation Commission ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-104 Surface Location: 1749' FNL, 2361' FWL, SEC. 9, TI 3N, R9E, UM Bottomhole Location: 3458' FNL, 4255' FEL, SEC. 5, T13N, R9E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.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, Daniel T. Seamount, Jr. Commissioner DATED this t day of August, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 JUL 16 ?6i9, (r° 1 a. Type of Work: Drill ❑v ' Lateral ❑ Redrill ❑ Reentry ❑ 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp [] Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone 04 1 c. Specify if well is proposed for: oalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket 0 Single Well ❑ Bond No. 59-52-180 11. Well Name and Number: KRU 3R-111 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 15,918' • TVD: 3,519' . 12. Field/Pool(s): Kuparak River Field West Sak Oil Pool 4a. Location of Well (Governmental Section): Surface: 1749' FNL & 2361' FWL, Sec 9, T13N, R9E, UM Top of Productive Horizon: 3490' FNL & 1950' FEL, Sec 4, T13N, R9E, UM Total Depth: 3458' FNL & 4255' FEL, Sec 5, T13N, R9E, UM 7. Property Designation: ADL355023, ADL355024, ADL373301 8. DNR Approval Number: 931933000 931934000 931953000 13. Approximate Spud Date: 9/01/2019 • 9. Acres in Property: 3255, 1817, & 677 14. Distance to Nearest Property: 3458' to ADL390616 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 520,666.78 y- 6,031,614.47 Zone- 4 10. KB Elevation above MSL (ft): 48.9' GL / BF Elevation above MSL (ft): 9.8' - 15. Distance to Nearest Well Open to Same Pool: 1260' to 313-102 16. Deviated wells: Kickoff depth: 260 feet • Maximum Hole Angle: 96.36 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 1,570 psi 4 Surface: 1,207 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 42" 20" 94# H-40 Welded 80' Surf Surf 119' 119' Existing, cement to surface 16" 13-3/8" 68# L-80 HYD563 2463' Surf Surf 2502' 2199' 1426 sx 11.0 ppg, 232 sx 12.0 ppg 12-1/4" 9-5/8" 40# L-80 HYD563 8783' Surf Surf 8822' 3667' 1283 sx Class G 15.8 ppg 6-3/4" 4-1/2" 12.6# L-80 HYD563 7518' 8400' 3642' 15918' 3519' N/A - Screens 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑� 20. Attachments: Property Plat El BOP SketchDrilling Diverter Sketch 8 Program Time v. Depth Plot /�, Shallow Hazard Analysis Seabed Report e Drilling Fluid Program l(tt0 AAC 25.050 requirements8 LTJ 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: Ben Tolman 65• '711(42-%'\ Authorized Name: Chip Alvord Contact Email: ben.v.tolman CO .Com Authorized Title: Alaska Drilling Manager C-• Contact Phone: 907-265-6825 Authorized Signature: f/lk Date: Z.,.J%� Commission Use Only Permit to Drill /�} Number: 2 [ 7 / API Number: _ 50-"�� ,�S ��1, Permit Approval Date: 1 I 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 methane, gas hydrates, or gas contained in shales: Ef Other: 36 p -t ?I c- -3 .5-0 0 F:5- i � 5-00Samples req'd: Yes ❑ No[� Mud log req'd: Yes ❑ No[� h n v!a r- /) f-'?- Vr n ttr f 2Ajinpsures: Yes ❑ Nog Directional svy req'd: Yes[ No E] gra 1-7 Spacing exception req'd: Yes ❑ No© Inclination -only svy req'd: Yes E] NoF' P �r Z dA C Z�. a35<h j (z) Post initial injection MIT req'd: Yes No F' Pp�o va ! )'s b t to th c :2, NG26 kic d ✓a,J rC/ctfVn fafl�cw�l �Di'7C17,f7�s e vtrocl rf��w1 G-�La t� tb APPROVED BY I J Approved by:,4 COMMISSIONER THE COMMISSION l r LISubmit Form and 0 R [G.11 NAL \�/ /llltll:11111CIIlJ III U KRU 3R-111(PTD 219-104) Conditions of Approval Based on the location of 311-111, that is, a surface location that is 660 feet or less of a coast line (20 AAC 25.265(d)(2)(f)) a SSSV is required if this well is capable of unassisted flow of hydrocarbons to surface (20 AAC 25.265(d)(1)). If a no -flow test to demonstrate the well is not capable of unassisted flow of hydrocarbons to surface is conducted and the well passes the test, a SSSV will not be required (20 AAC 25.265(k)). The following guidelines apply. 1. Reference AOGCC Guidance Bulletin 10-004 2. Up to a 30 day production period is acceptable prior to the no -flow test for this well 3. The no -flow test must be conducted within 30 days 4. A procedure must be submitted for AOGCC approval at least two weeks in advance. 5. CPAI must demonstrate that offset injectors have not been shut in prior to the no -flow test by providing a list of offset injectors with status and injection history for the past 6 months. Should conditions change, such as increased reservoir pressure due to water injection, an updated no - flow test may be required If the well does not pass a no -flow test, and CPAI proposes to use the deep-set operable valve as a SSSV, the following apply: 1. Provide the control process flow or MID for the SVS system. Specifically for the closing of the actuated valve on the IA prior to the recombination of the gas with produced fluids 2. Demonstrate the equivalence of the proposed deep-set operable valve to a SSSV. 3. The deep set operable valve would require a performance test every 6 months like a typical SSSV. 4. The SSSV or deep set operable valve would be required during ESP operation as well as gas lift operation. 5. If equivalence between the deep set operable valve and a SSSV cannot be demonstrated prior to running the completion or in a subsequent performance test(every 6 months), then a SSSV meeting regulations would be required for the well to remain on production. KRU 3R-111(PTD 219-104) Conditions of Approval: Approval is granted to run the (USIT)Sonic on upcoming well KRU 311-111 (with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement (and lengths) that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. (USIT)Sonic logs must show free pipe and Top of Cement, just as the a -line log does. CPAI must start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. Application for Permit to Drill, Well 3R-111 Saved: 16 -Jul -19 July 16, 2019 Alaska Oil and Gas Conservation Commission 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Well 311-111, a West Sak D Sand Multi -Lateral Producer Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots dual -lateral producer well from the 3R pad. The expected spud date for this well is September 01, 2019. It is planned to use rig Doyon 142. 3R-111 is planned to be a dual lateral horizontal producer in the West Sak D sand. ' The surface section will be drilled with a 16" bit and cased with 13-3/8" casing to ±2,502' MD / 2,199' TVD. The intermediate section will be drilled with a 12-1/4" bit and cased with 9-5/8" casing to ±8,822'MD / 3,667' TVD. The production section will be drilled with a 6-3/4" bit in the West Sak D sand ±15,918' MD / 3,519' TVD and lined with a 4-1/2" OHSAS liner. A separate PTD application will be submitted for the 3R-1 11 Ll lateral. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Ben Tolman at 265-6828 (ben.v.tolman@cop.com) or Chip Alvord at 265-6120. Sincerely, Chip Alvord0� Drilling Manager Application for Permit to Drill Document Kuparuk Well 3R-111 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 3R-111 ryk. =DrllCng aC &Welli coy«oPt,a��pe Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill trust be accompanied by each of the following items, except for an item alreadv on f le with the commission and identified in the application. (2) a plat identifying the property and the property's owners and showing (A) the coordinates of the proposed location of the well at the surface, at the top ojfeach objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates oj'the proposed location of the tire// at the surface. referenced to the state plane coordinate s7siem for this state as maintained by the A%ational Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top ofeach objective formation and at total depth; Location at Surface 1749' FNL & 2361' FWL, Sec 9, T13N, R9E, UM NGS Coordinates Northings: 6,031,614.47" Eastings: 520,666.78' RKB Elevation 48.9' AMSL Pad Elevation 9.8'AMSL Location at Top of Productive Interval West Sak D Sand 3490' FNL & 1950' FEL, Sec 4, TI 3N, R9E, UM NGS Coordinates Northings: 6,035,155.0' Eastings.• 551,616.7' Measured Depth, RKB: 8,822' Total Vertical Depth, RKB: 3,667' Total Vertical Depth, SS: 3,618' Location at Total Depth 3458' FNL & 4255' FEL, Sec 5, T13N, R9E, UM NGS Coordinates Northings: 6,035,168.1 ' Eastings: 514,032.9' Measured Depth, RKB: 15,918' Total Vertical Depth, RKB: 3,519' Total Vertical Depth, SS: 3,470' and (D) other inforntalion required bi, 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to he nttentionalh deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, dra,rn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed vrell; Please see Attachment: Directional Plan And (2) for all wells within 200 feet of the proposed ,rellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and shore that each named operator has been,f u•nished a copy of the application by certified mail: or (B) state that the applicant is the only a/fected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) .In application for a Permit to Drill must be accompanied by each oj'the following items. except for an item already on file with the commission and identified in the application. (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 -1,1C 25.035. 20 AAC25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142 and attachment. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) .r application for a Permit to Drill must be accompanied by each of the following items. except for an item alread} on file with the commission and identified in the application: (4) information on drilling ha=ards, including (A) the maxinuun doirnhole pressure that may, be encountered, criteria used to determine it, and maximum potential stnjaee pressure based on a methane gradient: The maximum potential surface pressure (MPSP) while drilling 3R-111 is 1,207 psi (based on offset 3R- 102 BHP and models): D Sand estimated BHP = 1,570 psi D Sand estimated depth = 3,638' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 363 psi (3,638' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 1,207 psi (1,570 psi — 363 psi) (B) data on potential gas =ones: The well bore is not expected to penetrate any shallow gas zones. And (C') data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation =ones, and =ones that have a propensity for differential sticking: See attached 311-111 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the folloiring items. except for an item already on file tirith the commission and identified in the application: (5) a description of the procedure for conductingfortnation integrity tests, as required under 20 AAC 25.030(f): A procedure is on file with the commission for performing LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already, alt file with lite commission and identified in the application: (6) a complete proposed casing and cementing program as required b} 20.4A('25.030. and a description ofatq! slotted liner, pre -perforated liner. or screen to be installed Casing and Cement Program Casin and Cementing Pro ram Csg/Tbg OD HoleWeight Sine Grade Conn. Length Top MD/TVD Btm MD/TVD Cement Program (in) tib/ft) (ft) (ft) (ft) 20 42 94 H-40 Welded 80 Surf 119 / 119 Existing Cement to Surface with 13-3/8 16 68 L-80 HYD563 2,463 Surf 2,502 / 2,199 1426 sx LiteCRETE Lead 11.0 ppg, 232 sx Dee CRETE Tail 12.0 ppg 9-5/8 12-1/4 40 L-80 HYD563 8,783 Surf 8,822 / 3,667 1283 sx Class G at 15.8 ppg w/ TOC at 5,425' MD 4-1/2 6-3/4 12.6 L-80 HYD563 7,518 8,400 / 3,642 15,918 / 3,519 N/A — Screens 4-1/2 6-3/4 12.6 L-80 HYD563 7,609 8,317 / 3,637 15,926 / 3,489' N/A — Screens 13-3/8" Surface casing run to 2,502' MD / 2,199' TVD Cement from 2,502' MD to 2,002'(500' of tail) with 12.0 ppg DeepCRETE, and from 2,002' to surface with 11.0 ppg LiteCRETE. Assume 0% excess in 20" conductor, 250% excess annular volume for lead in the permafrost and 50% annular excess below the permafrost, and 50% excess for tail. Lead slurry from 2,002' MD to surface with Arctic LiteCRETE @ 11 ppg Conductor (119' – 01) x 0.159 bbl/ft x 1.0 (0% excess) = 19 bbls Bottom of Permafrost to Conductor (1,825'– 119') x 0.0749 bbl/ft x 3.50 (250% excess) = 447 bbls Bottom of Lead to Permafrost (2,002'– 1,825') x 0.0749 bbl/ft x 1.50 (50% excess) = 19 bbls Total Volume = 19 + 447 + 19 = 485 bbls = 2,724 ft'— 1426 sx of 11.0 ppg LiteCRETE @ 1.91 ft3 /sk Tail slurry from 2,502' MD to 2,002 MD with DeepCRETE @ 12 ppg Shoe to Top of Tail (2,502' – 2,002') x 0.0749 ft'/ft x 1.50 (50% excess) = 56 bbls Shoe Joint (80') x 0.1497 ft'/ft x 1.0 (0% excess) =12 bbls Total Volume = 56 + 12 = 68 bbls = 382 ft' => 232 sx of 12.0 ppg DeepCRETE @ 1.65 Witsk 9-5/8" Intermediate casing run to 8822' MD / 3,648' TVD Single stage slurry is designed to be placed from TD to 3,403' MD, which is 250' TVD above top of the Ugnu B with 35% excess annular volume. Slurry from 8,822' MD to 5,425' MD (2,955' TVD) with 15.8 ppg Class G + additives (250' TVD above 3,205' TVD) Shoe to Top of Cement (8,822'– 5,425') X 0.0558 bbbl/ft X 1.35 (35% excess) = 256 bbls Shoe Joint (120') X 0.0732 bbl//ft X 1.0 (0% excess) = 9 bbls Total Volume = 256 + 9 = 265 bbls = 1488 ft' _> 1283 sx of 15.8 ppg Class G @ 1.16 ft3/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the folloiring items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 A.4( 25.035(h)(2): It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At 3R, there has not been an indication of shallow gas or gas hydrates through the surface hole interval. The previously drilled 3R-12 and 3R-10 are close offsets, with neither well encountering shallow gas. The referenced wellbores are (348' and 142' respectively) from the proposed base of permafrost location and the 3R-10 is 312' away from the proposed surface casing setting depth. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied bY each of the follotitiing items, escept,for an item alread}on file with the commission and identified in the application: (S) a drilling fluid program, inchuling it diagram and description of the drilling fluid system, as required by 10 AAC 15.033, Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file irith the commission and identified in the application: The proposed drilling program is included below. Please refer to Attachment 4 for proposed well schematic. Surface Intermediate Production 16" Hole 12-1/4" Hole 6-3/4" Hole 13-3/8" Casing 9-5/8" Casing 4-1/2" Liner Mud System Spud WBM) LSND (WBM) FloPro NT (WBM Density 8.8-9.5 9.0-9.5 9.0 — 9.5 ppg PV ALAP ALAP ALAP YP 30-80 20-30 15-20 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A N/A Initial Gel 30-50 9 - 11 7-10 10 -minute Gel 30-50 <20 8-16 API Filtrate NC < 6 <6 HTHP Fluid Loss at 160° F N/A < 10 <10 H 10.8-11.2 9.5-10.0 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file irith the commission and identified in the application: The proposed drilling program is included below. Please refer to Attachment 4 for proposed well schematic. I . Move in / rig up Doyon Rig 142. Install Annular with 16" diverter line and function test. Notify AOGCC 24 hrs before test. 2. P/U 16" bit & BHA (GR/RES/GWD). Spud Well. Drill surface hole to TD. BROOH to HWDP. TOOH & L/D BHA. 3. Rig up CRT. Run 13-3/8", 684, L-80, HYD563 casing and cement to surface. 4. Nipple down diverter and install GE MB222A wellhead housing and pressure test per GE. 5. Notify AOGCC Field Inspector 24 hours prior to BOPE test. Nipple up 13-5/8" 5M BOPE and test to 250/3,500 psi (annular to 3,500 psi). 5-7/8" a19-5/8" test joints. Record results. 6. Pick up 12-1/4" bit & BHA (GR/Res/PWD). Drill out shoe track. Perform FIT/LOT (11.5 ppg min). Drill intermediate hole to TD. BROOH to surface shoe. TOOH & L/D BHA. 7. Rig up CRT. Run 9-5/8", 40#, L-80, HYD563 casing. Cement with min 250' TVD above top hydrocarbon (estimated Ugnu B or Ugnu C). 8. Freeze protect the OA by bullheading water followed by LEPD once cement reaches 500 psi compressive strength. 9. PU 8-3/4" bit & drill out BHA. Drill out shoe track w/ 8-3/4" bit. Perform FIT/LOT (11.5 ppg min / 13 ppg max). TOOH. 10. PU 6-3/4" bit & BHA (GR/Res/PWD/Periscope HD). TIH w/ tapered string (will be installing 5" SS per WWT). Drill to TD of LO lateral (lower lobe of West Sak D Sand). 11. Backream to 9-5/8" shoe. Circulate casing clean. TIH. Lay in solids free mud/brine. TOOH and LD BHA. 12. TOOK L/D BHA. 13. PU lower liner assembly (OHSAS on 4-1/2", 12.64, L-80. HYD563 base pipe). R/U false table. P/U 2-7/8" inner string). P/U MLZXP liner hanger (w/ MWD). 14. RIH w/ liner to depth. Space out and orient. Set liner hanger and release from hanger (do not un -sting running tool). 15. Pump (and spot) wellbore cleanup treatments (9% formic acid). Let treatments soak and monitor wellbore. Circulate out. 16. Set liner top packer. Monitor well. TOOH & L/D running tools. 17. P/U whipstock (anchor, whipstock, mills, MWD). TIH with whipstock assembly. Get on depth, orient, and set whipstock anchor. Sheer mills off whpstock. Mill window. 18. Perform formation integrity test (11.5 ppg min). TOOK 19. Mill window. Clean, drift, and clean up window. TOOH. 20. P/U bit/motor BHA w/ with MWD. Drill out from window and land out lateral. TOOH 21. See separate PTD for Ll upper lateral. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a permit to Drill must be accompanied by each of the following items, except for an itent already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authori_ation under 20 AAC 21.080 for an annular disposal operation in the well.: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class 11 disposal well (DS 1B CRI), Milne Point, Prudhoe DS -4. All cuttings generated will be hauled to the DS 1B CRI, Milne Point, Prudhoe Bay Grind and Inject Facility (for temporary storage and eventual processing for injection down an approved disposal well), or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 BOP Configuration 14:52, May 31 2019 3R-111wp04.1 Permit Pack plan Summa i ! i m I i W ; d m 0 x 1 5/ " 12-1/4' 0 [ rff-, 20" x/42" 3000 6000 9000 12000 14-1/2" x 6-3, Measured Depth Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) I 20" x 42 2 04 0 U M N h OO O ' 4)00 eo ~ 13 3/8 X1 w p 1Q 39 260 0 2000 4000 6000 8000 10000 12000 14mnn 330 olrld 30 260 -450 He 9 5!8" x 12-1'fe 4-1/2" x 6-3/4" 450 - 640 3 640 - 830 830 - 1020 0 3 Ip 1 4 I 1020 - 1220 m 3R-10 60 1220 - 1410 X60 - --- - --i 1wpo1 1410 1600 ry olnt St to 1 l 1600 - 2200 %., 2200 2800 ' 2800 - 3400 v i 3400 - 4000 c.330 Wp 4- O R 3R-10 4000 4600 j 4600 - 5200 Equivalent Magnetic Distance r ""� 5200 ---- 5800 d) �� 5800 6400 U Q 3R 6400 - 7590 ,i 7590 - 8780 0 2000 4000 6000 8000 10000 12000 14000 24 +F% 120 8780 9970 3R...... Y� 9970 - 11160 Measured Depth "'+" Surface LOCatiOn 3R 11160 12350 12350 13540 Depth From Depth To Survey/Plan Tool 210 150 13540 14730 39.10 1100.00 3R 111111.p04.1 (Plan: 3R-111) GYD-GC-SS Pad Elevation: 9.80 14730 15918 1100.00 2100.00 3R-111wp04,1 (Plan: 3R-111) MWD OWSG 1100.00 2502.21 3R-111wp04.1 (Plan: 3R-111) MWD+IFR2+SAG+MS TVD MD Name 3R-26PB1 180 3R 26 3R-112wp04 2502.21 4002.21 3R-111wp04.1 (Plan: 3R-111) MWD OWSG 2502.21 8822.00 3R-111wp04.1 (Plan: 3R-111) MWD+IFR2+SAG+MS 118.00 118.00 20" x 42" 8822.00 10322.00 3R-111wp04.1 (Plan: 3R-111) MWD OWSG 2198.902502.21 13 3/8" X 16 Magnetic Model & Date: BGGM20f38Se -19 8822.00 15918.00 3R-111wpO4.1 (Plan: 3R-111) MWD+IFR2+SAG+MS 3666.728822.00 9 5/8" x 12-1/4' g p 3519.205918.00 4-1/2" x 6-3/4" Magnetic North is 16.43° East of True North (Magnetic Declination) Magnetic Dip & Field Strength: 80.95° 57412nT 1 39.10 0.00 0.00 39.10 0.00 0.00 0.00 0.00 0.00 2 260.00 0.00 0.00 260.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 65° TF, for 440' 3 400.00 2.10 65.00 399.97 1.08 2.32 1.50 65.00 -2.32 Start 25°1100' DLS, 0° TF, far 1363.19' Lithology Column 4 1763.19 36.18 65.00 1668.90 187.20 401.46 2.50 0.00 -401.46 Hold for 123.89' 5 1887.08 36.18 65.00 1768.90 218.11 467,74 0.00 0.00 -467.74 Start 3°/700' DLS, 0° TF, fm 615.13 6 2502.21 54.63 65.00 2198.90 402.43 863.02 3.00 l 0 -863.02 Hold for 20' 7 2522.21 54.63 65.00 2210.48 409.33 877.81 0.00 0.00 -877.81 Start 4°/100' DLS, d.99° V. for SIRS' 8 3218.70 82.44 63.12 2462.85 691.00 1454.50 4.00 -3.99 -1454.50 Hold far 781.2' aa'1G3 9 3999.90 82.44 63.12 2565.fi3 1041.15 2145.24 0.00 0.00 -2145.24 Siam 4°/100' DLS, -110.87° TF, for 3764.4' i ]ass 10 7764.29 66.63 270.50 3604.47 3533.44 1523.12 4.00 -710.87 -1523.12 Hold far 500' 11 8264.29 86.63 270.50 3633.90 3537.76 1024.01 0.00 0.00-1024.01 3R-111 T01 WSD 052119 BT Must TF to 0', for 150' pfrost 12 8414.29 86.63 270.50 3642.73 3539.05 874.27 0.00 0.00 -874.27 Start 2.5°1100' DLS, -179.88° TF, for 38.95 13 8453.24 85.65 270.49 3645.35 3539.39 835.42 2.50 -179.88 -835.42 Hold for 194.85' 14 8648.10 85.65 270.49 3660.12 3541.06 641.13 0.00 0.00 -641.13 Start 2.5°/100' DLS, 0.12° TF, for 173.97 15 8822.02 90.00 270.50 3666.72 3542.58 467.38 2.50 0.12 4,67.38 3R-111 T02 Fled 052119 BT Start 2°/100' DLS, 1.49° TF, for 41.79' 16 8863.81 90.84 270.52 3666.42 3542.95 425.60 2.00 1.49 425.60 Hdd for 1417.07' 1710280.88 90.84 270.52 3645.75 3555.93 -991.26 0.00 0.00 991.26 Start 2°/100' DLS, -174.52° TF, far 192.W 1810473.53 87.00 270.16 3649.39 3557.07 .1183.85 2.00 -174.52 1183.85 3R-111 T03 042619 AV Start 2.2-11W DLS, -181° TF, fcr 45.68' 1910519.22 86.00 270.16 3652.18 3557.20 -1229.44 2.20 -180.00 1229.44 Hold for 90.12' 2010609.34 86.00 270.16 3658.48 3557.44 -1319.34 0.00 0.00 1319.34 Start 2.2°/100' DLS, 0° TF, for 263.86' 2110873.20 91.80 270.16 3663.55 3558.16 -1583.04 2.20 0.00 1583.04 3R-111 T04 042619 AV Shit 2°/100' DLS, 183° TF, far 1.33 2210874.53 91.77270.16 3663.51 3558.17 -1584.37 2.00 180.00 1584.37 Hold far 879.27' K 1 5 2311753.80 91.77 270.16 3636.30 3560.56 -2463.22 0.00 0.00 2463.22 Start 2°/100' DLS, 0' TF, far 51.33 2411805.13 92.80 270.16 3634.25 3560.70 -2514.50 2.00 0.00 2514.50 3R-111 T05 042619 AV A4wt TF to 0°, for 33.08' 2511835.21 93.40 270.16 3632.62 3560.79 -2544.54 2.00 0.00 2544.54 Hold for 116.32' 2611951.53 93.40 270.16 3625.72 3561.10 -261166 0.00 0.00 2660.66 Start 2°/100' DLS, -180° TF, for 120.08' 2712071.61 91.00 270.16 3621.11 3561.43 -2780.64 2.00 -180.00 2780.64 3R-111 T06 042619 AV Aclust TF to 180°, for 13.46' 2812085.08 90.73 270.16 3620.91 3561.47 -2794.10 2.00 180.00 2794.10 Hold for 592.11' 2912677.18 90.73 270.76 3613.36 3563.08 -3386.16 0.00 0.00 3386.16 Start 2°/100' DLS, 0' TF, for 163.46' 3012840.65 94.00 270.16 3606.61 3563,53 -3549.46 2.00 0.00 3549.46 3R-111 T07 042619 AV Start 2.7'/100' DLS, 0- TF, for 87.3T 3112928.02 96.36 270.16 3598.72 3563.77 -3636.47 2.70 0.00 3636,47 Hold for 66.53' zs1].4 3212994.54 96.36 270.16 3591.36 3563.95 -3702.58 0.00 0.00 3702.58 Start 2.7°/100' DLS, -180° TF, for 217 3313211.54 90.50 270.16 3578.38 3564.54 -3919.10 2.70 .180.00 3919.10 3R-111 T08 042619 AV Start 2°/100' DLS, -180° TF, for 875' U G N U C 3413220.29 90.33 270.16 3578.32 3564.56 -3927.84 2.00 -180.00 3927.84 Hold for 518,91' - 3513739.20 90.33 270.16 3575.37 3565.98 A446.74 0.00 0.00 4446.74 Start 2°/100' DLS, 0' TF, far 78.56' 3613817.76 91.90 270.16 3573.85 3566.19 -4525.29 2.00 0.00 4525.29 3R-111 T09 042619 AV A4wt TF to 0', for 0.73' 33o3.e 3713818.49 91.91 270.16 3573.83 3566.19 -4526.02 2.00 0.00 4526A2 A4mt TF to 0', for 0.73' U G N U - B 3814698.24 91.91 270.16 3544.49 3568.59 -5405.28 0.00 0.00 5405.28 Start 2°/100' DLS, -180° TF, for 36.7' 3315.5 3914734.94 91.18 270.16 3543.50 3568.69 -5441.96 2.00 -180.00 5441.96 3R-111 T10042619 AV Hdd far 1183.07' UGNU_A 4015918.01 91.18 270.16 3519.20 3571.92 .6624.78 0.00 0.00 6624.78 3R-111 T11 042619 AV TD: 15918.01' MD, 3519.2'M 3148.8 TOP N SAND 3a WS D Tw Chalien�in ` By signing this I acknowledge that I have been informed of all risks, checked that thf data is correct, ensured it's completeness, and all surrounding wells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out ii 0 I c ntat� o n the audit ovAed approve it as the basis for the final well plan and w100 a draw lateral I also acknowledge that unless notified otherwise all targets have a 100 feet lateral Prepared by: Checked by: ccepted by Approved by: V. Osara H. Bu J. Ryan B. 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Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-111 Wellbore: Plan: 3R-111 Design: 3R-111 wp04.1 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 3R-111 TVD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) MD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyonl42) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit -2, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 3R Pad Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 usft Slot Radius: Well Plan: 3R-111 Well Position +N/ -S -32.29 usft Northing: +E/ -W 10.62 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore Plan: 3R-111 Magnetics Model Name Sample Date BGGM2018 9/15/2019 Latitude: Longitude: 0.000 in Grid Convergence: Latitude: Longitude: Ground Level: Declination 16.43 Dip Angle 80.95 Design 3R-111wp04.1 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.10 Vertical Section: Depth From (TVD) +N/ -S +EI -W Direction (usft) (usft) (usft) (°) 39.10 0.00 0.00 270.00 0.16° 9.80 usft' Field Strength (nT) 57,412 5/31/2019 2:44:13PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Date 5/31/2019 Database: OAKEDMP1 Local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc—Kuparuk TVD Reference: Project: Kuparuk River Unit -2 MD Reference: Site: Kuparuk 3R Pad North Reference: Well: Plan: 3R-111 Survey Calculation Method: Wellbore: Plan: 3R-111 1 Design: 3R-111wp04.1 1,100.00 Plan Survey Tool Program Date 5/31/2019 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.10 1,100.00 3R-111wp04.1 (Plan: 3R-111) GYD-GC-SS Gyrodata gyro single shots 2 1,100.00 2,100.00 3R-111wp04.1 (Plan: 3R-111) MWD OWSG OWSG MWD - Standard 3 1,100.00 2,502.21 3R-111wp04.1 (Plan: 3R-111) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + A 4 2,502.21 4,002.21 3R-111wp04.1 (Plan: 3R-111) MWD OWSG OWSG MWD - Standard 5 2,502.21 8,822.00 3R-111wp04.1 (Plan: 3R-111) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + � 8 8,822.00 10,322.00 3R-111wp04.1 (Plan: 3R-111) MWD OWSG OWSG MWD - Standard 7 8,822.00 15,918.00 3R-111wp04.1 (Plan: 3R-111) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + N ConocoPhillips Standard Proposal Report Well Plan: 3R-111 Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Plan: 9.8 + 39.10 @ 48.90usft (Doyonl42) True Minimum Curvature 5/31/2019 2 44 13PM Page 3 COMPASS 5000 14 Build 85D �►'' ConocoPhillips ConocoPhillips Dogleg Standard Proposal Report Database: OAKEDMP1 Local Co-ordinate Reference: Well Plan: 3R-111 Company: ConocoPhillips Alaska Inc-Kuparuk TVD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Project: Kuparuk River Unit -2 MD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon 142) Site: Kuparuk 3R Pad North Reference: True Well: Plan: 3R-111 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-111 39.10 0.00 Design: 3R-111wp04.1 0.00 0.00 Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°1100usft) (°/100usft) (°/100usft) (°) Target 39.10 0.00 0.00 39.10 0.00 0.00 0.00 0.00 0.00 0.00 260.00 0.00 0.00 260.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 2.10 65.00 399.97 1.08 2.32 1.50 1.50 0.00 65.00 1,763.19 36.18 65.00 1,668.90 187.20 401.46 2.50 2.50 0.00 0.00 1,887.08 36.18 65.00 1,768.90 218.11 467.74 0.00 0.00 0.00 0.00 2,502.21 54.63 65.00 2,198.90 402.43 863.02 3.00 3.00 0.00 0.00 2,522.21 54.63 65.00 2,210.48 409.33 877.81 0.00 0.00 0.00 0.00 3,218.70 82.44 63.12 2,462.85 691.00 1,454.50 4.00 3.99 -0.27 -3.99 3,999.90 82.44 63.12 2,565.63 1,041.15 2,145.24 0.00 0.00 0.00 0.00 7,764.29 86.63 270.50 3,604.47 3,533.44 1,523.12 4.00 0.11 -4.05 -110.87 8,264.29 86.63 270.50 3,633.90 3,537.76 1,024.01 0.00 0.00 0.00 0.00 3R-111 T01 WSD 052 8,414.29 86.63 270.50 3,642.73 3,539.05 874.27 0.00 0.00 0.00 0.00 8,453.24 85.65 270.49 3,645.35 3,539.39 835.42 2.50 -2.50 -0.01 -179.88 8,648.10 85.65 270.49 3,660.12 3,541.06 641.13 0.00 0.00 0.00 0.00 8,822.02 90.00 270.50 3,666.72 3,542.58 467.38 2.50 2.50 0.01 0.12 3R-111 T02 Heel 052 8,863.81 90.84 270.52 3,666.42 3,542.95 425.60 2.00 2.00 0.05 1.49 10,280.88 90.84 270.52 3,645.75 3,555.93 -991.26 0.00 0.00 0.00 0.00 10,473.53 87.00 270.16 3,649.39 3,557.07 -1,183.85 2.00 -1.99 -0.19 -174.52 3R-111 T03042619A 10,519.22 86.00 270.16 3,652.18 3,557.20 -1,229.44 2.20 -2.20 0.00 -180.00 10,609.34 86.00 270.16 3,658.48 3,557.44 -1,319.34 0.00 0.00 0.00 0.00 10,873.20 91.80 270.16 3,663.55 3,558.16 -1,583.04 2.20 2.20 0.00 0.00 3R-111 T04 042619 A 10,874.53 91.77 270.16 3,663.51 3,558.17 -1,584.37 2.00 -2.00 0.00 180.00 11,753.80 91.77 270.16 3,636.30 3,560.56 -2,463.22 0.00 0.00 0.00 0.00 11,805.13 92.80 270.16 3,634.25 3,560.70 -2,514.50 2.00 2.00 0.00 0.00 3R-111 TO5 042619 A 11,835.21 93.40 270.16 3,632.62 3,560.79 -2,544.54 2.00 2.00 0.00 0.00 11,951.53 93.40 270.16 3,625.72 3,561.10 -2,660.66 0.00 0.00 0.00 0.00 12,071.61 91.00 270.16 3,621.11 3,561.43 -2,780.64 2.00 -2.00 0.00 -180.00 3R-111 T06 042619 A 12,085.08 90.73 270.16 3,620.91 3,561.47 -2,794.10 2.00 -2.00 0.00 180.00 12,677.18 90.73 270.16 3,613.36 3,563.08 -3,386.16 0.00 0.00 0.00 0.00 12,840.65 94.00 270.16 3,606.61 3,563.53 -3,549.46 2.00 2.00 0.00 0.00 313-111 T07 042619 A 12,928.02 96.36 270.16 3,598.72 3,563.77 -3,636.47 2.70 2.70 0.00 0.00 12,994.54 96.36 270.16 3,591.36 3,563.95 -3,702.58 0.00 0.00 0.00 0.00 13,211.54 90.50 270.16 3,578.38 3,564.54 -3,919.10 2.70 -2.70 0.00 -180.00 3R-111 T08 042619 A 13,220.29 90.33 270.16 3,578.32 3,564.56 -3,927.84 2.00 -2.00 0.00 -180.00 13,739.20 90.33 270.16 3,575.37 3,565.98 -4,446.74 0.00 0.00 0.00 0.00 13,817.76 91.90 270.16 3,573.85 3,566.19 -4,525.29 2.00 2.00 0.00 0.00 3R-111 T09 042619 A 13,818.49 91.91 270.16 3,573.83 3,566.19 -4,526.02 2.00 2.00 0.00 0.00 14,698.24 91.91 270.16 3,544.49 3,568.59 -5,405.28 0.00 0.00 0.00 0.00 14,734.94 91.18 270.16 3,543.50 3,568.69 -5,441.96 2.00 -2.00 0.00 -180.00 3R-111 T10 042619 A 15,918.01 91.18 270.16 3,519.20 3,571.92 -6,624.78 0.00 0.00 0.00 0.00 3R-111 T11 042619 A 5/31/2019 2: 44 13P Page 4 COMPASS 5000 14 Build 85D ConocoPhillips philli Database: OAKEDMPI Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-111 Wellbore: Plan: 3R-111 Design: 3R-111 wp04.1 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 3R-111 TVD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon 142) MD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) r) (1) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°NDOusft) 39.10 0.00 0.00 39.10 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 118.00 0.00 0.00 118.00 0.00 0.00 0.00 0.00 0.00 0.00 20" x 42" 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 260.00 0.00 0.00 260.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 65° TF, for 140' 300.00 0.60 65.00 300.00 0.09 0.19 -0.19 1.50 1.50 0.00 400.00 2.10 65.00 399.97 1.08 2.32 -2.32 1.50 1.50 0.00 Start 2.5°/100' DLS, 0° TF, for 1363.19' 500.00 4.60 65.00 499.79 3.55 7.62 -7.62 2.50 2.50 0.00 600.00 7.10 65.00 599.26 7.86 16.86 -16.86 2.50 2.50 0.00 700.00 9.60 65.00 698.19 14.00 30.02 -30.02 2.50 2.50 0.00 800.00 12.10 65.00 796.40 21.95 47.08 -47.08 2.50 2.50 0.00 900.00 14.60 65.00 893.69 31.71 68.00 -68.00 2.50 2.50 0.00 1,000.00 17.10 65.00 989.88 43.25 92.75 -92.75 2.50 2.50 0.00 1,100.00 19.60 65.00 1,084.79 56.56 121.28 -121.28 2.50 2.50 0.00 1,200.00 22.10 65.00 1,178.23 71.60 153.54 -153.54 2.50 2.50 0.00 1,300.00 24.60 65.00 1,270.03 88.34 189.46 -189.46 2.50 2.50 0.00 1,400.00 27.10 65.00 1,360.02 106.77 228.97 -228.97 2.50 2.50 0.00 1,500.00 29.60 65.00 1,448.02 126.84 272.00 -272.00 2.50 2.50 0.00 1,600.00 32.10 65.00 1,533.86 148.51 318.47 -318.47 2.50 2.50 0.00 1,700.00 34.60 65.00 1,617.39 171.74 368.29 -368.29 2.50 2.50 0.00 1,763.19 36.18 65.00 1,668.90 187.20 401.46 -401.46 2.50 2.50 0.00 Hold for 123.89' 1,778.97 36.18 65.00 1,681.64 191.14 409.90 -409.90 0.00 0.00 0.00 T3 1,800.00 36.18 65.00 1,698.61 196.39 421.15 -421.15 0.00 0.00 0.00 1,847.31 36.18 65.00 1,736.80 208.19 446.46 -446.46 0.00 0.00 0.00 pfrost 1,887.08 36.18 65.00 1,768.90 218.11 467.74 -467.74 0.00 0.00 0.00 Start 3°/100' DLS, 0° TF, for 615.13' 1,900.00 36.57 65.00 1,779.31 221.35 474.69 -474.69 3.00 3.00 0.00 2,000.00 39.57 65.00 1,858.02 247.41 530.56 -530.56 3.00 3.00 0.00 2,100.00 42.57 65.00 1,933.41 275.17 590.10 -590.10 3.00 3.00 0.00 2,159.70 44.36 65.00 1,976.74 292.52 627.31 -627.31 3.00 3.00 0.00 K15 2,200.00 45.57 65.00 2,005.25 304.56 653.12 -653.12 3.00 3.00 0.00 2,300.00 48.57 65.00 2,073.36 335.49 719.47 -719.47 3.00 3.00 0.00 2,400.00 51.57 65.00 2,137.54 367.90 788.96 -788.96 3.00 3.00 0.00 2,500.00 54.57 65.00 2,197.62 401.67 861.39 -861.39 3.00 3.00 0.00 2,502.21 54.63 65.00 2,198.90 402.43 863.02 -863.02 3.00 3.00 0.00 Hold for 20'- 13 3/8" x 16" 2,522.21 54.63 65.00 2,210.48 409.33 877.81 -877.81 0.00 0.00 0.00 Start 4°/100' DLS, -3.99° TF, for 696.49' 21600.00 57.74 64.74 2,253.76 436.77 936.32 -936.32 4.00 3.99 -0.33 2,700.00 61.73 64.44 2,304.16 473.83 1,014.31 -1,014.31 4.00 3.99 -0.30 2,800.00 65.72 64.16 2,348.41 512.71 1,095.09 -1,095.09 4.00 3.99 428 2,900.00 69.71 63.89 2,386.32 553.24 1,178.26 -1,178.26 4.00 3.99 -0.27 3,000.00 73.71 63.64 2,417.70 595.20 1,263.41 -1,263.41 4.00 3.99 -0.25 3,100.00 77.70 63.40 2,442.39 638.41 1,350.12 -1,350.12 4.00 3.99 -0.24 3,200.00 81.69 63.16 2,460.27 682.64 1,437.98 -1,437.98 4.00 3.99 -0.23 3,218.70 82.44 63.12 2,462.85 691.00 1,454.50 -1,454.50 4.00 3.99 -0.23 5/31/2019 2:44:13PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMPI Company: ConocoPhillips Alaskalnc_Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-111 Wellbore: Plan: 3R-111 Design: 3R-111 wp04.1 Planned Survey Well Plan: 3R-111 TVD Reference: Measured MD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Depth Inclination Azimuth (usft) Vertical Dogleg Build Turn Hold for 781.2' Rate Rate Rate (usft) (usft) (usft) 3,300.00 82.44 63.12 3,400.00 82.44 63.12 3,500.00 82.44 63.12 3,600.00 82.44 63.12 3,700.00 82.44 63.12 3,800.00 82.44 63.12 3,900.00 82.44 63.12 3,999.90 82.44 63.12 Start 4°1100' DLS, -110.87° TF, for 3764.4' 4,000.00 82.44 63.12 4,100.00 81.03 59.33 4,200.00 79.66 55.52 4,300.00 78.34 51.67 4,400.00 77.07 47.79 4,500.00 75.85 43.87 4,600.00 74.70 39.91 4,700.00 73.62 35.91 4,800.00 72.62 31.86 4,900.00 71.70 27.77 5,000.00 70.87 23.64 5,100.00 70.13 19.47 5,200.00 69.49 15.26 5,300.00 68.95 11.02 5,400.00 68.51 6.75 5,407.05 68.49 6.45 UGNU_C 4.21 2,908.56 5,500.00 68.19 2.47 5,600.00 67.97 358.16 5,700.00 67.87 353.84 5,800.00 67.89 349.53 5,900.00 68.01 345.21 6,000.00 68.25 340.91 6,094.25 68.58 336.87 UGNU_B 2,367.92 -2,367.92 6,100.00 68.60 336.63 6,200.00 69.06 332.36 6,300.00 69.62 328.13 6,400.00 70.28 323.93 6,411.24 70.36 323.46 UGNU_A -3.95 3,510.45 6,500.00 71.04 319.77 6,600.00 71.90 315.65 6,700.00 72.84 311.57 6,800.00 73.86 307.53 6,848.34 74.38 305.59 TOP N SAND -1,976.29 4.00 6,900.00 74.95 303.54 7,000.00 76.12 299.58 7,100.00 77.34 295.67 7,200.00 78.63 291.80 7,300.00 79.96 287.96 7,400.00 81.34 284.16 Vertical Depth (usft) ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 3R-111 TVD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon 142) MD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Vertical Dogleg Build Turn +N/ -S +E/ -W Section Rate Rate Rate (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 2,473.55 727.45 1,526.39 -1,526.39 0.00 0.00 0.00 2,486.71 772.27 1,614.81 -1,614.81 0.00 0.00 0.00 2,499.86 817.09 1,703.23 -1,703.23 0.00 0.00 0.00 2,513.02 861.91 1,791.65 -1,791.65 0.00 0.00 0.00 2,526.18 906.73 1,880.07 -1,880.07 0.00 0.00 0.00 2,539.33 951.55 1,968.49 -1,968.49 0.00 0.00 0.00 2,552.49 996.37 2,056.91 -2,056.91 0.00 0.00 0.00 2,565.63 1.041.15 2,145.24 -2,145.24 0.00 0.00 0.00 2,565.65 1,041.20 2,145.33 -2,145.33 0.00 0.00 0.00 2,580.03 1,088.82 2,232.05 -2,232.05 4.00 -1.41 -3.79 2,596.80 1,141.88 2,315.11 -2,315.11 4.00 -1.37 -3.81 2,615.89 1,200.12 2,394.10 -2,394.10 4.00 -1.32 -3.85 2,637.20 1,263.25 2,468.64 -2,468.64 4.00 -1.27 -3.88 2,660.62 1,330.97 2,538.37 -2,538.37 4.00 -1.21 -3.92 2,686.04 1,402.95 2,602.94 -2,602.94 4.00 -1.15 -3.96 2,713.34 1,478.83 2,662.04 -2,662.04 4.00 -1.08 -4.00 2,742.38 1,558.25 2,715.38 -2,715.38 4.00 -1.00 -4.05 2,773.03 1,640.81 2,762.70 -2,762.70 4.00 -0.92 -4.09 2,805.13 1,726.12 2,803.78 -2,803.78 4.00 -0.83 4.13 2,838.53 1,813.77 2,838.41 -2,838.41 4.00 -0.74 4.17 2,873.06 1,903.32 2,866.42 -2,866.42 4.00 -0.64 4.21 2,908.56 1,994.33 2,887.67 -2,887.67 4.00 -0.54 -4.24 2,944.85 2,086.37 2,902.07 -2,902.07 4.00 -0.43 -4.27 2,947.43 2,092.89 2,902.83 -2,902.83 4.00 -0.38 -4.28 2,981.76 2,178.99 2,909.54 -2,909.54 4.00 -0.32 -4.29 3,019.10 2,271.73 2,910.05 -2,910.05 4.00 -0.21 -4.31 3,056.70 2,364.15 2,903.60 -2,903.60 4.00 -0.10 -4.32 3,094.37 2,455.79 2,890.20 -2,890.20 4.00 0.01 -4.32 3,131.93 2,546.20 2,869.94 -2,869.94 4.00 0.13 -4.31 3,169.19 2,634.95 2,842.91 -2,842.91 4.00 0.24 -4.30 3,203.88 2,716.69 2,811.35 -2,811.35 4.00 0.35 -4.29 3,205.98 2,721.60 2,809.24 -2,809.24 4.00 0.40 -4.27 3,242.11 2,805.74 2,769.09 -2,769.09 4.00 0.46 -4.26 3,277.41 2,886.95 2,722.66 -2,722.66 4.00 0.56 -4.23 3,311.71 2,964.83 2,670.18 -2,670.18 4.00 0.66 4.20 3,315.49 2,973.36 2,663.92 -2,663.92 4.00 0.72 -4.18 3,344.83 3,039.01 2,611.91 -2,611.91 4.00 0.77 -4.16 3,376.62 3,109.12 2,548.12 -2,548.12 4.00 0.85 -4.12 3,406.93 3,174.83 2,479.12 -2,479.12 4.00 0.94 4.08 3,435.60 3,235.81 2,405.26 -2,405.26 4.00 1.02 -4.04 3,448.83 3,263.50 2,367.92 -2,367.92 4.00 1.08 -4.01 3,462.50 3,291.77 2,326.90 -2,326.90 4.00 1.11 -3.98 3,487.49 3,342.43 2,244.41 -2,244.41 4.00 1.16 -3.95 3,510.45 3,387.54 2,158.19 -2,158.19 4.00 1.23 -3.91 3,531.27 3,426.90 2,068.67 -2,068.67 4.00 1.28 -3.87 3,549.86 3,460.30 1,976.29 -1,976.29 4.00 1.33 -3.84 3,566.11 3,487.58 1,881.48 -1,881.48 4.00 1.38 -3.81 5/31/2019 2:44:13PM Page 6 COMPASS 5000 14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP1 Local Co-ordinate Reference: Well Plan: 3R-111 Company: ConocoPhillips Alaska Inc-Kuparuk TVD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon 142) Project: Kuparuk River Unit -2 MD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyonl42) Site: Kuparuk 3R Pad North Reference: True Well: Plan: 3R-111 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-111 Design: 3 R-111 wp04.1 r Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 7,500.00 82.75 280.38 3,579.95 3,508.61 1,784.73 -1,784.73 4.00 1.42 -3.78 7,600.00 84.20 276.62 3,591.32 3,523.29 1,686.49 -1,686.49 4.00 1.45 -3.75 7,700.00 85.67 272.89 3,600.15 3,531.54 1,587.24 -1,587.24 4.00 1.47 -3.73 7,764.29 86.63 270.50 3,604.47 3,533.44 1,523.12 -1,523.12 4.00 1.49 -3.72 Hold for 500' 7,800.00 86.63 270.50 3,606.57 3,533.74 1,487.48 -1,487.48 0.00 0.00 0.00 7,900.00 86.63 270.50 3,612.46 3,534.61 1,387.66 -1,387.66 0.00 0.00 0.00 8,000.00 86.63 270.50 3,618.34 3,535.47 1,287.84 -1,287.84 0.00 0.00 0.00 8,100.00 86.63 270.50 3,624.23 3,536.34 1,188.01 -1,188.01 0.00 0.00 0.00 8,200.00 86.63 270.50 3,630.12 3,537.20 1,088.19 -1,088.19 0.00 0.00 0.00 8,264.29 86.63 270.50 3,633.90 3,537.76 1,024.01 -1,024.01 0.00 0.00 0.00 Adjust TF to 0°, for 150' 8,300.00 86.63 270.50 3,636.00 3,538.07 988.37 -988.37 0.00 0.00 0.00 8,328.86 86.63 270.50 3,637.70 3,538.32 959.56 -959.56 0.00 0.00 0.00 WSD 8,400.00 86.63 270.50 3,641.89 3,538.93 888.54 -888.54 0.00 0.00 0.00 8,414.29 86.63 270.50 3,642.73 3,539.05 874.27 -874.27 0.00 0.00 0.00 Start 2.5°/100' DLS, -179.88° TF, for 38.95' 8,453.24 85.65 270.49 3,645.35 3,539.39 835.42 -835.42 2.50 -2.50 -0.01 Hold for 194.85' 8,500.00 85.65 270.49 3,648.90 3,539.79 788.80 -788.80 0.00 0.00 0.00 8,600.00 85.65 270.49 3,656.48 3,540.65 689.09 -689.09 0.00 0.00 0.00 8,648.10 85.65 270.49 3,660.12 3,541.06 641.13 -641.13 0.00 0.00 0.00 Start 2.5°/100' DLS, 0.12° TF, for 173.92' 8,700.00 86.95 270.50 3,663.47 3,541.51 589.34 -589.34 2.50 2.50 0.01 8,800.00 89.45 270.50 3,666.61 3,542.38 489.40 -489.40 2.50 2.50 0.01 8,822.00 90.00 270.50 3,666.72 3,542.58 467.40 -467.40 2.50 2.50 0.01 9 5/8" x 12-1/4" 8,822.02 90.00 270.50 3,666.72 3,542.58 467.38 -467.38 2.50 2.50 0.01 Start 2°/100' DLS, 1.49° TF, for 41.79' 8,863.81 90.84 270.52 3,666.42 3,542.95 425.60 -425.60 2.00 2.00 0.05 Hold for 1417.07' 8,900.00 90.84 270.52 3,665.89 3,543.28 389.41 -389.41 0.00 0.00 0.00 9,000.00 90.84 270.52 3,664.43 3,544.20 289.42 -289.42 0.00 0.00 0.00 9,100.00 90.84 270.52 3,662.97 3,545.11 189.44 -189.44 0.00 0.00 0.00 9,200.00 90.84 270.52 3,661.51 3,546.03 89.45 -89.45 0.00 0.00 0.00 9,300.00 90.84 270.52 3,660.05 3,546.95 -10.53 10.53 0.00 0.00 0.00 9,400.00 90.84 270.52 3,658.60 3,547.86 -110.52 110.52 0.00 0.00 0.00 9,500.00 90.84 270.52 3,657.14 3,548.78 -210.50 210.50 0.00 0.00 0.00 9,600.00 90.84 270.52 3,655.68 3,549.69 -310.49 310.49 0.00 0.00 0.00 9,700.00 90.84 270.52 3,654.22 3,550.61 -410.47 410.47 0.00 0.00 0.00 9,800.00 90.84 270.52 3,652.76 3,551.52 -510.46 510.46 0.00 0.00 0.00 9,900.00 90.84 270.52 3,651.31 3,552.44 -610.44 610.44 0.00 0.00 0.00 10,000.00 90.84 270.52 3,649.85 3,553.36 -710.43 710.43 0.00 0.00 0.00 10,100.00 90.84 270.52 3,648.39 3,554.27 -810.41 810.41 0.00 0.00 0.00 10,200.00 90.84 270.52 3,646.93 3,555.19 -910.40 910.40 0.00 0.00 0.00 10,280.88 90.84 270.52 3,645.75 3,555.93 -991.26 991.26 0.00 0.00 0.00 Start 2°/100' DLS, -174.52° TF, for 192.66' 10,300.00 90.45 270.49 3,645.54 3,556.10 -1,010.38 1,010.38 2.00 -1.99 -0.19 10,400.00 88.46 270.30 3,646.48 3,556.78 -1,110.37 1,110.37 2.00 -1.99 -0.19 10,473.53 87.00 270.16 3,649.39 3,557.07 -1,183.85 1,183.85 2.00 -1.99 -0.19 Start 2.2°/100' DLS, -180° TF, for 45.68' 10,500.00 86.42 270.16 3,650.91 3,557.15 -1,210.27 1,210.27 2.20 -2.20 0.00 5/31/2019 2:44:13PM Page 7 COMPASS 5000.14 Build 85D ConocoPhillips philli ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Plan: 3R-111 Company: ConocoPhillips Alaska Inc-Kuparuk TVD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Project: Kuparuk River Unit -2 MD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan: 3R-111 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-111 Design: 3R-111 wp04.1 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NIS +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 10,519.22 86.00 270.16 3,652.18 3,557.20 -1,229.44 1,229.44 2.20 -2.20 0.00 Hold for 90.12' 10,600.00 86.00 270.16 3,657.82 3,557.42 -1,310.03 1,310.03 0.00 0.00 0.00 10,609.34 86.00 270.16 3,658.48 3,557.44 -1,319.34 1,319.34 0.00 0.00 0.00 Start 2.2°/100' DLS, 0° TF, for 263.86' 10,700.00 87.99 270.16 3,663.23 3,557.69 -1,409.88 1,409.88 2.20 2.20 0.00 10,800.00 90.19 270.16 3,664.82 3,557.96 -1,509.86 1,509.86 2.20 2.20 0.00 10,873.20 91.80 270.16 3,663.55 3,558.16 -1,583.04 1,583.04 2.20 2.20 0.00 Start 2°/100' DLS, 180° TF, for 1.33' 10,874.53 91.77 270.16 3,663.51 3,558.17 -1,584.37 1,584.37 2.00 -2.00 0.00 Hold for 879.27' 10,900.00 91.77 270.16 3,662.72 3,558.24 -1,609.83 1,609.83 0.00 0.00 0.00 11,000.00 91.77 270.16 3,659.63 3,558.51 -1,709.78 1,709.78 0.00 0.00 0.00 11,100.00 91.77 270.16 3,656.53 3,558.78 -1,809.73 1,809.73 0.00 0.00 0.00 11,200.00 91.77 270.16 3,653.44 3,559.05 -1,909.68 1,909.68 0.00 0.00 0.00 11,300.00 91.77 270.16 3,650.34 3,559.33 -2,009.64 2,009.64 0.00 0.00 0.00 11,400.00 91.77 270.16 3,647.25 3,559.60 -2,109.59 2,109.59 0.00 0.00 0.00 11,500.00 91.77 270.16 3,644.15 3,559.87 -2,209.54 2,209.54 0.00 0.00 0.00 11,600.00 91.77 270.16 3,641.06 3,560.15 -2,309.49 2,309.49 0.00 0.00 0.00 11,700.00 91.77 270.16 3,637.96 3,560.42 -2,409.44 2,409.44 0.00 0.00 0.00 11,753.80 91.77 270.16 3,636.30 3,560.56 -2,463.22 2,463.22 0.00 0.00 0.00 Start 2°/100' DLS, 0° TF, for 51.33' 11,800.00 92.70 270.16 3,634.50 3,560.69 -2,509.38 2,509.38 2.00 2.00 0.00 11,805.13 92.80 270.16 3,634.25 3,560.70 -2,514.50 2,514.50 2.00 2.00 0.00 Adjust TF to 0°, for 30.08' 11,835.21 93.40 270.16 3,632.62 3,560.79 -2,544.54 2,544.54 2.00 2.00 0.00 Hold for 116.32' 11,900.00 93.40 270.16 3,628.78 3,560.96 -2,609.22 2,609.22 0.00 0.00 0.00 11,951.53 93.40 270.16 3,625.72 3,561.10 -2,660.66 2,660.66 0.00 0.00 0.00 i Start 2°1100' DLS, -180° TF, for 120.08' 12,000.00 92.43 270.16 3,623.25 3,561.24 -2,709.06 2,709.06 2.00 -2.00 0.00 12,071.61 91.00 270.16 3,621.11 3,561.43 -2,780.64 2,780.64 2.00 -2.00 0.00 Adjust TF to 180°, for 13.46' 12,085.08 90.73 270.16 3,620.91 3,561.47 -2,794.10 2,794.10 2.00 -2.00 0.00 Hold for 592.11' 12,100.00 90.73 270.16 3,620.72 3,561.51 -2,809.03 2,809.03 0.00 0.00 0.00 12,200.00 90.73 270.16 3,619.44 3,561.78 -2,909.02 2,909.02 0.00 0.00 0.00 12,300.00 90.73 270.16 3,618.17 3,562.05 -3,009.01 3,009.01 0.00 0.00 0.00 12,400.00 90.73 270.16 3,616.89 3,562.33 -3,109.00 3,109.00 0.00 0.00 0.00 12,500.00 90.73 270.16 3,615.62 3,562.60 -3,208.99 3,208.99 0.00 0.00 0.00 12,600.00 90.73 270.16 3,614.34 3,562.87 -3,308.98 3,308.98 0.00 0.00 0.00 12,677.18 90.73 270.16 3,613.36 3,563.08 -3,386.16 3,386.16 0.00 0.00 0.00 Start 2°/100' DLS, 0° TF, for 163.46' 12,700.00 91.19 270.16 3,612.97 3,563.15 -3,408.97 3,408.97 2.00 2.00 0.00 12,800.00 93.19 270.16 3,609.16 3,563.42 -3,508.89 3,508.89 2.00 2.00 0.00 12,840.65 94.00 270.16 3,606.61 3,563.53 -3,549.46 3,549.46 2.00 2.00 0.00 Start 2.7°/100' DLS, 0° TF, for 87.37' 12,900.00 95.60 270.16 3,601.64 3,563.69 -3,608.60 3,608.60 2.70 2.70 0.00 12,928.02 96.36 270.16 3,598.72 3,563.77 -3,636.47 3,636.47 2.70 2.70 0.00 Hold for 66.53' 12,994.54 96.36 270.16 3,591.36 3,563.95 -3,702.58 3,702.58 0.00 0.00 0.00 Start 2.7°/100' DLS, -180° TF, for 217' 5/31/2019 2:44: 13PM Page 8 COMPASS 5000.14 Build 85D ConocoPhillips philli ConocoPhillips Standard Proposal Report Database: OAKEDMP1 Local Co-ordinate Reference: Well Plan: 3R-111 Company: ConocoPhillips Alaska Inc Kuparuk TVD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Project: Kuparuk River Unit -2 MD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan: 3R-111 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-111 Design: 3R-111 wp04.1 Planned Survey 1 Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (I (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 13,000.00 96.21 270.16 3,590.76 3,563.96 -3,708.01 3,708.01 2.70 -2.70 0.00 13,100.00 93.51 270.16 3,582.28 3,564.23 -3,807.64 3,807.64 2.70 -2.70 0.00 13,200.00 90.81 270.16 3,578.51 3,564.51 -3,9D7.56 3,907.56 2.70 -2.70 0.00 13,211.54 90.50 270.16 3,578.38 3,564.54 -3,919.10 3,919.10 2.70 -2.70 0.00 Start 2°/100' DLS, -180° TF, for 8.75' 13,220.29 90.33 270.16 3,578.32 3,564.56 -3,927.84 3,927.84 2.00 -2.00 0.00 Hold for 518.91' 13,300.00 90.33 270.16 3,577.86 3,564.78 -4,007.56 4,007.56 0.00 0.00 0.00 13,400.00 90.33 270.16 3,577.30 3,565.05 -4,107.55 4,107.55 0.00 0.00 0.00 13,500.00 90.33 270.16 3,576.73 3,565.32 -4,207.55 4,207.55 0.00 0.00 0.00 13,600.00 90.33 270.16 3,576.16 3,565.60 -4,307.55 4,307.55 0.00 0.00 0.00 13,700.00 90.33 270.16 3,575.60 3,565.87 -4,407.55 4,407.55 0.00 0.00 0.00 13,739.20 90.33 270.16 3,575.37 3,565.98 -4,446.74 4,446.74 0.00 0.00 0.00 Start 2°/100' DLS, 0° TF, for 78.56' 13,800.00 91.54 270.16 3,574.38 3,566.14 -4,507.54 4,507.54 2.00 2.00 0.00 13,817.76 91.90 270.16 3,573.85 3,566.19 -4,525.29 4,525.29 2.00 2.00 0.00 Adjust TF to 0°, for 0.73' 13,818.49 91.91 270.16 3,573.83 3,566.19 -4,526.02 4,526.02 2.00 2.00 0.00 Hold for 879.75' 13,900.00 91.91 270.16 3,571.11 3,566.42 -4,607.48 4,607.48 0.00 0.00 0.00 14,000.00 91.91 270.16 3,567.77 3,566.69 -4,707.43 4,707.43 0.00 0.00 0.00 14,100.00 91.91 270.16 3,564.44 3,566.96 -4,807.37 4,807.37 0.00 0.00 0.00 14,200.00 91.91 270.16 3,561.10 3,567.23 -4,907.32 4,907.32 0.00 0.00 0.00 14,300.00 91.91 270.16 3,557.77 3,567.51 -5,007.26 5,007.26 0.00 0.00 0.00 14,400.00 91.91 270.16 3,554.43 3,567.78 -5,107.20 5,107.20 0.00 0.00 0.00 14,500.00 91.91 270.16 3,551.10 3,568.05 -5,207.15 5,207.15 0.00 0.00 0.00 14,600.00 91.91 270.16 3,547.76 3,568.32 -5,307.09 5,307.09 0.00 0.00 0.00 14,698.24 91.91 270.16 3,544.49 3,568.59 -5,405.28 5,405.28 0.00 0.00 0.00 Start 2°/100' DLS, -180° TF, for 36.7' 14,700.00 91.88 270.16 3,544.43 3,568.60 -5,407.04 5,407.04 2.00 -2.00 0.00 14,734.94 91.18 270.16 3,543.50 3,568.69 -5,441.96 5,441.96 2.00 -2.00 0.00 Hold for 1183.07' 14,800.00 91.18 270.16 3,542.16 3,568.87 -5,507.01 5,507.01 0.00 0.00 0.00 14,900.00 91.18 270.16 3,540.11 3,569.14 -5,606.99 5,606.99 0.00 0.00 0.00 15,000.00 91.18 270.16 3,538.06 3,569.42 -5,706.97 5,706.97 0.00 0.00 0.00 15,100.00 91.18 270.16 3,536.00 3,569.69 -5,806.94 5,806.94 0.00 0.00 0.00 15,200.00 91.18 270.16 3,533.95 3,569.96 -5,906.92 5,906.92 0.00 0.00 0.00 15,300.00 91.18 270.16 3,531.89 3,570.23 -6,006.90 6,006.90 0.00 0.00 0.00 15,400.00 91.18 270.16 3,529.84 3,570.51 -6,106.88 6,106.88 0.00 0.00 0.00 15,500.00 91.18 270.16 3,527.79 3,570.78 -6,206.86 6,206.86 0.00 0.00 0.00 15,600.00 91.18 270.16 3,525.73 3,571.05 -6,306.84 6,306.84 0.00 0.00 0.00 15,700.00 91.18 270.16 3,523.68 3,571.33 -6,406.82 6,406.82 0.00 0.00 0.00 15,800.00 91.18 270.16 3,521.62 3,571.60 -6,506.79 6,506.79 0.00 0.00 0.00 15,900.00 91.18 270.16 3,519.57 3,571.87 -6,606.77 6,606.77 0.00 0.00 0.00 15,918.00 91.18 270.16 3,519.20 3,571.92 -6,624.77 6,624.77 0.00 0.00 0.00 4-1/2" x 6-3/4" 15,918.01 91.18 270.16 3,519.20 3,571.92 -6,624.78 6,624.78 0.00 0.00 0.00 TD: 15918.01' MD, 3519.2' TVD 5/31/2019 2:44:13PM Page 9 COMPASS 5000.14 Build 85D ep p lame er lame er ConocoPhillips ConocoPhillips Name (in) (in) 118.00 118.00 20" x 42" Standard Proposal Report Database: OAKEDMPI 2,502.21 2,198.90 Local Co-ordinate Reference: Well Plan: 3R-111 Company: ConocoPhillips Alaska Inc-Kuparuk 3,666.72 TVD Reference: 9.625 Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Project: Kuparuk River Unit -2 4-1/2" x 6-3/4" 4.500 MD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyonl42) Site: Kuparuk 3R Pad North Reference: True Well: Plan: 3R-111 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-111 Design: 3 R-111 wp04.1 Design Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape (°) (I (usft) (usft) (usft) (usft) (usft) Latitude Longitude 3R-111 T11 042619 AV 0.00 0.00 3,519.20 3,571.92 -6,624.78 6,034,920.00 1.654,064.34 70° 30' 25.173 N 1490 53' 18.017 W plan hits target center Circle (radius 100.00) 3R-111 T10 042619 AV 0.00 0.00 3,543.50 3,568.69 -5,441.96 6,034,920.00 1,655,247.04 70° 30'25.151 N 149° 52'43.181 W - plan hits target center -Circle (radius 100.00) 3R-111 T09 042619 AV 0.00 0.00 3,573.85 3,566.19 -4,525.29 6,034,920.00 1,656,163.63 70° 30'25.133 N 149° 52' 16.184 W! plan hits target center Circle (radius 100.00) 3R-111 T08 042619 AV 0.00 0.00 3,578.38 3,564.54 -3,919.10 6,034,920.00 1,656,769.76 70° 30' 25.120 N 149° 51'58.330 W - plan hits target center - Circle (radius 100.00) 3R-111 T07042619 AV 0.00 0.00 3,606.61 3,563.53 -3,549.46 6,034,920.00 1,657,139.36 70° 30'25.112 N 149° 51'47.444 W plan hits target center Circle (radius 100.00) 3R-111 T06 042619 AV 0.00 0.00 3,621.11 3,561.43 -2,780.64 6,034,920.00 1,657,908.11 70° 30'25.094 N 149° 51'24.801 W - plan hits target center - Circle (radius 100.00) 3R-111 T01 WSD 05211 0.00 0.00 3,633.90 3,537.76 1,024.01 6,034,906.71 1,661,712.43 70° 30'24.866 N 149° 49' 32.749 W plan hits target center Circle (radius 100.00) 3R-111 T05042619 AV 0.00 0.00 3,634.25 3,560.70 -2,514.50 6,034,920.00 1,658,174.22 70° 30'25.088 N 149° 51' 16.963 W plan hits target center Circle (radius 100.00) 3R-111 T03 042619 AV 0.00 0.00 3,649.39 3,557.07 -1,183.85 6,034,920.00 1,659,504.75 70° 30'25.056 N 149° 50'37.773 W - plan hits target center - Circle (radius 100.00) 3R-111 T04 042619 AV 0.00 0.00 3,663.55 3,558.16 -1,583.04 6,034,920.00 1,659,105.59 70° 30'25.066 N 149° 50'49.530 W plan hits target center Circle (radius 100.00) 3R-111 T02 Heel 05211E 0.00 0.00 3,666.72 3,542.58 467.38 6,034,910.01 1,661,155.85 70° 30'24.914 N 1490 49'49.142 W - plan hits target center - Circle (radius 100.00) - Casing Points Measured Vertical D th De th Casing Hole D' t D' t ep p lame er lame er (usft) (usft) Name (in) (in) 118.00 118.00 20" x 42" 20.000 42.000 2,502.21 2,198.90 13 3/8" x 16" 13.375 16.000 8,822.00 3,666.72 9 5/8" x 12-1/4" 9.625 12.250 15,918.00 3,519.20 4-1/2" x 6-3/4" 4.500 6.750 5/31/2019 2:44: 13PM Page 10 COMPASS 5000.14 Build 85D ConocoPhillips Database: Company: Project: Site: Well: Wellbore: Design: Formations Plan Annotations OAKEDMP1 ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit -2 Kuparuk 3R Pad Plan: 3R-111 Plan: 3R-111 3R-111 wp04.1 Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: 3R-111 Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) True Minimum Curvature Measured Vertical Local Coordinates Dip Depth Depth +N/ -S Dip Direction (usft) (usft) Name Lithology (1 (1) 1,778.97 1,681.64 T3 0.00 1,847.31 1,736.80 pfrost 0.00 2,159.70 1,976.74 K15 0.00 5,407.05 2,947.43 UGNU_C 0.00 6,094.25 3,203.88 UGNU_B 0.00 6,411.24 3,315.49 UGNU_A 0.00 6,848.34 3,448.83 TOP N SAND 0.00 8,328.86 3,637.70 WSD 0.00 Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 260.00 260.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 65° TF, for 140' 400.00 399.97 1.08 2.32 Start 2.5°/100' DLS, 0° TF, for 1363.19' 1,763.19 1,668.90 187.20 401.46 Hold for 123.89' 1,887.08 1,768.90 218.11 467.74 Start 3°/100' DLS, 0° TF, for 615.13' 2,502.21 2,198.90 402.43 863.02 Hold for 20' 2,522.21 2,210.48 409.33 877.81 Start 4°/100' DLS, -3.99° TF, for 696.49' 3,218.70 2,462.85 691.00 1,454.50 Hold for 781.2' 3,999.90 2,565.63 1,041.15 2,145.24 Start 4°/100' DLS, -110.87° TF, for 3764.4' 7,764.29 3,604.47 3,533.44 1,523.12 Hold for 500' 8,264.29 3,633.90 3,537.76 1,024.01 Adjust TF to 0°, for 150' 8,414.29 3,642.73 3,539.05 874.27 Start 2.5°/100' DLS, -179.88° TF, for 38.95' 8,453.24 3,645.35 3,539.39 835.42 Hold for 194.85' 8,648.10 3,660.12 3,541.06 641.13 Start 2.5°/100' DLS, 0.12° TF, for 173.92' 8,822.02 3,666.72 3,542.58 467.38 Start 2°/100' DLS, 1.49° TF, for 41.79' 8,863.81 3,666.42 3,542.95 425.60 Hold for 1417.07' 10,280.88 3,645.75 3,555.93 -991.26 Start 2°/100' DLS, -174.52° TF, for 192.66' 10,473.53 3,649.39 3,557.07 -1,183.85 Start 2.2°/100' DLS, -180° TF, for 45.68' 10,519.22 3,652.18 3,557.20 -1,229.44 Hold for 90.12' 10,609.34 3,658.48 3,557.44 -1,319.34 Start 2.2°/100' DLS, 0° TF, for 263.86' 10,873.20 3,663.55 3,558.16 -1,583.04 Start 2°/100' DLS, 180° TF, for 1.33' 10,874.53 3,663.51 3,558.17 -1,584.37 Hold for 879.27' 11,753.80 3,636.30 3,560.56 -2,463.22 Start 2°/100' DLS, 0° TF, for 51.33' 11,805.13 3,634.25 3,560.70 -2,514.50 Adjust TF to 0°, for 30.08' 11,835.21 3,632.62 3,560.79 -2,544.54 Hold for 116.32' 11,951.53 3,625.72 3,561.10 -2,660.66 Start 2°/100' DLS, -180° TF, for 120.08' 12,071.61 3,621.11 3,561.43 -2,780.64 Adjust TF to 180°, for 13.46' 12,085.08 3,620.91 3,561.47 -2,794.10 Hold for 592.11' 12,677.18 3,613.36 3,563.08 -3,386.16 Start 2°/100' DLS, 0° TF, for 163.46' 12,840.65 3,606.61 3,563.53 -3,549.46 Start 2.7°/100' DLS, 0° TF, for 87.37' 12,928.02 3,598.72 3,563.77 -3,636.47 Hold for 66.53' 12,994.54 3,591.36 3,563.95 -3,702.58 Start 2.7°/100' DLS, -180° TF, for 217' 13,211.54 3,578.38 3,564.54 -3,919.10 Start 2°/100' DLS, -180° TF, for 8.75' 13,220.29 3,578.32 3,564.56 -3,927.84 Hold for 518.91' 13,739.20 3,575.37 3,565.98 -4,446.74 Start 2°/100' DLS, 0° TF, for 78.56' 13,817.76 3,573.85 3,566.19 -4,525.29 Adjust TF to 0°, for 0.73' 13,818.49 3,573.83 3,566.19 -4,526.02 Hold for 879.75' 14,698.24 3,544.49 3,568.59 -5,405.28 Start 2°/100' DLS, -180° TF, for 36.7' 14,734.94 3,543.50 3,568.69 -5,441.96 Hold for 1183.07' 15,918.01 3,519.20 3,571.92 -6,624.78 TD: 15918.01' MD, 3519.2' TVD 5/31/2019 2:44:13PM Page 11 COMPASS 5000.14 Build 85D 0 Q s �°- v O a O V L ca � C � a U C a � a V N O V Q EL O o w x m o L M a + z £ N � C r N Q L CL a LL UR a N '/� o m LU c a m a a R a. ■� ■� V♦ 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C C C C C G O .�C .(O C6 R m UO Up U U C m m m LL C m m m LL C m YO m LL C mL m m LL C m m m LL YO m LL m C (p m LL m m LL C (p C N N LL N m N N N N O N N O N O y N a E ❑ ) 0 U)C ( n ❑ (n C N a)(0 C N ID N N N m C N ID N C C N N m N N N C C al (0 N N N C N N m d N y NN a a N N N a °_ N N a N N ('n y ,a am y .°_ am ami .a ami dl4)a 4)a U W U U W U U W U U W U U W U U W U w U U W U U w U U w O V O V m I- O m f- O O r O r- m (O (D C m lA M m l0 M N M y p M m N V M M N V 0 M I- N N (D M M r- N N (D Mm r- r m N N N (D I- V m N m 7 m (O V m N M m LO V 1� N N N R R N LL U 0 0 0 0 0 0 0 0 0 o O o 0 0 0 0 o O 0 0 0 0 0 0 0 0 0 0 a o 0 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ` LO O O LO O O O O O O O O O O O (O O (O O O O LO N O ((J m O O L to O. N O Ln N W O N O (fJ N N O Ln O O r O m O O O LO O O N N t- O M M co O N (O N I-_ 7 M V V m N t` m LO M V V V R y y r r (D (D (D 43 V O O 1- O O r- V M M V DD M d' 02 M f- .- V m W N r- (O O r(O I� O p M (O M M (O M N N N M M M M M M M M (D m m I. d 0 (D M M N N (D M M N NN N N O N N N O N N N N O (D N N m M (D (D 07 M OO CO m OJ N 1, (O N N y a y 0 0 0 M a W d N O (D co O m M m m r m M m a aj a �d E m �O 0o m (O W m (D V m (D V m 0 V O d' C' C M O M O LO (D LO (D Il Ln m r M m Ln y jd 7 � f- 7 V V V 7 f- V 7 I- 7 V h M M lO f C OCL R d N O 0 m o D aD N a m 7 M m M CC L M m M M (Cj O . 3 ��-' N C 6 -_ y Q y N I� O N r- O m 3 W R Q w W R L M 'C v O � R � � � M � 0 C y R T C a r o rn p a c (� O R a u d w m y (y 4 Q 0 0 0 0 0 0 R R jj � O. wi O1 M M M L Q O O O O 0 O O O n Zpl o c M 7 'y O y y O Y 2' x 2 LL'x LL' N y N Cl) M co M M M a o a R (0 C y C ;O Z C. Q. o O O O O O 'T C R R w C = - - - - a- y N U Y co co co co M M M , R R d U U F K (n fq O O 0 O O 0 O O 0 f- _ M O N (O N (O N O M m M m m V m m O m m 1- M r (O OJ f- In m M m m v m m c m m v v o v 0 (D (o (fl m Ln V m V V m V V m V N (O r m V V N V N I-_ V V (D (D (D M Cl) qT M m m m r OW� (O O M N O M N V � m V V o M M O O (D O O (D O O W f- _ M O N M N (O N O M m m V m m V m m O M M tl W Il LO M r (O m m M M V M m V M M V LO o 0 0 (D M (D (O V m M V V M N tO m V V N f� V N f� 0 V (D (D (D M M m V Cl) V V M V V V M M � M O N IT M s V 0 0 U l� 0 0 m y y y N y y y N y y y y y N y y y y (A y y y y y y y U) N Ul y y o_ 0- a o_ LL o_ a LL a d a a a a c 0 a c c c c c c c c c c v w E `o B `o g `o 4 `o 4 `o 4 `o 4 `o g o` g `o gti �o o `o [D c c c c c c m c C (p c m c LL M N LL M M LL (0 N LL (0 (6 LL (0 M LL LO M LL (6 N LL M N LL M l0 LL M YO LL t6 C O N N N N 03 N W CL N 0 o N CL N N N CL N N N CL N N W N N CL y O_ y E o (n o o (n o cn o cn o cn o (n , w o rm (n o in o E m m m d m u m m u m d m O C d C d M C fl M C d C L1 C d W C d M d C W 11 C N it C N M N N= d= N N= N= N= N= O N_ d N _N N tU y N U 0 W 0 0 W 0 0 W 0 0 W 0 0 W 0 0 W 0 U W 0 W 0 0 W U 0 W 0 0 O V O r r, n L` M 0 M r r VN M M N M 1, V r 0 V r 0 N M M N V LO r M N V Q) 0 W M V O V co m r- 0 O) O Q) M Q1 N M W N O N U W V V V O N 0) V M 0 Ln (O M N Ql V f* V I� N Q7 � O W M Ln V C O W LO N V M I� M O W M (- O M M V O M h M f, r- O V V (O V V O N U V N r O M r W Cl) r O M N r- 0 M V M N M M Nr- O � O O7 0) 4) r v LL U 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a 0 0 0 0 0 0 0 O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 v 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m o LO m 0 LO 0 0 0 0 0 0 0 Ci 0 L O Ln N LO LO O N Ln 0 t` LO O O LO O N N Ln r- N Ln r- O LO LO O 0 0 O LO LO M N Ln O LO V LO N r co Cl) LO Cl) Cl) LO r N LO r N Ln N V y y LO r r r (O co N y c N LO O Q) 0) O O) O) V N O O V LO W LO Ln O O M 00 M C O O V O (0 V O O M N Cl N N LO � N Ln Il N n m L O M N O LO N r O L` O N M O r 0 r O r O M 0 0 0 LO M c•- Ln LO V CO O O V N N Lb N N O ti t` M O O N O O N r t` N n r N m 01 V n r r r N N N N N N N N M r r N r r r r r r r r Ln r r U) r r N L t6 y r O 111 N M O O Of V O V r- O V O O O O O O 0 N _ V N _ V O O O O O O O O M a m O N O O W 0) N O O) N O 0) () M V O V O O O Il O O t -:O O (` M N O O V N O LO LO 0 V LO O O LO O O O (D 0 0 n 0) O) r� 0) 0) 0) L VN N V (T QO V V N V 0) V V 0) OD N V co N V<0 0) V V0) V V 0) V O y C. O) N LO O V O V r V r O M Cl) N M M LO N O N O N r- Lp d W Oi r r r N NM V V V V V m O 0 r r M (` LO O 0 W V M N V M N r r N r N V V r W V 0) OR V r O V W I� LO (O N LO LO r tD O) W O0 W 01 O) T r Q1 O . W O r E v co Ln (O M Ln (` N O N � 0 � M O O M M M M M M LO Q1 Q) M M V O U O Ln N Q) OO O M M O LO N N a2 O V O O N O O N d0 O LO (0 dp Ln D) O) N E N y c r r N N N N N N N N M r r N r r r r r r r r O r r f0 r r V C N m o o V O V l- a O O N 0) O W i L Cl) co O (O V N N C. rip O N LOj O V V O rn r y d D E i O 3 d V Ln Ln Ln n n M M M M M M M C r r r r r r E M M M M M M M m `m Z dV I Lu E r r r r r r r M U co M M co co co M O V O O O 0 O O O N r V N r V O O O O O N O O M W N O N N O W W M V r O V r O O O fl% O Or- O O L` O N N O V Ln O O Lo (O O O O 0 M 0 0 r- 0 M O V V N V d) V V W Lb NV LO N V LO d) c Q1 V V 01 V O V r V r O M CO Ln M Cl) N N N O N O N � r r N N N N N O O O CL a a ID 1010 3 3 3 O O O J J J O O O 3 3 3 0 0 o 3 3 3 a- a a M M Cl) O O O M M M M M M N N N J J W GD (0 O) d) Q) N N Ln (D co O of �& M J M M M M M V V V N N N N N NC? M M O O O O O O O O O � � � � � � � � r r r r r r r r r M M M M M M M M M M M M m m m c c d Q. d M M M M M M M M M O [O O O) O Q7 Ln Ln Ln (O (O O O O (O � � � N N N N N N N N N M M M M M M V V V M M M M M M M M M M M M M M M & & CL (� C� m L" LO LO (0 10 co N (O co co M M Cl) co M Cl) M M N N N N N N N N N C C C C C C C C c co Om') 00 co M co M Cl) M ClCl) Cl) M M M n. O. O_ LL O_ LL LL O_ O. 07 CO a 0 In i IA s �CL O O c Vlo 1 C c 0 a N E lG 7 m E A C E E co 4) V � C p � U W LL U M d � L � " a � @ W 7 M, a D N E Z v O mo 3 m E Z c m 0 E w WG w E A• O N U 41 41 r// LL @ @ a a N w M rO co W u) co O M M M V O o 0 O O o O O to O to N N co 0 0 0 0 0 0 C K m co n Cl) M M M co M C C C C C C d d LL d a 0_ @ @ @ @ @ @ @ @ @ @ @ @ @ @ @ @ @ @ @ @ a s n. LL LL a a LL LL LL LL LL LL a LL LL a LL LL a c N � O C @ d LL 0 c N c 0_ ca d U W U N V V N N O a0 Lq r (O l2 N 0 o O 0 o O 0 0 0 Ln O O V to W O M N (O O O 1-- O O M O O I) V) O to V u7 M LO N O V V (O to to M 0 O M O M LO O to LO C C C C C O N O O O O O y Q1 O O N O O O O O LL @ @ @ LL LL @ @ N @ LL N @ LL @ @ LL a a a a a v 'pO� p v v p p cn v C) cn Q 0 @ C d C @ @d C C d @ C d @ Q C @ m m- a a a— m m -4,(D U U W U U U W U U W U U W U W U U (O M (O 1� M M O M M u) W M to M O N N N M _ to O7 V' M V M M M M N O W to (D N � M u7 N N M M V 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O 0 O tri 0 0 0 o u) 0 o N o 0 0 0 O l() O u) N to O t0 t0 N O to N O O N to r N - N V M O O N M N N co N. N M - N N N N M 7 M M I--.- M r _ M t: m 1: O M M f� M to tO to O r-, . r -:m O r M M M M O O O N (o N O N M N (O O M t` M M M M O O O O m N t0 O O o W OO M O O N O O O O Il to N M O O7 O O r O O O O O O V O m t M M N M M N O o M (o (O M M Il_ N V N W V N W O to to N N V M M O N M O Nm O •- N M r r N N N V M M M M r� tr) V to tr] M oo to M M au O V M M M M M V' 1D N M (O N M (O to M o 7 V V V O V V O t() m 1` N N N N N ` r 1` N r N� M M M N r r r O O O O N N (o O o O M O O of o o N O O O O I- u7 N O O W O M o O 7 O O O O V O W N M M N M M N O O M M M M co r N V N N V N W O to to N N V M M O N M o N Mo r N M - N N N V M M M V V V aaaaaa W W 0 0 0 O O O O O O M M M M M M N M n) M M M 0 o O o 0 0 (if 0� 0� of ly a� M M M M M M 07 m w M M M O o 0 0 0 0 M M M M M M C C C C C C @ @ @ @ @ @ a_ d a- d d a_ N N N O O O a a a 3 3 3 v v J J J O O O 0 0 0 3 3 3 N N N OL LL Q' M M M N N N M M M O O O ' 3 3 3 O o o M M M C C C n d LL d m LL @ @ M M M M M M N N N O o 0 K x xa� cL cL M M M M M M C C C C C C a� a LL a LL v) a O O 7 O) a M A 3 c 0 CL m` in _ 0 a to N N m (0 !0 a_ d y E o m Ec m 2 .F 0 LL A N_ E n _ E N N N co N W U U co v d V U O Cl) A LLL U 3 a 7 V C R V V V O O O O O O O 3 3 3 3 3 3 3 M M M M M M M O O O O O O O N N O O O O O N N N N N O O O O N N L O Q] M m O O O O O O O N N O O M O O N N N N M O O O O N N LQ Lf M oc LL 7. — — N N OJ W U) CO a 0 O Lo 00l a N O N N Cl) a o LO oo O N ' Eo N c)i m moo d V C It M In ll� E mM CN E W C « N W N o u N L O 3 lA d x m w A 41 L M o W p r ,+ A � C � M � 0 C N LL p_ T t6 C Y Y 0 0 0 .y Y A 3 C' W lC N co U m y 2 4 U C a o U O O C C N d o O Cl- a. v G. W Y Y N p M G Y Y 2 H E m Z a — 4) m L = y h Gl 7�6 (0 r e a r 3: U 0 m c E N C W N a (Do e w E LL LL E m c a Z o. E o j C A A V Y Y U m iq U O O j w C C A d U U H K N N 3 a 7 V C R V V V O O O O O O O 3 3 3 3 3 3 3 M M M M M M M O O O O O O O N N O O O O O N N N N N O O O O N N L O Q] M m O O O O O O O N N O O M O O N N N N M O O O O N N LQ Lf M oc LL 7. — — N N OJ W U) CO a 0 O Lo 00l a N O N N Cl) 14:56, May 31 2019 3R-111wp04.1 Ladder View C, 0 0 a 3 3 �ooQ a o d N 3 0 3 CL J o v r�i M � a o CL 3 3 0 � o in c a o0 K ppb / M M/ 0 M +- co 1 // O i 1 - - 300— i I� rll 1 r c •� ! II j 1 ry�l. I� ca I U) Y 150 — o I o L I I .III I III . Equivalent Magnetic Distance III III 07-1 0 2500 5000 7500 10000 12500 15000 Measured Depth SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool VD MD Name 39.10 1100.00 3R-111wp04.1 (Plan: 3R-1 1 1)GYD-GC-SS 118.00 118.00 20" x 42" 1100.00 2100.00 3R-111wp04.1 (Plan: 3R-111)MWD OWSG 2198.90 2502.21 13 3/8" x 16" 1100.00 2502.21 3R-111wp04.1 (Plan: 3R-111)MWD+IFR2+SAG+MS 3666.72 8822.00 9 5/8" x 12-1/4" 2502.21 4002.21 3R-111wp04.1 (Plan: 3R-111)MWD OWSG 3519.2015918.00 4-1/2" x 6-3/4" 2502.21 8822.00 3R-111wp04.1 (Plan: 3R-111)MWD+IFR2+SAG+MS 8822.0010322.00 3R-111wp04.1 (Plan: 3R-111)MWD OWSG n o a a o 0 3 3 c _j 0 Q a C14 N p O Y1 O s 7Ahir 7 m � M O l Ca Q i U) lil I C 30 I U c a) I U Equivalent Magnetic Dis I ce jI 0 0 550 1100 1650 2200 2750 Partial Measured Depth 31 2019 3R-111wpO4.1 TC View From To Tool MD Inc Azi TVD Dleg TFace Target Annotation 39.101100.00 GYD-GC-SS 39.10 0.00 0.00 39.10 0.00 0.00 830 1100.002100.00 MWD OWSG 260.00 0.00 0.00 260.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 65° TF, for 140' 1100.0C2502.21MWD+IFR2+SAG+MS 400.00 2.10 65.00 399.97 1.50 65.00 Start 2.5°/100' DLS, 0° TF, for 1363.19' 2502.214002.21 MWD OWSG 1763.19 36.18 65.00 1668.90 2.50 0.00 Hold for 123.89' 2502.218822.00 MWD+IFR2+SAG+MS 1887.08 36.18 65.00 1768.90 0.00 0.00 Start 3°/100' DLS, 0° TF, for 615.13' 8822.000322.00 MWD OWSG 2502.21 54.63 65.00 2198.90 3.00 0.00 Hold for 20' 8822.005918.00 MWD+IFR2+SAG+MS 2522.21 54.63 65.00 2210.48 0.00 0.00 Start 4°/100' DLS, -3.990 TF, for 696.49' 6400 3218.70 82.44 63.12 2462.85 4.00 -3.99 Hold for 781.2' 8780 3999.90 82.44 63.12 2565.63 0.00 0.00 Start 4°/100' DLS, -110.87° TF, for 3764.4' 11160 7764.29 86.63 270.50 3604.47 4.00-110.87 Hold for 500' 13540 8264.29 86.63 270.50 3633.90 0.00 0.00 3R-111 T01 WSD 0521A®jt&TTF to 0°, for 150' 8414.29 86.63 270.50 3642.73 0.00 0.00 Start 2.5°/100' DLS, -179.88° TF, for 38.95' 8453.24 85.65 270.49 3645.35 2.50-179.88 Hold for 194.85' 8648.10 85.65 270.49 3660.12 0.00 0.00 Start 2.5°/100' DLS, 0.12° TF, for 173.92' 8822.02 90.00 270.50 3666.72 2.50 0.12 3R-111 T02 Heel 0521 BlaHT2°/100' DLS, 1.49° TF, for 41.79' 8863.81 90.84 270.52 3666.42 2.00 1.49 Hold for 1417.07' 10280.88 90.84 270.52 3645.75 0.00 0.00 Start 2°/100' DLS, -174.52° TF, for 192.66' 10473.53 87.00 270.16 3649.39 2.00-174.52 3R-111 T03 042619 A\6tart 2.2°/100' DLS, -180° TF, for 45.68' 10519.22 86.00 270.16 3652.18 10609.34 86.00 270.16 3658.48 10873.20 91.80 270.16 3663.55 2.20-180.00 0.00 0.00 2.20 0.00 Hold for 90.12' Start 2.2°/100' DLS, 0° TF, for 263.86' 3R-111 T04 042619 A\Start 2°/100' DLS, 180° TF, for 1.33' CASING DETAILS TVD MD Name me42" 10874.53 91.77 270.163663.51 2.00 180.00 Hold for 879.27' 118.00 118.0 118.00 118.00 20" x 20" " 11753.80 91.77 270.16 3636.30 0.00 0.00 Start 2°/100' DLS, 0° TF, for 51.33' 2198.9502.21 13 x 16" x 16" 11805.13 92.80 270.16 3634.25 2.00 0.00 3R-111 T05 042619 A\Adjust TF to 0°, for 30.08' 5/8" x 11835.21 93.40 270.16 3632.62 2.00 0.00 Hold for 116.32' 3666.72 8.00 4-1/2" x 6-3/4" 11951.53 93.40 270.16 3625.72 0.00 0.00 Start 2°/100' DLS, -180° TF, for 120.08' 12071.61 91.00 270.16 3621.11 2.00-180.00 3R-111 T06 042619 A\Adjust TF to 180°, for 13.46' 12085.08 90.73 270.16 3620.91 2.00 180.00 Hold for 592.11' 12677.18 90.73 270.16 3613.36 0.00 0.00 Start 2°/100' DLS, 0° TF, for 163.46' 12840.65 94.00 270.163606.61 2.00 0.00 3R-111 T07 042619 AN6tart 2.7°/100' DLS, 0° TF, for 87.37' 12928.02 96.36 270.16 3598.72 2.70 0.00 Hold for 66.53' 12994.54 96.36 270.16 3591.36 0.00 0.00 Start 2.7°/100' DLS, -180° TF, for 217' 13211.54 90.50 270.16 3578.38 2.70-180.00 3R-111 T08 042619 A\Start 2°/100' DLS,-180° TF, for 8.75' 13220.29 90.33 270.16 3578.32 2.00-180.00 Hold for 518.91' 13739.20 90.33 270.16 3575.37 0.00 0.00 Start 2°/100' DLS, 0° TF, for 78.56' 270 1 13818.49 9n91 270.16 3573.83 2.00 0.00 Adjust TF to 0°, for 0.7: 1469&.&7�1 6 3544.49 0.00 0.00 Start 2°/100' DLS, -18C 3.50 p2.00-180.00 3R-111 T10 042619 AWold for 1183.07' 0� 1 .P0 0.00 3R-111 T11 042619 AVfD: 15918.01' MD, 351 ,. Q) - ,, x ,Tj; i 33 85 150 �3RA 05wp05 120 � M wp01 ,! 1 , for 36.7' TVD 39 260 260 450 450 - 640 640 830 830 1020 1020 1220 1220 -"" -" 1410 1410 1600 1600 2200 2200 2800 2800 -W" 3400 3400 - "- - 4000 4000 4600 4600 5200 5200 5800 5800 6400 6400 7590 7590 8780 8780 9970 9970 11160 11160 12350 12350 13540 13540 14730 14730 15918 N O CD d 3 `a g N Cl) L Q �- 00 O 3 (n v 3 v ■ J 3 3 r- � CD o ,n co o r� CL coN M.. COO r Cl) O t- 4a. Jt O 3 g M Op C6 COIZ LO �O Oca {� p M Q �_ 0 O O C_ O a Y M C O Y O O O (0 0 O LO O O CLm LO M `° N N � d p O � c0 �"� M M W M f _.. do O crJ .O 5 m OCII S O Jy 9. OC� r � M ■ M GO CL N M r r O � �- 3 r J o M O � M � Cl) N O 4) p N h a` N (ui/}}sn 005Z) 6uiN�JaN 0 CD LO r O O Q m O CL M O M O O 0 0 O O O O N N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 M O M O CD = LOM M LO r- - O Q CO LO IT M O N IT 0 N N (D M N w N 'd' M O 'Ct 0 'q N LO m LO IT LO 0 I` r-- W O= O= O N M IT LO 0 r 3 O o M T M d7 O O O O O O O O M CD LO IT M N N 0 N IT O M O N Iq CD O 0 N O 0 w O 0 IT O 0 O O 0 O O 0 N O O 0 0 M It O 0 LO O 0 ti O fl- O O CD O LO M O IT LO O M ti ■ r- �- r N N M IT It LO LO O ti M O N M d O rn Q O O O N � 0 CD LO r O O Q m O CL M O M ,a- C0- 0- LU)��W� O + O + Q LL+ F O O N N O O O L O ON N N N a 0 O O O O N N O 00 co O p O O N N O O O OO N N N N M O O O O N 00N L NN O 00 d `— O 117 C) O N Q O CL r�+ 0 Q' -r OM 3 ---- T -� - - - O CL T M N 3 M � r M Ev�°vM m z X X T(o d O O o O O o O W O � o o o] O N M O N O O O O O O O O O O O O O O O O O O O O O O O 00 X U O O o 0 0 0 0 0) O of O O co O 7 V O N 0 0 0 O O O O O O O O O O O O O O O o o O O N M %< _ M O O N O O O O M O O o O M O O — O 7 0 0 0 O O O O O O O O O O O O 0 O O O O O O N H co nw m mm mm m LL 0700< co 'NOOOOOOO N N 000000 N N O M OOM OO M N N N OO NO OOOO (D (O (O (O O 0 0 6 o N N N N N M n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M M M O N M r r r r r r r r r r r r r r n r r r n r r r n r r r r r C O N O O N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N G pp N N 00 N X00000 N N ON NN NO00� o0 LoNM ONq 0 M N� X00 MtO Oig(7 N N0'7 N0] O O e0� �aiOOri�NNoi aivvvrim �i ri0 ri of of riv ri vi ui��ui�aeo v.=0 of t�ao oovm OSI McO O(O W ON�01 (O CO N V NcONI��Of�rNOMN1� W r7N W FNM 01M� O (]f N V'I�O]NNNOI�N V V t00]p�N V'N (O W OJ I�OON000(ONOONNI�mOD (O I�p� ONN �-- — N co M / T , = Q O 3 M' 0. Y O J O �e o r 3 O o M T M ,a- C0- 0- LU)��W� O + O + Q LL+ F O O N N O O O L O ON N N N a 0 O O O O N N O 00 co O p O O N N O O O OO N N N N M O O O O N 00N L NN O 00 d `— O 117 C) O N Q O CL r�+ 0 Q' -r OM 3 ---- T -� - - - O CL T M N 3 M � r M Ev�°vM m z X X T(o d O O o O O o O W O � o o o] O N M O N O O O O O O O O O O O O O O O O O O O O O O O 00 X U O O o 0 0 0 0 0) O of O O co O 7 V O N 0 0 0 O O O O O O O O O O O O O O O o o O O N M %< _ M O O N O O O O M O O o O M O O — O 7 0 0 0 O O O O O O O O O O O O 0 O O O O O O N H co nw m mm mm m LL 0700< co 'NOOOOOOO N N 000000 N N O M OOM OO M N N N OO NO OOOO (D (O (O (O O 0 0 6 o N N N N N M n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M M M O N M r r r r r r r r r r r r r r n r r r n r r r n r r r r r C O N O O N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N G pp N N 00 N X00000 N N ON NN NO00� o0 LoNM ONq 0 M N� X00 MtO Oig(7 N N0'7 N0] O O e0� �aiOOri�NNoi aivvvrim �i ri0 ri of of riv ri vi ui��ui�aeo v.=0 of t�ao oovm OSI McO O(O W ON�01 (O CO N V NcONI��Of�rNOMN1� W r7N W FNM 01M� O (]f N V'I�O]NNNOI�N V V t00]p�N V'N (O W OJ I�OON000(ONOONNI�mOD (O I�p� ONN �-- — N co M O O CL ■ w 15 O O O N IQ O O O LO r U CJ Cwm) Co) W O O 3 0 0 0 0 0 0 0 0 O O O (D Ln 'T M T--- 0 O O O O N N — 0 0 0 0 0 0 0 0 CO M M ti M Lt7 ti O CO 0 It M O N d' CO N w d O w N w T Ln � O In N - 0 M — — — — N N M d' It In Ln 0 ti M O r- r- r - O O O O O O O O O O O O O O O O O O O O O O O O M CO Ln It M N N— 0 0 0 0 0 0 0 0 0 M M ti 0 Lf )� M N 1CO 00 O T— T- M N N M�� Ln In CSO I` M O r- N M S 0 00 WO+(D+0+ co N(n N(nN N X x- . w UW W W 0 Q } O {. 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W 45 M O C 3 0 0 0 0 0 0 0 0 O O O CMO LO TM � O O O O N N — 0 0 0 0 0 0 0 0 0 M M I� M In ti O Cfl Ln ICT M O N IT O N 00 IT O CO N 00 V LO I� O N M It LO N It CO M — — r- — N N M 'T 'T LO Ln CO f` 00 O r- � � � -r-- 0 - O O O O O O O O O O O O O O O O O O O O O O O O M 0 LO d- M N N � 0 0 0 0 0 0 0 0 0 M M f` CO M T M o �OONNOO N It M 00 O N Iq O N w Iq O M N 00 IT M fl- O � M M f` N N M d IT LO L(i CO I� M O r O a 3 0 J CF) 0 A� 1 N O 00 T a� - U)o+ +0+ U) U) C'4 (1) C'4 U) CU X XNCO W 0 J Z= - O 00 - X NM X= 0 0 0 0 0 0 0 0 Q7 O - O O K/ 0 N M O N 0 0 0 O O O O O O o 0 0 0 0 0 0 0 0 0 0 0 0 V 0000000 a) 0000 oro 97 v 0Ln O 00000000000000000000 ('0+0 }} �oo�n0000c?0000aioo�ov0000000000000000000000 V) W c000 CO OO a0 QQQQ 0(\ Q M40- �ro >Q W � Q7 N 0000000 NNOOOOO N NO o U1 Oo(D c0 o o (O tO CO tOOOOOOO(D O t0 (O O O O O O O O �"A V V Lq Lq In 7 � U C c C C C C G G L G G G 0 V O 7 7 7 7 7 7 7 777 7 7 7 7 7 7 7 7 7 7 7 Q O O�� Lo HCl M M O O O O O O O O O O o O o O O O o O O o o o O o O o O O O O O O O O 0 0 0 OO N N 0 0 0 n 0 Z �O� O N O O wo0M0o��t��r�rrrnr�r�r��rr�� N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N t OO N N N N W E3 00 N N 00 c -O N p 0 0 0 M 0 0 M o M V O N M N V o M O M M N o0 In N V V M 0 W M V v 7 O O.- ONN I- (') NNN NN LO N MN Ln W Ln (O O Ln inN N I� V N C)O Q000 ON N In 000 M Q 00 § 01) 0MI�NNa0V V V MoONMOMoO)M V MNin��n l�0o0 V �00]I�OD 07 V W (00(ONON�Q1 (O mw m (O �n V NcO Nf��Ol�i��n0 Min 1�N1�7N0)�NM�r-O�M� N 00o ( b O S P P U O I� pl 0 N V 1� W �n �n ND)I�N V V (O D10pN V Lnt0 a0 DO I��OD 0]00(00]0)0 NNI�Na0 t0 I�p� N N M M 0J OJ m o) OJ a0 0 0 0 0 0 0 x c2 (2 V V n o �OONNOO 00 CO O c O O O N N N N >-d1, �p LO CO O O O O N N L e -LC) Lr) MW N M M ��NNO aO Ad O O CL ■ U. w -45 r O CL TOM TOM TOM 1 M Qj O o 0 0 0 0 0 0 0 0 0 0 0 i yr 00 O O O O N N 0 0 0 0 0 0 0 0 CO O OO Q- 00 In N O-) OO Ul NT M O N Q OO N 00 NT O CO N OO NT us ti O r N M xvLur) N Nt O 00 w- r- w- 7- N N M NT d' Ln In OO 1` 00 O T- T- T- Ir - CA dA 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M O 0lql- M N N 'r- 0 0 0 0 0 0 0 0 0 0 M I` O Us d' M N O a0 O� X- T- CA w N N M d" X 0 0 Ofl ti M M N M I- 0 0 r- 04 0 00 a, U) U) N(n C-4 C-4 N X x U 1 j w � LL LL lL Q+ + t (n (O z= - X 0 O 0 NM X= OOOOO O O m O f 0 0 0 0 O N Q] O N O O O O O O O O O O O O O O O O O O O O O O ...0.0 V o 0 0000 o Ol O o0 0 0 a0 0 V O UJ o 0 0 0 0 0 0 0 0 0 0 0 0 0 o O o 000 00 oolti0000cno00oaioo�oVo000000000000000000000 Q mm m ~ M , O > > L1J �"' 1 � N O O O O O O O N N O O O Q7 O O N N O O O (O M V7 M (6 U7 M (O (6 (6 (D (0 t0 t0 (0 O O V1 O M 0000000 � ��N M V V 1��11�1 cc cc cc ¢¢ G G G G Q �1 Q 0 0 16 6 N N M M 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O 0 0 0O ON C 7 Z QOM 00 O N O O N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N L OON NN C14 00 V 1tNV66 NO......... CWNOO 11MO�ONN�O VM0O' ON1O�M1O�A 6NN.VN.. p 0M0O(60O06(6) 0I�M ON�6M0NMM1�f11 C1N�6N00N0o1N�) 6N(I�61 VN�Qfll 6N(0001 0M6M1 COCODNON NNN O20 QNfOl NONO] OVm m(p60 OONN OOM O04OO NV HNV 04 O N N MM1f000M O 0 °9 - - - - - -X -- - - ---MM �Qp NNNN OO i00 A fM O N ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit -2 Kuparuk 3R Pad Plan: 3R-111 50029xxxxx00 Plan: 3R-111 Plan: 3R-111wp04.1 Error Ellipse Survey Report 31 May, 2019 Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-111 Wellbore: Plan: 3R-111 Design: 3R-111wp04.1 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 3R-111 Plan 9.8 + 39.10 @ 48.90usft (Doyon142) Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) True Minimum Curvature 2.00 sigma OAKEDMPI Project Kuparuk River Unit 2, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Northing: Easting: 0.00 usft Slot Radius: 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: Wellbore Plan: 3R-111 Magnetics Model Name Sample Date BGGM2018 9/15/2019 Design 3R-111wp04.1 Audit Notes: OWSG MWD - Standard Site Kuparuk 3R Pad Site Position: Depth From (TVD) From: Map Position Uncertainty: 39.10 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction Well Plan: 3R-111 Well Position +N/ -S (usft) +E/ -W Position Uncertainty 1,100.00 3R-111wp04.1 (Plan: 3R-111) r 2,100.00 3R-111wp04.1 (Plan: 3R-111) Northing: Easting: 0.00 usft Slot Radius: 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: Wellbore Plan: 3R-111 Magnetics Model Name Sample Date BGGM2018 9/15/2019 Design 3R-111wp04.1 Audit Notes: OWSG MWD - Standard Version: Phase: Vertical Section: Depth From (TVD) MWD+IFR2+SAG+MS (usft) MWD OWSG 39.10 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction Survey Tool Program Date 5/31/2019 From To (usft) (usft) Survey (Wellbore) 39.10 1,100.00 3R-111wp04.1 (Plan: 3R-111) 1,100.00 2,100.00 3R-111wp04.1 (Plan: 3R-111) 1,100.00 2,502.21 3R-111wp04.1 (Plan: 3R-111) 2,502.21 4,002.21 3R-111wp04.1 (Plan: 3R-111) 2,502.21 8,822.00 3R-111wp04.1 (Plan: 3R-111) 8,822.00 10,322.00 3R-11lwp04.1 (Plan: 3R-111) i 8,822.00 15,918.00 3R-111wp04.1 (Plan: 3R-111) Latitude: Longitude: 0.000 in Grid Convergence: Latitude: Longitude: Ground Level: Declination Dip Angle 16.43 80.95 PLAN +N/ -S (usft) 0.00 Tie On Depth: +E/ -W (usft) 0.00 Tool Name Description 39.10 Direction (I 270.00 Field Strength (nT) 57,412 0.16 ° 9.80 usft) J GYD-GC-SS Gyrodata gyro single shots MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 5/31/2019 2:44:40PM Page 2 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-111 Wellbore: Plan: 3R-111 Design: 3R-111 wp04.1 Plan Survey Tool Program Date 5131/2019 Depth From Depth To (usft) (usft) Survey (Wellbore) 1 39.10 1,100.00 3R-111wp04.1 (Plan: 3R-111) 2 1,100.00 2,100.00 3R-111wp04.1 (Plan: 3R-111) 3 1,100.00 2,502.21 3R-111wp04.1 (Plan: 3R-111) i 4 2,502.21 4,002.21 3R-111wp04.1 (Plan: 3R-111) 5 2,502.21 8,822.00 3R-111wp04.1 (Plan: 3R-111) 6 8,822.00 10,322.00 3R-111wp04.1 (Plan: 3R-111) 7 8,822.00 15,918.00 3R-111wp04.1 (Plan: 313-111) Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Depth Error Bias Depth Error Bias (usft) (°) (°) (usft) (usft) (usft) 39.10 0.00 0.00 39.10 0.00 0.00 100.00 0.00 0.00 100.00 0.09 0.00 118.00 0.00 0.00 118.00 0.38 0.00 200.00 0.00 0.00 200.00 0.38 0.00 260.00 0.00 0.00 260.00 0.55 0.00 300.00 0.60 65.00 300.00 0.65 0.00 400.00 2.10 65.00 399.97 0.90 0.00 500.00 4.60 65.00 499.79 1.16 0.00 600.00 7.10 65.00 599.26 1.44 0.00 700.00 9.60 65.00 698.19 1.72 0.00 800.00 12.10 65.00 796.40 2.01 -0.01 900.00 14.60 65.00 893.69 2.31 -0.01 1,000.00 17.10 65.00 989.88 2.61 -0.02 1,100.00 19.60 65.00 1,084.79 2.92 -0.02 1,200.00 22.10 65.00 1,178.23 3.08 -0.02 1,300.00 24.60 65.00 1,270.03 3.11 -0.02 1,400.00 27.10 65.00 1,360.02 3.22 -0.02 1,500.00 29.60 65.00 1,448.02 3.38 -0.02 1,600.00 32.10 65.00 1,533.86 3.62 -0.02 1,700.00 34.60 65.00 1,617.39 3.91 -0.02 1,763.19 36.18 65.00 1,668.90 4.12 -0.02 1,778.97 36.18 65.00 1,681.64 4.27 -0.02 1,800.00 36.18 65.00 1,698.61 4.27 -0.02 1,847.31 36.18 65.00 1,736.80 4.63 -0.02 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Tool Name Remarks GYD-GC-SS Gyrodata gyro single shots MWD OWSG OWSG MWD - Standard MWD+I FR2+SAG+M S OWSG MWD + IFR2 + Sag + MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + MWD OWSG OWSG MWD - Standard MWD+I FR2+SAG+M S OWSG MWD + IFR2 + Sag + Well Plan: 3R-111 Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) True Minimum Curvature 2.00 sigma OAKEDMPI Lateral Vertical Magnitude Semi -major Semi -minor Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 0.09 0.00 2.30 0.00 0.00 0.09 0.09 0.00 GYD-GGSS (1, 1) 0.38 0.00 2.30 0.00 0.00 0.38 0.38 0.00 GYD-GCSS (1, 1) 0.38 0.00 2.30 0.00 0.00 0.38 0.38 0.00 GYD-GC-SS (1, 1) 0.55 0.00 2.30 0.01 0.01 0.55 0.55 0.00 GYD-GCSS (1, 1) 0.65 0.00 2.30 0.01 0.01 0.65 0.65 135.00 GYD-GC-SS (1, 1) 0.89 0.00 2.30 0.02 0.02 0.90 0.89 135.00 GYD-GC-SS (1, 1) 1.16 0.00 2.30 0.03 0.03 1.17 1.16 155.59 GYD-GCSS (1, 1) 1.45 0.00 2.30 0.04 0.04 1.46 1.45 156.17 GYD-GC-SS (1, 1) 1.76 0.00 2.30 0.06 0.06 1.76 1.76 45.00 GYD-GCSS (1, 1) 2.09 0.00 2.29 0.07 0.08 2.09 2.07 63.61 GYD-GC-SS (1, 1) 2.46 0.00 2.28 0.10 0.10 2.46 2.38 64.27 GYD-GC-SS (1, 1) 2.86 0.00 2.28 0.12 0.12 2.86 2.70 64.49 GYD-GC-SS (1, 1) 3.30 0.00 2.28 0.14 0.15 3.30 3.04 64.61 GYD-GC-SS (1, 1) 3.60 0.00 2.52 0.01 0.03 3.60 3.26 64.75 MWD OWSG (1, 2) 4.08 0.00 2.55 0.01 0.03 4.08 3.34 65.21 MWD OWSG (1, 2) 5.01 0.00 2.61 0.01 0.03 5.01 3.48 65.38 MWD OWSG (1, 2) 6.30 0.00 2.68 0.01 0.03 6.30 3.67 65.42 MWD OWSG (1, 2) 7.89 0.00 2.78 0.01 0.03 7.89 3.90 65.42 MWD OWSG (1, 2) 9.73 0.00 2.92 0.01 0.03 9.73 4.17 65.40 MWD OWSG (1, 2) 11.00 0.00 3.02 0.01 0.03 11.00 4.36 65.39 MWD OWSG (1, 2) 11.77 0.00 3.08 0.01 0.03 11.77 4.48 65.39 MWD OWSG (1, 2) 11.77 0.00 3.08 0.01 0.03 11.77 4.48 65.39 MWD OWSG (1, 2) 13.61 0.00 3.29 0.01 0.03 13.61 4.73 65.37 MWD OWSG (1, 2) 5/31/2019 2 44.40PM Page 3 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-111 Wellbore: Plan: 3R-111 Design: 3R-111wp04.1 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 3R-111 Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Plan: 9.8 + 39.10 @ 48.90usft (Doycn142) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Serm-malor Semitninor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (') (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 1,887.08 36.18 65.00 1,768.90 4.63 -0.02 13.61 0.00 3.29 0.01 0.03 13.61 4.73 65.37 MWD OWSG (1,2) 1,900.00 36.57 65.00 1,779.31 4.68 -0.02 13.89 0.00 3.31 0.01 0.03 13.89 4.78 65.37 MWD OWSG (1, 2) 2,000.00 39.57 65.00 1,858.02 5.08 -0.02 16.17 0.00 3.55 0.01 0.03 16.17 5.11 65.36 MWD OWSG (1, 2) 2,100.00 42.57 65.00 1,933.41 5.52 -0.02 18.67 0.00 3.82 0.01 0.03 18.67 5.47 65.34 MWD OWSG (1, 2) 2,159.70 44.36 65.00 1,976.74 4.80 -0.02 10.35 0.00 3.59 0.01 0.03 10.36 5.01 66.64 MWD+IFR2+SAG+MS (2,2) 2,200.00 45.57 65.00 2,005.25 4.80 -0.02 10.35 0.00 3.59 0.01 0.03 10.36 5.01 66.64 MWD+IFR2+SAG+MS (2,2) 2,300.00 48.57 65.00 2,073.36 5.07 -0.02 11.62 0.00 3.80 0.01 0.03 11.62 5.25 66.53 MWD+IFR2+SAG+MS (2,2) 2,400.00 51.57 65.00 2,137.54 5.35 -0.02 12.99 0.00 4.03 0.01 0.03 12.99 5.48 66.42 MWD+IFR2+SAG+MS (2,2) 2,500.00 54.57 65.00 2,197.62 5.62 -0.02 14.45 0.00 4.28 0.01 0.03 14.45 5.71 66.32 MWD+IFR2+SAG+MS (2,2) 2,502.21 54.63 65.00 2,198.90 5.63 -0.02 14.48 0.00 4.28 0.01 0.03 14.48 5.71 66.31 MWD OWSG (2, 3) 2,522.21 54.63 65.00 2,210.48 5.67 -0.02 14.71 0.00 4.01 0.01 0.03 14.71 6.09 66.32 MWD OWSG (2,3) 2,600.00 57.74 64.74 2,253.76 5.57 -0.02 15.60 0.00 4.05 0.01 0.03 15.60 6.14 66.15 MWD OWSG (2,3) 2,700.00 - 61.73 64.44 2,304.16 5.52 -0.02 17.46 0.00 4.16. 0.01 0.03 17.46 6.24 65.84 MWD OWSG (2, 3) 2,800.00 65.72 64.16 2,348.41 5.55 -0.02 20.01 0.00 4.37 0.01 0.03 20.01 6.35 65.51 MWD OWSG (2.3) 2,900.00 69.71 63.89 2,386.32 5.67 -0.01 23.10 0.00 4.68 0.01 0.03 23.10 6.48 65.20 MWD OWSG (2.3) 3,000.00 73.71 63.64 2,417.70 5.88 -0.01 26.60 0.00 5.08 0.01 0.03 26.60 6.60 64.92 MWD OWSG (2,3) 3,100.00 77.70 63.40 2,442.39 6.17 -0.01 30.40 0.00 5.56 0.01 0.03 30.41 6.71 64.68 MWD OWSG (2,3) 3,200.00 81.69 63.16 2,460.27 6.52 -0.01 34.42 0.00 6.11 0.01 0.03 34.43 6.81 64.47 MWD OWSG (2,3) 3,218.70 82.44 63.12 2,462.85 6.60 -0.01 35.18 0.00 6.22 0.01 0.03 35.19 6.83 64.43 MWD OWSG (2,3) 3,300.00 82.44 63.12 2,473.55 7.08 -0.01 38.57 0.00 6.71 0.01 0.03 38.58 6.90 64.28 MWD OWSG (2,3) 3,400.00 82.44 63.12 2,486.71 7.71 -0.01 42.81 0.00 7.35 0.01 0.03 42.82 6.99 64.14 MWD OWSG (2,3) 3,500.00 82.44 63.12 2,499.86 8.37 -0.01 47.12 0.00 8.01 0.01 0.03 47.12 7.08 64.02 MWD OWSG (2,3) 3,600.00 82.44 63.12 2,513.02 9.04 -0.01 51.46 0.00 8.69 0.01 0.03 51.47 7.17 63.93 MWD OWSG (2,3) 3,700.00 82.44 63.12 2,526.18 9.73 -0.01 55.84 0.00 9.39 0.01 0.03 55.84 7.26 63.85 MWD OWSG (2,3) 3,800.00 82.44 63.12 2,539.33 10.44 -0.01 60.24 0.00 10.09 0,01 0.03 60.25 7.36 63.79 MWD OWSG (2.3) 3,900.00 82.44 63.12 2,552.49 11.15 -0.01 64.67 0.00 10.81 0.01 0.03 64.67 7.45 63.73 MWD OWSG (2.3) 3,999.90 82.44 63.12 2,565.63 11.87 -0.01 69.11 0.00 11.53 0.01 0.03 69.11 7.55 63.69 MWD OWSG (2, 3) 4,000.00 82.44 63.12 2,565.65 11.87 40.01 69.11 0.00 11.53 0.01 0.03 69.11 7.55 63.69 MWD+IFR2+SAG+MS (3, 3) 4,100.00 81.03 59,33 2,580.03 8.25 -0.01 35,95 0.00 7.90 0.01 0.03 36.06 7.32 63.96 MWD+IFR2+SAG+MS (3,3) 4,200.00 79.66 55.52 2,596.80 8.73 -0.01 37.45 0.00 8.29 0.01 0.03 37.81 7.40 63.65 MWD+IFR2+SAG+MS (3,3) 4,300.00 78.34 51.67 2,615.89 9.25 -0.01 38.71 -0.01 8.69 0.01 0.03 39.48 7.49 63.21 MWD+IFR2+SAG+MS (3, 3) 4,400.00 77.07 47.79 2,637.20 9.84 -0.01 39.72 -0.01 9.09 0.01 0.03 41.05 7.59 62.67 MWD+IFR2+SAG+MS (3, 3) 4,500.00 75.85 43.87 2,660.62 10.50 -0.01 40.46 -0.01 9.50 0.01 0.03 42.52 7.69 62.06 MWD+IFR2+SAG+MS (3, 3) 4,600.00 74.70 39.91 2,686.04 11.24 -0.01 40.92 -0.01 9.90 0.01 0.03 43.86 7.80 61.39 MWD+IFR2+SAG+MS (3, 3) 4,700.00 73.62 35.91 2,713.34 12.08 -0.01 41.07 -0.01 10.30 0.01 0.03 45.09 7.92 60.70 MWD+IFR2+SAG+MS (3, 3) 4,800.00 72.62 31.86 2,742.38 13.00 -0.01 40.92 -0.01 10.70 0.01 0.03 46.20 8.06 59.99 MWD+IFR2+SAG+MS (3, 3) 4,900.00 71.70 27.77 2,773.03 13.99 -0.01 40.45 -0.01 11.11 0.01 0.03 47.18 8.21 59.28 MWD+IFR2+SAG+MS (3,3) 5,000.00 70.87 23.64 2,805.13 15.05 -0.01 39.67 -0.02 11.51 0.01 0.03 48.03 8.39 58.58 MWD+IFR2+SAG+MS (3, 3) 5,100.00 70.13 19.47 2,838.53 16.16 -0.01 38.58 -0.02 11.90 0.01 0.03 48.77 8.61 57.90 MWD+IFR2+SAG+MS (3,3) 5,200.00 69.49 15.26 2,873.06 17.28 -0.01 37.19 -0.02 12.30 0.01 0.03 49.40 8.87 57.25 MWD+IFR2+SAG+MS (3,3) 5,300.00 68.95 11.02 2,908.56 18.39 -0.01 35.53 -0.02 12.70 0.01 0.03 49.92 9.20 56.64 MWD+IFR2+SAG+MS (3,3) 5,400.00 68.51 6.75 2,944.85 19.48 -0.01 33.61 -0.02 13.09 0.01 0.03 50.33 9.61 56.07 MWD+IFR2+SAG+MS (3,3) 5,407.05 68.49 6.45 2,947.43 20.50 -0.01 31.48 -0.02 13.48 0.01 0.03 50.66 10.12 55.56 MWD+IFR2+SAG+MS (3,3) 5,500.00 68.19 2.47 2,981.76 20.50 -0.01 31.48 -0.02 13.48 0.01 0.03 50.66 10.12 55.56 MWD+IFR2+SAG+MS (3,3) 5,600.00 67.97 358.16 3,019.10 21.44 -0.01 29.19 -0.02 13.88 0.01 0.03 50.90 10.74 55.10 MWD+IFR2+SAG+MS (3,3) 5,700.00 67.87 353.84 3,056.70 22.27 -0.01 26.82 -0.02 14.27 0.01 0.03 51.08 11.48 54.70 MWD+IFR2+SAG+MS (3, 3) 5,800.00 67.89 349.53 3,094.37 22.98 -0.01 24.47 -0.02 14.66 0.01 0.03 51.19 12.37 54.38 MWD+IFR2+SAG+MS (3, 3) 5,900.00 68.01 345.21 3,131.93 23.55 -0.01 22.27 -0.02 15.05 0.01 0.03 51.26 13.39 54.14 MWD+IFR2+SAG+MS (3, 3) 6,000.00 68.25 340.91 3,169.19 23.97 -0.01 20.42 -0.02 15.44 0.01 0.03 51.29 14.57 53.99 MWD+IFR2+SAG+MS (3,3) 6,094.25 68.58 336.87 3,203.88 24.24 -0.01 19.16 -0.02 15.84 0.01 0.03 51.29 15.88 53.94 MWD+IFR2+SAG+MS (3,3) 6,100.00 68.60 336.63 3,205.98 24.24 -0.01 19.16 -0.02 15.84 0.01 0.03 51.29 15.88 53.94 MWD+IFR2+SAG+MS (3,3) 6,200.00 69.06 332.36 3,242.11 24.37 -0.01 18.69 -0.02 16.23 0.01 0.03 51.29 17.33 54.03 MWD+IFR2+SAG+MS (3, 3) 6,300.00 69.62 328.13 3,277.41 24.37 0.00 19.18 -0.02 16.63 0.01 0.03 51.28 18.91 54.26 MWD+IFR2+SAG+MS (3, 3) 6,400.00 70.28 323.93 3,311.71 24.24 0.00 20.59 -0.02 17.02 0.01 0.03 51.29 20.58 54.68 MWD+IFR2+SAG+MS (3,3) 5131/2019 2:44.40PM Page 4 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-111 Wellbore: Plan: 3R-111 Design: 3R-111wp04.1 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 3R-111 Plan: 9.8 + 39.10 @ 48.90usft (Doyonl42) Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi-rninor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 6,411.24 70.36 323.46 3,315.49 24.02 0.00 22.78 -0.02 17.42 0.01 0.03 51.33 22.34 55.33 MWD+IFR2+SAG+MS (3, 3) 6,500.00 71.04 319.77 3,344.83 24.02 0.00 22.78 -0.02 17.42 0.01 0.03 51.33 22.34 55.33 MWD+IFR2+SAG+MS (3,3) 6,600.00 71.90 315.65 3,376.62 23.72 0.00 25.55 -0.02 17.83 0.01 0.03 51.42 24.15 56.24 MWD+IFR2+SAG+MS (3, 3) 6,700.00 72.84 311.57 3,406.93 23.37 0.00 28.71 -0.02 18.23 0.01 0.03 51.58 25.98 57.48 MWD+IFR2+SAG+MS (3,3) 6,800.00 73.86 307.53 3,435.60 23.01 0.00 32.11 -0.02 18.64 0.01 0.03 51.84 27.80 59.09 MWD+IFR2+SAG+MS (3, 3) 6,848.34 74.38 305.59 3,448.83 22.66 0.00 35.65 -0.02 19.05 0.01 0.03 52.23 29.55 61.12 MWD+IFR2+SAG+MS (3, 3) 6,900.00 74.95 303.54 3,462.50 22.66 0.00 35.65 -0.02 19.05 0.01 0.03 52.23 29.55 61.12 MWD+IFR2+SAG+MS (3,3) 7,000.00 76.12 299.58 3,487.49 22.34 0.00 39.24 -0.02 19.47 0.01 0.03 52.79 31.20 63.57 MWD+IFR2+SAG+MS (3,3) 7,100.00 77.34 295.67 3,510.45 22.09 0,00 42.82 402 19.89 0.01 0.03 53.55 32.69 66.37 MWD+IFR2+SAG+MS (3,3) 7,200.00 78.63 291.80 3,531.27 21.93 0.00 46.33 -0.02 20.31 0.01 0.03 54.52 33.98 69.42 MWD+IFR2+SAG+MS (3,3) 7,300.00 79.96 287.96 3,549.86 21.86 0.00 49.74 -0.02 20.74 0.01 0.03 55.73 35.05 72.51 MWD+IFR2+SAG+MS (3,3) 7,400.00 81.34 284.16 3,566.11 21.88 0.00 53.02 -0.02 21.17 0.01 0.03 57.16 35.90 75.44 MWD+IFR2+SAG+MS (3,3) 7,500.00 82.75 280.38 3,579.95 22.01 0.00 56.13 -0.01 21.60 0.01 0.03 58.79 36.53 78.05 MWD+IFR2+SAG+MS (3,3) 7,600.00 84.20 276.62 3,591.32 22.22 0.00 59.05 -0.01 22.03 0.01 0.03 60.58 36.97 80.23 MWD+IFR2+SAG+MS (3,3) 7,700.00 85.67 272.89 3,600.15 22.52 0.00 61.75 -0.01 22.46 0.01 0.03 62.48 37.25 81.96 MWD+IFR2+SAG+MS (3,3) 7,764.29 86.63 270.50 3,604.47 22.74 0.00 63.37 -0.01 22.74 0.01 0.03 63.74 37.36 82.84 MWD+IFR2+SAG+MS (3, 3) 7,800.00 86.63 270.50 3,606,57 22.90 0.00 64.11 -0.01 22.90 0.01 0.03 64.45 37.41 83.26 MWD+IFR2+SAG+MS (3,3) 7,900.00 86.63 270.50 3,612.46 23.34 0.00 66.21 -0.01 23.34 0.01 0.03 66.47 37.52 84.34 MWD+IFR2+SAG+MS (3,3) 8,000.00 86.63 270.50 3,618.34 23.77 0.00 68.33 -0.01 23.78 0.01 0.03 68.53 37.61 85.26 MWD+IFR2+SAG+MS (3,3) 8,100.00 86.63 270.50 3,624.23 24.21 0.00 70.47 -0.01 24.21 0:01 0.03 70.62 37.68 86.06 MWD+IFR2+SAG+MS (3,3) 8,200.00 86.63 270.50 3,630.12 24.65 0.00 72.63 -0.01 24.65 0.01 0.03 72.75 37.74 86.75 MWD+IFR2+SAG+MS (3,3) 8,264.29 86.63 270.50 3,633.90 24.93 0.00 74.03 -0.01 24.94 0.01 0.03 74.13 37.77 87.14 MWD+IFR2+SAG+MS (3,3) 8,300.00 86.63 270.50 3,636.00 25.09 0.00 74.81 -0.01 25.09 0.01 0.03 74.90 37.78 87.35 MWD+IFR2+SAG+MS (3, 3) 8,328.86 86.63 270.50 3,637.70 25.52 0.00 77.01 -0.01 25.53 0.01 0.03 77.07 37.82 87.87 MWD+IFR2+SAG+MS (3, 3) 8,400.00 86.63 270.50 3,641.89 25.52 0.00 77.01 -0.01 25.53 0.01 0.03 77.07 37.82 87.87 MWD+IFR2+SAG+MS (3,3) 8,414.29 86.63 270.50 3,642.73 25.59 0.00 77.33 -0.01 25.60 0.01 0.03 77.38 37.82 87.94 MW0+IFR2+SAG+MS (3,3) 8,453.24 85.65 270.49 3,645.35 25.77 0.00 78.19 -0.01 25.77 0.01 0.03 78.24 37.83 88.12 MWD+IFR2+SAG+MS (3,3) 8,500.00 85.65 270.49 3,648.90 25.98 0.00 79.22 -0.01 25.98 0.01 0.03 79.26 37.84 88.33 MWD+IFR2+SAG+MS (3,3) 8,600.00 85.65 270.49 3,656.48 26.42 0.00 81.45 -0.01 26.42 0.01 0.03 81.48 37.86 88.73 MWD+IFR2+SAG+MS (3,3) 8,648.10 85.65 270.49 3,660.12 26.63 0.00 82.52 -0.01 26.63 0.01 0.03 82.55 37.87 88.90 MWD+IFR2+SAG+MS (3, 3) 8,700.00 86.95 270.50 3,663.47 26.84 0.00 83.68 -0.01 26.86 0.01 0.03 83.70 37.88 89.08 MWD+IFR2+SAG+MS (3, 3) 8,800.00 89.45 270.50 3,666.61 27.29 -0.01 85.93 -0.01 27.30 0.01 0.03 85.94 37.89 89.39 MWD+IFR2+SAG+MS (3,3) 8,822.00 90.00 270.50 3,666.72 27.34 -0.01 86.17 -0.01 27.34 0.01 0.03 86.18 40.75 89.88 MWD OWSG (3.4) 8,822.02 90.00 270.50 3,666.72 27.34 -0.01 86.17 -0.01 27.34 0.01 0.03 86.18 40.75 89.88 MWD OWSG (3, 4) 8,863.81 90.84 270.52 3,666.42 27.35 -0.01 86.20 -0.01 27.35 0.01 0.03 86.20 40.77 90.11 MWD OWSG (3.4) 8,900.00 90.84 270.52 3,665.89 27.35 -0.01 86.27 -0.01 27.35 0.01 0.03 86.27 40.78 90.31 MWD OWSG (3,4) 9,000.00 90.84 270.52 3,664.43 27.38 -0.01 86.70 -0.01 27.38 0.01 0.03 86.70 40.81 90.85 MWD OWSG (3,4) 9,100.00 90.84 270.52 3,662.97 27.44 -0.01 87.48 -0.01 27.44 0.01 0.03 87.49 40.82 91.37 MWD OWSG (3,4) 9,200.00 90.84 270.52 3,661.51 27.51 -0.01 88.59 -0.01 27.51 0.01 0.03 88.61 40.82 91.86 MWD OWSG (3,4) 9,300.00 90.84 270.52 3,660.05 27.61 -0.01 90.03 -0.01 27.61 0.01 0.03 90.06 40.82 92.30 MWD OWSG (3,4) 9,400.00 90.84 270.52 3,658.60 27.73 -0.01 91.77 -0.01 27.73 0.01 0.03 91.82 40.81 92.68 MWD OWSG (3,4) 9,500.00 90.84 270.52 3,657.14 27.87 -0.01 93.80 -0.01 27.87 0.01 0.03 93.87 40.79 93.01 MWD OWSG (3,4) 9,600.00 90.84 270.52 3,655.68 28.04 -0.01 96.10 -0.01 28.03 0.01 0.03 96.19 40.77 93.28 MWD OWSG (3,4) 9,700.00 90.84 270.52 3,654.22 28.22 -0.01 98.65 -0.01 28.22 0.01 0.03 98.76 40.75 93.50 MWD OWSG (3,4) 9,800.00 90.84 270.52 3,652.76 28.42 -0.01 101.44 -0.01 28.42 0.01 0.03 101.56 40.72 93.68 MWD OWSG (3,4) 9,900.00 90.84 270.52 3,651.31 28.65 -0.01 104.43 -0.01 28.65 0.01 0.03 104.58 40.70 93.81 MWD OWSG (3, 4) 10,000.00 90.84 270.52 3,649.85 28.69 -0.01 107.63 -0.01 28.89 0.01 0.03 107.79 40.68 93.90 MWD OWSG (3,4) 10,100.00 90.84 270.52 3,648.39 29.15 -0.01 111.01 -0.01 29.15 0.01 0.03 111.18 40.67 93.96 MWD OWSG (3,4) 10,200.00 90.84 270.52 3,646.93 29.44 -0.01 114.55 -0.01 29.43 0.01 0.03 114.73 40.65 94.00 MWD OWSG (3, 4) 10,280.88 90.84 270.52 3,645.75 29.68 -0.01 117.52 -0.01 29.67 0.01 0.03 117.71 40.65 94.01 MWD OWSG (3,4) 10,300.00 90.45 270.49 3,645.54 29.73 -0.01 118.23 -0.01 29.73 0.01 0.03 118.43 40.64 94.01 MWD OWSG (3,4) 10,400.00 88.46 270.30 3,646.48 28.29 -0.01 94.36 -0.01 28.28 0.01 0.03 94.40 41.16 92.17 MWD+IFR2+SAG+MS (4,4) 10,473.53 87.00 270.16 3,649.39 28.41 -0.01 95.11 -0.01 28.37 0.01 0.03 95.16 41.18 92.24 MWD+IFR2+SAG+MS (4,4) 10,500.00 86.42 270.16 3,650.91 28.46 0.00 95.38 -0.01 28.40 0.01 0.03 95.43 41.18 92.26 MWD+IFR2+SAG+MS (4,4) 5/31/2019 2:44:40PM Page 5 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-111 Wellbore: Plan: 3R-111 Design: 3 R-111 wp04.1 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 3R-111 Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Plan: 9.8 + 39.10 @ 48.90usft (Doyonl42) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 10,519.22 86.00 270.16 3,652.18 28.50 0.00 95.58 -0.01 28.42 0.01 0.03 95.64 41.19 92.28 MWD+IFR2+SAG+MS (4,4) 10,600.00 86.00 270.16 3,657.82 28.60 0.00 96.46 -0.01 28.52 0.01 0.03 96.51 41.20 92.34 MWD+IFR2+SAG+MS (4,4) 10,609.34 86.00 270.16 3,658.48 28.61 0.00 96.56 -0.01 28.54 0.01 0.03 96.61 41.21 92.35 MWD+IFR2+SAG+MS (4,4) 10,700.00 87.99 270.16 3,663.23 28.68 -0.01 97.58 -0.01 28.66 0.01 0.03 97.64 41.23 92.41 MWD+IFR2+SAG+MS (4,4) 10,800.00 90.19 270.16 3,664.82 28.80 -0.01 98.75 -0.01 28.80 0.01 0.03 98.82 41.25 92.48 MWD+IFR2+SAG+MS (4,4) 10,873.20 91.80 270.16 3,663.55 28.92 -0.01 99.64 -0.01 28.90 0.01 0.03 99.71 41.26 92.52 MWD+IFR2+SAG+MS (4,4) 10,874.53 91.77 270.16 3,663.51 28.92 -0.01 99.66 -0.01 28.90 0.01 0.03 99.73 41.26 92.52 MWD+IFR2+SAG+MS (4,4) 10,900.00 91.77 270.16 3,662.72 28.96 -0.01 99.98 -0.01 28.94 0.01 0.03 100.05 41.27 92.53 MWD+IFR2+SAG+MS (4,4) 11,000.00 91.77 270.16 3,659.63 29.11 -0.01 101.24 -0.01 29.09 0.01 0.03 101.32 41.29 92.58 MWD+IFR2+SAG+MS (4, 4) 11,100.00 91.77 270.16 3,656.53 29.27 -0.01 102.55 -0.01 29.25 0.01 0.03 102.63 41.31 92.63 MWD+IFR2+SAG+MS (4,4) 11,200.00 91.77 270.16 3,653.44 29.43 -0.01 103.91 -0.01 29.42 0.01 0.03 103.99 41.33 92.67 MWD+IFR2+SAG+MS (4,4) 11,300.00 91.77 270.16 3,650.34 29.60 -0.01 105.30 -0.01 29.59 0.01 0.03 105.38 41.36 92.70 MWD+IFR2+SAG+MS (4,4) 11,400.00 91.77 270.16 3,647.25 29.78 -0.01 106.73 -0,01 29.76 0.01 0.03 106.82 41.38 92.73 MWD+IFR2+SAG+MS (4,4) 11,500.00 91.77 270.16 3,644.15 29.96 -0.01 108.19 -0.01 29.94 0.01 0.03 108.29 41.41 92.75 MWD+IFR2+SAG+MS (4,4) 11,600.00 91.77 270.16 3,641.06 30.15 -0.01 109.70 -0.01 30.13 0.01 0.03 109.79 41.43 92.77 MWD+IFR2+SAG+MS (4,4) 11,700.00 91.77 270.16 3,637.96 30.34 -0.01 111.23 -0.01 30.33 0.01 0.03 111.33 41.46 92.79 MWD+IFR2+SAG+MS (4,4) 11,753.80 91.77 270.16 3,636.30 30.45 -0.01 112.07 -0.01 30.43 0.01 0.03 112.17 41.47 92.79 MWD+IFR2+SAG+MS (4,4) 11,800.00 92.70 270.16 3,634.50 30.56 -0.01 112.80 -0.01 30.53 0.01 0.03 112.90 41.48 92.80 MWD+IFR2+SAG+MS (4,4) 11,805.13 92.80 270.16 3,634.25 30.57 -0.01 112.88 -0.01 30.54 0.01 0.03 112.99 41.48 92.80 MWD+IFR2+SAG+MS (4,4) 11,835.21 93.40 270.16 3,632.62 30.65 -0.01 113.36 -0.01 30.60 0.01 0.03 113.46 41.49 92.80 MWD+IFR2+SAG+MS(4,4) 11,900.00 93.40 270.16 3,628.78 30.78 -0.01 114.40 -0.01 30.73 0.01 0.03 114.50 41.51 92.81 MWD+IFR2+SAG+MS (4,4) 11,951.53 93.40 270.16 3,625.72 30.89 -0.01 115.23 -0.01 30.84 0.01 0.03 115.34 41.52 92.81 MWD+IFR2+SAG+MS (4,4) 12,000.00 92.43 270.16 3,623.25 30.97 -0.01 116.02 -0.01 30.94 0.01 0.03 116.13 41.54 92.81 MWD+IFR2+SAG+MS (4,4) 12,071.61 91.00 270.16 3,621.11 31.10 -0.01 117.21 -0.01 31.09 0.01 0.03 117.32 41.56 92.81 MWD+IFR2+SAG+MS (4,4) 12,085.08 90.73 270.16 3,620.91 31.13 -0.01 117.43 -0.01 31.12 0.01 0.03 117.54 41.56 92.81 MWD+IFR2+SAG+MS (4,4) 12,100.00 90.73 270.16 3,620.72 31.16 -0.01 117.68 -0.01 31.15 0.01 0.03 117.79 41.57 92.81 MWD+IFR2+SAG+MS (4,4) 12,200.00 90.73 270.16 3,619.44 31.38 -0.01 119.37 -0.01 31.37 0.01 0.03 119.48 41.59 92.81 MWD+IFR2+SAG+MS (4,4) 12,300.00 90.73 270.16 3,618.17 31.60 -0.01 121.08 -0.01 31.60 0.01 0.03 121.20 41.62 92.81 MWD+IFR2+SAG+MS (4,4) 12,400.00 90.73 270.16 3,616.89 31.83 -0.01 122.82 -0.01 31.83 0.01 0.03 122.94 41.65 92.80 MWD+IFR2+SAG+MS (4,4) 12,500.00 90.73 270.16 3,615.62 32.07 -0.01 124.58 -0.01 32.06 0.01 0.03 124.70 41.69 92.79 MWD+IFR2+SAG+MS (4,4) 12,600.00 90.73 270.16 3,614.34 32.31 -0.01 126.37 -0.01 32.30 0.01 0.03 126.49 41.72 92.78 MWD+IFR2+SAG+MS (4.4) 12,677.18 90.73 270.16 3,613.36 32.50 -0.01 127.76 -0.01 32.49 0.01 0.03 127.88 41.74 92.78 MWD+IFR2+SAG+MS (4,4) 12,700.00 91.19 270.16 3,612.97 32.56 -0.01 128.18 -0.01 32.55 0.01 0.03 128.30 41.75 92.77 MWD+IFR2+SAG+MS (4,4) 12,800.00 93.19 270.16 3,609.16 32.84 -0.01 130.00 -0.01 32.80 0.01 0.03 130.13 41.78 92.76 MWD+IFR2+SAG+MS (4,4) 12,840.65 94.00 270.16 3,606.61 32.96 -0.01 130.75 -0.01 32.90 0.01 0.03 130.87 41.80 92.76 MWD+IFR2+SAG+MS (4,4) 12,900.00 95.60 270.16 3,601.64 33.17 -0.01 131.85 -0.01 33.05 0.01 0.03 131.97 41.81 92.75 MWD+IFR2+SAG+MS (4, 4) 12,928.02 96.36 270.16 3,598.72 33.27 -0.01 132.36 -0.01 33.12 0.01 0.03 132.48 41.82 92.74 MWD+IFR2+SAG+MS (4,4) 12,994.54 96.36 270.16 3,591.36 33.44 -0.01 133.60 -0.01 33.29 0.01 0.03 133.72 41.85 92.74 MWD+IFR2+SAG+MS (4,4) 13,000.00 96.21 270.16 3,590.76 33.44 -0.01 133.70 -0.01 33.30 0.01 0.03 133.82 41.85 92.73 MWD+IFR2+SAG+MS (4,4) 13,100.00 93.51 270.16 3,582.28 33.61 -0.01 135.57 -0.01 33.56 0.01 0.03 135.70 41.88 92.72 MWD+IFR2+SAG+MS (4,4) 13,200.00 90.81 270.16 3,578.51 33.83 -0.01 137.48 -0.01 33.83 0.01 0.03 137.60 41.92 92.70 MWD+IFR2+SAG+MS (4,4) 13,211.54 90.50 270.16 3,578.38 33.86 -0.01 137.70 -0.01 33.86 0.01 0.03 137.82 41.92 92.70 MWD+IFR2+SAG+MS (4,4) 13,220.29 90.33 270.16 3,578.32 33.88 -0.01 137.87 -0.01 33.88 0.01 0.03 137.99 41.92 92.70 MWD+IFR2+SAG+MS (4,4) 13,300.00 90.33 270.16 3,577.86 34.10 -0.01 139.40 -0.01 34.10 0.01 0.03 139.52 41.95 92.69 MWD+IFR2+SAG+MS (4,4) 13,400.00 90.33 270.16 3,577.30 34.37 •0.01 141.34 -0.01 34.37 0.01 0.03 141.46 41.99 92.67 MWD+IFR2+SAG+MS (4,4) 13,500.00 90.33 270.16 3,576.73 34.65 -0.01 143.30 -0.01 34.65 0.01 0.03 143.42 42.03 92.65 MWD+IFR2+SAG+MS (4,4) 13,600.00 90.33 270.16 3,576.16 34.93 -0.01 145.27 -0.01 34.93 0.01 0.03 145.39 42.06 92.63 MWD+IFR2+SAG+MS (4,4) 13,700.00 90.33 270.16 3,575.60 35.22 -0.01 147.25 -0.01 35.21 0.01 0.03 147.38 42.10 92.61 MWD+IFR2+SAG+MS (4,4) 13,739.20 90.33 270.16 3,575.37 35.33 -0.01 148.03 -0.01 35.33 0.01 0.03 148.16 42.12 92.60 MWD+IFR2+SAG+MS (4,4) 13,800.00 91.54 270.16 3,574,38 35.52 -0.01 149.25 -0.01 35.50 0.01 0.03 149.37 42.14 92.59 MWD+IFR2+SAG+MS (4,4) 13,817.76 91.90 270.16 3,573.85 35.57 -0.01 149.61 -0.01 35.55 0.01 0.03 149.73 42.15 92.59 MWD+IFR2+SAG+MS (4,4) 13,818.49 91.91 270.16 3,573.83 35.57 -0.01 149.61 -0.01 35.55 0.01 0.03 149.73 42.15 92.59 MWD+IFR2+SAG+MS (4,4) 13,900.00 91.91 270.16 3,571.11 35.81 -0.01 151.26 -0.01 35.79 0.01 0.03 151.39 42.18 92.57 MWD+IFR2+SAG+MS (4,4) 14,000.00 91.91 270.16 3,567.77 36.11 -0.01 153.29 -0.01 36.09 0.01 0.03 153.41 42.22 92.55 MWD+IFR2+SAG+MS (4.4) 5/31/2019 2:44:40PM Page 6 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-111 Wellbore: Plan: 3R-111 Design: 3 R-111 wp04.1 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Pian: 3R-111 Plan: 9.8 + 39.10 @ 48.90usft (Doyonl42) Plan: 9.8 + 39.10 @ 48.90usft (Doyonl42) True Minimum Curvature 2.00 sigma OAKEDMPI Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°{ (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 14,100.00 91.91 270.16 3,564.44 36.40 -0.01 155.32 -0.01 36.39 0.01 0.03 155.45 42.26 92.53 MWD+IFR2+SAG+MS (4,4) 14,200.00 91.91 270.16 3,561.10 36.71 -0.01 157.37 -0.01 36.69 0.01 0.03 157.50 42.30 92.51 MWD+IFR2+SAG+MS (4,4) 14,300.00 91.91 270.16 3,557.77 37.01 -0.01 159.43 -0.01 36.99 0.01 0.03 159.56 42.34 92.49 MWD+IFR2+SAG+MS (4,4) 14,400.00 91.91 270.16 3,554.43 37.32 -0.01 161.50 -0.01 37.30 0.01 0.03 161.63 42.38 92.47 MWD+IFR2+SAG+MS (4,4) 14,500.00 91.91 270.16 3,551.10 37.63 -0.01 163.59 -0.01 37.61 0.01 0.03 163.71 42.42 92.45 MWD+IFR2+SAG+MS (4,4) 14,600.00 91.91 270.16 3,547.76 37.94 -0.01 165.68 -0.01 37.92 0.01 0.03 165.80 42.46 92.43 MWD+IFR2+SAG+MS (4,4) 14,698.24 91.91 270.16 3,544.49 38.25 -0.01 167.74 -0.01 38.23 0.01 0.03 167.87 42.51 92.41 MWD+IFR2+SAG+MS (4,4) 14,700.00 91.88 270.16 3,544.43 38.26 -0.01 167.78 -0.01 38.24 0.01 0.03 167.90 42.51 92.41 MWD+IFR2+SAG+MS (4,4) 14,734.94 91.18 270.16 3,543.50 38.36 -0.01 168.52 -0.01 38.35 0.01 0.03 168.64 42.52 92.40 MWD+IFR2+SAG+MS (4,4) 14,800.00 91.18 270.16 3,542.16 38.57 -0.01 169.89 -0.01 38.56 0.01 0.03 170.01 42.55 92.39 MWD+IFR2+SAG+MS (4,4) 14,900.00 91.18 270.16 3,540.11 38.89 -0.01 172.02 -0.01 38.88 0.01 0.03 172.14 42.59 92.37 MWD+IFR2+SAG+MS (4,4) 15,000.00 91.18 270.16 3,538.06 39.21 -0.01 174.15 -0.01 39.20 0.01 0.03 174.27 42.64 92.35 MWD+IFR2+SAG+MS (4,4) 15,100.00 91.18 270.16 3,536.00 39.54 -0.01 176.29 -0.01 39.53 0.01 0.03 176.40 42.68 92.33 MWD+IFR2+SAG+MS (4,4) 15,200.00 91.18 270.16 3,533.95 39.87 -0.01 178.43 -0.01 39.86 0.01 0.03 178.55 42.73 92.31 MWD+IFR2+SAG+MS (4,4) 15,300.00 91.18 270.16 3,531.89 40.20 -0.01 180.59 -0.01 40.19 0.01 0.03 180.71 42.77 92.29 MWD+IFR2+SAG+MS (4,4) 15,400.00 91.18 270.16 3,529.84 40.54 -0.01 182.75 -0.01 40.53 0.01 0.03 182.87 42.82 92.27 MWD+IFR2+SAG+MS (4,4) 15,500.00 91.18 270.16 3,527.79 40.87 -0.01 184.92 -0.01 40.86 0.01 0.03 185.04 42.86 92.25 MWD+IFR2+SAG+MS (4,4) 15,600.00 91.18 270.16 3,525.73 41.21 -0.01 187.10 -0.01 41.20 0.01 0.03 187.21 42.91 92.23 MWD+IFR2+SAG+MS (4,4) 15,700.00 91.18 270.16 3,523.68 41.55 -0.01 189.28 -0.01 41.54 0.01 0.03 189.40 42.96 92.21 MWD+IFR2+SAG+MS (4,4) 15,800.00 91.18 270.16 3,521.62 41.90 -0.01 191.47 -0.01 41.88 0.01 0.03 191.59 43.00 92.19 MWD+IFR2+SAG+MS (4,4) 15,900.00 91.18 270.16 3,519.57 42.24 -0.01 193.67 -0.01 42.23 0.01 0.03 193.78 43.05 92.17 MWD+IFR2+SAG+MS (4,4) 15,918.00 91.18 270.16 3,519.20 42.30 -0.01 194.07 -0.01 42.29 0.01 0.03 194.18 43.06 92.17 MWD+IFR2+SAG+MS (4,4) 15,918.01 91.18 270.16 3,519.20 42.30 -0.01 194.07 -0.01 42.29 0.01 0.03 194.18 43.06 92.17 MWD+IFR2+SAG+MS (4,4) 5/31/2019 2:44:40PM Page 7 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well Plan: 3R-111 Project: Kuparuk River Unit -2 TVD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Well: Plan: 3R-111 North Reference: True Wellbore: Plan: 3R-111 Survey Calculation Method: Minimum Curvature Design: 3R-111wp04.1 Output errors are at 2.00 sigma Database: OAKEDMPI Design Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting Shape (1 (1) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 3R-111 T11 042619 AV 0.00 0.00 3,519.20 3,571.92 -6,624.78 6,034,920.00 1,654,064.34 70° 30'25.173 N 149° 53' 18.017 W - plan hits target center - Circle (radius 100.00) 3R-111 T10 042619 AV 0.00 0.00 3,543.50 3,568.69 -5,441.96 6,034,920.00 1,655,247.04 70° 30' 25.151 N 1490 52'43.181 W - plan hits target center - Circle (radius 100.00) 3R-111 T09 042619 AV 0.00 0.00 3,573.85 3,566.19 -4,525.29 6,034,920.00 1,656,163.63 70° 30'25.133 N 149° 52' 16.184 W - plan hits target center - Circle (radius 100.00) 3R-111 T08 042619 AV 0.00 0.00 3,578.38 3,564.54 -3,919.10 6,034,920.00 1,656,769.76 70° 30'25.120 N 149° 51' 58.330 W - plan hits target center - Circle (radius 100.00) 3R-111 T07 042619 AV 0.00 0.00 3,606.61 3,563.53 -3,549.46 6,034,920.00 1,657,139.36 70° 30'25.112 N 149° 51'47.444 W - plan hits target center - Circle (radius 100.00) 3R-111 T06042619 AV 0.00 0.00 3,621.11 3,561.43 -2,780.64 6,034,920.00 1,657,908.11 70° 30'25.094 N 149° 51' 24.801 W - plan hits target center - Circle (radius 100.00) 3R-111 T01 WSD 05211 0.00 0.00 3,633.90 3,537.76 1,024.01 6,034,906.71 1,661,712.43 70° 30'24.866 N 149° 49' 32.749 W plan hits target center Circle (radius 100.00) 3R-111 T05 042619 AV 0.00 0.00 3,634.25 3,560.70 -2,514.50 6,034,920.00 1,658,174.22 70° 30' 25.088 N 149° 51' 16.963 W plan hits target center Circle (radius 100.00) 3R-111 T03 042619 AV 0.00 0.00 3,649.39 3,557.07 -1,183.85 6,034,920.00 1,659,504.75 70° 30'25.056 N 149° 50'37.773 W - plan hits target center - Circle (radius 100.00) 3R-111 T04 042619 AV 0.00 0.00 3,663.55 3,558.16 -1,583.04 6,034,920.00 1,659,105.59 70° 30'25.066 N 149° 50'49.530 W - plan hits target center - Circle (radius 100.00) 313-111 T02 Heel 05211£ 0.00 0.00 3,666.72 3,542.58 467.38 6,034,910.01 1,661,155.85 70° 30'24.914 N 149° 49' 49.142 W - plan hits target center - Circle (radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 118.00 118.00 20" x 42" 20.000 42.000 2,502.21 2,198.90 13 3/8" x 16" 13.375 16.000 8,822.00 3,666.72 9 5/8" x 12-1/4" 9.625 12.250 15,918.00 3,519.20 4-1/2" x 6-3/4" 4.500 6.750 5/31/2019 2:44:40PM Page 8 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well Plan: 3R-111 Project: Kuparuk River Unit -2 +N/ -S TVD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Site: Kuparuk 3R Pad (usft) MD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Well: Plan: 3R-111 0.00 North Reference: True Wellbore: Plan: 3R-111 1.08 Survey Calculation Method: Minimum Curvature Design: 3R-111wp04.1 187.20 Output errors are at 2.00 sigma 1,887.08 1,768.90 218.11 Database: OAKEDMPI Formations 2,198.90 402.43 863.02 Hold for 20' 2,522.21 Measured Vertical 409.33 877.81 Dip 3,218.70 Depth Depth 691.00 1,454.50 Dip Direction 3,999.90 (usft) (usft) Name Lithology (1 (1) 7,764.29 1,778.97 1,681.64 T3 1,523.12 0.00 8,264.29 1,847.31 1,736.80 pfrost 1,024.01 0.00 8,414.29 2,159.70 1,976.74 K15 874.27 0.00 8,453.24 5,407.05 2,947.43 UGNU_C 835.42 0.00 8,648.10 6,094.25 3,203.88 UGNU_B 641.13 0.00 8,822.02 6,411.24 3,315.49 UGNU_A 467.38 0.00 8,863.81 6,848.34 3,448.83 TOP N SAND 425.60 0.00 10,280.88 8,328.86 3,637.70 WSD -991.26 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 260.00 260.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 65° TF, for 140' 400.00 399.97 1.08 2.32 Start 2.5°/100' DLS, 0° TF, for 1363.19' 1,763.19 1,668.90 187.20 401.46 Hold for 123.89' 1,887.08 1,768.90 218.11 467.74 Start 3°/100' DLS, 0° TF, for 615.13' 2,502.21 2,198.90 402.43 863.02 Hold for 20' 2,522.21 2,210.48 409.33 877.81 Start 4°/100' DLS, -3.99° TF, for 696.49' 3,218.70 2,462.85 691.00 1,454.50 Hold for 781.2' 3,999.90 2,565.63 1,041.15 2,145.24 Start 4°/100' DLS, -110.87° TF, for 3764.4' 7,764.29 3,604.47 3,533.44 1,523.12 Hold for 500' 8,264.29 3,633.90 3,537.76 1,024.01 Adjust TF to 0°, for 150' 8,414.29 3,642.73 3,539.05 874.27 Start 2.5°/100' DLS, -179.88° TF, for 38.95' 8,453.24 3,645.35 3,539.39 835.42 Hold for 194.85' 8,648.10 3,660.12 3,541.06 641.13 Start 2.5°/100' DLS, 0.12° TF, for 173.92' 8,822.02 3,666.72 3,542.58 467.38 Start 2°/100' DLS, 1.49° TF, for 41.79' 8,863.81 3,666.42 3,542.95 425.60 Hold for 1417.07' 10,280.88 3,645.75 3,555.93 -991.26 Start 2°/100' DLS, -174.52° TF, for 192.66' 10,473.53 3,649.39 3,557.07 -1,183.85 Start 2.2°/100' DLS, -180° TF, for 45.68' 10,519.22 3,652.18 3,557.20 -1,229.44 Hold for 90.12' 10,609.34 3,658.48 3,557.44 -1,319.34 Start 2.2°/100' DLS, 0° TF, for 263.86' 10,873.20 3,663.55 3,558.16 -1,583.04 Start 2°/100' DLS, 180° TF, for 1.33' 10,874.53 3,663.51 3,558.17 -1,584.37 Hold for 879.27' 11,753.80 3,636.30 3,560.56 -2,463.22 Start 2°/100' DLS, 0° TF, for 51.33' 11,805.13 3,634.25 3,560.70 -2,514.50 Adjust TF to 00, for 30.08' 11,835.21 3,632.62 3,560.79 -2,544.54 Hold for 116.32' 11,951.53 3,625.72 3,561.10 -2,660.66 Start 2°/100' DLS, -180° TF, for 120.08' 12,071.61 3,621.11 3,561.43 -2,780.64 Adjust TF to 180°, for 13.46' 12,085.08 3,620.91 3,561.47 -2,794.10 Hold for 592.11' 12,677.18 3,613.36 3,563.08 -3,386.16 Start 2°/100' DLS, 0° TF, for 163.46' 12,840.65 3,606.61 3,563.53 -3,549.46 Start 2.7°/100' DLS, 0° TF, for 87.37' 12,928.02 3,598.72 3,563.77 -3,636.47 Hold for 66.53' 12,994.54 3,591.36 3,563.95 -3,702.58 Start 2.7°/100' DLS, -180° TF, for 217' 13,211.54 3,578.38 3,564.54 -3,919.10 Start 2°/100' DLS, -180° TF, for 8.75' 13,220.29 3,578.32 3,564.56 -3,927.84 Hold for 518.91' 13,739.20 3,575.37 3,565.98 -4,446.74 Start 2°/100' DLS, 0° TF, for 78.56' 13,817.76 3,573.85 3,566.19 -4,525.29 Adjust TF to 0°, for 0.73' 13,818.49 3,573.83 3,566.19 -4,526.02 Hold for 879.75' 14,698.24 3,544.49 3,568.59 -5,405.28 Start 2°/100' DLS, -180° TF, for 36.7' 14,734.94 3,543.50 3,568.69 -5,441.96 Hold for 1183.07' 15,918.01 3,519.20 3,571.92 -6,624.78 TD: 15918.01' MD, 3519.2' TVD 5/31/2019 2:44:40PM Page 9 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc—Kuparuk Local Co-ordinate Reference: Well Plan3R-111 Project: Kuparuk River Unit -2 ND Reference: Plan 9.8 + 39.10 @ 48.90usft (Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan: 9.8 + 39.10 @ 48.90usft (Doyon142) Well: Plan: 3R-111 North Reference: True Wellbore: Plan: 3R-111 Survey Calculation Method: Minimum Curvature Design: 3R-111wp04.1 Output errors are at 2.00 sigma Database: OAKEDMPI Checked By: Approved By: Date: 5/31/2019 2:44:40PM Page 10 COMPASS 5000.14 Build 85D Pool Report oa�00000aoo �;,0000000000a 2 H 2,2 ��vmoi vo °"r'amm� > mmmmmv'�i .n �n nm�n 2 O mm m� a Naaaaaaaaa�a o=mmo�mm��d� NdNNNNNNNN�, 3io'o'o'o'o'o oo$=o E^ 2�nn.�3�nno�inMnnn K M O O LO ti O O O O O O O O O O LO Ln O `-) (ui/}jsn 009Z) (+MJON/(-MnoSl� Ln O 0 LO [I-- O O O LO O O LO N i i = i O U O O + L N N 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Y: 1 6031614.46616772 i ............................................................ .Transform Quit Help 3R-11lwp04.1 Surface Casing l CPAI Coordinate Converter — ❑ X From: - — — To: -- Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska -.-3 C Latitude/Longitude Decimal Degrees r Latitude/Longitude IDecimal Degrees UTM Zone:— r South r UTM Zone: True r South re State Plane Zone:14 +j Units: us fk + State Plane Zone:4 Units: us ft D- r Legal Description (NAD27 only) r Legal Description (NAD27 only) i Starting Coordinates: - - Ending Coordinates: -- X: 11661560.02 X: 521528.658220982 Y: 6031771.27 Y: 6032019.18414224 ...................... .Transform Quit Help 3R-111wp04.1 Intermediate Casing L CPAI Coordinate Converter - ❑ X From: - -- To: Datum: INAD63 I Region: jalaska + Datum: NAD27 Region: alaska Latitude/Longitude Decimal Degrees i LatitudelLongitude IDecimal Degrees dam` UTM Zone: jj South t" UTM Zone: True South State Plane Zone:4 + Units: us fk t+ State Plane Zone: 4 + Units: ju,ft r Legal Description (NAD27 only) j Legal Description (NAD27 only) Starting Coordinates -- - --- - Ending Coordinates: -- - -- - X: 11661155.87 r X: 1521124.566871237 Y: 19034910.01 Y: 1 965E1 57 89934363 ................... ........................................ Transform Quik Help 3R-11lwp04.1 Top of Production Horizon 4 CPA[ Coordinate Converter - ❑ X -From: ---- - - -- -- To: Datum: NAD83 + Region: alaska Datum: NAD27 + Region: alaska + r Latitude/Longitude Decimal Degrees r Latitude/Longitude Decimal Degrees + (- UTM Zone: r- South (- UTM Zone: True f South C+ Skate Plane Zone: 4 + Units: us fk + C* State Plane Zone: 4 + Units: us—ft + t" Legal Description (NAD27 only) r Legal Description (NAD27 only) i Starting Coordinates: - --__ ---- Ending Coordinates: — - --- - ---- X: 11661647.99 ` X: 521616.70432201 Y: 16034907.09 Y:6035154.9644353 Transform Quit Help 3R-111 wp04.1 TD F CP -41 Coordinate Converter — ❑ x From: - ___ __. To: Datum: Npp53 Region: alaskaDatum: NgD27 Region: alaska f ` Latitude/Longitude Decimal Degrees 1 Latitude/Longitude Decimal Degrees UTM Zone: II— South UTM Zone: True r South State Plane Zone: 14 1 Units: u -s ft , r;'+ State Plane Zone: 4 Units: us ft -11 i` Legal Description (NAD27 only) { Legal Description (NAD27 only) Starting Coordinates: - - — Ending Coordinates: ----- ---- X: 11654064.34 X: 514032.87621754 Y: 16034920 Y: 6035168.0826171 ........................................................... Transform Quit Help 3R-111w 04.1 Surface Location CPAI Coordinate Converter - ❑ X F From: -- - - _ - - -- -- - — -- - To: - ---. — Datum: NAD83 t Region: alaska Datum: NAD27 Region: alaska " Latitude/Longitude Decimal Degrees Latitude/Longitude IDecimal Degrees --- r UTM Zone: �— (- South t` UTM Zone: True f South State Plane Zone: 4 Units: fus-ft -_-1 Skate Plane Zone: 4 Units: us fk r Legal D es cription NAD 27 only) r Legal Description (NAD27 only) Starting Coordinates: - Legal Description Y,: 1660698.18 Township: 013 N , Range: 009 E + Y: IG0313GG.52 Meridian: U T Section:.. FNL 1748.2984 FEL � 2919.0663 .......................................................... ...........Transform.................: Quit Help 3R-111wp04.1 Surface Casing CPAI Coordinate Converter - ❑ x From: _- _..__ __.-___ _.... _------- - To..d_. ___ __ _.-.. ._�_ -_ __.---- ...--- _ Datum: NAD83 Region: alaska Datum NAD27 Region: alaska r Latitude/Longitude Decimal Degrees r Latitude/Longitude IDecimalDegrees r UTM Zone: f— South (' UTM Zone: True r- South a: State Plane Zone: 14 1 Units: Fu-,-f-t---,-1 f State Plane Zone: 4 Units: us ft i" Legal De>cription (NAD2'7 onty) Legal Description (NAD27 only) Starting Coordinates: - - - — - X: 1661560.02 Legal Description ----------__---_-----__-----__----- ---_-- _ __---_.._-- Township: 013 N . Range: 009 E Y: 16031771.27 Meridian: Section:fg FNL 1345.9916 FEL 2054.9681 ........................................................... Transform Quit Help 3R-111wp04.1 Intermediate Casing__ M CPAI Coordinate Converter - From: - — Datum: NAD83 Region: alaska .j r Latitude/Longitude IDecimalDegrees r UTM Zone: — i South t* Skate Plane Zone: q T Units: us -ft w r Legal Description (rJAD27 onlyj Starting Coordinates: X: 11661155.87 Y: 16034910.01 -To: — ❑ X Datum: NAD27 Region: alaska ` Latitude/Longitude IDecimalDegrees r UTM Zone: True r South r Stake Plane Zone: q Units: us -it (-- Legal Description (NAD27 only) Township: 013 FN ---;l -Range: 009 E Meridian: U Section:�— FN -L --,-,l 3485.4014 FEL � 2442.4435 .Transform Quik Help I 3R-11lwPO4.1 Top of Production Horizon I M CPAI Coordinate Converter Datum: Ngpg3 Region: alaska -_! Latitude/Longitude IDecimal Degrees r UTM Zone: — r- South t+ State Plane Zone: q w Units: us -ft r Legal Description (NAD27 only) Starting Coordinates: — X: 11661647.99 Y: 16034907.09 — ❑ X - To: ----- -.. ----- _ ------ ----- .--. Datum: NAD27 J Region: alaska Latitude/Longitude IDecimal Degrees �+ r UTM Zone: True South r State Plane Zone: q � Units: us ft C� Legal Description (NAD27 only) - Legal Description------------ Township: escription- Township: 013 FN ---,l Range: 009 E Meridian: U Section: FFNL—wl 13489.7423 FEL � 1950.2844 Transform Quit Help 3R-111wp04.1 TD I CPAI Coordinate Converter — ❑ X Datum: NAD83 Region: alaska r Latitude/Longitude Decimal Degrees r UTM Zone: �! F South r+ State Plane Zone:4 Units: us ft 71 r Legal Description ,NAD27 only) Starting Coordinates: X: 11654064.34 Y: 1TEZ20 T Datum: NAD27 Region: alaska LatitudelLongitudeecimal Degrees _� t" UTM Zone: True r South I r State Plane Zone: F-----3 Units: us ft r: Legal Description [NAD27 only] -Legal Description -- - -- -- Township: 013 N I Range: 1009 E Meridian: U T Section:— FNL -1 3458.4328 FEL - 4254.7073 Transform Quit Help As -built 3 15/5/11 CC I JLS I jUpdated Per K190005ACS 12 112/18/1 JAH I JFC I I PER K160005ACS NOTES: T14NR9L NOC � " 13NR9E ! STP S 4 1. BASIS OF LOCATION AND ELEVATION IS DS3R MONUMENTATION PER LOUNSBURY & ASSOC. Q 16 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, PROJECT ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES aPP LOCATION ARE N.A.D. 27. ! i 3. ELEVATIONS ARE B.P.M.S.L. VICINITY MAP x 5 4 RE 0CATED T�ECTAON DEW LINE - W - - - 7 8 1064 PROTRACTEDALL 9RS TOWNSHIP 1I3 NORTH $ : 107 4 RANGE 9 EAST, UMIAT MERIDIAN, ALASKA. No � 111 3R 5. DATES OF SURVEY: 5/03/19 — 5/05/19. 7 c� r 6. ALL DISTANCES SHOWN ARE GROUND. 8 • 26 (�r _ c t! n / GRAPHIC SCALE 0 75 150 300 �j 1 inch = 150 ft. LOUNSBURY SEE SHEET 2 AND 3 FOR LOCATION INFORMATION0� 0s' oc aTEs, INC. SiIRVEY0R5 ENGINEERS PLANNERS AREA: 313 MODULE: XXXX UNIT: D3 ConocoPhillips DS3R WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CALK6318d18 12/29/09 DRAWING No. CEA—D3RX-6318D18 PART: 1 OF 3 REV: 3 NOC � " S 4 (�.e 18 Q 16 17 VICINITY MAP x 5 101 'j 6 1"= 1 MILE 102 '` 105 7 8 1064 9 : 107 4 10 11 No � 111 12 c� 1120 Q • 26 • 14 • 15 • 25 • 17 • 18 • 19 LEGEND • 20 • 21 • EXISTING CONDUCTOR LOCATION • 22 O AS—BUILT CONDUCTOR LOCATION k PLUGGED AND ABANDONED / GRAPHIC SCALE 0 75 150 300 �j 1 inch = 150 ft. LOUNSBURY SEE SHEET 2 AND 3 FOR LOCATION INFORMATION0� 0s' oc aTEs, INC. SiIRVEY0R5 ENGINEERS PLANNERS AREA: 313 MODULE: XXXX UNIT: D3 ConocoPhillips DS3R WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CALK6318d18 12/29/09 DRAWING No. CEA—D3RX-6318D18 PART: 1 OF 3 REV: 3 1 15/5/191 CC I JLS I IPER K190005ACS I I I I I I i CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 9. T. 13 N.. R. 9 E.. UMIAT MERDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geographic Coordinates Section Offset. Elev. Y X Lat. Long. F.N.L F.W.L O.G. PAD *105 6031685.03 520642.40 70' 29' 51.808" 149' 49' 52.295" 1678' 2337' 4.8' 9.8' *106 6031666.09 520649.00 70' 29' 51.621 " 149' 49' 52.102" 1697' 2343' 4.9' 9.8' *107 6031633.15 520660.18 70' 29' 51.297" 149' 49' 51.776" 1730' 2354' 5.0' 9.8' *111 6031614.47 520666.78 70' 29' 51.113" 149' 49' 51.583" 1749' 2361' 5.1' 9.8' *112 6031581.19 520678.16 70' 29' 50.785" 149' 49' 51.251" 1782' 2372' 5.2' 9.8' * CONDUCTOR ASBUILT THIS SURVEY OF -44 to •C �`'•• 49th ............. --f- :.......A... Ie ........ .................................... ZIAH F. CORNELL.- LS -12663 JAZ_ •..,, ;9,..•,,.•• o"A.. �ROFESSIONAL�♦♦ SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT i AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF MAY 5, 2019. LOUNSBURY o & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: 3R MODULE: XXXX UNIT: D3 ConocoPhillips DS3R WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE N0. DRAWING NO. PART: REV: LK6318d18 12/29/09 1 CEA-D3RX-6318D18 1 3 OF 3 1 Appendix M L- 0 O N i N H L 0 O O c N a) N .N d -J O t Ul M L -J C: a- c O E N Q 4 E N — N +� O QJ -O � 4- � c ra U i U o � � � � - 4- C� C N E N N ra O to Q c N i 4J -0 O O _ u Uro O Q c _ CU N ru a� C O .N O U N to N N Q Q tab O t a J O Ln O c co Q = = N U C 4- Ln O }, 4 ru N Q) 4- N O O N0A c N J O U w O O aJ ro N �C L O � U qA c L � 0 c N p �+ C U u co c •Ln E cu f0 N N L LJ D LL ■ L Q m 0 L fB a N 4- C� U a Qj = CD � Q) � L � L o oN +J a) N f0 Q) O L Ln 4 a, c o U N Q }, e — N Q) U f0 a0 O L Z 0 U N (D � 0 0 ate-+ Q1 N -a c) O L N F� Q U W/, O cz U m i C) c� 4-1N O_ «i a -J 86 E bIJ M Q6 � N L v_ F-- U N d O i U N ■ a) t a 4 +� � O N O L � N > L 4- O � U Y 4- 'L L U Q U 4� a--+ Vf L O U m 'U Q) cr m a) _ _ L _ pi > two 4- L 0 O t N m M U N a s 4-+ L 3 N U U V 0 +' N O C M ++ o O co N O�. U (Q v +++ •- E [B v N O m i O > =5O 0 0- s -0 a GJ Q) �+- N Q) CL Q) M L CT i) �O U Q) w U -u U O i o CA O N >` > Q (D D o m Y s N U 4- u N +� Qj f0 m O O 0 L O y � i c� `~ v O C 4 -J C c Q c� 4-1N O_ «i a -J 86 E bIJ M Q6 � N L v_ F-- U N d O i U N ■ Attachment 2: Drilling Hazards Summary 16" Oven Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low Reduced pump rates, Reduced drilling fluid temperatures, Additions of ScreenKleen Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Washouts / Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible Anti -Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with, gyro survey to ensure survey accuracy. 12-1/4" Oven Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight. Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out. Anti -Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with, real-time survey corrections. 6-3/4" Oven Hole / 4-1/2" Liner Intervals Hazard Risk Level Mitigation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight if possible if pipe does get stuck. Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. Differential Sticking Moderate Follow mud program, keep pipe moving when able. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or backreamin . Fault Crossings and Concretions Moderate Use developed best practices for concretion drilling. Anti -Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with. Utilize periscope to maintain geological certainty to stay within zone. Casing wear Moderate Maintain low dog legs in the surface interval and utilize super sliders for drilling, milling, and liner running operations to minimize casing wear. Getting Liner to Bottom Moderate Properly clean hole on the trip out with the BHA, perform clean out run if necessary, utilize super sliders for weight transfer, monitor torque and drag, utilize lubes. Whipstock Retrieval Moderate A dedicated clean out run prior to attempting to pull whipstock can be used to reduce the risk of fishing operations. t � , M M � ; �o O r � U ' x at CStn ; z 3 ; 1 U 7 M N G N G o > a 3 ,! v E a > 5 , v E a G ) a 3 o N > > q� x >cn U � R q N N v th N m 45 �' 00 00 N � � � � N � 1✓P' I O a v O l `° F o a 9 h u 0 oz � z � 1 t U 4 en ________• d a q v 7 V L. ConocoPhillips 311-111 OHSAS Prod 3R-111S-henmti—ith SW-,vpl.,,sd T 1,nmr 7161 19 Alaska Attachment 4: BOP Configuration The following ram configuration will be utilized for the West Sak wells. Further details regarding the BOPE specifications can be found with the Doyon 142 documentation on file with the State. Loepp, Victoria T (CED) From: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Sent: Thursday, August 8, 2019 4:27 PM To: Loepp, Victoria T (CED); Buck, Brian R; Tolman, Ben V Subject: RE: [EXTERNAL]KRU 3R-111 and 3S/NUNA Completions: Regulation Requirements: SSSVs; No -flow test Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you for your email. I wanted to confirm that this is how we plan to proceed for 3R-111. Please let us know if you need any other information. Sandeep Pedam Completions Engineer ConocoPhillips Alaska Office: 907.263.4724 Cell: 512.507.9537 Email: Sandeep.Pedam@Conocophillips.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, August 8, 2019 10:50 AM To: Buck, Brian R <Brian.R.Buck@conocophillips.com>; Pedam, Sandeep <Sandeep.Pedam@conocophillips.com>; Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Subject: [EXTERNAL]KRU 311-111 and 3S/NUNA Completions: Regulation Requirements: SSSVs; No -flow test I am currently holding this PTD(3R-111 and 3R-1111-1) while we discuss this issue. From: Buck, Brian R <Brian.R.Buck@conocophillips.com> Sent: Wednesday, August 7, 2019 1:51 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Cc: Regg, James B (CED) <iim.regg@alaska.gov> Subject: RE: [EXTERNAL]KRU 311-111 and 3S/NUNA Completions: Regulation Requirements: SSSVs; No -flow test Thanks for the note Victoria and for the conversation today. We'll confirm with a couple other groups and get back to you shortly. Thank you, Brian Buck Completions Engineering Supervisor office: 907-265-6826, cell: 907-223-6320, fax: 918-662-6213; 700 G St., ATO -1558; Anchorage, AK 99501 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, August 7, 2019 1:37 PM To: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com>; Buck, Brian R <Brian.R.Buck@conocophillips.com> Cc: Regg, James B (CED) <iim.regg@alaska.gov> Subject: [EXTERNAL)KRU 311-111 and 3S/NUNA Completions: Regulation Requirements: SSSVs; No -flow test Sandeep, Brian, In our conversation today you mentioned that CPAI would perform a no -flow test after KRU 311-111 was brought on production. If a no -flow test is conducted and the well passes, a SSSV will not be required in the well. 1. Reference AOGCC Guidance Bulletin 10-004 2. Up to a 30 day production period is acceptable prior to the no -flow test for this well 3. The no -flow test must be conducted within 30 days 4. A procedure must be submitted for AOGCC approval at least two weeks in advance. 5. CPAI must demonstrate that offset injectors have not been shut in prior to the no -flow test. That is provide a list of offset injectors with status and injection history for the past 6 months. 6. Should conditions change, such as increased reservoir pressure due to water injection, an updated no -flow test may be required. Let me know if this is how you plan to proceed for KRU 311-111. 1 am reviewing the PTD at this time. 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. LoeppCa)alaska. gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.aov From: Loepp, Victoria T (CED) Sent: Wednesday, August 7, 2019 7:54 AM To: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Subject: KRU 3R-111 and 3S/NUNA Completions: Regulation Requirements: SSSVs Sandeep, Wanted to touch bases with you on this email and make sure you had received it. 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. LoeppQ)alaska.gov CONFIDENTIALLY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepg4alaska.aov From: Loepp, Victoria T (CED) Sent: Tuesday, July 30, 2019 2:35 PM To: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Cc: Regg, James B (CED) <iim.regg@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: KRU 311-111 and 3S/NUNA Completions: Regulation Requirements Sandeep, In reviewing the proposed completions for 311-111 and 3S Torok producers the following is required: 311-111 1. Provide the control process flow or P&ID for the SVS system. Specifically for the closing of the actuated valve on the IA prior to the recombination of the gas with produced fluids 2. Demonstrate the equivalence of the proposed deep-set operable valve to a SSSV. 3. The deep set operable valve would require a performance test every 6 months like a typical SSSV. 4. The SSSV or deep set operable valve would be required during ESP operation as well as gas lift operation. 5. If equivalence between the deep set operable valve and a SSSV cannot be demonstrated prior to running the completion or in a subsequent performance test(every 6 months), then a SSSV meeting regulations would be required for the well to remain on production. 6. Since the well will be equipped with a regulation SSSV or equivalent, a no -flow test is not required. 7. Explain why a typical SSSV or WRDP cannot be run. 3S Torok Producers The completion proposed is acceptable providing none of these wells are located in a location where a SSSV is required. A no -flow test is not required. Provide the control process flow or P&ID for the SVS system. Specifically for the closing of the actuated valve on the IA prior to the recombination of the gas with produced fluids. 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. Loepp(c alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Sent: Tuesday, July 30, 2019 10:03 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: Buck, Brian R <Brian.R.Buck@conocophillips.com>; Senden, R. Tyler <R.TVIer.Senden@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophilIips.com>; Valentine, Doug K <Doug.K.Valentine@conocophillips.com>; Aleshire, Lynn <Lynn.Aleshire@conocophillips.com>; Livingston, Erica J <Erica.J. Livingston @conocophillips.com>; Pessetto, Scott T <Scott.T. Pessetto@conocophillips.com> Subject: RE: 311-111 and 3S/NUNA Completions Victoria, Following up on your request last week, I've included a drawing of the Skimpy panel and a testing procedure for ESP lifted oil wells. The Skimpy Details.pdf shows both the SSV and SSSV are on the same panel. This panel contains pilot switches for both SSV and SSSV that trip when either high or low pressures are exceeded. We are able to shut ESPs remotely. Also, the attachment is for a 5000 psi option but if we needed a higher pressure SSSV, we would just upgrade the accumulator and gauges on the same panel to 6000 psi. Testing procedure is as follows: 311-111 Planned Procedure: Deep -operable valve with ESP in the well: • Performance test (every 6 months) for the SSV o Trip device (pressure switch and solenoid) • Function test SSV anytime the well is shut-in o To ensure pilot will trip and close SSSV with the well on back-up gas lift: • Performance test (every 6 months) for the SSV and the SSSV o Trip device (pressure switch and solenoid) • Function test SSV and SSSV anytime the well is shut-in o To ensure pilot will trip and close Please let us know if you need any additional information. Regards, Sandeep Pedam Completions Engineer ConocoPhillips Alaska Office: 907.263.4724 Cell: 512.507.9537 Email: Sandeep.Pedam@Conocophillips.com From: Pedam, Sandeep Sent: Monday, July 15, 2019 9:58 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Cc: Pessetto, Scott T <Scott.T.Pessetto@conocophillips.com>; Buck, Brian R <Brian.R.Buck@conocophillips.com>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Valentine, Doug K <Doug.K.Valentine@conocophillips.com>; Aleshire, Lynn <Lynn.Aleshire@conocophillips.com>; Livingston, Erica 1 <Erica.J.Livingston @conocophillips.com> Subject: 3R-111 and 3S/NUNA Completions Victoria/Mel, Thank you for taking the time to meet with us this morning. Attached is our planned completions setup for 311-111 and 3S/NUNA wells and we would appreciate your acknowledgement and/or comments on the same. Please see details below: For 3R -111, our setup is as follows: • Tubing with sliding sleeve and deep operable valve stung into liner top packer (20 AAC 25.200 (d)) • Sliding sleeve run closed on rig will allow us to test the tubing seals on rig • During production, the sleeve will be open. This is to allow flow up the annulus prior to flow being directed into the ESP pump intake. Any free gas would be vented up the IA through the gas discharge sleeve in the ESP. • This is because ESP efficiency is severely impacted if free gas is run through the pump stages, causing both pump damage and impacting well production rates • Should we need to isolate the IA, we have two options: • We would operate the deep operable valve to help isolate the well from flow via the deep operable valve in the tubing and the liner top packer. • In the event the valve fails, we would plan to pull the Access ESP jewelry and either set a plug below the sleeve or close the sliding sleeve itself. • Because 311 is within 660' of navigable waters, we plan to install a deep-set operable valve in the event our ESP fails, and we need to switch artificial lift to backup gas lift. (20 AAC 25.265 (d) (2) (F) as 20 AAC 25.265 (d) (4) would no longer apply). • When we go to backup GL after pulling the Access ESP, we will treat it as an SSSV. • For any well control event, we would plan to bullhead down the IA/tubing no matter the completion type. For 3S/NUNA wells, our setup is as follows: • No SSSV is needed given that these wells are outside the 660' radius for shoreline or navigable waters. (20 AAC 25.265 (d) (2) (F) or (H) • Tubing will be stung into a liner top packer and/or anchored with a tubing packer. (20 AAC 25.200 (d)) • Tubing will include rigless ESP set up with a sliding sleeve below the ESP. • Sliding sleeve run closed on rig will allow us to test the tubing seals on rig • During production, the sleeve will be open. This is to allow flow up the annulus prior to flow being directed into the ESP pump intake. Any free gas would be vented up the IA through the gas discharge sleeve in the ESP. • This is because ESP efficiency is severely impacted if free gas is run through the pump stages, causing both pump damage and impacting well production rates • Should we need to isolate the IA — we would plan to pull the Access ESP jewelry and either set a plug below the sleeve or close the sliding sleeve itself. • For any well control event, we would plan to bullhead down the IA/tubing no matter the completion type. This setup would be very similar to Access ESPs we have run in 1J-120, 1J-137, 1C-153, 1D-145. All of these wells have tubing stung into a liner top packer with a sliding sleeve open above. For both wells, we would like to clarify that our setup is consistent with current AOGCC regulations. Our understanding is that we have tubing x IA isolation, given that the tubing is stung into the liner top packer in both 311-111 and 3S/NUNA wells. The sliding sleeve will be open during ESP production, but can be closed in the event that we need to have isolation between tubing and annulus. Open sliding sleeve installations could be considered similar to jet pump completions. Our first well is 311-111 and is currently slated to spud —Sep 1, 2019. 3S wells are slated to spud—Q12020. Concurrence with this plan that we have designed to meet the proximity to shoreline/navigable water requirements is appreciated. Thank -you and we appreciate the time. Sandeep Pedam Completions Engineer ConocoPhillips Alaska Office: 907.263.4724 Cell: 512.507.9537 Email: Sandeep.Pedam@Conocophillips.com Sandeep Pedam Completions Engineer ConocoPhillips Alaska Office: 907.263.4724 Cell: 512.507.9537 Email: Sandeep.Pedam@Conocophillips.com TRANSMITTAL LETTER CHECKLIST WELL NAME: P'__!t / / / PTD: 19 IL) V Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: 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- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well 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 order approving a spacing exception. (Company Name) Operator 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, WEST SAK OIL - 490150 Well Name: KUPARUK RIV UNIT 3R-111 Program DEV_ Well bore seg nc. PTD#: 2191040 Company ConocoPhillips Alaska, IInitial Class/Type DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 1 Permit fee attached- - NA_ -- - 2 Lease number appropriate- - - - - - - - - - - Yes - - - - Surf Loc & Top Prod Int lie in_A_DL0355023; Portion -of Productive Interval -lies in ADL0373301; 3 Unique well_n_ame and number - - - - - - - - - - - - Yes - - - - - TD lies in ADL0355024-- - _ - - - - - - - - - - - - - - 4 Well located in -a- deiinedpool - . - - - - - Yes Kuparuk River, W_est_Sak Oil Pool - 490150, governed by CO 4060 - - - _ - _ . . 5 Well located proper distance from drilling unit boundary ---------------- Yes - - - - - - - CO 4060, Rule 3; no- restrictions_as to well -spacing -except that no pay shall be opened -in a well closer 6 Well located proper distance from other wells_ - - - - - Yes - - - - - - - than 500 feet to_an external_property line where ownership. or landownership changes. - - - - - - - - - - _ 7 Sufficient acreage available in_drilling unit - - - - - - - - - - - - - - Yes - - - - - - - As planned, well conforms to spacing requirements. - - - - - - - - 8 -if-deviated, is wellbore plat-inc-luded - - - Yes 9 Operator only affected party - - - - Yes - - . 10 Operator has -appropriate_ bond in force - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - . - . - - . - - - - - - 11 Permit_can be issued without conservation order_ . _ Yes _ --------------------------------------------------------- Appr Date 12 Permit can be issued without administrative -approval - - - - - - - - - - - - - - - - - - - - - - Yes . - - . - - - - - - - - - - 13 Can permit be approved before 15 -day wait_ - - Yes- SFD 7/19/2019 _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - _ _ - - - - - - - - . 14 Well located within area and -strata authorized by Injection Order # (put_10# in_ comments)_(For_ NA_ - - - - - - - - - - _ - - . 15 All wells_within -114-mite-area-of review identified (For service well only) - - - - NA_ ------------------------------------------------ 16 Pre -produced injector; duration of pre production less than 3 months_ (For service well only) NA_ - - - - - - - - - - _ . - - _ - -- 17 Nonconven. gas conforms to AS31.05.030Q.1_.A),0.2_.A-D) - - - - - _ - - - - - - - - NA_ ---------------------------- 18 Conductor string -provided - - - - - _ - - - - - - - - - - - - - - Yes - 80' conductor set_ Engineering 19 Surface casing_ protects all -known USDWs - - - - - - - - - - - - - - Yes - - - - - Surface casing set at 2502' MD - - - - 20 CMT vol, adequate to circulate on conductor& surf csg Yes 24.2% -excess cement planned - - 21 CMT -vol _adequate _to tie-in long string to surf csg----- - No- - - - - - - - - 22 CMT -will coverall known -productive horizons_ - - - --- -- ---------- No Productive- interval will be completed with uncemented screens_ _ - 23 Casing designs adequate for C, -T, B &_ permafrost_ - - - - . - - Yes - - - - - - - - - - - - - - - - - - - - - 24 Adequate tankage -or reserve pit Yes - - - - - - - Rig has steel tanks; all -waste -to approved disposal wells- - - - - - - - - _ 25 If-a_re-drill,has_a10-403forabandonmentbeen approved___... NA_________________________________________ 26 Adequate wellbore separation proposed - - - - - - - - - - - - - - Yes - - - . - - - Anti -collision analysis complete; major risk failure w/ planned well 3R-105_ 27 If_diverter required, does it meet regulations_ - _ _ - -- ----- - Yes Diyerter waiver ranted per 20 AAC 25.035(h)(2) 9 -p ----------------- -------- Appr Date 28 Drilling fluid_ program schematic_& equip list -adequate- - - - - - - - - - - - -------- Yes - - - - - - - Max formation_ pressure is_ 1570 psig(8.3 ppg EMW ); will drill w/-8.8-9.5 ppg EMW - - VTL 8/13/2019 29 BOPEs,_dotheymeetregulation------------ - - - - -- - - - -- Yes ----------------------------------------------------------- 30 BOPE_press rating appropriate; test to -(put psig in comments)- - - - - - - - - - - - - - - - - - - Yes - - - - - - - MPSP is 1207 psig; will test BOPs_to 3500-psig _ . - - _ _ - - - - . _ - - _ - - _ - - - _ - - - - - - - - - - 31 Choke -manifold complies w/API_ RP -53 (May 84)- - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will occur without operation shutdown- _ - - Yes - _ - 33 Is presence- of 1-12S gas_ probable - - - - No - - - - - - - I - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 34 -Mechanical conditionofwells within AOR verified (For _service well only) ----- NA- - - _ _ - - - - - - - -- - - - - - -- - - -- - - - - - - -- - - - - - - - - - - - - - - - - - -- -- - - - - 35 Permit_can be issued w[o hydrogen_ sulfide measures - ------ - - - - ------- ---- Yes - - - - - - - H2S recorded_in the West Salk open_to 3R-101 is less than 1Q ppm. - _ - _ _ - - ----------- Geology 36 Data_presented on potential overpressure zones - - - - - - - - - Yes - y at 3R Pad. - - - - - - Shallow gas or h drates_not expected-lbased_on _past extensive drilling - Appr Date 37 Seismic analysis_of shallow gas_zones_ - - - NA_ - - Some potential for lost_ circulation and_ fault_ crossings. Mitigation measures discussed in SFD 7/19/2019 38 Seabed condition survey (if off -shore) - - - - - - - - - - - - - - - _ _ NA_ - - - - - - - Drilling Hazards_ section._ 39 Contact name/phone for weekly -progress reports_ [exploratory only] - - - - - - - - - - - - - - - NA_ - - _ . - - - - - - - - - Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date .241:1 V/5-PI/I