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Home My WebLink About217-013C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\5NH9KXKT\2025-06-06_16035_KRU_3R-101_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16035 KRU 3R-101 50-029-23574-00 Caliper Survey w/ Log Data 06-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 217-013 T40537 6/10/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.10 11:40:03 -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 16433'feet None feet true vertical 3511' feet None feet Effective Depth measured 16433'feet 6306', 9466'feet true vertical 3511'feet 3215', 3606'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 9266' 3597' Packers and SSSV (type, measured and true vertical depth)6306' 9466' 2092' 3215' 3606' 2036' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: 3603-3588', 3589-3595', 3591-3589', 3587-3591', 3593-3588', 3584-3580', 3579-3574', 3574-3555' 10345-10869', 11033-11438', 11755-12283', 12446-12957', 13177-13713', 13881-14446', 14665-15181', 15305-15824' 2244' 2166' 20" 13-3/8" Burst Collapse Intermediate Production 9693' Casing 2634'9732' 15967' 3551' 2205' 119'Conductor Surface 80; measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-013 50-029-23574-00-00 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: ADL0355023, ADL0355024 Kuparuk River Field/ West Sak Oil Pool KRU 3R-101 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) 600 Gas-Mcf MD 170 Size 119' 4000 11801000 170 1501400 225 324-129 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 50 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB BluePack Packer: Baker MLZXP SSSV: TRMAXX-5E Shane Germann shane.germann@conocophillips.com (907) 263-4597Staff RWO/CTD Engineer 6501' 4-1/2" Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:57 pm, Jun 05, 2024 Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann , E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2024.06.05 07:58:45-08'00' Foxit PDF Editor Version: 13.0.0 Page 1/9 3R-101 Report Printed: 6/3/2024 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) 4/28/2024 12:00 4/28/2024 16:00 4.00 MIRU, MOVE MOB P Move office off location. Pull rig around pad. Move rig T/ 2B. Move rig T/ 2C/ 4/28/2024 16:00 4/28/2024 18:30 2.50 MIRU, MOVE MOB P Hold for field C/O. 4/28/2024 18:30 4/29/2024 00:00 5.50 MIRU, MOVE MOB P Move rig T/ 2C 4/29/2024 00:00 4/29/2024 02:30 2.50 MIRU, MOVE MOB P Move rig to Olicktok Y. 4/29/2024 02:30 4/29/2024 03:30 1.00 MIRU, MOVE MOB P Hold to have emergency equipment moved. 4/29/2024 03:30 4/29/2024 04:30 1.00 MIRU, MOVE MOB P Move rig to KDTH. 4/29/2024 04:30 4/29/2024 06:30 2.00 MIRU, MOVE MOB P Hold for filed C/O. 4/29/2024 06:30 4/29/2024 16:30 10.00 MIRU, MOVE MOB P Continue move to 3R, Stop at 1Q for tire check and traffic, Stop at CPF 3 for tire check and traffic 4/29/2024 16:30 4/29/2024 20:00 3.50 MIRU, MOVE MOB P Arrive at 3R pad. Load tree components in cellar, Status wellhead Lay Herculite around wellhead, Set mats 4/29/2024 20:00 4/29/2024 22:00 2.00 MIRU, MOVE MOB P Spot sub over well. Berm in rig. 4/29/2024 22:00 4/30/2024 00:00 2.00 MIRU, MOVE MOB P MIRU. Spot auxiliary equipment. Mud shack, cuttings tang. Tiger tank, open top tank. 4/30/2024 00:00 4/30/2024 03:00 3.00 MIRU, MOVE MOB P Obtain initial pressures on well T/IA/OA = 300/300/200. Take on seawater. Complete rig acceptance checklist. R/U tiger tank lines. R/U circ manifold. Rig accepted @ 03:00 Hrs. 4/30/2024 03:00 4/30/2024 22:00 19.00 MIRU, WELCTL RGRP T 3" Demco top drive isolation valve was changed out on rig move. Failed initial X-ray inspection. Call out welder. Re weld failed area. Re X-ray - passed. Reconnect mud manifold 5ea gray lock connections, 2ea 1502 connections. Attempt PT. Troubleshoot and address small leaks. Perform shell test to 5000 psi. Passed. 4/30/2024 22:00 5/1/2024 00:00 2.00 MIRU, WELCTL RURD P BD and RD testing equipment. PT hardline out to tiger tanks to 2,500 psi. Found leak on tank manifold outside cellar. Tighten up 1502 connections. Re-test to 2,500 psi. Bleed free gas from Tubing and IA to tiger tank. 5/1/2024 00:00 5/1/2024 04:00 4.00 MIRU, WELCTL KLWL P Finish bleeding free gas from IA and Tubing. Found plug valve leaking on rig floor circ. manifold. Double blocked at choke. Line up circ. manifold to pump down the IA. Bullhead 777 bbls down the IA @ 5 BPM / 368 psi. Shut in IA. IA = 0 psi. OA = 30 psi. Swap to pump down Tubing. Bullhead 185 bbls down the Tubing @ 5 BPM / 300 psi. Rig: NORDIC 3 RIG RELEASE DATE 5/8/2024 Page 2/9 3R-101 Report Printed: 6/3/2024 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) 5/1/2024 04:00 5/1/2024 04:45 0.75 MIRU, WELCTL OWFF P OWFF for 30-min. Monitor Tubing and IA in cellar. RU 600 psi gauges to Tubing and IA. Tubing = 0 psi. IA = 75 psi. Tiger Tank Volume prior to bleed off = 43 bbls. Tubing = 0 psi. IA = 75 psi. Monitor for 15 Min. Bleed 10 bbls from IA. Shut in IA. Monitor pressure for 15-min. Tubing = 0 psi, IA = 80 psi. Bleed 10 bbls from IA. Shut in IA. Monitor for 15-min. Tubing = 0 psi, IA =85 psi. 5/1/2024 04:45 5/1/2024 06:45 2.00 MIRU, WELCTL KLWL P Initial PSI TBG=0, IA=85. Circ 1.5 TBG volume 170 Bbls down TBG taking returns out IA to tiger tank w/ open choke. 97 Bbls returned. Allow well to relax flowing additional 20 Bbls back to tank. SI. Order more seawater. 5/1/2024 06:45 5/1/2024 11:30 4.75 MIRU, WELCTL OWFF P SI. TBG=35, IA=60. Monitor for 15 Min. TBG=35, IA=60. Bleed 10 Bbls from TBG & IA. SI. TBG=15, IA=23. Monitor for 15 Min. TBG=15 ,IA=23 Bleed 10 Bbls from TBG & IA. Reduced to no flow at tank. Monitor flow in cellar. TBG no flow. IA flowing. Allow well to exhaust. SI. TBG=0, IA=10. Monitor for 30 Min. Bleed gas off IA. No flow TBG & IA for 30 Min. 5/1/2024 11:30 5/1/2024 12:00 0.50 MIRU, WELCTL MPSP P Pull tree cap off. Install BPV. 5/1/2024 12:00 5/1/2024 12:30 0.50 MIRU, WELCTL PRTS P Pressure Test BPV from below for 10- min. Performed rolling test @ 5 BPM. 5/1/2024 12:30 5/1/2024 19:15 6.75 MIRU, WHDBOP NUND P Function LDS. Replace/Repair damaged LDS. 5/1/2024 19:15 5/1/2024 21:30 2.25 MIRU, WHDBOP NUND P ND Tree. Install tree test dart. Inspect hanger neck threads. Threads looked good. Unable to grind stuck LDS cone to clear false bowl. Called DHD and Town Engineer to discuss. Made decision to install false bowl plate. Will call out DHD in the AM to drill out LDS and install cap. 5/1/2024 21:30 5/2/2024 00:00 2.50 MIRU, WHDBOP NUND P NU BOP. Measure RKBs. Install riser. 5/2/2024 00:00 5/2/2024 01:00 1.00 MIRU, WHDBOP RURD P RU testing equipment. Grease mud cross. Rig: NORDIC 3 RIG RELEASE DATE 5/8/2024 Page 3/9 3R-101 Report Printed: 6/3/2024 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) 5/2/2024 01:00 5/2/2024 11:00 10.00 MIRU, WHDBOP BOPE P PJSM. Flood stack. Purge air from system. Obtain shell test. Begin initial BOP Test to 250/2500 psi using 3 1/2" and 4 1/2" donut test joints. Initial BOPE test continued, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's w/ 3 1/2" & 4 1/2" test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 4 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3050 PSI, after closure = 1650 PSI, 200 PSI attained = 28 sec, full recovery attained = 132 sec. UVBR's = 8 sec, LPRs= 5 sec. Annular= 16 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Adam Earl. 5/2/2024 11:00 5/2/2024 13:30 2.50 MIRU, WHDBOP BOPE T Blind Rams failed. Replace 5/2/2024 13:30 5/2/2024 14:00 0.50 MIRU, WHDBOP RURD P Blowdown lines. RD testing equipment. Drain stack. 5/2/2024 14:00 5/3/2024 00:00 10.00 MIRU, WHDBOP NUND T RU DHD LDS drill. Drill out seized LDS. 5/3/2024 00:00 5/3/2024 01:15 1.25 MIRU, WHDBOP NUND T Finish drilling out seized LDS. R/D drill. Install dummy plug in gland nut threads. 5/3/2024 01:15 5/3/2024 01:45 0.50 MIRU, WHDBOP MPSP P Pull test dart and BPV. 5/3/2024 01:45 5/3/2024 02:00 0.25 COMPZN, RPCOMP OWFF P OWFF for 10-min 5/3/2024 02:00 5/3/2024 03:00 1.00 COMPZN, RPCOMP THGR P MU 4.909" long nose landing joint. Screw into tubing hanger neck threads. Screw in TD. Set 10K down. BOLDS. Pull tubing hanger to rig floor. Unseated @ 130K. Drug to floor @ 110K. 7,323.0 7,283.0 5/3/2024 03:00 5/3/2024 03:45 0.75 COMPZN, RPCOMP PULD P Cut ESP cable. Pull to first full joint w/ clamp. Cut ESP above clamp. TIH w/ clean joint spaced out across stack. L/D landing joint and tubing hanger. 7,278.0 7,278.0 5/3/2024 03:45 5/3/2024 04:00 0.25 COMPZN, RPCOMP RURD P MU head pin and circ hose. 7,278.0 7,278.0 5/3/2024 04:00 5/3/2024 05:15 1.25 COMPZN, RPCOMP CIRC P Fill hole with charge pump. See returns @ 36 BBLS pumped (est. fluid level of 500'). Kick mud pump on @ 4 BPM. Catch pressure @ 85 BBLS pumped. SPP = 60 psi. Circ BU @ 4 BPM / 58 psi. Lost returns @ 268 bbls away. Shut down pumps at 326 bbls. Dropped rate to 2 BPM to attempt to re-establish returns. Pumped 326 BBLS. Lost 271 BBLS. SD Pumps. 7,278.0 7,278.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2024 Page 4/9 3R-101 Report Printed: 6/3/2024 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) 5/3/2024 05:15 5/3/2024 06:30 1.25 COMPZN, RPCOMP OWFF P OWFF. Empty TT. Fill through kill line down IA. Returns T/ surface. Shut down. Let fluid fall for 30 Min. Fill through kill line down IA. Returns to surface 27 Bbls pumped. Static loss rate 54 BPH. Reduce fill rate T/ 20 Bbls every 30 Min. 7,278.0 7,278.0 5/3/2024 06:30 5/3/2024 07:00 0.50 COMPZN, RPCOMP RURD P RD circ hose and head pin. Connect ESP cable to spooling unit through sheave. 7,278.0 7,236.0 5/3/2024 07:00 5/3/2024 15:00 8.00 COMPZN, RPCOMP PULL P L/D 4 1/2" completions spooling up ESP cable F/ 7236' to surface'. PUW=100K. Filling hole w/ 20 Bbls every 30 Min down IA T/ 1850'. Filling hole w/ 20 Bbls every 30 Min down TBG F/ 1850' T/ surface. 185 cross collar clamps recovered. 7,236.0 0.0 5/3/2024 15:00 5/3/2024 15:30 0.50 COMPZN, RPCOMP RURD P Run ESP cable over sheave to spooling unit. 0.0 0.0 5/3/2024 15:30 5/3/2024 17:00 1.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. Scrub RF. 0.0 0.0 5/3/2024 17:00 5/3/2024 17:30 0.50 COMPZN, RPCOMP RURD P Install wear bushing. 0.0 0.0 5/3/2024 17:30 5/3/2024 21:30 4.00 COMPZN, RPCOMP BHAH P Crew C/O. Load Baker tools. MU BHA #1 (SBE cleanout). 0.0 213.0 5/3/2024 21:30 5/4/2024 00:00 2.50 COMPZN, RPCOMP PULD P Single in hole w/ BHA #1 to midnight depth of 1,039'. Maintain fill schedule of 15 BBLS every 30 minutes. 213.0 1,039.0 5/4/2024 00:00 5/4/2024 03:45 3.75 COMPZN, RPCOMP PULD P Continue single in hole w/ BHA #1 to 4,492'. PUW=85K, SOW=70K. Maintain fill schedule of 15 BBLS every 30 minutes. 1,039.0 4,492.0 5/4/2024 03:45 5/4/2024 06:30 2.75 COMPZN, RPCOMP SLPC P Slip and cut 66' drill line Maintain fill schedule of 15 BBLS every 30 minutes. 4,492.0 4,492.0 5/4/2024 06:30 5/4/2024 08:15 1.75 COMPZN, RPCOMP PULD P Cont. PUDP F/ 4492' T/ 6295', PUW=98K, SOW=70K. S/O weight showing drag of 10K. Maintain fill schedule of 15 BBLS every 30 minutes. 4,492.0 6,295.0 5/4/2024 08:15 5/4/2024 08:45 0.50 COMPZN, RPCOMP REAM P K/U Circ @ 3 BPM, 324 PSI, 4 BPM, 610 PSI, 5 BPM, 975 PSI. Rot @ 50 RPM, 6.4K Tq. ROT=83K. Ream stand up and back down. ROT PUW=85K. ROT SOW=77K. Pumped total of 100 Bbls. Saw returns T/ surface @ 69 Bbls. Overboard diesel returns. 6,295.0 6,295.0 5/4/2024 08:45 5/4/2024 09:45 1.00 COMPZN, RPCOMP PULD P PUDP F/ 6295' PUW=99K, SOW=65K, T/ 7380', PUW=110K, SOW=63K Maintain fill schedule of 15 BBLS every 30 minutes. 6,295.0 7,380.0 5/4/2024 09:45 5/4/2024 10:15 0.50 COMPZN, RPCOMP REAM P K/U Circ @ 5 BPM, 1080 PSI. Rot @ 50 RPM, 7.7K Tq. ROT=85K. Ream stand up and back down. ROT PUW=90K. ROT SOW=83K. Pumped total of 80 Bbls. Saw returns T/ surface @ 67 Bbls. Overboard diesel returns. 7,380.0 7,380.0 5/4/2024 10:15 5/4/2024 11:00 0.75 COMPZN, RPCOMP PULD P PUDP F/ 7380' PUW=118K, SOW=65K, T/ 8373', PUW=118K, SOW=57K Maintain fill schedule of 15 BBLS every 30 minutes. 7,380.0 8,373.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2024 Page 5/9 3R-101 Report Printed: 6/3/2024 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) 5/4/2024 11:00 5/4/2024 11:30 0.50 COMPZN, RPCOMP REAM P K/U Circ 32 Bbls Deep clean pill @ 5 BPM, 1170 PSI. Rot @ 50 RPM, 8.6K Tq. ROT=90K. Ream stand up and back down. ROT PUW=95K. ROT SOW=84K. Pumped total of 93 Bbls. Saw returns T/ surface @ 40 Bbls. Overboard diesel returns. 8,373.0 8,373.0 5/4/2024 11:30 5/4/2024 12:00 0.50 COMPZN, RPCOMP PULD P PUDP F/ 8373' PUW=118K, SOW=65K, T/ 8808', PUW=122K, SOW=55K. Lost SOW. Maintain fill schedule of 15 BBLS every 30 minutes. 8,373.0 8,808.0 5/4/2024 12:00 5/4/2024 12:30 0.50 COMPZN, RPCOMP REAM P K/U Wash & ream F/ 8808' T/ 8839'. Circ @ 5 BPM, 1270 PSI. Rot @ 50 RPM, 8.6K Tq. ROT=90K. ROT PUW=95K. ROT SOW=83K. Pumpted total of 80 Bbls. Saw returns T/ surface @ 70 Bbls. Overboard diesel returns. 8,808.0 8,839.0 5/4/2024 12:30 5/4/2024 13:00 0.50 COMPZN, RPCOMP PULD P PUDP F/ 8839' PUW=122K, SOW=55K, T/ 9077', PUW=124K, SOW=55K. Maintain fill schedule of 15 BBLS every 30 minutes. 8,839.0 9,077.0 5/4/2024 13:00 5/4/2024 15:15 2.25 COMPZN, RPCOMP REAM P K/U Wash & ream F/ 9077'. T/ 9257;'Circ @ 5 BPM, 1270 PSI. Rot @ 50 RPM, 9.2K Tq. ROT=95K. ROT PUW=100K. ROT SOW=55K. Saw TOP of SBE @ 9237'. BTM @ 9257' 9,077.0 9,257.0 5/4/2024 15:15 5/4/2024 22:30 7.25 COMPZN, RPCOMP TRIP P TOOH F/ 9,257' T/ surface. PUW=124K. Filling 15 bbls / 30-min down DP. 9,257.0 213.0 5/4/2024 22:30 5/5/2024 00:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA #1 (SBE cleanout). 213.0 213.0 5/5/2024 00:00 5/5/2024 00:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #1 (SBE cleanout). L/D drill collars. 213.0 0.0 5/5/2024 00:30 5/5/2024 02:00 1.50 COMPZN, RPCOMP BHAH P M/U BHA #2 (SBE Pack-Off + Muleshoe). 0.0 72.0 5/5/2024 02:00 5/5/2024 07:30 5.50 COMPZN, RPCOMP TRIP P TIH w/ BHA #2 to 9089' (above SBE). Obtain parameters. PUW = 118K, SOW = 57K. 72.0 9,089.0 5/5/2024 07:30 5/5/2024 08:15 0.75 COMPZN, RPCOMP RURD P Pull mousehole. RU sensator and hose to test spool in prep for 9 5/8" pressure testing. 9,089.0 9,089.0 5/5/2024 08:15 5/5/2024 08:45 0.50 COMPZN, RPCOMP TRIP P PUDP F/ 9089' and sting pack-off into SBE top at 9,238'. PUW=126K, SOW=50K. Fully locate at bottom of SBE @ 9256'. . 9,089.0 9,256.0 5/5/2024 08:45 5/5/2024 09:15 0.50 COMPZN, RPCOMP RURD P R/U testing equipment. Fill hole w/ seawater. 9,256.0 9,256.0 5/5/2024 09:15 5/5/2024 09:45 0.50 COMPZN, RPCOMP PRTS P PT 9 5/8" casing to 2,500 psi - Failed. 9,256.0 9,256.0 5/5/2024 09:45 5/5/2024 10:15 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 9,256.0 9,256.0 5/5/2024 10:15 5/5/2024 14:30 4.25 COMPZN, RPCOMP TRIP P POOH F/ 9256' T/ 72', PUW=126K. 9,256.0 72.0 5/5/2024 14:30 5/5/2024 15:00 0.50 COMPZN, RPCOMP RURD P R/U tubing handling equipment. 72.0 72.0 5/5/2024 15:00 5/5/2024 15:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #2. 72.0 0.0 5/5/2024 15:30 5/5/2024 16:00 0.50 COMPZN, RPCOMP RURD P R/D tubing hadling equipment. 0.0 0.0 5/5/2024 16:00 5/5/2024 16:30 0.50 COMPZN, RPCOMP RURD P Mobilize BHA #3 T/ RF. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2024 Page 6/9 3R-101 Report Printed: 6/3/2024 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) 5/5/2024 16:30 5/5/2024 17:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #3 test packer T/ 15' 0.0 15.0 5/5/2024 17:00 5/5/2024 21:30 4.50 COMPZN, RPCOMP TRIP P RIH w/ BHA #3 F/ 15' T/ 5,255'. Set 7K down. PUH. RIH to 5,249'. Set 5K down. Discuss with Baker rep. Test Packer partially set. PUH rotate slowly to the left to disengage test packer. PUW = 83K. SOW = 75K. TBIH clean. Cont. TIH to 6,494'. PUW = 90K. SOW = 73K. See 2K drag increase from 5,259'. 15.0 6,494.0 5/5/2024 21:30 5/5/2024 21:45 0.25 COMPZN, RPCOMP MPSP P Set Test Packer COE @ 6,489'. 6,494.0 6,494.0 5/5/2024 21:45 5/5/2024 22:15 0.50 COMPZN, RPCOMP RURD P Fill backside through kill line. Once fluid packed, close UPR. RU sensator. 6,494.0 6,494.0 5/5/2024 22:15 5/5/2024 22:30 0.25 COMPZN, RPCOMP PRTS P Pressure Test 9 5/8" Casing against test packer to 6,489' for 15-min. Charted. Passed. Bleed off. Open UPR. Initials: T = 0 psi IA (9 5/8" CSG) = 2660 psi OA = 50 psi 15-min: T = 0 psi IA (9 5/8" CSG) = 2640 psi OA = 50 psi 6,494.0 6,494.0 5/5/2024 22:30 5/5/2024 22:45 0.25 COMPZN, RPCOMP MPSP P PUH rotating slowly to the left. Release Test Packer @ 6,489'. PUW = 90K. SOW = 73K. 6,494.0 6,494.0 5/5/2024 22:45 5/5/2024 23:15 0.50 COMPZN, RPCOMP TRIP P Cont. TIH F/ 6,494' T/ 7,046', monitoring drag. PUW = 95K. SOW = 75K. Cont. TIH from 7,046' - 7,520'. 6,494.0 7,520.0 5/5/2024 23:15 5/5/2024 23:30 0.25 COMPZN, RPCOMP MPSP P Set Test Packer COE @ 7,515'. Drag not as noticable as with longer BHA's. Decide to stop here. Short Test Packer BHA may not be representative of the drag we will see on the 4 1/2" completions run, and Ball and Rod will have to travel and stay on seat @ 83-89 deg dev any deeper. 7,520.0 7,520.0 5/5/2024 23:30 5/6/2024 00:00 0.50 COMPZN, RPCOMP PRTS P Fill backside. Close UPR. Begin to Pressure Test 9 5/8" Casing against test packer to 7,515'. 7,520.0 7,520.0 5/6/2024 00:00 5/6/2024 00:30 0.50 COMPZN, RPCOMP PRTS P Fill backside. Close UPR. Pressure Test 9 5/8" Casing against test packer to 7,515' for 15-min. Charted. Pass. Bleed off. Open UPR. Initials: T = 0 psi IA (9 5/8" CSG) = 2640 psi OA = 50 psi 15-min: T = 0 psi IA (9 5/8" CSG) = 2640 psi OA = 50 psi 7,520.0 7,520.0 5/6/2024 00:30 5/6/2024 07:30 7.00 COMPZN, RPCOMP PULD P PJSM. TOOH LDDP F/ 7,520' to 1400'. 7,520.0 1,400.0 5/6/2024 07:30 5/6/2024 08:15 0.75 COMPZN, RPCOMP TRIP P RIH w/ DP out of derrick F/ 1400' T/ 3253', PUW=76K. SOW=70K. 1,400.0 3,253.0 5/6/2024 08:15 5/6/2024 10:30 2.25 COMPZN, RPCOMP PULD P LDDP F/ 3253' T/ 15', PUW=76K 3,253.0 15.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2024 Page 7/9 3R-101 Report Printed: 6/3/2024 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) 5/6/2024 10:30 5/6/2024 11:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #3 (9 5/8" Test Packer) 15.0 0.0 5/6/2024 11:00 5/6/2024 11:30 0.50 COMPZN, RPCOMP RURD P Pull wear bushing. 0.0 0.0 5/6/2024 11:30 5/6/2024 12:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. 0.0 0.0 5/6/2024 12:00 5/6/2024 15:30 3.50 COMPZN, RPCOMP RURD P Mobilize spooling units & clamps T/ RF. 0.0 0.0 5/6/2024 15:30 5/6/2024 16:15 0.75 COMPZN, RPCOMP RURD P Deck test SSSV. Process 4 1/2" tubing. 0.0 0.0 5/6/2024 16:15 5/6/2024 17:15 1.00 COMPZN, RPCOMP RURD P Feed rope through sheaves. Hang SSSV sheave with control line through it. 0.0 0.0 5/6/2024 17:15 5/6/2024 18:00 0.75 COMPZN, RPCOMP RURD P Mobilize packer & modified seal T/ RF. 0.0 0.0 5/6/2024 18:00 5/6/2024 19:00 1.00 COMPZN, RPCOMP RURD P R/U GBR torque turn. Verify joint count and jewelry running order. 0.0 0.0 5/6/2024 19:00 5/6/2024 19:15 0.25 COMPZN, RPCOMP SFTY P PJSM w/ rig crew SLB, GBR & HES reps on running completion w/ stacker packer & control lines. 0.0 0.0 5/6/2024 19:15 5/7/2024 00:00 4.75 COMPZN, RPCOMP PUTB P Run 4 1/2", 12.6#, L-80, Hyd 563 tubing as per tally T/ midnight depth of 2,997'. SOW=63K. Hyd 563 torque turned T/ 3800 Ft/lbs. Best'o'life 2000 arctic grade dope used. 0.0 2,997.0 5/7/2024 00:00 5/7/2024 00:30 0.50 COMPZN, RPCOMP SEQP P Surface test chemical injection line. Opened up at 1,900 psi. Dropped to 1,000 psi and held. Good test. 2,997.0 2,997.0 5/7/2024 00:30 5/7/2024 15:30 15.00 COMPZN, RPCOMP PUTB P MU Opsis DHG mandrel. Connect and test TEC wire. Cont. to run 4 1/2", 12.6#, L-80, Hyd 563 tubing as per tally T/ 9,246' (Joint #218). PUW = 92K. SOW=65K. Reconfigure chem. inj. control line sheaves to mitigate wear at beaver slide. C/O collar on Joint #89. Hyd 563 torque turned T/ 3800 Ft/lbs. Best'o'life 2000 arctic grade dope used. HES completions checking DHG on the fly. Continue to hole fill w/ CI @ 15 bbls / 30-min. At 11AM, re-route sheave in derrick per SLB to reduce risk of damaging SSSV control line. 2,997.0 9,247.0 5/7/2024 15:30 5/7/2024 16:00 0.50 COMPZN, RPCOMP HOSO P MU Joint #219. TIH and fully locate in SBE @ 9,261.4' (N3 RKB). See seal stack drag when entering SBE. Set 10K down to confirm fully located. PU 4' for space out @ 9,257.4' (N3 RKB). Mark pipe. Fill backside to confirm seals are stung in. Took 12 bbls. Static fluid at floor. Pull out of SBE. Watch fluid level drop @ approx. 9,241'. L/D partial Joint #219 (11.7' pulled) and Full Joint #218 (41.47'). Total pulled = 53.17'. Need 37.77' for RKB + Tbg Hanger + Hanger Pup. Delta = 15.4'. Calc space out pups. L/D Full Joint #217. MU space out pups (5.75', 9.71') = 15.46'. MU Joint #217. Cont. backside hole fill 15 bbls / 30-min w/ SW from pits. 9,247.0 9,235.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2024 Page 8/9 3R-101 Report Printed: 6/3/2024 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) 5/7/2024 16:00 5/7/2024 19:30 3.50 COMPZN, RPCOMP THGR P Select and MU timed collar. MU hanger on landing joint to determine baseline orientation. Utilize 12:30 timed collar to align hanger port with wellhead side outlet port. Install dummy penetrator. Terminate control lines and TEC wire through hanger w/ landing leads. Check TEC wire electrical integrity. Land Hanger. RILDS. Re-check TEC wire integrity after landing hanger. Bottom of Seals @ 9,262' (ORKB w/ 4' space out). 9,235.0 9,235.0 5/7/2024 19:30 5/7/2024 20:15 0.75 COMPZN, RPCOMP PRTS P PT hanger seals T/ 5,000 psi for 15-min. 9,235.0 9,235.0 5/7/2024 20:15 5/7/2024 21:00 0.75 COMPZN, RPCOMP RURD P Drop Ball and Rod (high angle w/ roller stem and G-FN). RU testing equipment (1 leg to Tubing, 1 leg to IA) with isolation valves. 9,235.0 9,235.0 5/7/2024 21:00 5/7/2024 21:45 0.75 COMPZN, RPCOMP PACK P Pump ball and rod on-seat. Pressure up and set 4 1/2" x 9 5/8" BluePack Packer as per SLB completions. Pump @ 1.5 bbls /min ball on seat 21 bbls pumped // Stage up setting pressure on packer 500 psi up to 3800psi 9,235.0 9,235.0 5/7/2024 21:45 5/7/2024 23:30 1.75 COMPZN, RPCOMP PRTS P PT Tubing to 3,800 psi for 30-min. Charted. Bleed to 1,500 psi. Close SSSV. Bleed off above SSSV. Close in and chart for 15-min, watching for build up. Pressure back up to 1,500 psi to equalize at SSSV. Open SSSV. Pressure up Tubing to 1,500 psi. PT IA to 2,500 psi for 30-min. Charted. Dump tubing pressure to shear SOV. 0.0 0.0 5/7/2024 23:30 5/8/2024 00:00 0.50 COMPZN, RPCOMP RURD P Rig down hoses and landing joint to set BPV 0.0 0.0 5/8/2024 00:00 5/8/2024 00:30 0.50 COMPZN, RPCOMP RURD P Lay down hoses and landing jt to set BPV 0.0 0.0 5/8/2024 00:30 5/8/2024 01:30 1.00 COMPZN, WHDBOP MPSP P Set BPV // Pressure test 1000psi from good test 0.0 0.0 5/8/2024 01:30 5/8/2024 04:00 2.50 COMPZN, WHDBOP NUND P Nipple down BOPs. Set test dart. 0.0 0.0 5/8/2024 04:00 5/8/2024 07:00 3.00 COMPZN, WHDBOP THGR P HES terminate control lines and TEC wire at tubing hanger. MU tbg head adapter. Termine lines. PT hanger void to 5,000 psi for 15-min. 0.0 0.0 5/8/2024 07:00 5/8/2024 09:45 2.75 COMPZN, WHDBOP NUND P NU new tree. Replace damaged tree top flange. 0.0 0.0 5/8/2024 09:45 5/8/2024 10:45 1.00 COMPZN, WHDBOP PRTS P R/U LRS. PT tree to 5,000 psi for 15- min. 0.0 0.0 5/8/2024 10:45 5/8/2024 11:00 0.25 COMPZN, WHDBOP MPSP P Pull test dart/BPV. 0.0 0.0 5/8/2024 11:00 5/8/2024 15:00 4.00 COMPZN, WHDBOP CIRC P R/U circ. manifold in cellar. PT lines. Attempt to pump diesel down IA. Unable to circulate. Blow air through surface lines to ensure clear. Good air to tanks. Pump open SSSV. Circulate 144 bbls diesel down IA taking returns from Tubing to tanks. 2 BPM @ 500 psi. Change out drive tire with bad bead while pumping FP. SD. RD LRS pump. Blowdown lines. U-Tube for 1 hour. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2024 Page 9/9 3R-101 Report Printed: 6/3/2024 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) 5/8/2024 15:00 5/8/2024 18:00 3.00 DEMOB, MOVE RURD P RD LRS and circ equipment. RD hardline. RU tree gauge manifolds. Gather final pressures. T/I/O =50/50/50 Final reading from TEC Wire = 1,441 psi / 59.4 deg F. Secure tree. Clean and clear cellar. Release rig @ 18:00 and prep for move to 2T-215. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2024 Page 1/1 3R-101 Report Printed: 6/3/2024 WSR Historical - QC JOB Well Type Development Orig KB/RT (ft) 49.00 Well Status PROD Legal WellName 3R-101 API / UWI 5002923574 Field Name TRACT OPERATION WSAKTR05 Start Date 5/13/2024 14:00 End Date 5/25/2024 22:00 Secondary Job Type CHANGE ARTIFICIAL LIFT TYPE Objective Final Job Status COMPLETED Primary Wellbore Affected 3R-101 NETWORK Job Type Project Desc Common WellName Cost Type Network/Order Number OPTIMIZE WELL 3R-101 RWO - Wells 3R-101 Capitalize 10455438 UNIT/RIG: HES SLICK LINE 765 Rig Accept Date 5/13/2024 Rig Release Date 5/13/2024 Rig Supervisor ROGERS, BRENT,Wells Supervisor Title Wells Supervisor Company CPAI Phone W 659-7043 Mobile N/A Pager N/A Job scope, work string information, or noted if job is performed during drilling operations Comment Daily Operations Report Start Date 5/13/2024 16:00 Report End Date 5/13/2024 21:00 Status at Reporting Time 05/14/2024 Time Log Hrs (hr) 5.00 ZX Code ZX36 Artificial Lift Installation / Removal / Main this data box is reviewed daily by engineers, supervisors, and techs. Last 24hr Summary SET 4.5'' SLIP STOP CATCHER 2966' RKB, ATTEMPT TO PULL 1.5'' SOV w/ RK LATCH FROM ST # 2.. IN PROGRESS General Remarks T/I/O INITIAL= 0/0/0 FINAL= 0/0/0 weather related data when and if weather has affect on job Weather Wind T (°F) CONTRACTOR Supervisor Title Company Phone Work Mobile Pager CONNOR, DAVE,Slickline Operator Slickline Operator HES N/A 907-317-8156 N/A TIME LOG - enter a Vendor if trouble time occurs during operation Start Time End Time Dur (hr) Cum Dur (hr) Major Equip Activity Code Time P-T-X Operation Vendor (NPT) Wellbore 16:00 17:00 1.00 1.00 SW TRAV P CONTACT DSO, TRAV FROM 1Q-22 *****START TKT 14:00**** 3R-101 17:00 18:00 1.00 2.00 SW RURD P ARRIVE, SPOT IN EQUIP, INSPECT AREA, TGSM, RU .125'' WIRE & 2.625'' ROLLER STEM (3.50'' WHEELS) TOOK CONTROL OF SAFETY VLV 4500 PSI 3R-101 18:00 18:30 0.50 2.50 SW SLKL P PT W/ LRS 2000 PSI, RIH W/ 4.5'' GS & 4.5'' SLIPSTOP CATCHER ( 41''), SET CATCHER BELOW ST #2 2940' SLM, POOH.. OOH W/O CATCHER 3R-101 18:30 19:30 1.00 3.50 SW SLKL P PT W/ LRS 2000 PSI, RIH W/ 4.5'' OM-1 & 1.625'' JDC, LOCATE / SD 2891' RKB / 2865' SLM, JD 3X, 500 # OVER PULL, CAME FREE... POOH OOH W/O VLV... SCALE FROM LAST JOB & PIPE DOPE ON WIRE FROM THIS JOB, DIFFCULT TO SEE SPANGS DUE TO WIRE CHATTER 3R-101 19:30 20:30 1.00 4.50 SW RURD P **** END 19:00**** SECURE WELL, PJSM, CONTACT DSO, LDFN 3R-101 20:30 21:00 0.50 5.00 SW TRAV P TRAV TO OFFICE, SYNC CPU, TIWF 3R-101 FLUIDS - for CT include "BHA no" + "String Name" into Purpose field Fluid Fluid Sub Type To (bbl) Note DIESEL 0.0 PT LUBE Job: OPTIMIZE WELL Report Date: 5/13/2024 Rig: HES SLICK LINE 765 Page 1/2 3R-101 Report Printed: 6/3/2024 WSR Historical - QC JOB Well Type Development Orig KB/RT (ft) 49.00 Well Status PROD Legal WellName 3R-101 API / UWI 5002923574 Field Name TRACT OPERATION WSAKTR05 Start Date 5/13/2024 14:00 End Date 5/25/2024 22:00 Secondary Job Type CHANGE ARTIFICIAL LIFT TYPE Objective Final Job Status COMPLETED Primary Wellbore Affected 3R-101 NETWORK Job Type Project Desc Common WellName Cost Type Network/Order Number OPTIMIZE WELL 3R-101 RWO - Wells 3R-101 Capitalize 10455438 UNIT/RIG: HES SLICK LINE 765 Rig Accept Date 5/14/2024 Rig Release Date 5/14/2024 Rig Supervisor FERGUSON, SID,Wells Supervisor Title Wells Supervisor Company CPAI Phone W 659-7223 Mobile 943-1065 Pager N/A Job scope, work string information, or noted if job is performed during drilling operations Comment Daily Operations Report Start Date 5/14/2024 05:30 Report End Date 5/14/2024 17:00 Status at Reporting Time 05/15/2024 Time Log Hrs (hr) 11.50 ZX Code ZX36 Artificial Lift Installation / Removal / Main this data box is reviewed daily by engineers, supervisors, and techs. Last 24hr Summary REPLACED SOV @ 2891' RKB W/ 1/4 PORT OV w/ RK LATCH ( GOOD 1500 PSI TEST). CLEAN DRIFT W/ 3'' BAILER ( NOTHING RECOVERED), PULLED 2.625'' BALL & ROD @ 6364' RKB. PULLED 3.81'' RHC PLUG BODY 6374' RKB JOB COMPLETE. General Remarks T/I/O INITIAL= 0/0/0 FINAL= 0/0/0 weather related data when and if weather has affect on job Weather Wind T (°F) CONTRACTOR Supervisor Title Company Phone Work Mobile Pager CONNOR, DAVE,Slickline Operator Slickline Operator HES N/A 907-317-8156 N/A TIME LOG - enter a Vendor if trouble time occurs during operation Start Time End Time Dur (hr) Cum Dur (hr) Major Equip Activity Code Time P-T-X Operation Vendor (NPT) Wellbore 05:30 06:30 1.00 1.00 SW TRAV P HAL MEETING, MEET W/ CWG, AQUIRE WELL FILE, SYNC CPU, CONTACT DSO, TRAV TO 3R-101 3R-101 06:30 07:30 1.00 2.00 SW RURD P ARRIVE, WARM UP EQUIPMENT, INSPECT AREA, TGSM, RU .125'' WIRE & 2.625'' ROLLER (WHEELS 3.50'') TS = RS QC, QC 5' QC, QC KJ 5' QC, OJS, LSS (26') 3R-101 07:30 08:30 1.00 3.00 SW SLKL P ****START TKT 07:00**** PT W/ LRS 2000 PSI, RIH W/ 4.5'' OM-1 & 1.625'' JDC, LOCATE / SD ST #3 2981' RKB / 2966' SLM, LATCH VLV, 1X SPANG LICK , CAME FREE.. POOH.. OOH W/ 1.5'' UN SHEARED SOV 3R-101 08:30 09:30 1.00 4.00 SW SLKL P PT W/ LRS 2500 PSI, RIH W/ 4.5'' OM-1 & 1.5'' .25'' PORT OV w/ RK LATCH, LOCATE / SD 2981' RKB / 2966' SLM, WORKED VLV IN POCKET, SEEN 2' TRAV, SET VLV, LRS PRESSURED UP TUBING FROM 0-1500 PSI, GOOD TEST, SHEARED OFF VLV.. POOH.. OOH W/O VLV 3R-101 09:30 10:30 1.00 5.00 SW SLKL P PT W/ LRS 2500 PSI, RIH W/ 4.5'' GR , SD / LATCH 4.5'' SLIP STOP CATCHER 2940' SLM, JARRED FREE, POOH.. OOH W/ CATCHER 3R-101 10:30 12:00 1.50 6.50 SW SLKL P MU 8' RISER, ADD 5' 2.625'' ROLLER , PT W/ LRS 2500 PSI, RIH W/ QC 5' 3'' BAILER, CLEAN DRIFT, TAGGED B&R 6333' SLM / 6363' RKB.. POOH.. OOH W/ TOOLS .. NO SOLIDS RECOVERED 3R-101 12:00 13:30 1.50 8.00 SW SLKL P PT W/ LRS 2500 PSI, RIH W/ 3'' GR, SD / LATCH B&R 6663' RKB / 6633' SLM, 1100 # OJ LICK CAME FREE.. POOH.. OOH W/ B&R ( OAL 126'') 3R-101 13:30 15:00 1.50 9.50 SW SLKL P PT W/ LRS 2500 PSI, RIH W/ 4.5'' GR, STALLING OUT 4000' SLM, DUE TO LACK OF FLUID BYPASS & SCALE ON WIRE FROM PREVIOUS JOB, LRS ONLINE 1 BPM, SD / LATCH 3.81'' RHC PLUG BODY 6374' RKB / 6346' SLM, 1X SPANG LICK, CAME FREE, POOH.. OOH W/ RHC PLUG BODY 3R-101 15:00 16:00 1.00 10.50 SW SLKL P SECURE WELL, DISCONNECTED AND SECURED SSSV CONTROL LINE (4500 PSI), PJSM, CONTACT DSO, RDMO 3R-101 16:00 17:00 1.00 11.50 SW TRAV P *****END TKT 1600**** TRAV CONTACT DSO, TRAV TO 3O PAD, SHOVELED SNOW TO GET WELLHOUSE DOORS OPEN, SPOT UP ON WELL # 06 FOR THE NIGHT., TRAV TO OFFICE, SYNC CPU, TIWF 3R-101 Job: OPTIMIZE WELL Report Date: 5/14/2024 Rig: HES SLICK LINE 765 Page 2/2 3R-101 Report Printed: 6/3/2024 WSR Historical - QC FLUIDS - for CT include "BHA no" + "String Name" into Purpose field Fluid Fluid Sub Type To (bbl) Note DIESEL 20.0 PT , ASSIST SL Job: OPTIMIZE WELL Report Date: 5/14/2024 Rig: HES SLICK LINE 765 Page 1/1 3R-101 Report Printed: 6/3/2024 WSR Historical - QC JOB Well Type Development Orig KB/RT (ft) 49.00 Well Status PROD Legal WellName 3R-101 API / UWI 5002923574 Field Name TRACT OPERATION WSAKTR05 Start Date 5/13/2024 14:00 End Date 5/25/2024 22:00 Secondary Job Type CHANGE ARTIFICIAL LIFT TYPE Objective Final Job Status COMPLETED Primary Wellbore Affected 3R-101 NETWORK Job Type Project Desc Common WellName Cost Type Network/Order Number OPTIMIZE WELL 3R-101 RWO - Wells 3R-101 Capitalize 10455438 UNIT/RIG: PW SLICK LINE 56TU - Hoss Rig Accept Date 5/24/2024 Rig Release Date 5/24/2024 Rig Supervisor FERGUSON, SID,Wells Supervisor Title Wells Supervisor Company CPAI Phone W 659-7223 Mobile 943-1065 Pager N/A Job scope, work string information, or noted if job is performed during drilling operations Comment Daily Operations Report Start Date 5/24/2024 16:00 Report End Date 5/24/2024 21:00 Status at Reporting Time 05/25/2024 Time Log Hrs (hr) 5.00 ZX Code ZX36 Artificial Lift Installation / Removal / Main this data box is reviewed daily by engineers, supervisors, and techs. Last 24hr Summary UNABLE TO PASS 358' W/ SLIP STOP CATCHER. DRIFTED W/ 5' X 2.5" BAILER, WORKING IT IN SPOTS DOWN TO 2335' SLM, POOH HYDRATES. PUMPED 35 BBLS OF HOT DIESEL & DRIFTED TBG W/ 3.74" GAUGE RING TO 2950' RKB , BRUSH AND FLUSHED TBG TO 2950' RKB. LDFN. JOB IN PROGRESS. General Remarks INITIAL T/ IA/ OA = 100/ 1200/ 0 FINIAL T/ IA/ OA = 100/ 1200/ 0 weather related data when and if weather has affect on job Weather Wind T (°F) CONTRACTOR Supervisor Title Company Phone Work Mobile Pager GAINEY, TRENT,Slickline Supervisor Slickline Supervisor PW N/A N/A N/A TIME LOG - enter a Vendor if trouble time occurs during operation Start Time End Time Dur (hr) Cum Dur (hr) Major Equip Activity Code Time P-T-X Operation Vendor (NPT) Wellbore 16:00 16:15 0.25 0.25 SW TRAV P CONTACT DSO, TRAVEL WITH EQUIP FROM 3B-PAD. 3R-101 16:15 17:30 1.25 1.50 SW RURD P ARRIVE LOC, SPOT EQUIP, TGSM, JSA, R/U .125" WIRE, CUT RE-TIE, SWAP TO 1.875" TS = RS, 5', KJ, 5', OJ, KJ, LSS, R/U LRS TO PMP N SUB. 3R-101 17:30 17:45 0.25 1.75 SW SLKL P PT W/ LRS TO 2500, RIH W/ QC, 4-1/2" GS ( 1/4" BRASS ), 4-1/2" SS CATCHER OAL = 41", SD @ 358' SLM, POOH. OOH W/ CATCHER, SLIPS NOT SHEARED. CONFER W/ CWG-REP. 3R-101 17:45 18:30 0.75 2.50 SW SLKL P PT W/ LRS TO 2500, RIH W/ QC, 5' X 2.5" DD BLR, WORK THRU TIGHT SPOTS @ 500' SLM, TROUBLE SHOOT / TAKE CONTROL OF SSSV, PMP SSSV UP TO 4700 PSI, TOOLS DRIFT TO 2325' SLM, CWG-FIELD-REP ON UNIT, POOH. OOH W/ HYDRATES IN BLR. 3R-101 18:30 19:30 1.00 3.50 SW SLKL P PT W/ LRS TO 2500, LRS ONLINE 35 BBLS HOT DWN TBG, RIH W/ QC, 3' X 1.875" WB, 4-1/2" BLB, 3.75" GAUGE-RING, SD @ 371' SLM, WORK TOOLS DWN TO 1100' SLM, BREAK FREE, DRIFT FREELY TO 2950' SLM, CONFER W/ CWG-REP, POOH. 3R-101 19:30 20:15 0.75 4.25 SW RURD P BEGIN LDFN, PJSM, R/D LRS, SECURE WELL, CONTACT DSO 3R-101 20:15 21:00 0.75 5.00 SW TRAV P TRAVEL TO WLB, DROP OFF GAUGES, TRAVEL TO F-WING SYNC CPU / TURN IN WELL FILE. END TICKET. 3R-101 FLUIDS - for CT include "BHA no" + "String Name" into Purpose field Fluid Fluid Sub Type To (bbl) Note DIESEL DISPLACEME NT 35.0 Job: OPTIMIZE WELL Report Date: 5/24/2024 Rig: PW SLICK LINE 56TU - Hoss Page 1/2 3R-101 Report Printed: 6/3/2024 WSR Historical - QC JOB Well Type Development Orig KB/RT (ft) 49.00 Well Status PROD Legal WellName 3R-101 API / UWI 5002923574 Field Name TRACT OPERATION WSAKTR05 Start Date 5/13/2024 14:00 End Date 5/25/2024 22:00 Secondary Job Type CHANGE ARTIFICIAL LIFT TYPE Objective Final Job Status COMPLETED Primary Wellbore Affected 3R-101 NETWORK Job Type Project Desc Common WellName Cost Type Network/Order Number OPTIMIZE WELL 3R-101 RWO - Wells 3R-101 Capitalize 10455438 UNIT/RIG: PW SLICK LINE 56TU - Hoss Rig Accept Date 5/25/2024 Rig Release Date 5/25/2024 Rig Supervisor FERGUSON, SID,Wells Supervisor Title Wells Supervisor Company CPAI Phone W 659-7223 Mobile 943-1065 Pager N/A Job scope, work string information, or noted if job is performed during drilling operations Comment Daily Operations Report Start Date 5/25/2024 06:00 Report End Date 5/25/2024 22:00 Status at Reporting Time 05/26/2024 Time Log Hrs (hr) 16.00 ZX Code ZX36 Artificial Lift Installation / Removal / Main this data box is reviewed daily by engineers, supervisors, and techs. Last 24hr Summary SET 4-1/2" SS-CATCHER 2426' RKB. SET 4-1/2" HOLE FINDER ON TOP OF CATCHER @ 2426' RKB. PULLED AND REPLACED STA # 1-1/2" DMY VLV, W/ 1-1/2" LIVE-GLV ( 3/16" PORT / 1420 TRO, RK LATCH ), OBTAINTED PASSING TBG TEST TO 1500 PSI, PULLED HOLE FINDER, PULLED CATCHER, RDMO. JOB COMPLETE. NOTE: HAD HYDRATES IN THE CATCHER SUB, SUGGESTED PUMPING A HOT FLUSH PRIOR TO BOL. General Remarks INITIAL T/ IA/ OA = 100/ 1200/ 0 FINIAL T/ IA/ OA = 250/ 1145/ 0 weather related data when and if weather has affect on job Weather Wind T (°F) CONTRACTOR Supervisor Title Company Phone Work Mobile Pager GAINEY, TRENT,Slickline Supervisor Slickline Supervisor PW N/A N/A N/A TIME LOG - enter a Vendor if trouble time occurs during operation Start Time End Time Dur (hr) Cum Dur (hr) Major Equip Activity Code Time P-T-X Operation Vendor (NPT) Wellbore 06:00 07:00 1.00 1.00 SW TRAV P MEET W/ CWG-REP, P/U WELL FILE / CPU, P/U HEATER FROM AK-ELINE, CONTACT DSO, TRAVEL TO 3R-PAD. WASH BOARD ROADS. 3R-101 07:00 08:30 1.50 2.50 SW RURD P ARRIVE LOC, TGSM, JSA, R/U .125" WIRE, 1.875" TS = RS, 5', KJ, 5', OJ, KJ, LSS, STANDBY FOR LRS, R/U LRS TO PMP N SUB, TAKE CONTROL OF SSSV. 3R-101 08:30 09:30 1.00 3.50 SW SLKL P PT W/ LRS TO 2500, RIH W/ QC, 4-1/2" GS ( 1/4" BRASS ), 3.70" OD SS CATCHER ( 3/16" BRASS ), OAL = 41" , TOOLS FALL SLOW, SET CATCHER SUB @ 2426' SLM, SEE WT LOSS, POOH. OOH W/ SHEARED GS. 3R-101 09:30 12:00 2.50 6.00 SW SLKL P PT W/ LRS 2500, TBG @ 100 PSI, IA @ 1200 PSI, BLEED DWN IA, PRESSURE FALLS TO 0 PSI, IA HAS NO FLOW, CONFER W/ CWG-REP, VR PLUG STILL INSTALLED IN TREE ON IA, STANDBY FOR CWG-DHD- REP, DSO ON LOC, DMP SSV'S ON IA & FLOW-LINE, DHD-REP ON LOC, CONFIRM VR PLUG IN TREE, STANDBY FOR PLAN FOWARD, CONTACT DSO, TIE INTO VALVE ON AL -LINE ( AL-LINE TRIPLE BLOCKED FROM MANIFOLD BUILDING ), BLEED IA DWN FROM 1377 PSI TO 1160 PSI DWN 3R-105 FLOW-LINE,CWG-REP HOT SHOT TO WLB FOR 4-1/2" HOLE FINDER, SHUT SWAB BLEED -OFF PCE, STANDBY. 3R-101 12:00 13:15 1.25 7.25 SW SLKL P PT W/LRS TO 2500, RIH W/ QC, 4-1/2" GS ( 1/4" BRASS ), 4-1/2" BAIT SUB, GUTTED 3" JD, STUBBY 4-1/2" D & D HOLE FINDER, TOOLS FALL SLOW, SET HF ON TOP OF CATCHER @ 2426' SLM, LRS ONLINE TO PRESSURE UP TBG TO 1500 PSI, TBG HOLDING, BLEED TBG TO 1000 PSI, SHEAR OFF HF, POOH. OOH W/ SHEARED GS. CWG-FIELD-REP ON UNIT. 3R-101 13:15 14:30 1.25 8.50 SW SLKL P PT W/ LRS TO 2500, RIH W/ QC, 4-1/2" OM-1, 7" EXT, 1-5/8" JD, HAVE TROUBLE LOCATING, ABLE TO LOC AND SD @ 2174' SLM / 2198' RKB, UNABLE TO LATCH VALVE, RELOCATING, CWG-REP SUSPECT JD SHEARED, HIT SPANGS TO SKIP PAST LOC SLOT, POOH. OOH JD NOT SHEARED. 3R-101 Job: OPTIMIZE WELL Report Date: 5/25/2024 Rig: PW SLICK LINE 56TU - Hoss Page 2/2 3R-101 Report Printed: 6/3/2024 WSR Historical - QC TIME LOG - enter a Vendor if trouble time occurs during operation Start Time End Time Dur (hr) Cum Dur (hr) Major Equip Activity Code Time P-T-X Operation Vendor (NPT) Wellbore 14:30 16:30 2.00 10.50 SW SLKL P PT W/ LRS TO 2500, RIH W/ QC, 4-1/2" OM-1, 7" EXT, GUTTED 1-5/8" JD, LOC AND SD STA # 1 @ 2174' SLM / 2198' RKB, TAP DWN LATCH VLV, PULL VALVE, TBG DROP FROM 1100 PSI TO 500 PSI, IA @ 1160 PSI NO CHANGE, POOH. OOH W/ 1-1/2" DMY VLV, HOT SHOT TO WLB FOR NEW GLV. STANDBY. 3R-101 16:30 18:15 1.75 12.25 SW SLKL P PT W/ LRS TO 2500, RIH W/ QC, 4-1/2" OM-1, RT, RK LATCH 1-1/2" GLV ( 3/16" PORT / 1420 PSI TRO ) RK LATCH, LOC AND SD STA # 1 @ 2174' SLM / 2198' RKB, SET VLV, SEE TRVL, PRESSURE UP TBG TO 1500 PSI HOLDING, IA @ 1160 PSI NO CHANGE, SHEAR OFF, BLEED TBG BACK TO 500 PSI, POOH. OOH, KOT INDICATES GOOD SET. CWG-FIELD REP ON UNIT. 3R-101 18:15 19:15 1.00 13.25 SW SLKL P PT W/ LRS TO 2500, RIH W/ QC, 4-1/2" GR, SD @ 2418' SLM, LATCH AND PULL BAITED HF, SEE TBG DROP FROM 600 PSI DWN TO 250 PSI, POOH. OOH W/ BAITED 4-1/2" STUBY HOLE-FINDER ELEMENT NOT DAMAGED, CONFER W/ CWG FIELD-REP. 3R-101 19:15 20:15 1.00 14.25 SW SLKL P PT W/ LRS TO 2500, RIH W/ QC, 4-1/2" GR, SD @ 2426' SLM, UNABLE TO LATCH, BEAT DWN, LATCH AND PULL CATCHER, POOH. OOH W/ SS- CATCHER, PACKED OFF WITH HYDRATES. CONFER W/ CWG-REP. 3R-101 20:15 21:15 1.00 15.25 SW RURD P BEGIN RDMO, PJSM, R/D LRS, SECURE WELL, NOTIFY DSO OF WELL STATUS, AND POSSIBLE HOT FLUSH BEFORE BOL WELL, AS PER CWG-REP. 3R-101 21:15 22:00 0.75 16.00 SW TRAV P TRAVEL W/ EQUIP TO HEAVY-LINE, WASH BOARD ROADS, TRAVEL TO F- WING SYNC CPU, TURN IN WELL FILE. END TICKET. 3R-101 Job: OPTIMIZE WELL Report Date: 5/25/2024 Rig: PW SLICK LINE 56TU - Hoss Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 3R-101 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Replaced DMY w/ GLV 3R-101 5/25/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: pproven 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 19.12 39.0 119.0 119.0 62.58 B SURFACE 13 3/8 12.42 41.6 2,243.9 2,165.5 68.00 L-80 HYD563 INTERMEDIATE 9 5/8 8.84 38.9 9,732.2 3,633.6 40.00 L-80 Hyd 521 SEALBORE DIVERTER LATERAL L1 8.48 3.71 9,385.2 9,507.3 3,612.3 WINDOW 5.2 3.96 9,392.0 9,409.6 3,603.6 LEM/SLZXP 4 1/2 3.96 9,223.0 9,407.8 3,603.5 12.60 L-80 IBTm LOWER LATERAL LINER 4 1/2 3.96 9,466.2 15,967.4 3,551.4 12.60 L-80 TXP-m Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth 9,265.8 String Max No 4 1/2 Set Depth 3,597.3 Tubing Description Tubing Completion Upper 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) 34.1 34.1 0.19 Hanger 10.813 Vault 10 3/4" x 4.5" - offset MB228 hanger w/ parent bowl (13 3/8") Vetco Gray MB228 offset 5.750 2,091.8 2,035.8 28.70 Safety valve 6.925 4 1/2" TRMAXX-5E SSSV w/ 3.812" X profile, SN# C22S-0750 SLB TRMaxx -5E 3.813 2,198.6 2,128.0 33.23 Mandrel GAS LIFT 7.033 4 1/2" x 1 1/2" MMRG GLM SN# 24880-01 SLB MMRG 3.865 2,891.0 2,603.1 62.08 Mandrel GAS LIFT 7.036 4 1/2" x 1 1/2" MMRG GLM SN# 24880-02 SLB MMRG 3.865 6,109.2 3,183.1 80.34 Sleeve - Sliding 5.500 NEXA-2, CMU sliding sleeve with 3.813" X profile, SN# 4792048639- 01*05 SLB NEXA-2 3.813 6,175.0 3,193.9 80.60 Sensor - Discharge Gauge 5.685 HES Opsis Gauge Mandrel, SN# MSM19367-05 HES Opsis Gauge 3.920 6,240.1 3,204.6 80.50 Mandrel INJ 5.569 HES Chemical Injection Mandrel, SN# 050632732 HES Chem Injection Mandrel 3.901 6,305.7 3,215.3 80.74 Packer 8.835 4 1/2" x 9 5/8" SLB BluePack Max RH Packer, SN# C21P-0808 SLB BP Max RH 3.867 6,374.2 3,226.3 80.69 Nipple - X 5.203 4 1/2" x 3.813" X nipple, SN# 0004915658-3 HES X Nipple 3.813 9,243.7 3,596.6 88.15 Locator 5.200 Baker locator (No-Go = 4.88") 3.870 9,244.9 3,596.7 88.16 Seal Assembly 4.730 Baker 192-47 Seal Assembly w/ HES ratcheting mule shoe (4' space out), Baker 192-47 3.870 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) 2,198.6 2,128.0 33.23 1 GAS LIFT GLV RK 1 1/2 1,420.0 5/25/2024 SLB MMRG 0.188 2,891.0 2,603.1 62.08 2 GAS LIFT OV RK 1 1/2 0.0 5/14/2024 SLB MMRG 0.250 6,175.0 3,193.9 80.60 3 Opsis Gauge Mandre l 5.68 5 5/7/2024 HES Opsis Gauge 6,240.1 3,204.6 80.50 4 Chemic al Injectio n Mandre l 5.68 5 5/7/2024 HES Chem Inject 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) 9,309.8 3,598.7 88.25 Nipple - DB, XN, DS, D 4.500 4-1/2" Camco DB-6 3.75" Landing Nipple SN# 101742646 Camco PN# 101742646, SN# WO4341-4 3.750 9,380.8 3,601.7 86.52 LEM 6.980 RAM Hanger LEM completion module (Collet to Top LEM) - Baker Comm # H289-06- 0010, SN# 104586419 3.730 9,406.1 3,603.4 85.68 WLEG 5.000 Re-entry Guide 3.730 9,385.2 3,601.9 86.38 Diverter 8.480 Baker Seal Bore Diverter, Position #1, 4-1/2" 12.6 ppf L-80 IBT-m (below collet) Baker SBD 103998246 SN2 3.710 9,457.0 3,607.7 84.94 NIPPLE 4.500 Camco 4-1/2" IBT-m, DB Nipple, 3.562" profile (Baker locked) Camco DB SN# N15N1149 3.562 9,474.6 3,609.2 84.82 Anchor 6.500 Baker MLHR Production Anchor (120ksnap), 4-1/2" IBT b x p (Below) BakerRA M ML 101643333 4 3.900 9,481.2 3,609.8 84.77 XO Threads 4.500 X-O pup jt, 4-1/2" 12.6 ppf L-80 IBT-m box x 4-1/2" STL pin 3.870 MULTIPLE LATERALS, 3R-101, 6/3/2024 12:14:21 PM Vertical schematic (actual) LOWER LATERAL LINER; 9,466.2-15,967.4 SLOTS; 15,305.0-15,824.3 SLOTS; 14,665.0-15,180.7 SLOTS; 13,880.6-14,446.1 SLOTS; 13,176.9-13,717.3 SLOTS; 12,446.2-12,956.6 SLOTS; 11,754.7-12,282.9 SLOTS; 11,032.5-11,437.7 SLOTS; 10,345.1-10,869.2 INTERMEDIATE; 38.9-9,732.2 UPPER LATERAL LINER w/ RAM hanger; 9,380.5-15,863.9 SLOTS; 9,627.9-10,356.6 SEALBORE DIVERTER LATERAL L1; 9,385.2-9,507.3 WINDOW; 9,392.0-9,409.6 LEM/SLZXP; 9,223.0-9,407.8 Seal Assembly; 9,244.9 Nipple - X; 6,374.2 Packer; 6,305.7 Mandrel INJ; 6,240.1 Sensor - Discharge Gauge; 6,175.0 Sleeve - Sliding; 6,109.1 Mandrel GAS LIFT; 2,891.0 SURFACE; 41.6-2,243.9 Mandrel GAS LIFT; 2,198.6 Safety valve; 2,091.7 CONDUCTOR; 39.0-119.0 Hanger; 34.1 KUP PROD KB-Grd (ft) 39.10 RR Date 4/28/2017 Other Elev 3R-101 ... TD Act Btm (ftKB) 16,433.0 Well Attributes Field Name Wellbore API/UWI 500292357400 Wellbore Status PROD Max Angle & MD Incl (°) 98.19 MD (ftKB) 16,346.29 WELLNAME WELLBORE3R-101 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE 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) 9,466.2 3,608.5 84.88 PACKER 7.000 Baker MLZXP Liner hanger packer 7" X 9 5/8", 7" 29# Hydril 563 pin dn Baker Comm No.: H296-33- 0023, control # 105629670- 01 6.090 9,492.7 3,610.9 84.69 XO REDUCING 7.000 XO 7" 29# Hydril 563 box X 5 1/2" 15.5# Hydril 563 pin 4.900 9,513.8 3,612.9 84.54 XO Thread 5.500 Crossover, 5-1/2" 15.5 ppf Hyd 563 box x 4-1/2" 12.6 ppf L-80 TXP pin 3.970 10,294.1 3,605.9 93.72 Swell Packer 8.250 Baker swell packer, 4-1/2" x 8.25" "F" S/N - 0531-61-001-3 Baker PN: H301- 87-0437, ser # 053161-001 -3 3.970 10,304.1 3,605.2 93.77 XO Thread 4.500 X-O 'Pup Joint, 4-1/2", 12.6 ppf, L- 80, TXP-m Box x Hyd 563 pin 3.958 10,314.0 3,604.6 93.64 XO Thread 4.500 Crossover 4-1/2" 12.6 ppf, L-80 Hyd 563 box x 5-1/2" 15.5 ppf L- 80 Hyd 511 Box Tracerco 3.958 10,335.0 3,603.3 93.16 XO Thread 4.500 Crossover 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 12.6 ppf L- 80 Hyd 563 pin Tracerco 3.958 10,335.8 3,603.3 93.15 XO Thread 4.500 X-O Pup Joint, 4-1/2", 12.6 ppf, L- 80 Hyd 563 Pin x TXP pin 3.958 11,443.8 3,595.1 88.68 Swell Packer 8.250 Baker swell packer, 4-1/2" x 8.25" "E" S/N - 0531-61-001-1 Baker PN: H301- 87-0437, ser # 053161-001 -1 3.960 11,703.5 3,593.3 92.74 Swell Packer 8.250 Baker swell packer, 4-1/2" x 8.25" "D" S/N - 0531-61-001-4 Baker PN: H301- 87-0437, ser # 053161-001 -4 3.960 11,713.6 3,592.8 92.88 XO Thread 4.500 X-O 'Pup Joint, 4-1/2", 12.6 ppf, L- 80, TXP-m Box x Hyd 563 pin 3.958 11,723.4 3,592.3 93.01 XO Thread 4.500 Crossover 4-1/2" 12.6 ppf, L-80 Hyd 563 box x 5-1/2" 15.5 ppf L- 80 Hyd 511 Box Tracerco 3.958 11,744.4 3,591.2 92.74 XO Thread 4.500 Crossover 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 12.6 ppf L- 80 Hyd 563 pin Tracerco 3.958 11,745.2 3,591.2 92.72 XO Thread 4.500 X-O Pup Joint, 4-1/2", 12.6 ppf, L- 80 Hyd 563 Pin x TXP pin 3.958 13,125.6 3,592.5 89.57 Swell Packer 8.240 Baker swell packer, 4-1/2" x 8.25" "C" S/N - 053161-001-6 Baker PN: H301- 87-0437, ser # 053161-001 -6 3.960 13,135.7 3,592.6 89.60 XO Thread 4.500 X-O 'Pup Joint, 4-1/2", 12.6 ppf, L- 80, TXP-m Box x Hyd 563 pin 3.958 13,145.6 3,592.6 89.62 XO Thread 4.500 Crossover 4-1/2" 12.6 ppf, L-80 Hyd 563 box x 5-1/2" 15.5 ppf L- 80 Hyd 511 Box Tracerco 3.958 13,166.5 3,592.8 89.66 XO Thread 4.500 Crossover 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 12.6 ppf L- 80 Hyd 563 pin Tracerco 3.958 13,167.3 3,592.8 89.66 XO Thread 4.500 X-O Pup Joint, 4-1/2", 12.6 ppf, L- 80 Hyd 563 Pin x TXP pin 3.958 14,614.2 3,579.4 90.67 Swell Packer 8.250 Baker swell packer, 4-1/2" x 8.25" "B" S/N - 053161-001-7 Baker PN: H301- 87-0437, ser # 053161-001 -7 3.980 14,624.2 3,579.2 90.74 XO Thread 4.500 X-O 'Pup Joint, 4-1/2", 12.6 ppf, L- 80, TXP-m Box x Hyd 563 pin 3.958 14,633.7 3,579.1 90.80 XO Thread 4.500 Crossover 4-1/2" 12.6 ppf, L-80 Hyd 563 box x 5-1/2" 15.5 ppf L- 80 Hyd 511 Box Tracerco 3.958 14,654.6 3,578.8 90.95 XO Thread 4.500 Crossover 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 12.6 ppf L- 80 Hyd 563 pin Tracerco 3.958 14,655.4 3,578.8 90.96 XO Thread 4.500 X-O Pup Joint, 4-1/2", 12.6 ppf, L- 80 Hyd 563 Pin x TXP pin 3.958 15,830.4 3,554.6 91.96 Swell Packer 8.250 Baker swell packer, 4-1/2" x 8.25" "A" S/N - 053161-001-2 Baker PN: H301- 87-0437, ser # 053161-001 -2 3.970 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,345.1 10,869.2 3,602.8 3,588.4 4/12/2017 32.0 SLOTS 11,032.5 11,437.7 3,589.3 3,594.9 4/12/2017 32.0 SLOTS 11,754.7 12,282.9 3,590.7 3,589.1 4/12/2017 32.0 SLOTS 12,446.2 12,956.6 3,587.3 3,590.8 4/12/2017 32.0 SLOTS 13,176.9 13,717.3 3,592.8 3,587.5 4/12/2017 32.0 SLOTS 13,880.6 14,446.1 3,584.2 3,580.3 4/12/2017 32.0 SLOTS 14,665.0 15,180.7 3,578.6 3,573.9 4/12/2017 32.0 SLOTS 15,305.0 15,824.3 3,574.0 3,554.8 4/12/2017 32.0 SLOTS MULTIPLE LATERALS, 3R-101, 6/3/2024 12:14:22 PM Vertical schematic (actual) LOWER LATERAL LINER; 9,466.2-15,967.4 SLOTS; 15,305.0-15,824.3 SLOTS; 14,665.0-15,180.7 SLOTS; 13,880.6-14,446.1 SLOTS; 13,176.9-13,717.3 SLOTS; 12,446.2-12,956.6 SLOTS; 11,754.7-12,282.9 SLOTS; 11,032.5-11,437.7 SLOTS; 10,345.1-10,869.2 INTERMEDIATE; 38.9-9,732.2 UPPER LATERAL LINER w/ RAM hanger; 9,380.5-15,863.9 SLOTS; 9,627.9-10,356.6 SEALBORE DIVERTER LATERAL L1; 9,385.2-9,507.3 WINDOW; 9,392.0-9,409.6 LEM/SLZXP; 9,223.0-9,407.8 Seal Assembly; 9,244.9 Nipple - X; 6,374.2 Packer; 6,305.7 Mandrel INJ; 6,240.1 Sensor - Discharge Gauge; 6,175.0 Sleeve - Sliding; 6,109.1 Mandrel GAS LIFT; 2,891.0 SURFACE; 41.6-2,243.9 Mandrel GAS LIFT; 2,198.6 Safety valve; 2,091.7 CONDUCTOR; 39.0-119.0 Hanger; 34.1 KUP PROD 3R-101 ... WELLNAME WELLBORE3R-101 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 16433'None Casing Collapse Conductor Surface Intermediate Lower Lateral Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 10345-10869' 11033-11438' 11755-12283' 12446-12957' 13177-13713' 13881-14446' 14665-15181' 15305-15824' 6501' 3603-3588' 3589-3595' 3591-3589' 3587-3591' 3593-3588' 3584-3580' 3579-3574' 3574-3555' 4-1/2" 4-1/2" 20" 13-3/8" 80' 2205' Perforation Depth MD (ft): 9-5/8"9693' MD 115' 2166' 3634' 119' 2244' 3551'15967' 9732' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 3635'16433'3635'814 None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355023, ADL0355024 217-013 P.O. Box 100360, Anchorage, AK 99510 50-029-23574-00-00 ConocoPhillips Alaska, Inc. KRU 3R-101 NoneWest Sak Oil Pool Kuparuk River Field N/A Tubing Grade:Tubing MD (ft): Packer: 9466'MD/3609'TVD SSSV: None Perforation Depth TVD (ft):Tubing Size: L-80 7323' 4/10/2024 Packer: Backer MLZXP SSSV: None 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Shane Germann shane.germann@conocophillips.com (907) 263-4597 CTD/RWO Engineer P s 66 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:55 am, Mar 04, 2024 Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann , E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2024.03.04 09:42:44-09'00' Foxit PDF Editor Version: 13.0.0 324-129 DSR-3/4/24 SFD Obsolete form. SFD 3511' SFD 3/4/2024 X 10-404 X BOP test to 2500 psig Annular preventer test to 2500 psig VTL 3/6/2024 JLC 3/6/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.03.06 13:31:06 -09'00'03/06/24 RBDMS JSB 030724 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 29, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Shane Germann Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 3R-101 (PTD# 217-013). Well 3R-101 was drilled and completed in April of 2017 by Parker 141 as a West Sak D/B sands dual lateral producer. In 2023 the well became a RWO candidate due to multiple identified tubing leaks. If you have any questions or require any further information, please contact me at +1-406-670-1939. In order to bring the well back online we request approval to proceed with a RWO to replace the tubing. The well will be set up for gas lift. Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E=shane.germann@ conocophillips.com Reason: I have reviewed this document Location: Date: 2024.03.04 09:43:09-09'00' Foxit PDF Editor Version: 13.0.0 3R-101 RWO Procedure West Sak Producer P&R Tubing PTD #217-013 Page 1 of 2 Pre-Rig Work 1. T-PPPOT, T-POT, IC-PPPOT, and IC-POT tests. 2. Pull ESP. 3. Measure SBHP. 4. Prepare well within 48-96 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3R-101. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve 4-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing spooling ESP cable and TEC wire (packerless ESP completion, total depth of ~7323’ RKB). Cleanout Run and Test Packer Run 6. Perform a Cleanout run to sealbore extension at ~9246’ RKB. 7. MU test packer and confirm casing integrity down to SBE. Locate leaks as necessary. 8. POOH laying down DP. Install 4-½” Tubing Gas Lift Completion 9. MU 4 ½” completion with seal assembly, nipples, chemical injection mandrel, DH gauge, GLM’s, and SSSV. RIH to SBE. a. Contingency plan is to run packer completion if unable to confirm casing integrity down to and including SBE. 10. Once on depth, circulate CI brine, stab seals into SBE and space out as needed, land hanger, RILDS, and drop B&R if needed. 11. Pressure test tubing to 3,000 psig for 30 minutes and chart. 12. Pressure test inner annulus to 2,500 psig for 30 minutes and chart. ND BOP, NU Tree 13. Confirm pressure tests, then shear out SOV with pressure differential. 14. Install BPV. 15. ND BOPE. NU tree. 16. Pull BPV and freeze protect well. 17. RDMO. Post-Rig Work 18. Run GLD. Pull any plugs or ball/rod used for testing tubing. 3R-101 RWO Procedure West Sak Producer P&R Tubing PTD #217-013 Page 2 of 2 General Well info: Wellhead type/pressure rating: Vault PC (Vetco Gray) MB-222A Horizontal, 5M psi top and bottom flange Production Engineer: Will Parker Reservoir Development Engineer: Miriam Walker Estimated Start Date: 4/10/2024 Workover Engineer: Shane Germann (406-670-1939 / shane.germann@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 4-1/2” packerless ESP completion, install a new 4-1/2” gas lift completion. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T N/A (tubing leaks) MIT-IA Passed 6/6/2023 (gas, packerless producer) MIT-OA N/A IC POT &PPPOT PASSED – 2/18/2024 TBG POT &PPPOT PASSED – 2/18/2024 MPSP: 814 psi using 0.1 psi/ft gradient Static BHP: 827 psi / 2720’ TVD measured on 11/15/2023 + 0.393 psi/ft estimated gradient between pressure measurement and top of L1 window at 3602’ TVD (1174 psi, 6.3 ppg) Co n v e n t i o n a l E S P – w i r e l i n e r e t r i e v a b l e p u m p / t u b i n g c o n v e y e d m o t o r . @ 7 , 3 2 3 ' M D / 3 , 4 0 4 ' T V D @ 7 9 ° i n c In s u l a t e d C o n d u c t o r C a s i n g , 2 0 " , 94 # , K 5 5 x 3 4 " , 0 . 3 1 2 " W T @ + / - 1 0 8 ' M D 13 - 3 / 8 " , 6 8 # , L - 8 0 , H y d r i l - 5 6 3 @ 2 , 2 4 4 ' M D / 2 , 1 6 6 ' T V D @ 3 5 ° i n c T D 1 6 " h o l e 9- 5 / 8 " , 4 0 # , L - 8 0 , H y d r i l 5 6 3 & 5 2 1 @ 9 , 7 3 2 ' M D / 3 , 6 3 5 ' T V D TD 1 2 - 1 / 4 " h o l e @ 8 8 . 6 ͼ i n c . We l l h e a d / T u b i n g H e a d / T r e e , 13 - 3 / 8 " x 4 - ½ " , 5 , 0 0 0 p s i 3R-101 Well Schematic (Dual Lateral)_Actual.vsd Tolman 5/25/2017 3R-101 Well Design (Dual Lateral) Tu b i n g S t r i n g : 4 - 1 / 2 " , 1 2 . 6 # , L - 8 0 , T X P 8- 3 / 4 ” D s a n d l a t e r a l TD @ 1 6 , 4 3 3 ' M D / 3 , 5 1 1 ' T V D 6, 6 9 0 ' f t L a t e r a l l e n g t h ML Z X P P a c k e r f o r m a i n b o r e @ 9 , 4 6 6 ' M D Ga s L i f t M a n d r e l , 4 - 1 / 2 " x 1 - 1 / 2 " w / n o v a l v e s @ 2 5 6 7 ' M D / 2 , 4 7 3 ' T V D @ 5 0 ° i n c 3. 5 6 2 " L a n d i n g n i p p l e p r o f i l e @ 9 4 5 7 ' M D ( S B D ) Se a l b o r e D i v e r t e r ( S B D ) P O S - 1 Ba k e r S L Z X P P a c k e r @ ~ 9 , 2 2 3 ' M D / 3 , 5 9 6 ' T V D @ 8 8 ° i n c Do w n h o l e G a u g e - D i s c h a r g e a n d I n t a k e B a c k u p @ 7 , 2 1 6 ' M D Ga s L i f t M a n d r e l , 4 - 1 / 2 " x 1 - 1 / 2 " w / d u m m y v a l v e @ 7 , 1 5 4 ' M D / 3 , 3 7 0 ' T V D @ 7 8 ° i n c Le v e l - 3 M L J u n c t i o n S y s t e m Tu b i n g S e a l A s s e m b l y 8- 3 / 4 ” D s a n d l a t e r a l TD @ 1 5 , 8 9 6 ' M D / 3 , 5 4 0 ' T V D 6, 5 0 4 ' f t L a t e r a l l e n g t h L1 W i n d o w T o p @ 9 , 3 9 2 ' M D / 3 , 6 0 2 . 4 ' T V D @ 8 6 . 1 5 ° i n c L1 W i n d o w B t m @ 9 , 4 1 0 ' M D / 3 6 0 3 . 2 ' T V D @ 8 8 . 2 9 ° i n c La t e r a l E n t r y M o d u l e P O S - 1 Oi l & W a t e r T r a c e r C a r t r i d g e @ 10 , 3 1 5 ' , 1 1 , 7 2 4 ' , 1 3 , 1 4 6 ' , & 1 4 , 6 3 4 ' 3R - 1 0 1 D u a l L a t e r a l P r o d u c e r (A s R a n ) 4- 1 / 2 " , 1 2 . 6 # L 8 0 , T X P , S l o t t e d L i n e r 15 , 8 6 4 ' M D / 3 , 5 4 6 ' T V D 4- 1 / 2 " , 1 2 . 6 # L 8 0 , T X P , S l o t t e d L i n e r 15 , 9 6 7 ' M D / 3 , 5 5 3 ' T V D ML H R P r o d A n c h o r 3. 7 5 0 " L a n d i n g n i p p l e p r o f i l e @ 9 , 3 1 0 ' ( L E M ) 4- ½ ” x 8 - ¼ ” O D S w e l l P a c k e r @ 1 0 , 2 9 4 ' , 1 0 , 4 4 4 , 1 1 , 7 0 4 ' , 1 3 , 1 2 6 ' , 1 4 , 6 1 4 ' , & 1 5 , 8 3 0 ' Oi l & W a t e r T r a c e r C a r t r i d g e @ 9, 5 9 7 ' & 1 2 , 3 3 0 ' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:3R-101 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull RBP and Leak Detect 3R-101 11/17/2023 famaj Notes: General & Safety Annotation End Date Last Mod By NOTE:pproven 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 19.12 39.0 119.0 119.0 62.58 B SURFACE 13 3/8 12.42 41.6 2,243.9 2,165.5 68.00 L-80 HYD563 INTERMEDIATE 9 5/8 8.84 38.9 9,732.2 3,633.6 40.00 L-80 Hyd 521 SEALBORE DIVERTER LATERAL L1 8.48 3.71 9,385.2 9,507.3 3,612.3 WINDOW 5.2 3.96 9,392.0 9,409.6 3,603.6 LEM/SLZXP 4 1/2 3.96 9,223.0 9,407.8 3,603.5 12.60 L-80 IBTm LOWER LATERAL LINER 4 1/2 3.96 9,466.2 15,967.4 3,551.4 12.60 L-80 TXP-m Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 34.0 Set Depth … 7,322.9 Set Depth … 3,404.0 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP 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) 34.0 34.0 0.19 HANGER 13.375 Vetco Gray 10-3/4" x 4.5" - offset MB228 hanger w/ parent bowl(13- 3/8") GE Vetco MB228 Offset, ser # 3.958 2,566.8 2,412.9 46.60 GAS LIFT 6.438 Camco 4-1/2" x 1" KBMG GLM ( 2412' TVD) Camco KBMG 3.860 7,154.5 3,370.1 77.74 GAS LIFT 6.438 Camco 4-1/2" x 1" KBMG GLM ( 3370' TVD) Camco MMG 3.860 7,216.1 3,382.8 78.26 Gauge / Pump Sensor 4.500 Centrilift Discharge Guage Unit , EUE Centrilift PN: PWLE00 16, SN: 1365745 4.00 3.854 7,283.8 3,396.4 78.68 ESP Pumps 4.500 Centralift Base Receiving, RCVG GAS DISSP 513 SEAL , 4.5" NSCT sn# 13237500 Centrilift PN: C30880 9 SN:1323 7500 3.958 7,294.3 3,398.4 78.73 ESP Pumps 5.130 Centrilift Seal, ESP, GSB3DB UT FER HL H6 SN# 13964711 Centrilift PN: C30916 0, SN: 1396471 1 7,301.2 3,399.8 78.76 ESP Pumps 5.130 Centrilift Seal, ESP, GSB3DB LT FER HL H6 SN# 13967409 Centrilift PN: C30916 1, SN:1396 7409 7,308.1 3,401.1 78.79 ESP Motors & Cables 5.620 Centrilift Motor 562XP 150/ 2420/ 38_42/ 1055 06R SN# 14138727 Centrilift PN: 1051003 89, MM: 1377071 3, SN: 1413872 7 7,319.1 3,403.2 78.84 ESP Motors & Cables 4.500 Centrilift Motor Guage Kit SN# 192- 01048 Centrilift PN: PWLE90 001, MM: 1338574 1, SN: 192- 01048 7,321.0 3,403.6 78.85 ESP Motors & Cables 5.850 2-3/8" Centrilift Motor Centralzier (5.85" OD) Centrilift PN: C63569, MM: 1324476 4 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) 3,134.0 2,696.9 72.51 LEAK - TUBING Found leak with invertible test tool between 3,134'-3,137'. Likely additional leaks below this depth. 11/14/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,566.8 2,412.9 46.60 1 GAS LIFT SOV 1 0.0 8/4/2017 2000# Shear 0.000 7,154.5 3,370.1 77.74 2 GAS LIFT DMY BK 1 1/2 0.0 4/28/2017 0.000 MULTIPLE LATERALS, 3R-101, 11/17/2023 3:25:21 PM Vertical schematic (actual) LOWER LATERAL LINER; 9,466.2-15,967.4 Shoe; 15,965.5-15,967.4 Swell Packer; 15,830.4-15,837.0 SLOTS; 15,305.0-15,824.3 SLOTS; 14,665.0-15,180.7 XO Thread; 14,654.6-14,655.4 Screen; 14,634.4-14,654.6 XO Thread; 14,633.7-14,634.4 Swell Packer; 14,614.2-14,620.9 SLOTS; 13,880.6-14,446.1 SLOTS; 13,176.9-13,717.3 XO Thread; 13,166.5-13,167.3 Screen; 13,146.3-13,166.5 XO Thread; 13,145.6-13,146.3 Swell Packer; 13,125.6-13,132.3 SLOTS; 12,446.2-12,956.6 SLOTS; 11,754.7-12,282.9 XO Thread; 11,744.4-11,745.1 Screen; 11,724.2-11,744.4 XO Thread; 11,723.4-11,724.2 Swell Packer; 11,703.5-11,710.2 Swell Packer; 11,443.8-11,450.5 SLOTS; 11,032.5-11,437.7 SLOTS; 10,345.1-10,869.2 XO Thread; 10,335.0-10,335.8 Screen; 10,314.8-10,335.0 XO Thread; 10,314.0-10,314.8 Swell Packer; 10,294.1-10,300.8 INTERMEDIATE; 38.9-9,732.2 UPPER LATERAL LINER w/ RAM hanger; 9,380.5-15,863.9 SLOTS; 9,627.9-10,356.6 XO Thread; 9,617.6-9,618.3 Screen; 9,597.4-9,617.6 XO Thread; 9,596.6-9,597.4 XO Thread; 9,513.8-9,515.0 SEALBORE DIVERTER LATERAL L1; 9,385.2-9,507.3 SEAL ASSY; 9,504.1-9,507.3 Seal Bore Extension; 9,494.1- 9,513.8 XO REDUCING; 9,492.7- 9,494.1 XO Threads; 9,481.2-9,504.1 PACKER; 9,466.2-9,492.7 Anchor; 9,474.6-9,481.2 NIPPLE; 9,457.0-9,459.0 XO Thread; 9,417.3-9,419.1 WINDOW; 9,392.0-9,409.6 LEM/SLZXP; 9,223.0-9,407.8 WLEG; 9,406.1-9,407.8 Window; 9,392.0-9,409.6 Diverter; 9,385.2-9,413.1 HANGER; 9,380.5-9,417.3 LEM; 9,380.8-9,406.1 Nipple - DB, XN, DS, D; 9,309.8- 9,311.9 XO Reducing (Casing); 9,266.0- 9,267.4 Seal Bore Extension; 9,246.3- 9,266.0 XO Reducing (Casing); 9,244.9- 9,246.3 Liner Top Packer; 9,223.0- 9,244.9 ESP Motors & Cables; 7,321.0 ESP Motors & Cables; 7,319.1 ESP Motors & Cables; 7,308.1 ESP Pumps; 7,301.2 ESP Pumps; 7,294.3 ESP Pumps; 7,283.8 Gauge / Pump Sensor; 7,216.1 GAS LIFT; 7,154.5 LEAK - TUBING; 3,134.0 GAS LIFT; 2,566.8 SURFACE; 41.6-2,243.9 Float Shoe; 2,240.7-2,243.9 CONDUCTOR; 39.0-119.0 HANGER; 34.0 KUP PROD KB-Grd (ft) 39.10 RR Date 4/28/2017 Other Elev… 3R-101 ... TD Act Btm (ftKB) 16,433.0 Well Attributes Field Name Wellbore API/UWI 500292357400 Wellbore Status PROD Max Angle & MD Incl (°) 98.19 MD (ftKB) 16,346.29 WELLNAME WELLBORE3R-101 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE 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) 9,309.8 3,598.7 88.25 Nipple - DB, XN, DS, D 4.500 4-1/2" Camco DB-6 3.75" Landing Nipple SN# 101742646 Camco PN# 101742646, SN# WO4341-4 3.750 9,380.8 3,601.7 86.52 LEM 6.980 RAM Hanger LEM completion module (Collet to Top LEM) - Baker Comm # H289-06- 0010, SN# 104586419 3.730 9,406.1 3,603.4 85.68 WLEG 5.000 Re-entry Guide 3.730 9,385.2 3,601.9 86.38 Diverter 8.480 Baker Seal Bore Diverter, Position #1, 4-1/2" 12.6 ppf L-80 IBT-m (below collet) Baker SBD 103998246 SN2 3.710 9,457.0 3,607.7 84.94 NIPPLE 4.500 Camco 4-1/2" IBT-m, DB Nipple, 3.562" profile (Baker locked) Camco DB SN# N15N1149 3.562 9,474.6 3,609.2 84.82 Anchor 6.500 Baker MLHR Production Anchor (120ksnap), 4-1/2" IBT b x p (Below) BakerRA M ML 101643333 4 3.900 9,481.2 3,609.8 84.77 XO Threads 4.500 X-O pup jt, 4-1/2" 12.6 ppf L-80 IBT-m box x 4-1/2" STL pin 3.870 9,466.2 3,608.5 84.88 PACKER 7.000 Baker MLZXP Liner hanger packer 7" X 9 5/8", 7" 29# Hydril 563 pin dn Baker Comm No.: H296-33- 0023, control # 105629670- 01 6.090 9,492.7 3,610.9 84.69 XO REDUCING 7.000 XO 7" 29# Hydril 563 box X 5 1/2" 15.5# Hydril 563 pin 4.900 9,513.8 3,612.9 84.54 XO Thread 5.500 Crossover, 5-1/2" 15.5 ppf Hyd 563 box x 4-1/2" 12.6 ppf L-80 TXP pin 3.970 10,294.1 3,605.9 93.72 Swell Packer 8.250 Baker swell packer, 4-1/2" x 8.25" "F" S/N - 0531-61-001-3 Baker PN: H301- 87-0437, ser # 053161-001 -3 3.970 10,304.1 3,605.2 93.77 XO Thread 4.500 X-O 'Pup Joint, 4-1/2", 12.6 ppf, L- 80, TXP-m Box x Hyd 563 pin 3.958 10,314.0 3,604.6 93.64 XO Thread 4.500 Crossover 4-1/2" 12.6 ppf, L-80 Hyd 563 box x 5-1/2" 15.5 ppf L- 80 Hyd 511 Box Tracerco 3.958 10,335.0 3,603.3 93.16 XO Thread 4.500 Crossover 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 12.6 ppf L- 80 Hyd 563 pin Tracerco 3.958 10,335.8 3,603.3 93.15 XO Thread 4.500 X-O Pup Joint, 4-1/2", 12.6 ppf, L- 80 Hyd 563 Pin x TXP pin 3.958 11,443.8 3,595.1 88.68 Swell Packer 8.250 Baker swell packer, 4-1/2" x 8.25" "E" S/N - 0531-61-001-1 Baker PN: H301- 87-0437, ser # 053161-001 -1 3.960 11,703.5 3,593.3 92.74 Swell Packer 8.250 Baker swell packer, 4-1/2" x 8.25" "D" S/N - 0531-61-001-4 Baker PN: H301- 87-0437, ser # 053161-001 -4 3.960 11,713.6 3,592.8 92.88 XO Thread 4.500 X-O 'Pup Joint, 4-1/2", 12.6 ppf, L- 80, TXP-m Box x Hyd 563 pin 3.958 11,723.4 3,592.3 93.01 XO Thread 4.500 Crossover 4-1/2" 12.6 ppf, L-80 Hyd 563 box x 5-1/2" 15.5 ppf L- 80 Hyd 511 Box Tracerco 3.958 11,744.4 3,591.2 92.74 XO Thread 4.500 Crossover 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 12.6 ppf L- 80 Hyd 563 pin Tracerco 3.958 11,745.2 3,591.2 92.72 XO Thread 4.500 X-O Pup Joint, 4-1/2", 12.6 ppf, L- 80 Hyd 563 Pin x TXP pin 3.958 13,125.6 3,592.5 89.57 Swell Packer 8.240 Baker swell packer, 4-1/2" x 8.25" "C" S/N - 053161-001-6 Baker PN: H301- 87-0437, ser # 053161-001 -6 3.960 13,135.7 3,592.6 89.60 XO Thread 4.500 X-O 'Pup Joint, 4-1/2", 12.6 ppf, L- 80, TXP-m Box x Hyd 563 pin 3.958 13,145.6 3,592.6 89.62 XO Thread 4.500 Crossover 4-1/2" 12.6 ppf, L-80 Hyd 563 box x 5-1/2" 15.5 ppf L- 80 Hyd 511 Box Tracerco 3.958 13,166.5 3,592.8 89.66 XO Thread 4.500 Crossover 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 12.6 ppf L- 80 Hyd 563 pin Tracerco 3.958 13,167.3 3,592.8 89.66 XO Thread 4.500 X-O Pup Joint, 4-1/2", 12.6 ppf, L- 80 Hyd 563 Pin x TXP pin 3.958 14,614.2 3,579.4 90.67 Swell Packer 8.250 Baker swell packer, 4-1/2" x 8.25" "B" S/N - 053161-001-7 Baker PN: H301- 87-0437, ser # 053161-001 -7 3.980 14,624.2 3,579.2 90.74 XO Thread 4.500 X-O 'Pup Joint, 4-1/2", 12.6 ppf, L- 80, TXP-m Box x Hyd 563 pin 3.958 14,633.7 3,579.1 90.80 XO Thread 4.500 Crossover 4-1/2" 12.6 ppf, L-80 Hyd 563 box x 5-1/2" 15.5 ppf L- 80 Hyd 511 Box Tracerco 3.958 14,654.6 3,578.8 90.95 XO Thread 4.500 Crossover 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 12.6 ppf L- 80 Hyd 563 pin Tracerco 3.958 14,655.4 3,578.8 90.96 XO Thread 4.500 X-O Pup Joint, 4-1/2", 12.6 ppf, L- 80 Hyd 563 Pin x TXP pin 3.958 15,830.4 3,554.6 91.96 Swell Packer 8.250 Baker swell packer, 4-1/2" x 8.25" "A" S/N - 053161-001-2 Baker PN: H301- 87-0437, ser # 053161-001 -2 3.970 MULTIPLE LATERALS, 3R-101, 11/17/2023 3:25:22 PM Vertical schematic (actual) LOWER LATERAL LINER; 9,466.2-15,967.4 Shoe; 15,965.5-15,967.4 Swell Packer; 15,830.4-15,837.0 SLOTS; 15,305.0-15,824.3 SLOTS; 14,665.0-15,180.7 XO Thread; 14,654.6-14,655.4 Screen; 14,634.4-14,654.6 XO Thread; 14,633.7-14,634.4 Swell Packer; 14,614.2-14,620.9 SLOTS; 13,880.6-14,446.1 SLOTS; 13,176.9-13,717.3 XO Thread; 13,166.5-13,167.3 Screen; 13,146.3-13,166.5 XO Thread; 13,145.6-13,146.3 Swell Packer; 13,125.6-13,132.3 SLOTS; 12,446.2-12,956.6 SLOTS; 11,754.7-12,282.9 XO Thread; 11,744.4-11,745.1 Screen; 11,724.2-11,744.4 XO Thread; 11,723.4-11,724.2 Swell Packer; 11,703.5-11,710.2 Swell Packer; 11,443.8-11,450.5 SLOTS; 11,032.5-11,437.7 SLOTS; 10,345.1-10,869.2 XO Thread; 10,335.0-10,335.8 Screen; 10,314.8-10,335.0 XO Thread; 10,314.0-10,314.8 Swell Packer; 10,294.1-10,300.8 INTERMEDIATE; 38.9-9,732.2 UPPER LATERAL LINER w/ RAM hanger; 9,380.5-15,863.9 SLOTS; 9,627.9-10,356.6 XO Thread; 9,617.6-9,618.3 Screen; 9,597.4-9,617.6 XO Thread; 9,596.6-9,597.4 XO Thread; 9,513.8-9,515.0 SEALBORE DIVERTER LATERAL L1; 9,385.2-9,507.3 SEAL ASSY; 9,504.1-9,507.3 Seal Bore Extension; 9,494.1- 9,513.8 XO REDUCING; 9,492.7- 9,494.1 XO Threads; 9,481.2-9,504.1 PACKER; 9,466.2-9,492.7 Anchor; 9,474.6-9,481.2 NIPPLE; 9,457.0-9,459.0 XO Thread; 9,417.3-9,419.1 WINDOW; 9,392.0-9,409.6 LEM/SLZXP; 9,223.0-9,407.8 WLEG; 9,406.1-9,407.8 Window; 9,392.0-9,409.6 Diverter; 9,385.2-9,413.1 HANGER; 9,380.5-9,417.3 LEM; 9,380.8-9,406.1 Nipple - DB, XN, DS, D; 9,309.8- 9,311.9 XO Reducing (Casing); 9,266.0- 9,267.4 Seal Bore Extension; 9,246.3- 9,266.0 XO Reducing (Casing); 9,244.9- 9,246.3 Liner Top Packer; 9,223.0- 9,244.9 ESP Motors & Cables; 7,321.0 ESP Motors & Cables; 7,319.1 ESP Motors & Cables; 7,308.1 ESP Pumps; 7,301.2 ESP Pumps; 7,294.3 ESP Pumps; 7,283.8 Gauge / Pump Sensor; 7,216.1 GAS LIFT; 7,154.5 LEAK - TUBING; 3,134.0 GAS LIFT; 2,566.8 SURFACE; 41.6-2,243.9 Float Shoe; 2,240.7-2,243.9 CONDUCTOR; 39.0-119.0 HANGER; 34.0 KUP PROD 3R-101 ... WELLNAME WELLBORE3R-101 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,345.1 10,869.2 3,602.8 3,588.4 4/12/2017 32.0 SLOTS 11,032.5 11,437.7 3,589.3 3,594.9 4/12/2017 32.0 SLOTS 11,754.7 12,282.9 3,590.7 3,589.1 4/12/2017 32.0 SLOTS 12,446.2 12,956.6 3,587.3 3,590.8 4/12/2017 32.0 SLOTS 13,176.9 13,717.3 3,592.8 3,587.5 4/12/2017 32.0 SLOTS 13,880.6 14,446.1 3,584.2 3,580.3 4/12/2017 32.0 SLOTS 14,665.0 15,180.7 3,578.6 3,573.9 4/12/2017 32.0 SLOTS 15,305.0 15,824.3 3,574.0 3,554.8 4/12/2017 32.0 SLOTS MULTIPLE LATERALS, 3R-101, 11/17/2023 3:25:23 PM Vertical schematic (actual) LOWER LATERAL LINER; 9,466.2-15,967.4 Shoe; 15,965.5-15,967.4 Swell Packer; 15,830.4-15,837.0 SLOTS; 15,305.0-15,824.3 SLOTS; 14,665.0-15,180.7 XO Thread; 14,654.6-14,655.4 Screen; 14,634.4-14,654.6 XO Thread; 14,633.7-14,634.4 Swell Packer; 14,614.2-14,620.9 SLOTS; 13,880.6-14,446.1 SLOTS; 13,176.9-13,717.3 XO Thread; 13,166.5-13,167.3 Screen; 13,146.3-13,166.5 XO Thread; 13,145.6-13,146.3 Swell Packer; 13,125.6-13,132.3 SLOTS; 12,446.2-12,956.6 SLOTS; 11,754.7-12,282.9 XO Thread; 11,744.4-11,745.1 Screen; 11,724.2-11,744.4 XO Thread; 11,723.4-11,724.2 Swell Packer; 11,703.5-11,710.2 Swell Packer; 11,443.8-11,450.5 SLOTS; 11,032.5-11,437.7 SLOTS; 10,345.1-10,869.2 XO Thread; 10,335.0-10,335.8 Screen; 10,314.8-10,335.0 XO Thread; 10,314.0-10,314.8 Swell Packer; 10,294.1-10,300.8 INTERMEDIATE; 38.9-9,732.2 UPPER LATERAL LINER w/ RAM hanger; 9,380.5-15,863.9 SLOTS; 9,627.9-10,356.6 XO Thread; 9,617.6-9,618.3 Screen; 9,597.4-9,617.6 XO Thread; 9,596.6-9,597.4 XO Thread; 9,513.8-9,515.0 SEALBORE DIVERTER LATERAL L1; 9,385.2-9,507.3 SEAL ASSY; 9,504.1-9,507.3 Seal Bore Extension; 9,494.1- 9,513.8 XO REDUCING; 9,492.7- 9,494.1 XO Threads; 9,481.2-9,504.1 PACKER; 9,466.2-9,492.7 Anchor; 9,474.6-9,481.2 NIPPLE; 9,457.0-9,459.0 XO Thread; 9,417.3-9,419.1 WINDOW; 9,392.0-9,409.6 LEM/SLZXP; 9,223.0-9,407.8 WLEG; 9,406.1-9,407.8 Window; 9,392.0-9,409.6 Diverter; 9,385.2-9,413.1 HANGER; 9,380.5-9,417.3 LEM; 9,380.8-9,406.1 Nipple - DB, XN, DS, D; 9,309.8- 9,311.9 XO Reducing (Casing); 9,266.0- 9,267.4 Seal Bore Extension; 9,246.3- 9,266.0 XO Reducing (Casing); 9,244.9- 9,246.3 Liner Top Packer; 9,223.0- 9,244.9 ESP Motors & Cables; 7,321.0 ESP Motors & Cables; 7,319.1 ESP Motors & Cables; 7,308.1 ESP Pumps; 7,301.2 ESP Pumps; 7,294.3 ESP Pumps; 7,283.8 Gauge / Pump Sensor; 7,216.1 GAS LIFT; 7,154.5 LEAK - TUBING; 3,134.0 GAS LIFT; 2,566.8 SURFACE; 41.6-2,243.9 Float Shoe; 2,240.7-2,243.9 CONDUCTOR; 39.0-119.0 HANGER; 34.0 KUP PROD 3R-101 ... WELLNAME WELLBORE3R-101 3R-101 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 119 119 20"19.124"94#-Welded Welded Surface 2244 2166 13-3/8"12.415"68#L-80 HYD563 HYD563 Intermediate 9732 3634 9-5/8"8.835"40#L-80 HYD563 HYD563 Upper Lateral 15864 3546 4-1/2"3.96"12.6#L-80 TXP TXP Lower Lateral 15967 3553 4-1/2"3.96"12.6#L-80 TXP TXP Tubing 7323 3404 4 1/2"3.958"12.6#L-80 TXP TXP Surface Casing Conductor Perfs 4-1/2" Hyd563 tubing to surface 4-1/2" SSSV @ ~1750' RKB (control line to surface) 4-1/2" x GLM's @ ~1800' & 3100' RKB 4-1/2" Sliding sleeve @ ~9000' RKB 4-1/2" Gauge @ ~9050' RKB (TEC wire to surface) 4-1/2" Chemical Injection Mandrel @ ~9150' RKB (3/8" control line to surface) 4-1/2" X Nipple @ ~9200' RKB (3.813" ID) 80-47 Seal Assembly @ 9246' MD ZXP Hanger and Packer @ 9223' MD Baker 190-47 SBE @ 9246' MD LEM @ 9310' MD B Sand Lateral (Mainbore): 7" x 9 5/8" ML-ZXP w/ HR Profile Liner Top Packer @ 9466' RKB 4 3/4" ID Seal Bore 20' Lng @ 9494' RKB 4 1/2" 12.6lb/ft Slotted liner with Swell Packers and Tracer Subs LEM Intermediate Casing D Sand Lateral (L1 Liner): RAM Hanger @ 9380' RKB 4 1/2" 12.6lb/ft Slotted liner with Swell Packers and Tracer Subs RAM Hanger RAM SBD C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-11-15_22135_KRU_3R-101_CaliperSurvey_CoilFlag_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22135 KRU 3R-101 50-029-23574-00 Caliper Survey / Coil Flag w/ log Data 15-Nov-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: 217-013 T38140 11/21/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.21 11:23:55 -09'00' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 ! " # $! % " "#& ' ($)"" *+$ ,-+# . #/0$ 10 2$$ " ## ! 3 -3 4 $ 5+ 6' $7896 7 + :+6 7 + ;+6 7 , #+ :+ , #+ ;+ :6 7 6:+7<=6:+7 />)..? " 0 '%@' '%'!' = ;= ;:+6 7;+6 7 ( ." != + A= ,- +# # ), + * != " 0'0$<+' /;#+&&& '@& " #&0$< ! "$ ", " + " #$ " #! $ 0A : 0 '" 00B:0 ?34 $ ,- 34 $ ;,+A4 # "::00$, C,"::00$ + " " , & , , 65817(/.%.1.. -B!D -! E @. %8 E= #9 = .>*?/>)..?.>/.* F$ &:+6 7 .>*88%.>/.*? $$, + ;+6 7 F ,'E 'E0'$+&"$, ;0$"::00$ (8"(*(28 .**8(.>+'.**8() (1%8. A-88./8> > =55*8 *8%8(5%(.*1)%88%88 " =>0 '%28 !" 1>(2)? 5? (>//? .>/.)? 5? (>())? .>*)8?)%9(G (8G .%.92G 28? /%*92G5>/5.? (>(8(? *>25/? + :+6 7 5>1.(? 5>)//?%/>)..? />*8)? )%9(G F 10 # ! # ! !# F A+ />)..?/>/58? )%9(G .>*? $$, -! 8%)8. # .9(8(8 "# $ %#$&"'()&") $ & "#* By Samantha Carlisle at 8:20 am, Jun 16, 2020 320-262 Alexander J Trower Digitally signed by Alexander J Trower Date: 2020.06.15 16:54:45 -08'00' X DSR-6/16/2020 10-404 DLB 06/16/20 X VTL 9/30/20" 10/1/2020 dts 9/30/2020 JLC 9/30/2020 RBDMS HEW 10/27/2020 !" #$$% & !'( )!*((!!+, #(-./0-1 2'" 2!+3,+ 14 ((!+3 (( !'( )!"+",-1 /'5&6 1 0 )33*"+"(!!+!3$ 171 !3 85, ! -(+3( '(3 !! 85, '2" 51 77 !" #$$% 144 '9/$ 071 85,:!!((! !"#$%$& ' ( ( ' ' ( ( ' & ' ( #' )(!*!+ ,-&./0 1 $/0 # *(/2)+ )($/.+,- (' ' '(# ( Conventional ESP – wireline retrievable pump / tubing conveyed motor. @ 7,323' MD / 3,404' TVD @ 79° incInsulated Conductor Casing, 20", 94#, K55 x 34", 0.312" WT @ +/- 108' MD13-3/8", 68#, L-80, Hydril-563 @ 2,244' MD / 2,166' TVD@ 35° inc TD 16" hole9-5/8", 40#, L-80, Hydril 563 & 521@ 9,732' MD / 3,635' TVDTD 12-1/4" hole @ 88.6ͼ inc.Wellhead / Tubing Head / Tree, 13-3/8" x 4-½", 5,000 psi3R-101 Well Schematic (Dual Lateral)_Actual.vsd Tolman 5/25/2017 3R-101 Well Design (Dual Lateral)Tubing String: 4-1/2", 12.6 #, L-80, TXP 8-3/4” D sand lateralTD @ 16,433' MD / 3,511' TVD6,690' ft Lateral lengthMLZXP Packer for main bore @ 9,466' MDGas Lift Mandrel, 4-1/2" x 1-1/2" w/ no valves @ 2567' MD / 2,473' TVD @ 50° inc 3.562" Landing nipple profile @ 9457' MD (SBD) Sealbore Diverter (SBD) POS-1Baker SLZXP Packer @ ~9,223' MD / 3,596' TVD @ 88° incDownhole Gauge - Discharge and Intake Back up @ 7,216' MDGas Lift Mandrel, 4-1/2" x 1-1/2" w/ dummy valve @ 7,154' MD / 3,370' TVD @ 78° incLevel-3 ML Junction SystemTubing Seal Assembly8-3/4” D sand lateralTD @ 15,896' MD / 3,540' TVD6,504' ft Lateral lengthL1 Window Top @ 9,392' MD / 3,602.4' TVD @ 86.15° incL1 Window Btm @ 9,410' MD / 3603.2' TVD @ 88.29° incLateral Entry Module POS-1Oil & Water Tracer Cartridge @ 10,315', 11,724', 13,146', & 14,634'3R-101 Dual Lateral Producer(As Ran)4-1/2", 12.6# L80, TXP, Slotted Liner15,864' MD / 3,546' TVD4-1/2", 12.6# L80, TXP, Slotted Liner15,967' MD / 3,553' TVDMLHR Prod Anchor3.750" Landing nipple profile @ 9,310' (LEM)4-½” x 8-¼” OD Swell Packer @ 10,294', 10,444, 11,704', 13,126', 14,614', & 15,830'Oil & Water Tracer Cartridge @9,597' & 12,330' _ Page 1 ----------------------------------------------------------------------------------- Engineer : Dornan Dataset : 3R-101 GLD failed ESP 09-02-20.snp Title : 3R-101 GLD for failed TTCESP. IPR based on 11-13-15 welltest for 3K-105. 09-02-2020 ----------------------------------------------------------------------------------- Important Note: Review page 3 of this report for actual and potential problems. Dornan Solution Rate: 1141 stbf/ Pvc Bottom Bellows: 1288 GL Design Press: 1330 Solution fbhp: 918 psia Operating Pressure: 981 Wellhead Pressure: 250 Flwg Wh Temp (Twh): 55 Casing DP: 148 SNAP IPR function Top Valve Flwg Temp: 68 Orifice DP: 256 Static BHP(Pws): 1400 Static BH Temp: 75 KO Gas Gradient : 0.0433 SNAP 2.700 11/11/2019 Tubing Size: 3.958 Operating Gas Grd: 0.0308 09/02/20 14:41:29 Design GL Rate: 1500 Watercut: 45.0 % Model: HagedornBrown Unloading Gradient: 0.450 Formation GOR: 100 Design QO: 627 stbf/d Design QW: 513 stbf/d Design QFmGas: 63 mscf/d Rn Sta Depth Depth Valve Valve Valve Port Valve Valve Flwg Or # TVD MD OD Type Model Size Ap/Ab Ppef Tmp 2 1 2413 2567 1.0 Bellows Camco_BK 0.1875 0.0940 0.1038 68 1 2 3406 7356 1.0 Orifice Camco_BKO-3 0.3125 0.0000 0.0000 73 Rn Sta Ppd Pwf Qliq* TGLR Qgi(req) Qgi(VPC) Qgi(ThH) Qgi(Wnk) Ptro60 Ptro Or # Prs psia stbf/d scf/b mscf mscf mscf mscf calc Instld 2 1 648 1491 200 423 74 313 1135 331 1508 1508 1 2 830 918 1141 1371 1500 1504 2019 2299 Rn Sta Pgd GLD GLD GLD Pvc Ppd-Pmin Or # Prs Piod Pvcd PpTran Ct Pio Psc DP psia 2 1 1435 1435 1393 991 0.981 1326 1288 20 343 1 2 1478 1085 256 Slick Line Procedure Run the following gas lift design based on the HagedornBrown hydraulic correlation, 1140 BLPD, 45% Water Cut, 1500 Mscfd lift gas, 100 FGOR, kickoff pressure of 1330.0 psi, and Camco_BK valves. Surf. Surf. TRO MD Valve Valve Port Open Close Press GLM (RKB) Size Name Size Press Press 60° F 1 2567 1" Camco_BK 3/16" 1326 1288 1508 2 7356 1" Camco_BKO-3 5/16" ------ Orifice ------ Recommended Unloading Procedure 1) Slowly work the production choke open to reduce the tubing pressure to common line pressure. 2) Start lift gas injection at 50-150 Mscfd. 3) Monitor the casing annulus pressure to target a 50-100 psi increase every 30 minutes (50-100 psi/30 min) 4) Increase lift gas injection to a maximum of 200 Mscfd. 5) At 200 Mscfd the calculated time to drop the annulus fluid level to the 1st gas lift valve is 12 hrs. 6) After unloading to the 1st gas lift valve, increase the gas lift rate to 2/3 of the design rate. (2/3) ( 1500 Mscfd) = 999 Mscfd. 7) The annulus fluid level will drop past each unloading valve and stabilize lift gas injection at the orifice within 12-18 hours depending on the number of valves. 8) Check that the annulus casing pressure is less than the closing pressure of the bottom gas lift valve = 1288 psig. 9) Increase the lift gas rate to the design rate of 1500 Mscfd. 10) The stabilized operating annulus casing pressure is 981 psig. 11) Contact CPF3 Production Engineer: ¾ For any questions or issues with unloading the well. ¾ If the operating annulus casing pressure is 150 psi above or below design. From:Trower, Alex J To:Loepp, Victoria T (CED) Subject:RE: [EXTERNAL]RE: KRU 3R-101(PTD 217-013, Sundry 320-262) ESP to GL Date:Friday, September 18, 2020 3:28:38 PM Attachments:3R-101 Backup GLD 9-17-20.docx Hello Victoria, Finally closing the loop on this – sorry for the delay! Here are the details you requested on 3R-101. Regarding the reservoir pressure, the best & most recent datapoint we have is from the directly- offset injector 3R-102. I also included the last flowing pressure we saw from the 3R-101 downhole gauge before it went offline. No flow test Passed 11/17/2017 Reservoir pressure Static: 1538 psi (from offset injector 3R-102 pressure fall-off in 2019) Flowing: 720 psi (last suction pressure gauge reading from 3R-101 before loss of gauges) Gas lift design Attached Still working on that other request (re: all WSak NFTs) but let me know if you need any additional information to support 3R-101. Thanks, Alex Trower Drillsite Petroleum Engineer Kuparuk | 3ABCFJK/R ConocoPhillips Alaska O: (907) 263-3733 C: (785) 691-6746 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, September 2, 2020 12:01 PM To: Trower, Alex J <Alex.J.Trower@conocophillips.com> Subject: [EXTERNAL]RE: KRU 3R-101(PTD 217-013, Sundry 320-262) ESP to GL CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Alex, Haven’t heard back from you on this well. Let me know if you want to continue with this sundry. 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@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: Loepp, Victoria T (CED) Sent: Sunday, July 26, 2020 10:28 AM To: Trower, Alex J <Alex.J.Trower@conocophillips.com> Subject: KRU 3R-101(PTD 217-013, Sundry 320-262) ESP to GL Alex, Has this well ever had a no flow test? What is the reservoir pressure in the area? Do you have the gas lift design available? 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@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: Trower, Alex J <Alex.J.Trower@conocophillips.com> Sent: Thursday, July 23, 2020 10:38 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: COP 3R-101 Sundry (ESP to GL) Hello Victoria, I recently took over for Doug Valentine here at COPA covering his CPF3 West Sak areas & a few other drillsites. I wanted to reach out and check on a 10-403 we submitted a few weeks ago and see if you’d had a chance to review. Additionally, we’ve had some personnel changes so I figured it wouldn’t hurt to make sure you’re not waiting on anything else from us! The sundry in question is sort of a contingency plan so we didn’t have a hard & fast operation date filled in (I think I put “TBD” in that space) so Jody Colombie recommended I give you a shout to see where it’s at. Thanks in advance! Alex Trower Drillsite Petroleum Engineer Kuparuk | 3ABCFJK/R ConocoPhillips Alaska O: (907) 263-3733 C: (785) 691-6746 �wP�\ �//�s THE STATE �� i;9 Alaska Oil and Gas A4," �f�T AsKe Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage,e, Alaska 99501-3572`* Main: 907.279.1433ALAS Fax: 907.276.7542 www.aogcc.alaska.gov November 29, 2017 Mr. Patrick Wolfe North Slope Integrated Operations and Project Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 RE: No-Flow Verification Kuparuk River Unit 3R-101 PTD 2170130 Dear Mr. Wolfe: On November 17, 2017 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Kuparuk River Unit 3R-101. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. 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. The AOGCC Inspector confirmed that proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004—was rigged up to test Kuparuk River Unit 3R-101. The well was open to atmosphere with no discernable flow upon the Inspector's arrival at location. The well was shut in for three hours with pressures recorded at half-hour increments, then opened to atmosphere to monitor the well's flow capability. Shut in pressures in the tubing and tubing-casing annulus declined to zero psi within 5 minutes. The maximum observed gas flow rate was 720 standard cubic feet per hour; there was no liquid production. The test results meet AOGCC acceptance criteria for a passing no-flow test. The subsurface safety valve must be installed if Kuparuk River Unit 3R-101 demonstrates an ability to flow unassisted to surface at rates exceeding the no-flow test acceptance criteria. Any cleanout,perforating or other stimulation work in this well will necessitate a new no-flow test. Sincerely, James B. Regg • Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors pT,D ?,jT —ol3 Loepp, Victoria T (DOA) From: Pessetto, Scott T <Scott.T.Pessetto@conocophillips.com> Sent: Tuesday, November 28, 2017 10:24 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]3R-101(PTD 217-013, Sundry 317-443) Convert to Gaslift-Please withdraw sundry Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please withdraw Sundry 317-443 Convert to Gaslift for well 311-101. Sorry for the delay. The no flow test was conducted Friday November 17°. The test was witnessed by Chuck Scheve and he said the well passed the test. I have not seen Chuck's official report. Thanks, Scott Scott T. Pessetto Drillsite Petroleum Engineer ATO 1352 (907) 263-4146 From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, November 28, 2017 9:29 AM To: Pessetto, Scott T <Scott.T.Pessetto@conocophillips.com> Subject: [EXTERNAL]3R-101(PTD 217-013, Sundry 317-443) Convert to Gaslift-Please withdraw sundry Scott, Please reply to this email with a request to withdraw this sundry. Has the no flow test been conducted? 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. LoeopCo)alaska.aov 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 Loepp, Victoria T (DOA) From: Regg, James B (DOA) Sent: Friday, November 10, 2017 9:33 PM To: Loepp, Victoria T (DOA) Subject: Re: [EXTERNAL]Re: 3R-101 No Flow Test Follow Up Flag: Follow up Flag Status: Flagged There is an alternate no -flow test procedure in the SVS regulations that only requires a calibrated pressure gauge. They shut the well in when Inspector arrives. Monitor pressure buildup for 3 hrs then open well to atmospheric tank. Pressure must bleed off within 5 minutes to pass. They do not need a waiver. Sent via the Samsung Galaxy S8 active, an AT&T 4G LTE smartphone -------- Original message -------- From: "Loepp, Victoria T (DOA)" <victoria.loepp@alaska.gov> Date: 11/10/17 1:38 PM (GMT -09:00) To: "Regg, James B (DOA)" <jim.regg@alaska.gov> Subject: Fwd: [EXTERNAL]Re: 311-101 No Flow Test Should we allow them to use the meter or order new one and extend allowable flow period two weeks - Sent from my iPhone Begin forwarded message: From: NSK Prod Engr Specialist <n1139@conocophillips.com> Date: November 10, 2017 at 1:03:04 PM AKST To: "Loepp, Victoria T (DOA)" <victoria.loepp@alaska.aov> Subject: RE: [EXTERNAL]Re: 3111-101 No Flow Test The approved flow period ends November 17, 2017. Thanks, Darrell Humphrey 907-659-7535 From: Loepp, Victoria T (DOA)[mailto:victoria.loepp@alaska.eov] Sent: Friday, November 10, 2017 12:58 PM To: NSK Prod Engr Specialist <n1139@conocophillips.com> Subject: [EXTERNAL]Re: 313-101 No Flow Test When is the approved flow period over? Sent from my iPhone On Nov 10, 2017, at 11:39 AM, NSK Prod Engr Specialist <n1139(a@conocophi11ips.com> wrote: Victoria - In preparation for the no -flow test on well 3R-101 we have been gathering our equipment and we have run into a problem. Our low rate gas meter was purchased new on May 4`", (invoice and factory calibration information attached). We have been unable to find a vendor in Alaska to provide an air or gas recalibration. The meter has never been used. The recommended equipment drawing provided by AOGCC shows "should carry a recent calibration (within the past 6 months)" although other AOGCC guidance on calibrations has suggested one- year intervals. We would like permission to use this meter for the 313-101 test, or alternatively an extension of flow period until a new meter can be obtained (we have a vendor who says they can ship in approximately 20 days). The pressure gauge for our setup was calibrated by deadweight tester on October 24" 2017. Please let us know how you would like us to proceed. Darrell Humphrey/ Matthew Raiche Production Engineering Specialist <image001.jpg> Ph: 907.659.7535 1 Pg: 924 1 Mail: NSK 69 <Dwyer instrument purchase order 10-17.pdf> MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ��P��fi DATE: 11/17/2017 P. I. Supervisor -7 FROM: Chuck Scheve SUBJECT: No Flow Test Petroleum Inspector KRU 3R-101 ConocoPhillips PTD 2170130 Friday, November 17, 2017: 1 traveled to the Kuparuk River Field to witness verification of no -flow status on Well 3R-101. The well was open to atmosphere with the proper test equipment installed when I arrived at location with no discernable flow. The well was then shut in for 3 hours with a pressure increase of 50 psi on the tubing. Upon reopening the well to atmosphere, the pressure dissipated rapidly (<5 min) with a flow rate of 720 scf/hr and decreasing. Tho fnllnWinn fnhlo shows tett details - Time Pressures' (psi) Flow Rate Gas — scf/hr Liquid — al/hr Remarks 0/0/0 0 0 Oen to atmosphere 9:30 - 0/0/0 0 0 Shut in 10:30 23/0/224 0 0 Shut in 11:30 38/0/223 0 0 Shut in 12:30 50/1/223 0 0 Shut in 12:35 0/0/223 720 0 Oen to atmosphere Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr This well meets the AOGCC criteria for no flow status. Attachments: none 2017-1117_No-Flow_KRU_3R-101 cs.doex Page 1 of 1 P►b F1 7 6130 Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Wednesday, November 15, 2017 12:52 PM 1-7 To: DOA AOGCC Prudhoe Bay; DOA AOGCC Prudhoe Bay Subject: 3R-101 No Flow Test Procedure ((( Attachments: 311-101 No Flow Test Procedure 10-17.pdf Enclosed is the procedure that was approved for the upcoming No Flow test on 311-101. If you have any questions please call me and I'll get you the needed information. Thanks, Darrell Humphrey/ Matthew Raiche Production Engineering Specialist ConocoPhi ip5 Alaska Ph: 907.659.7535 1 Pg: 924 1 Mail: NSK 69 N&e' tiled( ak) ttrcs 31?-tD1t-1 Ch Z7-16140, 311-101 NO FLOW TEST PROCEDURE Well Work Justification & Objectives: 3R-101 is a newly drilled West Sak producer on 313 pad. The well is a packerless completion with electric submersible pump artificial lift system. A subsurface safety valve was not installed in the well due to the ESP installation, as allowed in Alaska Code. The AOGCC has requested that this well have a no flow test conducted on it. The objective of this procedure is to perform a "state witnessed" no flow test to demonstrate that the well is not capable of unassisted flow. Pre Job Preparation: - Flow well on production until well is in pseudo steady state flow. AOGCC has initially agreed to a 30day target for this flow interval, measured from well start up on October 18, 2017. - Obtain calibrated low press gauge and flow meter. ' - Give 48 hrs. notice to AOGCC Inspector. - Prepare a proper connection with testing equipment at the tree cap. Complete Rig Up at least 24 hrs. prior to procedure Rig Up 1. Operations to shut in well prior to the test. ' 2. Operations to isolate the well from flowline. 3. SVS Techs 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 Q per hour, and the measured gas production is not greater than 900 standard cubic feet per hour, or O 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. Rig Down 1. Rig down test equipment. 2. If AOGCC confirms No Flow results, follow PE procedure to return to production. Figure 1. Recommended Equipment (Provided by AOGCC) \n.Flmr Text YnxecAure vnA 12ernnunrnaled 2:al uipmcrrr 'L'ss! ecpsctix[c .9ni11era/ till muR Lc ibui dCrap noel f6c .acfl l.r c c! p o the vol ..fry Cr Ir:Speeiur, ARer pldrwuo is hlerf, rhv- well r n: h•.'hn<J ;ry; rr vumasphclrc trek : sel n eaFlable ur evPwring nny proniueeV :Iwd During rhe rev, n nnnlmum 1-hpm' mivaexs«I r n o vtilu cd. IL4y]4lslli!Y-.L�plex 1b.—I am AP! RF 14AI themaxi m .11—bic liquid cnd enx Flow dws vn We ailnwnbly rim» eerahlisiuJ (cr aubsurinr<�rerF." vvivex in ,4f'1 IiecmmnendeS P..,.- 6.3 ..,. a6.3 $.lion per hm, r Gna '1VO crt Mc Ie<t ptt hmrr 16WiFmull sugRcmm evu:pm<r rnllgw:afDn nn me nn no.e resl i sou'. n in un, r,;nrr 6d.,.. n -'I .di. —duel be, -.d , and in ymrd wm'kin. order. 1>rceo-u:n Rnntiro anA 0m.. nsrcr vha.add o.nv :r rtcun .elibrm inry m f x'iWin V.e pear G rcmuurs). rAw me gx.uVc: 1�-fn d.-.irrnnx 0.wm Full ' �V.rlveg I _ _ Firrw Mc �Ilrs (1 -Flc 1 1 to im 11 I k( g 1 k•` STATE OF ALASKA A ;KA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS RECEIVE® OCT 19 2017 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑Qa o s utdown E]Performed: Suspend ❑ Perforate EJ Other Stimulate ❑ Alter Casing ❑ C a rogram ❑ e ppr Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Scale Inhibitor Treatment ❑� 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillj s Alaska, Inc. Development Q Exploratory ❑ Stratigraphic ❑ Service ❑ 217-004 3. Address: 6. API Number: P.O. Box 100360, Anchorage, AK 99510 50-103-20526-01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105 364471, 364470 CRU CD3 -111A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 11642 feet Plugs measured None feet true vertical 6922 feet Junk measured None feet Effective Depth measured 11595 feet Packer measured 8008 feet true vertical 6922 feet true vertical 6848 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 2685' 9.625" 2721' 2469' Intermediate Production 8496' 7" 8530' 6933' Liner 3477' 4.5" 11609' 6922' Perforation depth Measured Depth: Liner with frac Sleeves, 8897' - 10915' True Vertical Depth: 6943' - 6930' Tubing (size, grade, measured and true vertical depth) 3.5", L-80, 8149' MD, 6887' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Packer, 8008' MD, 6848' TVD SSSV: TRMAXX-SE TRSV, 2150' MD, 2010' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8897'- 10915' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 725 1001 1079 1129 302 Subsequent to operation: 753 670 1 815 1067 299 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.293) 15. Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Kaylie Plunkett Email Kaylie.B.PlunkeU coD.com Printed Name KKaylie// Plunkett Title Production Engineer Signature (0,�,�1c�-�� Phone 265-6450 Date lo -(7-('7 / R3L-iyi3 ( V OCT 2 3 26'17 / z Form 10-404 Revised 5!2015 /,� /7(n Submit Original Only CD3 -111A Scale Inhibition Treatment 9/18/17 Non -Aqueous Scale Inhibitor Squeeze Job pumped from 11:17 hrs to 23:00 hrs on 9/18/17. LRS = Little Red Services ACF = Alpine Central Facility • Initial pressure TBG/IA/OA-48/1281/417 • LRS pumped 18 bbls WAW5206 preflush at 0.34 bpm while ACF pumped 72 bbls diesel at 1.1 bpm, TBG/IA/OA — 400/1525/369 • LRS pumped 90 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at 1.0- 1.7 bpm, TBG/IA/OA — 0/1480/310 • ACF pumped 500 bbls diesel overflush at 1.1 bpm, TBG/IA/OA — 281/1584/316 Interval treated: 8897' —10915' M D A-�\'� WNS PROD CD3 -111A Lonoeomnups Well Attributes Max An la&MD TO Ad•9{fa IIIc FIe14 Name Wellbore 3lalue ncl l'I MO(NK01 Act Blm l(tK81 4rk"AdvllborI 501032052601 FIORONECHELIK PROD 91.16 11,23028 11,642.0 Commanl HUS(pep) dess SSSV: TRMAXXSE MnMallon EnE PIY K&GN (fH RIp RNeesaOW (asl WO: 42.61 3125/2006 CD&t11A.1.111 ePm mavc acrvai Annolalbn Oapin 696(8) End Oa4 Mnahtlan Last MOE BY En0 W1e _ Last Tag: Rev Reawn: SIDE TRACK, PULLED PLUG,ISO ppmven 511020 1] SLEEVE and GLV C/O XANCER', 3fA rugs m d Ching lion Wllnl IOl15 Top (NK36 5¢l Oeplb (N vol) nt aid $el Depth D114 WVLen(I...Or55 Topded! 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Top(TVOI NIKB) Tap Incl l') IYm Oea Com Normal lD n 8.131 4 08831 7803 PACKER Liner Top Packer,HROE Z%P, w/1 t25'SBE 4.350 8,151.4 6,8870 78.96 NIPPLE RS Nipple, 5-12', Hyd563 4.250 8,154.3 13,888.4 77.09 HANGER Liner Han9eDDO FL pinned 2500 psi 4,290 8,163.3 6,890.4 77.51 XO R19dudn9 SOL -80.512' Hyd563 Box X 412"TXP Pin 3,920 (Casing) 0,8957 6.9420 90.74 Frac Sleeve Baker Express F2c Sleeve #4(2.00" ball, 1.94890) 1.948 SAFETY VLV. 1,1504 1":1114] 9,226.1 7935.7 1.11 ECPal Saltel FracPaGeq BTG N4 3.958 Replied CSG Parker) 9,560.1 6,930.9 9061 Frac Sleeve Baker Express Frac Sleeve #3(1.938- ball, 1.805"ID) 1,885 Gmem Sa eu; eS210rra SViSACE]6]1,121.4 9,8940 6.929.2 0991 ECP(E xlemal Bullet FrecPaMer, BTC 43 SEW CSG Packer) 10,237.1 6.929.5 8991 Fmc Sleeve Baker Express FrecSleeve #217875"Call, 1.823"ID) 1.823 GoSLIFT;3,7000 10,5730 6,929.0 9018 ECP(ExSellel FrecPeQer, BTC #2 3.958 p CSG Peckelow)r) 10,915.0 6,930.2 89.28 Frac Sleeve Baker Express Frac Sleave #1(1813' b -a-1 L 1.7W)1]6D 11,243.9 6,9274 91.74 ECF(Exlemal Saltel FrecPacker, BTO #1 Seat GAS LIPT, 6288.3 CSG Packer) 11.580.9 69225 90.]8 Port Collar Alpha Pressure Sleeve'10500pal Burst Pressure' 3000 11,594.5 6,9223 9078 Valve WN( Wellbore lSplalion Valve)Ball on Seat 0.000 GAS U11r.fi201 Tubing Strings wpvLEn.Mse Tubing-vmplon Bmng Ma... m(in) Top INKid Saf OvPm Set Depm (rvD)1... wglont) Graee oO TUBING 3112 2.992 31.0 8,149.0 6.86] 2 9.30 L-80 EVEBNM T,, EU 8rdM Ginam1peepearms-7wee Completion Oetalls Nominal to Tap (NKB) Top PVC)MKS) Top Incl l') It.. Dee Cam did 31.0 31.0 0.09 HANGER FMC 4-12' Tubing Hanger TXP 3.958 PAd(EX, e,ms4 75.7 75.7 0.22 XO Redudng CROSSOVER,412"TXP X 3112"EUE.BP 2.992 NIPPLE:a0340 2,150.0 2,009.9 3820 SAFETY VLV TRMAX%-SE. TRSV,TGII 2.812 LOCATOR e1211 7,645.6 6,6888 56.08 NIPPLE NIPPLE ,LANDING312';XS 813.r EUE8RDM 2.813 LOCATOR; alma 7,964.8 6,8328 6894 Gauge/Pump PTS Gauge Carrier, 9.3#L-80 EUEbm PinxPin wltop 2,913 Sensor ..plug YULE SHOEe147.9 BOOB4 6.04].] 70.67 PACKER Baker Premier Packer3-12"x 7'removeble 2.870 - 8.024.9 6,853.1 71.35 NIPPLE NIPPLE,LANDING,3112',X9,2813",EUE8ROM,275 no- 2.813 go WIRHC (pulled RHC plug on 4)9201]) 8,127.2 6,882.1 7504 LOCATOR MCAankal locator, EVE KP OD lowtoO 2970 8,128.1 6,882.3 >5. LO ATOR McChanICBI expand Shearsub(8Ip Shearacrews) 2970 8.1479 6.88].0 1 76]9 MULE SHOE Jesusr WLEG 30W INTERMEMATE:341d,M0 i Stimulations & Treatments Pmppanl Oesigneb(C proppant In Formall.P 6e) Oale 41412013 NY0 BaoGekPwRc 8,9ea 0 1 1 Proppaet Designed lid - d'vired, Fomatlon 116) O.Y 100.000.0 1020000 411312017 Stimulations & Treatments bYptl Top 1%1(81 B6n 1XKB) pads stlmRrul Nuld rry dalbe 1 0 00 4113201] Hybpr G, Gelled Salt Water 000 2 10,909.0 10,910.0 41 2017 Xibor G. Gelled Salt Water 66500 M12000O Rp Rac,...br8593.0 1 I 3 10,231.0 10,232.0 4/1 X207H Hybor G, Gelled Salt Water 230.00 1 9,553. 9.5540 4113201] Hybor G, Gelled Sall Water 09900 5 8.880.0 8,BB9041IN2017 Heard G. Gelled Sall Water 200.00 Mandrel Inserts st all do' Frac-GeYMabr: 10,2]10 ' ' N Top(fte Top lrvO) a., YaM Yodel CO (In) Sary Vel" Type bar n Type Ponslae (in) TRORun (me) Run 08Y Com 3.7900 3.416.3 Camm KBMG 1 GAS LIFT GLV BK 0.188 18630 9182017 2 6,286.3 5813.0 Camw KBMG 1 GASLIFT GLV BK 0.188 1,8550 U19209 Hgb Seal PKIN G 3 ],628.4 6,6769 Cameo KBMG 1 GASLIFT OV BKO-3 0250 0.0 5G32017 EX PACKI KpF-G.Mdabr,faawo I I NO w1 O. RING 8 LME0.:8,191.511609.1 pTD X17-613 Loepp, Victoria T (DOA) From: Pessetto, Scott T <Scott.T.Pessetto@conocophill ips.com> Sent: Monday, October 02, 2017 11:05 AM To: Loepp, Victoria T (DOA) Cc: Braun, Michael (Alaska); Kanady, Randall B Subject: 311-101 Update Follow Up Flag: Follow up Flag Status: Flagged Good morning Victoria, I wanted to give you an update on the status of WSAK well 3R-101. We attempted to bring the well online September 27`" Since trying to bring online we have been troubleshooting the ESP variable frequency drive and severe pump efficiency problems. It appears both need to be replaced. The well was shut-in today to pull and replace the pump and packoffs once they have been sourced. Depending on the pump availability and ongoing permanent variable frequency drive it could be several weeks before we bring the well online. We will notify the AOGCC once the new equipment is installed and operational and we can schedule a no -flow test. Regards, Scott Scott T. Pessetto Drillsite Petroleum Engineer ATO 1352 (907) 263-4146 P i P a 17 -0/3 Loepp, Victoria T (DOA) From: Pessetto, Scott T <Scott.T.Pessetto@conocophillips.com> Sent: Thursday, September 21, 2017 9:08 AM To: Loepp, Victoria T (DOA) Subject: 3R-101 10-403 Good morning Victoria, Earlier this week I submitted at 10-403 request for conversion of 311-101 to gas lift. It appears we were unexpectedly able to get our ESP motor working late last night. For the time being please hold off on processing that application as intend to pursue ESP lift as originally planned. Regards, Scott Scott T. Pessetto Drillsite Petroleum Engineer ATO 1352 (907) 263-4146 Loepp, Victoria T (DOA) From: Pessetto, Scott T <Scott.T.Pessetto@conocophillips.com> Sent: Tuesday, September 19, 2017 9:15 AM To: Loepp, Victoria T (DOA) Subject: KRU 3R-101(PTD 217-013) Packerless ESP completion w/out SSSV Follow Up Flag: Follow up Flag Status: Flagged Good Morning Victoria, Since we spoke last, well 313-101 has not come on production, the well's ESP motor is malfunctioning and not able to turn the pump. The motor is not wireline retrievable. Well 3R-101 was completed with backup gas lift mandrels in case of an ESP failure. A 10-403 requesting permission to convert well 311-101 to gas lift service will be submitted to the AOGCC today. I wanted to give you a heads up this is coming and also request the same approvals granted previously for ESP lift which where: Approval is granted to bring KRU 3R-101 online with the following conditions: 1. The well must pass a no flow test within 30 days of initial production. 2. 48 hours notice must be provided to the AOGCC Inspector to witness the test. Thanks, Scott Scott T. Pessetto Petroleum Engineer ATO 1352 (907) 263-4146 From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, August 28, 2017 10:09 AM To: Pessetto, Scott T <Scott.T.Pessetto@conocophillips.com> Cc: Kanady, Randall B <Randall.B.Kanady@conocophillips.com>; Regg, James B (DOA) <jim.regg@alaska.gov> Subject: [EXTERNAL]RE: KRU 3R-101(PTD 217-013) Packerless ESP completion w/out SSSV Scott, We have reviewed the information you have provided concerning the packerless ESP completion and the SSSV requirements as it relates to bringing on new well KRU 311-101. Please note 20 AAC 25.200(d) which requires "all producing wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer..." Approval is granted to bring KRU 313-101 online with the following conditions: 1. The well must pass a no flow test within 30 days of initial production. 2. 48 hours notice must be provided to the AOGCC Inspector to witness the test. 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. LoeppCavlalaska.aov, 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.Loeoa@alaska.aov From: Pessetto, Scott T [mailto:Scott.T.Pessetto@conocophillips.comj Sent: Friday, August 25, 2017 1:58 PM To: Loepp, Victoria T (DOA) <yictoria.loepp@alaska.Rov> Cc: Kanady, Randall B <Randall.B.KanadV@conocophillips.com>; Driscoll, Michael D <M ichael. D. Driscol I @conocophillips.com> Subject: KRU 3R-101 Victoria, As Randy mentioned in our phone call earlier, we are planning to bring 313-101 online early next week. Well 3R-101 is a WSAK producer with a packerless ESP. Typically wells on 3R require a SSSV to produce but the installation of the ESP exempts us from this regulation, per 20 AAC 25.265 (D): "(4) an onshore well in a location described under (2) of this subsection and equipped with an electric submersible pump or capillary string run within the tubing is not required to be equipped with a subsurface safety valve;" We have no plans to conduct a state witnessed no flow test or install a SSSV in well 313-101. It is our understanding that a no flow test is only required if an operator wishes to operate a well without a SSSV in a well where a SSSV is required. Due to 3R-101 having an ESP and being onshore, 3R-101 is not required to be equipped with a SSSV and does not require a passing no flow test to obtain the SSSV exemption. We are confident bringing the well online will be within AOGCC regulations, but we want to confirm with you that we do not need any other written or verbal approval from the AOGCC. I have also attached the email Michael Sullivan sent regarding this subject back in May. -Scott Scott T. Pessetto Drillsite Petroleum Engineer ATO 1352 (907) 263-4146 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Monday, August 28, 2017 10:09 AM To: Pessetto, Scott T Cc: Kanady, Randall B; Regg, James B (DOA) Subject: RE: KRU 3R-101(PTD 217-013) Packerless ESP completion w/out SSSV Scott, We have reviewed the information you have provided concerning the packerless ESP completion and the SSSV requirements as it relates to bringing on new well KRU 311-101. Please note 20 AAC 25.200(d) which requires "all producing wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer..." Approval is granted to bring KRU 313-101 online with the following conditions: 1. The well must pass a no flow test within 30 days of initial production. 2. 48 hours notice must be provided to the AOGCC Inspector to witness the test. 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. Loeoo(aalaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information trom 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. LoeDDIYalaSka-aov From: Pessetto, Scott T [mailto:Scott.T.Pessetto@conocophillips.com] Sent: Friday, August 25, 2017 1:58 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Kanady, Randall B <Randall.B.Kanady@conocophillips.com>; Driscoll, Michael D <Michael.D.Driscoll@conocophillips.com> Subject: KRU 3R-101 Victoria, As Randy mentioned in our phone call earlier, we are planning to bring 311-101 online early next week. Well 311-101 is a WSAK producer with a packerless ESP. Typically wells on 311 require a SSSV to produce but the installation of the ESP exempts us from this regulation, per 20 AAC 25.265 (D): "(4) an onshore well in a IULOtion described under (2) of this subsection and equipped with an electric submersible pump or capillary string run within the tubing is not required to be equipped with a subsurface safety valve," We have no plans to conduct a state witnessed no flow test or install a SSSV in well 311-101. It is our understanding that a no flow test is only required if an operator wishes to operate a well without a SSSV in a well where a SSSV is required. Due to 311-101 having an ESP and being onshore, 311-101 is not required to be equipped with a SSSV and does not require a passing no flow test to obtain the SSSV exemption. We are confident bringing the well online will be within AOGCC regulations, but we want to confirm with you that we do not need any other written or verbal approval from the AOGCC. I have also attached the email Michael Sullivan sent regarding this subject back in May. -Scott Scott T. Pessetto Drillsite Petroleum Engineer ATO 1352 (907) 263-4146 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Monday, August 28, 2017 10:09 AM To: Pessetto, Scott T Cc: Kanady, Randall B; Regg, James B (DOA) Subject: RE: KRU 3R-101(PTD 217-013) Packerless ESP completion w/out SSSV Scott, We have reviewed the information you have provided concerning the packerless ESP completion and the SSSV requirements as it relates to bringing on new well KRU 311-101. Please note 20 AAC 25.200(d) which requires "all producing wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer..." Approval is granted to bring KRU 311-101 online with the following conditions: 1. The well must pass a no flow test within 30 days of initial production. 2. 48 hours notice must be provided to the AOGCC Inspector to witness the test. 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. LoegP(g7alaska.goy 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. Loeoo@aloska aov From: Pessetto, Scott T (mailto:Scott.T.Pessetto@conocophillips.com] Sent: Friday, August 25, 2017 1:58 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Kanady, Randall B <Randall.B.Kanady@conocophillips.com>; Driscoll, Michael D <Michael.D.Driscoll@conocophillips.com> Subject: KRU 311-101 Victoria, As Randy mentioned in our phone call earlier, we are planning to bring 313-101 online early next week. Well 311-101 is a WSAK producer with a packerless ESP. Typically wells on 311 require a SSSV to produce but the installation of the ESP exempts us from this regulation, per 20 AAC 25.265 (D): "(4) an onshore well in a tv,otion described under (2) of this subsection and equipped with an electric submersible pump or capillary string run within the tubing is not required to be equipped with a subsurface safety valve;" We have no plans to conduct a state witnessed no flow test or install a SSSV in well 311-101. It is our understanding that a no flow test is only required if an operator wishes to operate a well without a SSSV in a well where a SSSV is required. Due to 3R-101 having an ESP and being onshore, 311-101 is not required to be equipped with a SSSV and does not require a passing no flow test to obtain the SSSV exemption. We are confident bringing the well online will be within AOGCC regulations, but we want to confirm with you that we do not need any other written or verbal approval from the AOGCC. I have also attached the email Michael Sullivan sent regarding this subject back in May. -Scott Scott T. Pessetto Drillsite Petroleum Engineer ATO 1352 (907) 263-4146 WELL NAME STATUS LIFT TYPE vumvixr4a[vRPisuR[ A g WC% Ped D¢pth, TVD Fluid Column, psi Fluid Column Greater than Current Intake Pressure? Pressure Differential 1C-153 Rueew RIGLESS ESP 463 8.6 see 1597 ves 1ve 1D-105 uniax¢ TTC-FSPCP No Working Ga 11.8 uo 1602 1D-108 Rurarixa TTC-ESPCP S07 20.5 M71 1636 1. vas 16112 wrnsnw TTC-ESPCP 596 66.7 nn 1656 res use 1D-113 Ruxruxp TTC-ESPCP 595 46.5 asn 1656 ves uu 1D-115 Runraxe TTC-ESPCP 532 4L8 nu 1648 ves no. 10-116 Rumm TrC-ESPCP 506 1 67 sRse 1687 res vu 16123Ruxxi Is TTC-ESPCP No Works Gauges 50.3 sen 1668 16133 Rux7axc TTC-FSPCP 532 67.3 Aso,3688 11w 16134 RuxaxR TrC-ESPCP 518 45.0 sen 1654 res 1236 16335 Ruxnixs 774FSPCP 534 63.9 asks 1683 1. 1D-145 Ranum RIGLBS ESP 727 53.2 aaa 1666 1 Yes eR .Us aal PAM PW WaM OAS PW Loepp, Victoria T (DOA) From: Pessetto, Scott T <Scott.T.Pessetto@conocophillips.com> Sent: Friday, August 25, 2017 6:34 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: KRU 3R-101 Attachments: WSAK Running ESPs.xlsx Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for the response. The answers to your questions are below. • How many WSak wells are there on ESPs 12 WSAK ESPs running currently (2 rigless ESP, 10 ESPCP). I have attached a spreadsheet with the well names and additional data. • Of those, how many would pass a no flow test? • Based on current flowing bottom hole pressures and historical pressure build up data, all of the West Sak ESP wells would pass a no flow test conducted within 30 days of shut-in. • Is there a well(s) on gas lift and packerless? Wells 1E-123, 1J-174, and 1J-115 (RWO planned for September) are currently on gas lift with packerless ESPs. Scott T. Pessetto Drillsite Petroleum Engineer ATO 1352 (907)163-4146 From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, August 25, 2017 2:55 PM To: Pessetto, Scott T <Scott.T.Pessetto@conocophillips.com> Subject: [EXTERNAL]RE: KRU 311-101 Scott, We are reviewing this. I have a few questions: How many WSak wells are there on ESPs Of those, how many would pass a no flow test? Is there a well(s) on gas lift and packerless? Thanx, Victoria From: Pessetto, Scott [mailto:Scott.T.Pessetto@conocophillips com] Sent: Friday, August 25, 2017 1:58 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Cc: Kanady, Randall B <Randall.B.Kanadv@conocophillips.com>; Driscoll, Michael D <M ichael. D. Driscoll @conocophi I I i ps.com> Subject: KRU 311-101 Victoria, As Randy mentioned in our phone call earlier, we are planning to bring 3R-101 online early next week. Well 311-101 is a WSAK producer with a packerless ESP. Typically wells on 311 require a SSSV to produce but the installation of the ESP exempts us from this regulation, per 20 AAC 25.265 (D): "(4) an onshore well in a location described under (2) of this subsection and equipped with an electric submersible pump or capillary string run within the tubing is not required to be equipped with a subsurface safety valve," We have no plans to conduct a state witnessed no flow test or install a SSSV in well 311-101. It is our understanding that a no flow test is only required if an operator wishes to operate a well without a SSSV in a well where a SSSV is required. Due to 3R-101 having an ESP and being onshore, 313-101 is not required to be equipped with a SSSV and does not require a passing no flow test to obtain the SSSV exemption. We are confident bringing the well online will be within AOGCC regulations, but we want to confirm with you that we do not need any other written or verbal approval from the AOGCC. I have also attached the email Michael Sullivan sent regarding this subject back in May. -Scott Scott T. Pessetto Drillsite Petroleum Engineer ATO 1352 (907) 263-4146 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED SEP 19 2017 AOGCC 1. Type of Request: Abandon U Plug Perforations U Fracture Stimulate U Repair Well U Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other Convert to Gaslift ❑+ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill NumbqF ConocoPhilli sAlaska Inc. Exploratory ❑ Development Q. Stratigraphic ❑ Service ❑ 217-013 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 9-23574-00-00 - 7. If perforating: 8. Well Name and mber: What Regulation or Conservation Order govems well spacing in this pool? 411- Will planned perforations require a spacing exception? Yes ❑ No KRU 3R-101, 9. Property Designation (Lease Number): 10. Field/Pool(s): 355023, ADL 355024 Kuparuk River Field /7#49ak Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 16,433', 3,511' , 16,433' 3,635' Casing Length Size MD T Burst Collapse Conductor 80' 20" 119' 1 9' Surface 2,202' 13-3/8" 2,244' Intermediate 9,693' 9-5/8" 9,732' Liner Upper Lateral 6,504' 4-1/2" 15,896' ,5 ' Liner Lower Lateral 6,690' 4-1/2" 16,433' 3,511' Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: in Grade: Tubing MD (ft): 9,466'- 16,433' 3,500'-3,635' 4-1/2" L-80 7,284' Packers and SSSV Type: P s and MD (ft) and TVD (ft): NC)N'E r 4,AAAf >GM E 12. Attachments: Proposal Summary lj+l Wellbore schematic Lfj Qq. Well Class after pro work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stretigraphic ❑ Development Q , Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/24/2017 OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the proced a approved herein will not be deviated from without prior written approval. Authorized Name: Scott Pesselto Contact Name: Scott Pessetto Authorized Title: Petroleum Engineer Contact Email: scott.t.pessetto@conocophillips.com Contact Phone: (907) 2634146 /1 /Zdq, Authorized Signature: -/4 Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a r presentative may witness Sundry Number: 317-`f `f3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes No ❑ Spacing Exception Required? Y ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Rev sea 4/201) ORIGINAL RBMIAS v"4r-0?r1en�017 Approved application is valid for 12 months from the date of approval. Attachmenu in Duplicate RECEIVED SEP 19 2017 Al. GCC ConocoPhillips September 19, 2017 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7`h Ave. Ste. 100 Anchorage, AK 99501 Dear Commissioner, Scott T. Pessetto Petroleum Engineer ANC 1352 700 G Street Anchorage, AK 99501-3448 Phone: (907) 263-4146 Scott.T.Pessetto@conocophillips.com conocophillips.com ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 3R- 101 from ESP artificial lift to gas lift artificial lift. Enclosed you will find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding well 3R-101, (PTD# 217-013). If you have any questions regarding this matter, please contact myself at 907-263-4146. Sincerely, Scott Pessetto Attachments Report of Sundry Well Operations Proposal Summary Well Schematic 3R-101 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. is seeking approval to convert the apcial lift method from electric submersible pump (ESP) to gas lifted production in West Sak Well 313-1 01. -The current ESP motor in well 3R-101 is unable to turn the pump and has prevented bringing well 3R-101 on production. Converting the artificial lift method to gas lift will allow the start of production. The well was originially completed as a packerless ESP producer, with a tubing conveyed ESP motor set at 7,323' MD. The 4.5" tubing is equipped with two 1.5" side -pocket gas lift mandrels at 2,567' and 7,154' MD. Gas lift valves will be run, replacing dummy valves currently in the gas lift mandrels. The through tubing conveyed pump was removed during diagnostic wellwork. A gas MIT of the inner annulus will performed to 1000 psi prior to bring on gas lift to confirm production casing integrity. The well must also pass a no flow test within 30 days of initial production. r ,111,• �: . v� ; q > = F v III h � pi • m III — ^ Fo • n1 I 01 : m , ^� • III � P 111 � ab." . III • m b III u mm� � III .�OY• III �'p� � • III � b . III ' �-] V .III• • III �� q � � � III • �\ � III ; U C v � . 111 � • III v �� . 111 q III � u • q • III F III .a b CCJI � 111 � � III � F ry • III • III • • III • III 9 "— • III � � III — • III • O III �Q'� o 111 L u 111 . jn inp 4j k F. � a F Q C • III . III iIII • III � � �'�' III • b I11 � 111 • /p� 111 N :R Z > _ ryl . rn • iii p ° N 111 • ul 9 •p q III III •JN ; � 111 lu 111 = o •m� = � ,'y^ • = — a^I m _ C q m G. M O• ij d qm �` III I_\' V x - T •'p �" ISI 111 E III i6 III N a a `� � V N O - ." SII • G 11, ;= p` iNc � y' 'C o. ©� VTi 111 III III ; 111 •� 3 a ° q III 1 F � ._ � Y� � F o o III • U m} Ow v p0 E p bH@) c o Y m o m> d E-= �e m NO w a � q�aq yiyp� o<'.Jq F 0.m °—' c m g S m 9 n1 N- R .ippj zJ >= - _ � Q C � N P C V r s 3R-101 Well Design IPe05AMo lli�„nvml, Ivmn,,N R.M,Conocomilli (Dual Lateral) A4vsica Loepp, Victoria T (DOA) From: Pessetto, Scott T <Scott.T.Pessetto@conocophillips.com> Sent: Tuesday, November 28, 2017 10:24 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]3R-101(PTD 217-013, Sundry 317-443) Convert to Gaslift-Please withdraw sundry Victoria, Please withdraw Sundry 317-443 Convert to Gaslift for well 311-101. Sorry for the delay. The no flow test was conducted Friday November 17th. The test was witnessed by Chuck Scheve and he said the well passed the test. I have not seen Chuck's official report. Thanks, Scott Scott T. Pessetto Drillsite Petroleum Engineer ATO 1352 (907) 263-4146 From: Loepp, Victoria T (DOA) (mailto:victoria.loepp@alaska.gov] Sent: Tuesday, November 28, 2017 9:29 AM To: Pessetto, Scott T <Scott.T.Pessetto @conocophi IIips.com> Subject: [EXTERNAL]3R-101(PTD 217-013, Sundry 317-443) Convert to Gaslift-Please withdraw sundry Scott, Please reply to this email with a request to withdraw this sundry. Has the no flow test been conducted? 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. Loeon0alaska.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. LoeooCaalaska.aov Loepp, Victoria T (DOA) From: Pessetto, Scott T <Scott.T.Pessetto@conocophillips.com> Sent: Thursday, September 21, 2017 9:08 AM To: Loepp, Victoria T (DOA) Subject: 3R-101 10-403 Good morning Victoria, Earlier this week I submitted at 10-403 request for conversion of 311-101 to gas lift. It appears we were unexpectedly able to get our ESP motor working late last night. For the time being please hold off on processing that application as intend to pursue ESP lift as originally planned. Regards, Scott Scott T. 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Well Status: Oil ❑✓ , Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 2DA c 25.105 20A C 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 4/Zq/l; 14. Permit to Drill Number / Sundry: ConocoPhillips Alaska, Inc. Abend.: 4M828gF 217-013 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 3/24/2017 50-029-23574-00-00 ` 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: Surface: 1630.5' FNL, 2959.2' FEL, Sec 9, T13N, R9E, UM 4/10/2017 KRU 3R-101 , Top of Productive Interval: 818' FNL, 396' FEL,Sec 5, T13� R9E, UM 9. Ref Elevations: KBA8.9 GL:9.9 BF: 17. Field / Pool(s): Kuparuk River Field/West Sak Oil Pool . Total Depth: 10. Plug Back Depth MDfFVD: 18. Property Designation: 980' FNL, 1809' FEL, Sec 6, Tl 3N, R9E, UM N/A 355023, ADL 355024 , 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MDITVD: i, 19. DNR Approval Number: Surface: x- 520626 y- 6031732 Zone -4 16433 3511 • 931933000, 931934000 TPI: x- 517877 y- 6037816 Zone -4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/ VD: Total Depth: x- 511186 y- 6037641 Zone -4 N/A 1730/1701 5. Directional or Inclination Survey: Yes. ✓ (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res/Periscope 23. CASING, LINER AND CEMENTING RECORD WT. PER I GRADE SETTING DEPTH MD SETTING DEPTH TVD I CASING HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 20 62.6 B 39 119 39 119 42 Existing 133/8 68 L-80 42 2243 42 2165 16 932 sx 11.0ppg, Class G, 260 sx 9 518 40 L-80 39 9732 39 3634 12.25 1878 sx 15.8ppg, ClassG 41/2 12.6 L-80 9466 15967 3608 3551 8.75 Liner 24. Open to production or injection? Yes ❑✓ No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Perfd): 4 1/2 7323 N/A SLOTTED LINER @ 10345-10869 MD, 3603-3588 TVD COMPLETION 11032-11437 MD, 3589-3595 TVD 11754-12283 MD, 3591-3589 TVD DATE 12446-12957 MD, 3567-3591 TVD Lf i -i' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes El No ✓ Per 20 AAC 25.283 (i)(2) attach electronic and printed information 13177-13717 MD, 3593-3587 TVD VERIFIED DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 13881-14446 MD, 3584-3580 TVD lt, 14665-15181 MD, 3579-3574 TVD 15305-15824 MD, 3574-3555 TVD 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): CPAI intends to produce with ESP up the WAITING FOR HOOK-UP tubing and gas up the IA to increase production (20 AAC 25.200(d)). Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period __* Flow Tubing Casing Press: I lCalculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): Press. 124 -Hour Rate Form 10-407 Revised /2017 V%�� CONTINUED ON PAGE 2 RBDIMS L'" MAY J U 2017 Submit ORIGINAL on}y. 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1730 1701 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 9732 3635 information, including reports, per 20 AAC 25.071. Formation @ TPI -West D UGNU A 6822 3304 WEST SAK D 9361 3601 TD 16433 3511 Formation at total depth: West Sak C 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaical report. production or well test results, ner 20 AAC 25.070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. T. Authorized Name: G.L. Alvord Contact Name: Ben Tolman vs I Zorn Authorized Title: AK Drilling Manager Contact Email: Ben.V.Tolman co .com Authorized�1� Contact Phone: 265-6828 Signature:-W�— Date:�i 2S' 2or INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Wellhead /Tubing Head / Tsee, 13-318" .4-W', 5,000 pci huulaed35x M', r 312" WT@ 94M, KSS x34',0312"WT® p/ H-108'MD 13-3/8', 686, 1-30, Hyddl-563 @2,244'MD/2,166'ND @ 35° um TD 16" hole Beker SLZXP Pmker @-9,223' MD/ 3,596 ND @ 88° um Laeral Enuy Modde POS -1 3.750" Landing nipple pmfile @ 9310' (LEM) S 1,ore Dlvew(SBD) MS -I Tubing Seal Assembly J 3.562' Landing nipple pmflle @ %5T MD (SBD) - Shing'. 4-12",116 6, L-89 TXP 3R-101 Dual lateral Producer (As Ran) Gu Lift Mmdml, 4-1/2' x 1-112" w/ m valves @ 256T MD 12,4)3' ND @ 50° inc MLHR Prod Amhor AW, 406,1-80, Hyddl563 k 521 @ 9,732' MD /3,635'ND TD 12-114" hoic @ 88.6° ism. Gas Lift MuWrel, 4@" x I -In" w/dummy valve @ 7,154' MD 13,370' ND@ 78" im D .I� Gm.,- Diahu,p aM Ismke Buk up@7,216'MD _Cuuv ui,ul ESP- wimbac muievable WmP/tubing con' Wnmlor. @ 7,323' hB)/ 3,404'ND @ 79" ine LI WIMow Top @ 9,392' MD/3,602.4' ND@ M, IS- ine LI Wino B.@ 9,4 IV MD/3W32'ND@88.29-im evel-3 ML Jmmeion Sysmn 4-1/2", 1366 LBO, TX?, 5loued Liner 8-M/'D smd Hunel �I5,864'MD/3,546'NO TD@ 15,adIm540'NO� 6,504'fl.8wn%' D/3,540' 3, Dil$ Waar T. Cartridge@ .. 9,59T $12}30' `_________"______________________________________________._ M=Px urfmmunbmn @ 9,466' MD M@ La ual longlh KUP PROD ConocoPhillips\l AWS , inc. MT ESP Mahn IMEPMEUNM: 35 8.0.1323 BLOTS', .S, SLOTS: BLms: SLOTS: SLOTB'. 3R-101 KUP PROD 3R -101L1 LonocctPhtlhps Weil Att i6 tes Max MgleBMD TD Aitlycy'�r1(,. - weneom avxuwl mxd xeme 50029235]460 TRACT OPERATION N TR05 welleom sln�e PROD eG90.20 eD1 111,]58.10 115,896.0 Convnenl N281ppm) OM annobtion Entl Dale KaOm IN RIg WI;;O NIILP%EIATERN4-]F-1pIL1, 5RS2p1]3'.13b1 PM 39.10 412&201) Mnq ien DgAh(MB) .7 MlWelbn Lpr M04 By EnCPob __...... Rev Reason: New Well ppmven 5124201] HMGER. 34. Casing rings Laing De¢wpnon m(1^) 0(..) Top(me) sb Depm fnKBl y10epB111VD1._-wuLw P... Greer Tapmmaa UPPER LATERAL LINER 412 3.958 9,380.5 15.8639 3541.1 12.60 L-80 TXP-m wI RAM hanger Liner Detalls xemn.Im Top (e ) Te p RVDl lruml Top I. mm Da eom pry 9. .5 3,801.6 85M Hanger Baker RAN Helper,(Above Mille) F 8.090 CONDUCTOR: 390 -neo 9,591.4 3,613.9 87.91 Saeen Tac. T., C.rtm8, 5-W-155 PPf Hyl 511 1958 Pin x Pin, ser# 8 12,329.7 35856 WA4 Screen Tlemrw Tbcer Cadodge, 5-112 15.5 ppf Hy -511 3.958 Pin x Pin, ser# 5 1 PerforaWns 8 slots SDRFALE:e16224]8 Bnol DBw TOPIry01 a Isno1N To IK0 Blm(ft. PI 1 1 (xKBI s") (12,6 ]nne U Ty"OTS Corn 9,62].9 10,3566 3,814.] 3,801.2 a(P 4124201] 32.0 SLOTS Ga811ei:I5E8 B 10,51].5 1IA59 3,603.d ,5 5J 4n4120ll 32. SLOTS 11,8442 12,152.9 3,567Zd ,58 B d12M209 320 SLOTS 12.359.8 12,902.0 3,585.8 3.5]1.0 G2dn01] 320 SLOTS 13009.4 13,586.8 3,571.4 3.575.1 412112017 320 SLOTS GAS LIFT; ],159 5 13.]52] 14.319.1 3,93.6 3,585.F 412112017 320 S OTS 14480.115 M5.5 3,564.3 415206.5 35810 4na2017 320 SLOTS 15,]2]3 3,5600 3,5447 1 41242017 320 SLOTS a,.p.lwmps.me<'. ].ae.1 Notes: General8 Saftity End Ogle Mmle4nn NOTE: ESp Pulp¢;]2BJBAWa¢ ESp Plnps: ]29fi ESPPwps;7.MJ ESPa LYY¢; ].308.1 ESP Mebn B CHYc]. ESP Mdola B CeYYe; ],321M 0 IMERMEONTE; 30.96,]322 LEMLV(F.9='...90) B SM E9NERTER IATFAALLI'.9.365S9 73 y SLOTS D82].8-10.358.8-4 F SLOTS 10.511911,9859- 'FLCF SLOTS: 11.644?R,152.9�� j YOT5:12 M5 AL ..4- 7C SLOTS 13.N8.91J,SB8 B ' SLOTS: 13.]52]-14.3181 -� i SLOTS:14 .4B0.0.15.M5b-� r SLOTB', 152W,15.R72�� IIPPERIATE LINER M RMI lulyr, 9,]BO.SIS.BBJ.9 AL Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stall Time End! Time Our (hr) Phase Op Cada tivi ActyCade Time PJA Operation ataDepth (n Die End DapN (%(B) 3/22/2017 3/22/2017 0.75 MIRU MOVE RURD P Rig release from 3R-102 at 16:00 hrs. 0.0 0.0 16:00 16:45 Swap to generator power. Continue blowing down steam lines. Remove cuttings tank and containment. Continue disconnecting service lines. 3/22/2017 3/22/2017 0.75 MIRU MOVE MOB P Move power complex and rockwasher 0.0 0.0 16:45 17:30 and stage on pad. 3/22/2017 3/22/2017 1.25 MIRU MOVE MOB P Move pump module and pit module 0.0 0.0 17:30 18:45 and stage on pad. Continue moving rockwasher and move pipeshed module and stage on pad. 3/22/2017 3/22/2017 0.75 MIRU MOVE MOB P Skid rig floor and install tongue for 0.0 0.0 18:45 19:30 towing substructure. 3/22/2017 3/22/2017 1.75 MIRU MOVE MOB P Lift sub stompers and finish installing 0.0 0.0 19:30 21:15 tongue for towing substructure. 3/22/2017 3/23/2017 2.75 MIRU MOVE MOB P Pull substructure off 3R-102. Shuffle 0.0 0.0 21:15 00:00 and lay dg mats for spotting sub on 3R -101. 3/23/2017 3/23/2017 0.50 MIRU MOVE MOB P Cont. to spot sub base over well 3R- 0.0 0.0 00:00 00:30 101 3/23/2017 3/23/2017 1.50 MIRU MOVE MOB P Set down rear stompers and apply 0.0 0.0 00:30 02:00 pressure. Skid the rig floor over the center of the well. Remove towing tongue from sub. 3/23/2017 3/23/2017 1.00 MIRU MOVE MOB P Spot pit complex, hook up 0.0 0.0 02:00 03:00 interconnect lines between sub base and pit complex. Hook up lines post rig floor skid. 3/23/2017 3/23/2017 2.00 MIRU MOVE MOB P Spot pump complex, SIMOPS hook up 0.0 0.0 03:00 05:00 interconnects. 3/23/2017 3/23/2017 0.50 MIRU MOVE MOB P Spot motor complex, SIMOPS, hook 0.0 0.0 05:00 05:30 up interconnects between pump complex and pit complex. 3/23/2017 3/23/2017 1.00 MIRU MOVE MOB P Spot rock washer. 0.0 0.0 05:30 06:30 3/23/2017 3/23/2017 2.00 MIRU MOVE MOB P Spot pipe shed. 0.0 0.0 06:30 08:30 3/23/2017 3123/2017 1.50 MIRU MOVE RURD P Scope cattle chute to sub and install 0.0 0.0 08:30 10:00 skate ramp. Install cuttings box and berm area. Install berming around cellar, complete interconnects, and start sending steam around rig. Rig accepted at 10:00 hrs. 3/23/2017 3/23/2017 4.50 MIRU MOVE RURD P Install studs in diverter, lower riser 0.0 0.0 10:00 14:30 through table and nipple up. SIMOPS Take on spud mud to pits. 3123/2017 3/23/2017 3.00 MIRU MOVE RURD P Continue tightening up flanges, Make 0.0 0.0 14:30 1730 up hydraulic hoses to diverter, Wrap diverter and apply heat to thaw out, take on 2nd load of spud mud. Inspect conductor ports on starter head and grind down outlets to provide more clearance between conductor outlets and starter head. 3/23/2017 3/23/2017 1.25 MIRU MOVE RURD P Install mouse hole and change out the 0.0 0.0 17:30 18:45 1 1 1 blocks on iron roughneck 3/23/2017 3/23/2017 0.75 MIRU MOVE SFTY P Hold pre -spud with crew and CPAI 0.0 0.0 18:45 19:30 I drilling engineer for 3R-101. Page 1/50 Report Printed: 51212017 - Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tie End rima our (no Phase Op Code Acti dy Coda Tune P -T -X O paretion Start Depth (fl Ka) End Depth (WB) 3/23/2017 3/23/2017 2.75 MIRU MOVE PULD P Pick up and rack back 20 x stands 5" 0.0 0.0 19:30 22:15 19.5# S-135 NC50 DP, drifted w/ 2.867" rabbit. RIH and tag up at 112.85' MD. 3/23/2017 3/24/2017 1.75 MIRU MOVE PULD P Pick up and rack back 5 x stands 5" 0.0 0.0 22:15 00:00 HWDP Standard 1340 grade, 50.38ppf adjusted weight NC50, and jar stand w/ 6-1/4" WFT Mechanical jars. SIMOPS prep for koomey test and prime mud pumps. 3/24/2017 3/24/2017 1.00 MIRU MOVE ROPE P Perform diverter test, witnessed 0.0 0.0 00:00 01:00 waived AOGCC rep Brian Bixby. Test all gas alarms, PVT alarms, rig evacuation alarms, surface annular, and knife valve - good tests. Annular closing time = 28 seconds. Knife opening time = 7 seconds. Perform Koomey drawdown test, Initial pressure = 3050 psi, Manifold pressure = 1500 psi. System pressure after functioning annular = 1900 psi. Build 200 psi in 13 seconds using 2 x electric pumps. Continue building pressure with 2 x electric and 2 x air pumps to full system pressure in 82 seconds. Average pressure of 6 x nitrogen backup bottles = 2600 psi. Finish priming mud pumps and hold PJSM for making up BHA. 3/24/2017 3/24/2017 1.00 MIRU MOVE BHAH P Mobilize BHA components to rig floor 0.0 0.0 01:00 02:00 via beaver slide. 3/24/2017 3/24/2017 1.00 MIRU MOVE BHAH P M/U BHA# 1, clean out BHA 0.0 31.0 02:00 03:00 consisting Baker Hughes MX -1 16" mill -tooth bit, 9-5/8" Mud motor w/ 1.83' bend, 12-1/8" NM Stab, XO, and 5" HWDP. 3/24/2017 3/24/2017 0.50 MIRU MOVE SEQP P Fill lines and conductor w/ thinned out 31.0 31.0 03:00 03:30 spud mud and inspect for leaks, good. Pressure test lines to 3500 psi, good. 3/24/2017 3/24/2017 1.00 SURFAC DRILL DDRL P RIH and spud 16" hole at 03:30 hrs. 45.0 200.0 03:30 04:30 Drill 16" Surface hole from 113 -ft to 20D -ft MD, 200 A TVD at 450 gpm at 460 psi with 20% return flow. Rotating at 40 rpm's at 3k on, 3K off TQ wl 6K WOB. 56K Up wt, 56K On Wt, 56K Rot Wt, MW @ 8.9 ppg, AST =.0, ART = .50, ADT =.50, Bit hrs =.50 3/24/2017 3/24/2017 0.25 SURFAC DRILL TRIP P Stand back 2 stands of 5" HWDP to 200.0 31.0 04:30 04:45 the mud motor to 31' MD and blow down top drive. 3/24/2017 3/24/2017 2.75 SURFAC DRILL BHAH P M/U BHA # 2, drilling BHA consisting 31.0 250-0- 04:45 07:30 of MX -1 16" bit, 1.83 deg motor, GyroPluse, acrVison and Telescope to 125' MD as per SLB DD. Page 2150 ReportPrinted: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stag Time Ertl Time Dur hr ( ) Phase Op Code Activity Code Time P -T-% Operation Start Depth (rt Ka) End Depth (MB) 3/24/2017 3/24/2017 4.50 SURFAC DRILL DDRL P Drill 16" Surface hole from 200 -ft to 200.0 460.0 07:30 12:00 460 -ft MD, 460 A TVD at 450-500 gpm, On Btm SPP 750 psi, Off Btm SPP 500 psi with 15% return flow. Rotating at 50 rpm's at 8k on, 7K off TQ w/ 22K WOB. 67K Up wt, 76K Dn Wt, 79K Rot Wt, MW @) 9.0 ppg, AST = .97, ART, ART= 1.22 , ADT = 2.19, Bit hrs =.2.69, Jar hours= 16.95. Note: Kicked off at 215'. 3/24/2017 3/24/2017 6.00 SURFAC DRILL DDRL P DDrill 16" hole f/ 460'to 870' MD, 866' 460.0 870.0 12:00 18:00 TVD, w/ 550 gpm, On trim SPP 1015 psi, Off btm SPP 758 psi, 16% F/O, 50 rpm, 5-7k Tq, 20-25k WOB, PUW 93k, SOW 85k, ROT 83k w/ 3k Tq, MW 9.1 ppg, AST 2.18, ART 1.61, ADT 3.79, Bit hrs 6.06, Jar hrs 20.74. Note: Swapped from GyroPulse to Telescope readings from 676' onwards. 3/24/2017 3/25/2017 6.00 SURFAC DRILL DDRL P Mill 16" hole f/ 870'to 1164' MD, 870.0 1,164.0 18:00 00:00 1061' TVD, w/ 550 gpm, On Btm SPP 1000 psi, Off Blm SPP 788 psi, 16% F/O, 60 rpm, 3-5k Tq, 20-25k WOB, PUW 90k, SOW 100k, ROT 85k w/ 4k Tq, MW 9.3 ppg, AST 3.68, ART 0.46, ADT 4.14, Bit hrs 10.62, Jar hrs 24.88. 3/25/2017 3/25/2017 6.00 SURFAC DRILL DDRL P Drill 16" Surface hole from 1164' MD 1,164.0 1,613.0 00:00 06:00 to 1613' MD, TVD= 1590' at 550 gpm, On Btm SPP 1240 psi, Off Btm SPP 990 psi with 16% return flow. Rotating at 50 rpm's at 6k on, 4K off TQ w/ 20- 25K WOB. 104K Up wl, 108K Dn Wt, 107K Rot Wt, MW @ 9.3 ppg, AST = 2.5, ART= 2.43 , ADT = 4.43, Bit hrs =15.55, Jar hours= 29.81. 3/25/2017 3/25/2017 6.00 SURFAC DRILL DDRL P Drill 16" Surface hole from1613' MD to 1,613.0 2,170.0 06:00 12:00 2170' MD, TVD= 2109" pump 550- 700 gpm, On Btm SPP 1320-1650 psi, Off Btm SPP 1540 psi with 16% return flow. Rotating at 50 rpm's at 7k on, 5K off TQ w/ 20-25K WOB, 117K Up wt, 112K Dn Wt, 119K Rot Wt, MW @J 9.5 ppg, AST = 2.17, ART= 1.97 , ADT = 4.14, Bit hrs =19.26, Jar hours= 33.52. 3/25/2017 3/25/2017 1.00 SURFAC DRILL DDRL P Drill 16" Surface hole from2170' MD to 2,170.0 2,254.0 12:00 13:00 2254' MD, TVD= 2174' pump 700 gpm, On Btm SPP 1650 psi, Off Btm SPP 1540 psi with 16% return flow. Rotating at 50 rpm's at 7k on, 5K off TQ w/ 20-25K WOB. 117K Up wt, 112K On Wt, 119K Rot Wt, MW @ 9.5 ppg, AST = 0.87, ART= 0, ADT = 0.87, Bit hrs =20.13, Jar hours= 34.39. Page 3150 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log $tart Time End Time Dur hn Phase Op Code Activity Code Time P -T -X Dperabon shot Depth (110) EM Depth (fIKB) 3/25/2017 3/25/2017 1.00 SURFAC CASING CIRC P Circulate bottoms up at TD 2,254.0 2,195.0 13:00 14:00 reciprocating between 2254'- 2195'w/ 800 gpm, 1824 psi, 23% F1O, 60 rpm, 4k Tq, PUW 120k, SOW 114k, ROT 120k. 3/25/2017 3/25/2017 0.50 SURFAC CASING OWFF P Monitor well for flow while rotating at 5 2,195.0 2,195.0 14:00 14:30 rpm, 2k Tq, ROT 120k - well static. 3/25/2017 3/25/2017 2.25 SURFAC CASING BKRM P Backream OOH 112195'- 1720' MD w/ 2,195.0 1,720.0 14:30 16:45 800 gpm, 1820 psi, 23% F/O, 60 rpm, 4k Tq, 500 Whir pulling speed, slowing as needed when pump pressure increases through slides. 3/25/2017 3/25/2017 3.25 SURFAC CASING BKRM P Backream OOH f/ 1720'- 770' MD w/ 1,720.0 770.0 16:45 20:00 550 gpm, ICP 916 psi, FCP 798 psi, 17% F/O, 60 rpm, 1-5k Tq, 500 Whir pulling speed and slowing to 300 Whir for last two stands to CBU x 1 per stand. 3/25/2017 3/25/2017 0.25 SURFAC CASING OWFF P Blowdown topdrive, fill trip tank, and 770.0 770.0 20:00 20:15 monitor well for flow at top of HW DP - well static. 3/25/2017 3125/2017 0.75 SURFAC CASING TRIP P Pull OOH on elevators f/ 770'- 124' 770.0 124.0 20:15 21:00 MD, standing back 5" HWDP and 6- 3/4" NMDC's, monitoring displacement on trip tank. 3/25/2017 3/25/2017 2.00 SURFAC CASING BHAH P Pull OOH f/ 124'- surface laying out 124.0 0.0 21:00 23:00 BHA #1 per SLB, monitoring displacement on trip tank. Bit was packed off with Gays, but other than that no issues observed with BHA. Both 12-1/8" NM Stabilizers were in gauge. The 15-7/8" stabilizer on the mud motor came out 1/8" undergauge. The Baker MX -1 bit graded 1 -1 -WT -A- E -0 -NO -TD. 3/25/2017 3/26/2017 1.00 SURFAC CASING BHAH P Clear floor of BHA components. 0.0 0.0 23:00 00:00 3/26/2017 3/26/2017 2.00 SURFAC CASING RURD P Rig up to run 13-3/8" casing. Rig up 0.0 0.0 00:00 02:00 GBR Volant, Spiders, bail extensions and 150T elevators. SIMOPS, prep pipe shed for running casing and install stop collars on shoe track. 3/2612017 3/26/2017 1.00 SURFAC CASING PUTB P RIH w/ 13-3/8", 68#, L-80 Hydrill 563 0.0 122.0 02:00 03:00 casing. M/U Shoe track consisting of DavisLynch float collar and DavisLynch float shoe to 122' MD. Test floats, good. 3/26/2017 3/26/2017 5.50 SURFAC CASING PUTB P RIH w/ 13-3/8", 68#, L-80 Hydrill 563 122.0 1,760.0 03:00 08:30 casing f/ 122' MD to 1760' MD installing a bow spring centralizer around every collar.. Ran 29 joints of 13-3/8" Hydrill 563 Dopeless from # 4 to #32. Torqued dopeless pipe to 33K to fully make up. After # 32 13-3/8" Hydrill 563 doped pipe was made up to 26K. 3/26/2017 3/26/2017 1.00 SURFAC CASING CIRC P Circulate casing volume below base of 1,760.0 1,760.0 08:30 09:30 permafrost. Stage pumps up to 6 bpm= 150 psi. P/U= 142K, S/O= 136K, Page 4/50 ReportPrinted: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) Phase Op Code Activity cede Time P -R% Operenon Stan Oepth (Po(a) End Oepm (WS) 3/26/2017 3/26/2017 1.50 SURFAC CASING PUTS P RIH wl 13-318", 68#, L-80 Hydrill 563 1,760.0 2,199.0 09:30 11:00 casing f/ 1760' MD to 2199' MD installing a bow spring centralizer around every collar. A total of 55 bow springs ran in the hole. 3/26/2017 3126/2017 0.25 SURFAC CASING CIRC P Circulate while moving the landing 2,199.0 2,199.0 11:00 11:15 joint to pipe skate. Stage pumps up to 3 bpm= 108 psi. P/U= 190K, S/0= 150K. 3/26/2017 3/2612017 0.25 SURFAC CASING HOSO P M/U GE mandrel casing hanger and 2,199.0 2,243.0 11:15 11:30 landing joint. RIH and landing casing on load ring @ 2243' MD PIU 191K, S/0= 153K. 3/26/2017 3/2612017 3.50 SURFAC CEMENT CIRC P Circulate/ condition mud through 2,243.0 2,243.0 11:30 15:00 volant tool while reciprocating pipe f/ 2243'- 2213', staging up pumps to 7 bpm, 65 psi, 7% F/0, PUW 184k, SOW 160k. Pump 85 bbl red -dye marker pill and circulate around, see at surface at 5700 strokes. 3/26/2017 3/26/2017 0.25 SURFAC CEMENT RURD P Blow down topdrive and rig up cement 2,243.0 2,243.0 15:00 15:15 hose to side -entry sub on volant tool. 3/26/2017 3126/2017 1.25 SURFAC CEMENT CIRC P Circulate / condition mud through 2,243.0 2,243.0 15:15 16:30 cement hose while reciprocating pipe V 2243'- 2213' at 7 bpm, 171 psi, 8% F/O, PUW 189k, SOW 163k, total strokes pumped = 16143. Hold PJSM with crew for cement job. 3/26/2017 3/26/2017 2.25 SURFAC CEMENT CMNT P Line up to Schlumberger cementers 2,243.0 2,243.0 16:30 18:45 and pressure test lines to 4500 psi - good test. Reciprocate pipe —20 It and Pump 40.3 bbls of 8.3ppg CW100 at 6.5 bpm, 135 psi, followed by 80 bbls of 10.5ppg Mudpush II spacer at 5.5 bpm, 90 psi. Shut down and drop bottom plug, using back-up tongs while releasing / making up Volant tool to prevent moving landing joint. Pump 316.6 bbls 11.0ppg Lilecrete lead cement at 6.5 bpm, ICP 200 psi, FCP 180 psi, 10% FIC, followed by 75.9 bbis 12.Oppg Deeperete tail cement at 6.5 bpm, 200 psi, 8% F/0. Observe hole suddenly get sticky, losing 40k down weight with 50 bbls of tail pumped so landed pipe for remaining part of job. Shut down and drop top plug, using back-up tongs while releasing / making up Volant tool to prevent moving landing joint. Page 5150 Report Printed: 51212017 J_�� Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL rime Log seen Time EM Time our hr ( ) phase Op Code ACbvity Code Time P -T -X Operaaan start Depth (n De End Depth (WB) 3/26/2017 3/26/2017 1.00 SURFAC CEMENT CMNT P Line up to rig pump and displace 2,243.0 0.0 18:45 19:45 cement with treated 9.6ppg spud mud at 7 bpm, ICP 166 psi, FCP 455 psi, 9% F/O. Slow down to 3 bpm, 290 psi, 5% F/O 10 bbls prior to bumping plug. Bump plug at 3090 strokes and pressure up to 800 psi. Hold for 5 minutes, bleed off and check floats - floats holding. Total of 86 bbis of cement returned to surface. Cement in place @ 19:39 hrs. 3/26/2017 3/26/2017 1.25 SURFAC CEMENT RURD P Rig down volant tool, drain riser and 0.0 0.0 19:45 21:00 stack, and flush surface equipment with black water pill. Blow down and clean out cement valves. Clean / clear rig floor. 3/26/2017 3/26/2017 2.00 SURFAC CEMENT RURD T Attempt to back out 13-3/8" landing 0.0 0.0 21:00 23:00 joint with chain tongs (right-hand release) with bushings installed - unsuccessful. Make up rig tong for right-hand release and attempt to back out 13-3/8" landing joint with bushings installed - unsuccessful. Rig down riser and pull bushings. Attempt to back out landing joint with rig tong while monitoring coupling in middle of landing joint - observe top pup making up into bottom pup joint. Discuss path forward with town. Note: Hanger has 13-5/8" Stub ACME pin w/ 2 threads per inch looking up. Bottom of 13-3/8" BTC landing joint makes up into "landing sub" which is 13-3/8" BTC box looking up by 13-5/8" Stub ACME pin looking down. Observe 13-3/8" landing joint naturally wanting to lean towards driller cab and contacting side of flow box at rig floor. 3/26/2017 3/27/2017 1.00 SURFAC CEMENT RURD T Hold PJSM with crew. Nipple down 0.0 0.0 23:00 00:00 surface annular at knife valve, de - energize starting head, make up bridge crane to annular and lift above top of wellhead and secure lines. Observe landing sub still made up flush to wellhead. Start heating up ACME connection with steam. SIMOPS - continue cleaning pits, load 5" DP in shed, and prep for rigging down diverter line. 3/27/2017 3/27/2017 1.50 SURFAC CEMENT RURD T Hold PJSM with crew. Re -install 0.0 0.0 00:00 01:30 bushings and rig up GBR Volant tool while healing up ACME connection with steam. Attempt to back -out landing joint w/ 30k torque to the right - unsucessful. No movement observed. Page 6/50 Report Printed: wvnll Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) Phase Op Code Adivity Code Time P -T -X Operators Start Dept, (ftKB) Ertl Depth (fiKB) 3/27/2017 3/27/2017 1.00 SURFAC CEMENT RURD T Remove Volant tool, pull bushings, 0.0 0.0 01:30 02:30 and make up rig tong for right-hand release while heating ACME connection with steam. Attempt to back -out landing joint with 30k torque - observe buttress connection making up into landing sub just above wellhead. No sign of movement for ACME connection - landing sub still flush on top of wellhead. Discuss path forward with town. SIMOPS - Install 9-5/8" casing rams in top set of rams in BOP. 3/27/2017 3/27/2017 2.00 SURFAC CEMENT RURD T Weld top and bottom of coupling to 0.0 0.0 02:30 04:30 landing joint to ensure top pup would not make up anymore into bottom pup. Weld top of landing sub to landing joint to ensure buttress connection would not make up anymore into landing sub. Heat up ACME connection with torch (rose -bud tip) to temperature limit of 300°F per Vetco. 3/27/2017 3/27/2017 0.25 SURFAC CEMENT RURD T Make up rig tong for right-hand 0.0 0.0 04:30 04:45 release and attempt to back -out landing joint with bushings removed, staging up slowly to 42k torque - at 42k torque, observe entire landing joint / landing sub / hanger / landing ring turn 2.5 inches. Discuss path toward with town. 3/27/2017 3/27/2017 0.50 SURFAC CEMENT RURD T Weld bottom part of landing ring to 0.0 0.0 04:45 05:15 conductor and re -heat ACME connection with torch (rose -bud fip) to temperature limit of 300°F per Vetco. 3/27/2017 3/27/2017 0.25 SURFAC CEMENT RURD T Make up rig tong for right-hand 0.0 0.0 05:15 05:30 release and attempt to back -out landing joint with bushings removed, staging up slowly to 42k torque - at 42k torque, observe ACME connection come free and start turning. Make up chain tongs and confirm landing joint released from hanger. 3/27/2017 3/27/2017 0.50 SURFAC CEMENT RURD T Lower surface annular and starting 0.0 0.0 05:30 06:00 head back down onto conductor and secure. 3/27/2017 3/27/2017 0.50 SURFAC CEMENT RURD P Back out landing joint with chain tongs 0.0 0.0 06:00 06:30 and pull to rig floor. Inspect ACME threads - no noticeable damage observed to indicate galling. Lay down landing joint. 3/27/2017 3/27/2017 1.00 SURFAC CEMENT RURD P Rig down GBR Volant tool, bail 0.0 0.0 06:30 07:30 extensions, and elevators and clear rig floor. SIMOPs - Nipple down diverter line. 3127/2017 3/27/2017 1.50 SURFAC WHDBOP NUND P Nipple down surface diverter and 0.0 0.0 07:30 0900 starting head. Page 7150 Report Printed: 5/212017 . ` Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Tma ow(hr) Phase op code Activity Code Time P -T -X opeezaen Bf ( Depth(rt (MB) Eno Depth (hKB) 3/27/2017 3/27/2017 2.00 SURFAC WHDBOP NUND P Remove starting thread protector on 0.0 0.0 09:00 11:00 rasing hanger and nipple up Vetoo MB 222A wellhead system. Test seal sub to 2000 psi / 15 min - good test. Note: Inspected internal ACME threads on hanger - no signs of galling or damage observed. 3/27/2017 3/27/2017 4.50 SURFAC WHDBOP NUND P Nipple up spacer spools and 13-5/8" 0.0 0.6- 11:00 15:30 BOPE stack w/ 9-5/8" casing rams in top set and 3-1/2" x 6" VBR's in bottom set. Install riser. Remove 4" valves and 90° elbows on conductor and install caps. Install mousehole. 3/27/2017 3/28/2017 8.50 SURFAC CEMENT PULD P Pick up and rack back 70 x stands 5" 0.0 0.0 15:30 00:00 19.5# S-135 NC50 drill pipe via mousehole. 3/28/2017 3/28/2017 1.00 SURFAC CASING PULD P Cont to pick up 5" DP via mouse hole 0.0 0.0 00:00 01:00 and stand back in the derrick. Picked up a total of 77 stands of 5" DP. 3/28/2017 3/28/2017 1.00 SURFAC WHDBOP RURD P Rig to test BOPE, set test plug, install 0.0 0.0 01:00 02:00 9-5/8" test joint and purge air from system. 3/28/2017 3/28/2017 5.00 SURFAC WHDBOP BOPE P The BOPE was tested on 3/28/17 0.0 0.0 02:00 07:00 with 5" and 9-5/8" test joint to 250/3500 psi. Guy Cook of AOGCC waived witness Test Sequence as follows: With 9-5/8 Test joint 1) Annular, Mud Manifold valves 1,12,13, 14, and 4" Kill line, 4-1/2" IF Dart Valve 2) Upper Rams, Mud Manifold valves 9, 11 and Mezz Kill line, 4-1/2" IF Full Open Safety Valve 3) Upper Rams, Mud Manifold valves 8,10 and HCR Kill line 4) Upper Rams, Mud Manifold valves 6, 7 and HCR Kill line 5) Manually Operated Choke 6) Super Choke 7) Manual Kill, Mud Manifold valves 2 and 5 8) HCR Choke 9) Manual Choke With 5" Test Joint 10) Annular, and Upper IBOP 11) LPR's with 3-1/2 x 6" VBR's, and Lower MOP 12) Blinds, Mud Manifold valves 3, 4, and 6 System Pressure = 3,050 psi PSI after closure = 1,800 psi 200 psi Attained = 9 seconds Full Pressure attained = 51 seconds N2 = 6 each [art 2,583 psi Pass / Fails Choke valve #8, greased and cycled, pass Page 8/50 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) Phase Do Code Ac My Code Time P-T-X O peration Stan Depth n De EM Depth (flKB) 3/28/2017 3/28/2017 1.00 SURFAC WHDBOP RURD P RID testing equipment, blow down 0.0 0.0 07:00 08:00 choke and kill lines. Install GE wear bushing, ID- 12-3/8". 3/28/2017 3/28/2017 3.00 SURFAC CASING BHAH P Pick up BHA as per SLB, M/U 12-1/4" 0.0 413.0 08:00 11:00 MSi619 bit, Xceed, Telescope and arcVision. 3/28/2017 3/28/2017 2.00 SURFAC CASING TRIP P RIH with 5" DP up wt = 108k, DWN 413.0 2,022.0 11:00 13:00 100K. Monitor displacement via trip tank. 3/28/2017 3/28/2017 2.00 SURFAC CASING SLPC P Slip Cut 44' Drill line. Calibrate blocks. 2,022.0 2,022.0 13:00 15:00 3/28/2017 3/28/2017 1.00 SURFAC CASING PRTS P RU and flood lines Test surface casing 2,022.0 2,155.0 15:00 16:00 to 3000 PSI. charted 30 min (PASSED). 47 STKS to pressure up with 4 1/2 BELS bleed back. 3/28/2017 3/28/2017 6.00 SURFAC CASING DRLG P Drill out shoe track from TOC at 2,155' 2,155.0 2,254.0 16:00 22:00 to 2,254' MD at 450 GPM 535 PSI 15% F/O 60 RPM, 71K tq, 2-20K WOB. Off bottom = 530- PSI UP WT =108K, DWN WT=100 K. ROT= 108K 51K To. 3/28/2017 3/28/2017 0.50 SURFAC CASING DRLG P Drill 20' new hole in prep for FIT. 2,254.0 2,274.0 22:00 22:30 2,274' MD. 2,174' TVD. @ 512 GPM 682 PSI DPP. 17% F/O 60 RPM, 3- 6K TO. 4K WOB Off BTM = 669 PSI Up WT 111K, DWN = 100K. ROT- 108K 5K To. 3/28/2017 3/28/2017 0.50 SURFAC CASING CIRC P Circulate bottoms up plus to condition 2,274.0 2,274.0 22:30 23:00 mud prior to FIT. 9.5 in / out. 3/28/2017 3/29/2017 1.00 SURFAC CASING LOT P Perform LOT / PIT 2. 12.6 PPG 2,274.0 2,274.0 23:00 00:00 achieved @ 340 PSI. Total strokes = 8. Bled .2 BBLS back. 3/29/2017 3/29/2017 1.00 INTRMI DRILL CIRC P Displace well to 9.2 LSND. 800 GPM 2,274.0 2,274.0 00:00 01:00 at 1000 PSI. Send down links to orient Xceed due to quick turn. 3/29/2017 3/29/2017 5.00 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 2,274.0 2,928.0 01:00 06:00 2274' MD to 2928' MD, TVD= 2625'. Pump @ 800 gpm= 1039 psi w/ 20 % FO. Rotate @ 120 rpm w/ 7K Tq on, 4K Tq off. WOB= 1-8K, ECD= 9.7 ppg EMW with 9.2 ppg MW. ADT= 4.14, Bit hrs= 4.14, Total Jar hrs= 152.42. P/U= 120K, S/O= 102K, ROT= 116K. Max gas= 0. Obtain slow pump rates @ 2822' MD, TVD= 2569 Pump #1: 30 spm= 120 psi, 40 spm=150 psi. Pump # 2: 30 spm= 120 psi, 40 spm= 140 psi. Page 9150 ReportPrinted: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time EM Time ur D(hr) Phase op Code Activity Code Time P -T -X Operation SteM1 � (ttK8) End DapM (WB) 3/29/2017 3/29/2017 6.00 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 2,928.0 3,950.0 06:00 12:00 2928' MD to 3950' MD, TVD= 2836'. Pump @ 926 gpm= 1605 psi w/ 22 % FO. Rotate @ 160 rpm w/ 13K Tq on, 8K Tq off. WOB= 6-9K, ECD= 9.82 ppg EMW with 9.2 ppg MW. ADT= 4.11, Bit hrs= 8.25, Total Jar hrs= 156.53. P/U= 123K, S/O= 89K, ROT= 106K. Max gas= 0. 2822' TVD SPR 1 - 30 SPM 120 140 SPM 150 SPR 2 - 30 SPM 120 / 40 SPM 140 3/29/2017 3/29/2017 6.00 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 3,950.0 5,050.0 12:00 18:00 3950' MD to 5,050' MD, TVD= 3,000'. Pump @ 925 gpm= 1,902 psi w/ 22 % FO. Rotate @ 160 rpm w/ 1-13K Tq on, 7K Tq off. WOB= 6-9K, ECD= 10.09 ppg EMW with 9.4 ppg MW. ADT= 4.38, Bit hrs= 12.63, Total Jar hrs= 160.91. 4,855' TVD / 2,970' TVD / MW = 9.41 1730 PM SPR 1 - 30 SPM 150 / 40 SPM 180 SPR 2 - 30 SPM 150 / 40 SPM 180 3/29/2017 3/30/2017 6.00 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 5,050.0 5,808.0 18:00 00:00 5,050' MD to 5,808' MD, TVD= 3,131'. Pump @ 925 gpm= 2.132 psi w/ 22 °% FO. Rotate @ 100-160 rpm w/ 12K Tq on, 7-15K WOB, ECD= 10.10 ppg / Off Bottom -2,126 PSI, UP WT = 132 / DWN WT = 90K. ROT 112K w/8K TO // EMW with 9.4 ppg MW. ADT= 4.06, Bit hrs= 16.69, Total Jar hrs= 164.97. 3/30/2017 3/30/2017 6.00 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 5,808.0 6,659.0 00:00 06:00 5,808' MD to 6659' MD, TVD=3280'. Pump @ 925 gpm= 2415 psi w/ 22 % FO. Rotate @ 100-160 rpm w/ 14K Tq on, 4-15K WOB, ECD= 10.30 ppg / Off Bottom -2240 PSI, UP WT = 150 / DWN WT = 72K. ROT 115K w/8K To, 9.4 ppg MW. ADT= 4.2, Bit hrs= 20.89, Total Jar hrs= 169.17. Page 10/50 Report Printed: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM Time Dur hr ( ) Phase Op code Activity Cotle Time P -T -X Opeeefion Stan Depth (rt De End Depth (kKe) 3/30/2017 3/30/2017 6.00 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 6,659.0 7,405.0 06:00 12:00 6659' MD to 7405' MD, TVD=3422'. Pump @ 925 gpm= 2515 psi w/ 22 % FO. Rotate @ 150-160 rpm w/ 13K Tq on, 4-17K WOB, ECD= 10.04 ppg / Off Bottom -2436 PSI, UP WT = 158 / OWN WT = 79K. ROT 115K W/1 2K TO , 9.4 ppg MW. ADT= 4.63, Bit hrs= 25.52, Total Jar hrs= 173.80. Obtain slow pump rates @ 6848' MD, TVD= 3305 Pump #1: 30 spm= 220 psi, 40 spm=240 psi. Pump # 2: 30 spm= 220 psi, 40 spm= 240 psi. 3/30/2017 3/30/2017 7.25 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 7,405.0 8,030.0 12:00 19:15 7405' MD to 8030' MD, TVD=3501'. Pump @ 750 gpm= 1775 psi w/ 21 % FO. Rotate @ 160 rpm mill 5K TQ , 5- 15K WOB, ECD= 10.22 ppg / Off Bottom -1790 PSI, UP WT = 161 / OWN WT = 82K. ROT 114K w/12K To, 9.4 ppg MW. ADT= 5.42, Bit hrs= 30.94, Total Jar hrs= 179.22. Obtain slow pump rates @ 7,505' MD, TVD= 3,440'@ 13:15hrs Pump #1: 30 spm= 200 psi, 40 spm= 240 psi. Pump # 2: 30 spm= 200 psi, 40 spm= 240 psi. 3/30/2017 3/30/2017 0.75 INTRMI DRILL CIRC P Rotate and circulate bottoms up to 8,030.0 8,030.0 19:15 20:00 clean hole & send dwn links. from 8,030' MD to 7,983' MD @ 850 GPM 2,257PSI, 21% F/O. 120 RPM with 12K TQ. TOT stks = 7,822 Discuss with Anch turn requirements. 3/30/2017 3/30/2017 0.50 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 8,030.0 8,078.0 20:00 20:30 8,030' MD to 8,078' MD, TVD='. Pump @ 751 gpm= 1791 psi w/ 21 % FO. Rotate @ 160 rpm w/1 5K TQ , 7K WOB, ECD= 10.12 ppg / Off Bottom -1795 PSI, UP WT = 164 / OWN WT = 72K. ROT 118K w/1 2K TO, 9.4 ppg MW. ADT= 1.36, Bit hrs= 31.22, Total Jar hrs= 179.5. 3/30/2017 3/30/2017 1.00 INTRMI DRILL CIRC T Rotate and circulate bottoms up while 8,078.08,078.0 20:30 21:30 in discussion with Anchorage over inability to gain desired directional tum. Rotating from 8,058' to 7,983'@ 850 GPM 2,229 PSI 120 RPM. 14K TO total strokes 11,947. Page 11160 Report Printed: 512/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log shed Time Ed Time Our (hr) Phase Op Code A= Code ty Toe P-T-X Operation rt De Start depth End OepVi (MCB) 3/30/2017 3/31/2017 2.50 INTRMI DRILL BKRM T BROOH from 8,078'to 7,418' @ 909 8,078.0 7,418.0 21:30 00:00 GPM ICP = 2,462'22% F/O. 150 RPM 15K TQ. Up WT 164K OWN 72K w/o pumping Prior to BROOK 8,056' MD 3,504' TVD MW PPG - 9.4 PPG. Time 2130 hrs. MP1 - 30 SPM 225PSI 40 SPM 275 PSI MP2 - 30 SPM 225PSI 40 SPM 275 PSI Perfom no flow check for 10 min prior to BROOK (Passed) 3/31/2017 3131/2017 6.00 INTRMI DRILL BKRM T BROOH from 7,418'to 5140' MD. 7,418.0 5,140.0 00:00 06:00 Circulating 900 SPM @ 2,410 PSI DPP 150 RPM @ 11 K TQ. ECD = 10.21 PPG. 97 UP WT. 3/31/2017 3/31/2017 7.00 INTRMI DRILL BKRM T BROOH from 5140'to inside casing 5,140.0 2,422.0 06:00 13:00 shoe @ 2208' MD. Circulating 900 SPM @ 2,145 PSI DPP 150 RPM @ 4K TQ. ECD = 10.15 PPG. 98 UP WT. Observed cuttings load increase 100% @ — 2700' MD and increase 300% @ 2450' MD. Circulating out large clay/sand balls about 4" to 8" in diameter. 3/31/2017 3/31/2017 3.00 INTRMI DRILL TRIP T Monitor for flow (Static) and POOH on 2,422.0 182.0 13:00 16:00 elvators to 413' Stand back HW DP and prep to LD BHA 3/31/2017 3/31/2017 2.00 INTRMI DRILL BHAH T LD BHA#2 as per SLMB DD. Monitor 182.0 0.0 16:00 18:00 well for flow. (Static). 3/31/2017 3/31/2017 1.50 INTRMI DRILL SHAH T Clean rig floor and LD BHA3@ 0.0 0.0 18:00 19:30 outside. Pick up BHA#3 from outside and prepare to RIH. 3/31/2017 3/31/2017 3.00 INTRMI DRILL BHAH T PU Intermediate BHA #3 as per SLB 0.0 238.0 19:30 22:30 1 1 DO to 238'MD Monitor disp via TT. 3/31/2017 3/31/2017 1.25 INTRMI DRILL TRIP T PU Non mag HWDC & HWDP to 425' 238.0 2,215.0 22:30 23:45 MD. Up WT 63K DWN=71 K. Continue to RIH to 2,215' MD UP 105K OWN 106K Monitor disp via TT. 3/31/2017 4/1/2017 0.25 INTRMI DRILL DHEQ T Shallow hole lest of MWD / roll hole to 2,215.0 2,220.0 23:45 00:00 1.5% lube 656 GPM 893 PSI DPP. 22% F/O good test. UP WT = 108K Up. 99K OWN. 4/1/2017 4/1/2017 6.00 INTRMI DRILL TRIP T Circulate and rotate while RIH filling 2,220.0 7,998.0 00:00 06:00 every ten stands and performing check shot surveys. RIH fromt 2,210 MD - to - 7,998' MD... 675 GPM, 1270 PSI, 19% FIC, 20 RPM 4K TQ. MW in 9.3 - MW out 9.3+ Obtain SPR's and service washpipe. UP WT 107K DWN WT = 109K. ROT 106K. SPR @ 2,210' MD 2,137' TVD MW = 9.3 PPG Time 0030 MP-1) 20 SPM-100 PSI / 30 SPM - 120 PSI MP-2) 20 SPM-100 PSI / 30 SPM - 120 PSI Page 12150 Report Printed: 51212017 - - Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dm (hr) Phase Op Cade Aativi Cada ly Time P4 -X 0 perstxm Start Depth (flK8) End Depth (fl B) 4/1/2017 4/1/2017 1.25 INTRMI DRILL CIRC T CBU to condition hole and remove 7,988.0 8,078.0 06:00 07:15 heavy mud post trip. Rotate and Recip from 7998' MD to 8078' MD, pump @ 650 gpm= 1600 psi, 20% FO, 50 rpm's w/ 12K Tq, ECD= 9.81, MW= 9.3 + ppg. P/U= 153K, S/O= 79K, ROT= 121 K. SPR @ 8,068' MD 3,504' TVD MW = 9.3+ PPG Time 0700 MP -1) 20 SPM - 200 PSI / 30 SPM - 230 PSI MP -2) 20 SPM - 200 PSI 130 SPM - 230 PSI 4/1/2017 4/1/2017 4.75 INTRMI DRILL DDRIL P DDRIL from 8078' MD to 8,240' MD 8,078.0 8,240.0 07:15 12:00 3,520' TVD. 850 GPM 2,560 PSI DPP. 22% F/O, 40 RPM, 15K TQ, 6.51K WOB ECD = 9.83, UP WT = 150K, OWN WT = 79K, ROT = 123K, 13K TQ, ADT = 2.01, ART =.51, AST =1.5 BIT HRS =2.01, jar hrs= 181.51. 4/1/2017 4/1/2017 6.00 INTRMI DRILL DDRIL P DDRIL from 8,240' MD to 8,535' MO 8,240.0 8,535.0 12:00 18:00 3,572' TVD. 635 GPM 1,618 PSI DPP. 22% F/O, 40 RPM, 15K TQ, 6.51K WOB ECD = 9.84, UP WT = 160K, OWN WT= 72K, ROT= 115K, 13K TQ, ADT = 3.13, ART =.66, AST = 2.47 BIT HRS = 5.14, jar hrs = 184.64. 4/1/2017 4/2/2017 6.00 INTRMI DRILL DDRIL P DDRIL from 8,240'MD to 894VMD 8,535.0 8,941.0 18:00 00:00 3,520' TVD. 7750 GPM 2415 PSI DPP. 22% F/O, 40 RPM, 15K TO, 15K WOB ECD = 9.94, UP WT = 150K, DWN WT = 70K, ROT = 116K, 14K TQ, ADT = 3.81, ART =.44, AST = 3.37 BIT HRS = 8.95, jar hrs = 188.45. SPR Q 8841' MD 3591' TVD MW = 9.5 PPG Time 2230 MP -1) 20 SPM -330 PSI / 30 SPM - 360 PSI MP -2) 20 SPM -320 PSI / 30 SPM - 340 PSI 4/2/2017 4/2/2017 6.00 INTRMI DRILL DDRIL P DDrill 12-1/4" Intermediate hole from 8,941.0 9,538.0 00:00 06:00 8941' MD to 9538' MD, TVD= 3612'. Pump @ 850 gpm= 3150 psi w/ 80% FO. Rotate @ 40 rpm's w/ 15K Tq on / 13K off. WOB= 4K, ECD= 10.3 ppg w/ 9.4 ppg MW. P/U 171 K, S/O= 81 K, ROT= 130K. ADT= 3.43, AST= .66, ART= 2.77, Total bit hours= 12.38, Total Jars hours= 191.88. Page 13/50 ReportPrinted: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur hr Dur(hr) Phase Op Calle Activity CcOe Time P -T -X Operation Sten cepth (flKe) Entl OspN (N(a) 4/2/2017 4/2/2017 4.50 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 9,538.0 9,743.0 06:00 10:30 9538' MD to 9743' MD, TVD= 3636'. Pump @ 650 gpm= 2300 psi wl 20% FO. Rotate @ 40 rpm's w/ 15K Tq on I 13K off. WOB= 4K, ECD= 10.3 ppg w/ 9.5 ppg MW. P/U 184K, S/O= 77K, ROT= 130K. ADT= 2.27, AST= 1.48, ART= .79, Total bit hours= 15.01, Total Jars hours= 194.51. 4/2/2017 4/2/2017 1.50 INTRM1 CASING CIRC P Obtain on bottom survey as per DO 9,743.0 9,691.0 10:30 12:00 and stand 1 stand back to 9691' MD. Pump 70 bbls of weighted high vis sweep and circulate sweep around. Pump @ 850 gpm= 3420 psi w/ 20% FO, Rotate @ 80 rpm's w/ 16K Tq. ECD= 10.3 ppg EMW. 4/2/2017 4/2/2017 0.25 INTRMI CASING OWFF P 9691 Observer well for flow. NOflow. 9,691.0 9,691.0 12:00 12:15 4/2/2017 4/2/2017 6.25 INTRMI CASING BKRM P BKRM OOH 9,691-7,955 MD UP WT 9,691.0 7,955.0 12:15 18:30 171 K. DWN = 87K. 850 GPM w/ICP = 3,290 PSI, FCP = 2,920 PSI. Flo 22%,40 RPM, 15K TO. ROT WT 130K. Observed tight spot at 8,300' MD. 10.3 ECD. Circ and condition hole while backreamming. 4/2/2017 4/2/2017 0.25 INTRMI CASING OWFF P OWFF / Blow down top drive. 7,955.0 7,995.0 18:30 18:45 4/2/2017 4/3/2017 5.25 INTRMI CASING TRIP P POOH on elevators monitor 7,995.0 2,697.0 18:45 00:00 displacement via TT. UP WT = 177K DWN WT = 70K. Observe 30K overpull at 3,966', 3,490', 3,465' MD. 4/312017 4/3/2017 0.50 INTRMI CASING TRIP P Continue to POOH from 2,697'to 2,697.0 2,220.0 00:00 00:30 2,220' MD. up wt = 107K DWN = 106K 4/3/2017 4/3/2017 1.00 INTRMI CASING CIRC P Pull stripping rubber and circulate 2,220.0 2,220.0 00:30 01:30 bottoms up while rotating and reciprocating from 2,220'- 2,130' MD. 850 GPM at 1,970 PSI. F/O 23% at 40 RPM 3-6K To. MW in I out 9.5 PPG. Dry job 11.4#. install strip rubber and BD TD. 4/3/2017 4/3/2017 1.00 INTRMI CASING TRIP P POOH from 2,220' to 425' MD. 2,220.0 425.0 01:30 02:30 Monitor disp via TT. 4/3/2017 4/3/2017 0.25 INTRMI CASING OWFF P Pull stripping rubber and monitor well 425.0 0.0 02:30 02:45 f.10 min. dropped 1'. 4/3/2017 4/3/2017 2.75 INTRMI CASING SHAH P Stand back HWDP & collars. LD BHA 0.0 0.0 02:45 05:30 #3 per DO from 425'. Monitor well disp via TT. Trip disp = 90.6 BBLS. 4/3/2017 4/3/2017 3.00 INTRMI CASING RURD P Clean rig floor and surrounding area. 0.0 0.0 05:30 08:30 LD BHA on and off floor. Take measurements and photo's for Anch. Flush stack and pull wear bushing. Rig up casing running equipment Volant CRT, install bail extensions/ elevatorslspiders and verify casing count. Page 14150 ReportPrinted: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur (hr) Phase Op Code Acbvdy Code Time P -T -X O peaeon S Depui rft ((t De End DepUt (ttKa) 4/3/2017 4/3/2017 3.50 INTRMI CASING PUTB P PJSM and RIH with 9 5/8" 40# rasing 0.0 1,027.0 08:30 12:00 per pipe tally. fill on the fly with Volant CRT. top off every ten joints check float equip on joint #3. (passed). 2 BPM = 5% F/O, 5 BPM = 7% F/O. 8 BPM = 13% F/O. Torqing connections to 15K FT/LB. 4/3/2017 4/3/2017 3.00 INTRMI CASING PUTS P RIH with 9 5/8" 40# casing from 1027- 1,027.0 2,228.0 12:00 15:00 2228' MD. fill on the fly with Volant CRT. top off every ten joints. 15K TO. 4/3/2017 4/3/2017 0.50 INTRM1 CASING CIRC P Cir and condition mud. stage pumps 2,228.0 2,228.0 15:00 15:30 up to 6 BPM. ICP = 81 PSI. 8% F/O. UP WT = 116K, OWN WT = 116. ROT WT = 118 with 4K TQ.@ 20 RPM. 4/3/2017 4/3/2017 6.00 INTRMI CASING PUTS P Continue to RIH from 2228 - 4380' 2,228.0 4,380.0 15:30 21:30 MD. Instaling Hydroform centralizers and stop rings on the fly. TQ conn to 15K. fill with Volant tool every 10. 4/3/2017 4/3/2017 1.00 INTRMI CASING CIRC P Mud weight found to be 9.8+ during 4,380.0 4,380.0 21:30 22:30 displacement. Stag up pumps to 6 BPM. ICP = 220 PSI. FCP 163 PSI. 8% F/O Mup weight in 9.4 Final mud weight out = 9.6 PPG. Pumped 3,490 strokes. Wt increase to 114K after shutting pumps dwn. 4/3/2017 4/4/2017 1.50 INTRMI CASING PUTS P Continue to RIH with 9 5/8" casing 4,380.0 5,075.0 22:30 00:00 installing Hydraform centralizers on rig floor. torque all conections to 15K. 4/4/2017 4/4/2017 3.00 INTRMI CASING PUTS P Continue to RIH with 9 5/8" casing as 5,075.0 6,410.0 00:00 03:00 per pipe tally. 15K TO filling on the fly every 10 joints. 4/4/2017 4/4/2017 1.50 INTRMI CASING CIRC P Circulate bottoms up while RIH with 6,410.0 6,500.0 03:00 04:30 three joints to 6,500' MD. 6 BPM @ 230 PSI, 7% F/O. Pumped a total of 3,800 STKS MW in 9.5 PPG. MWO 9.7 PPG. DWN WT 109K. 4/4/2017 4/4/2017 5.50 INTRMI CASING PUTS P Continue to RIH with 9 5/8" Hyddl 521 6,500.0 8,816.0 04:30 10:00 Casing to 8,816' MD. all connections torqued to 15K with Volant tool. Fill on fly every 10 joints. 4/4/2017 4/4/2017 2.75 INTRMI CASING PUTB P C/O elevators and make up crass over 8,816.0 9,692.0 10:00 12:45 from 9 5/8" 521 to 9 5/8" 563 casing. Continue to RIH with Hydril 563 casing to 9,565 MD. Torque all oonenctions to 15K and fill on the fly with Volant tool. Top off every 10. 74K OWN WT. 4/4/2017 4/4/2017 0.25 INTRMI CASING PUTS P MU hanger and landing joint / pull 9,692.0 9,732.0 12:45 13:00 spiders and RIH to 9,732' MD 4/4/2017 4/4/2017 1.50 INTRM1 CASING CIRC P Reciprocate casing from 9,732'-9,724' 9,732.0 9,732.0 13:00 14:30 MD conditioning mud. Stage pumps to 7 BPM. 296 GPM = 389 PSI, Up WT=268K. OWN WT=54K. Pumped total 22 BBIs. 9.5 PPG in / 10.3 out VIS 250 H2O @ 20. Page 15150 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Steil Depm Stag Time End Time our (hr) Phase op Code Activity Code Time PJA Operation (WS) End Depth (WS) 4/4/2017 4/4/2017 2.25 INTRMI CASING CIRC P Install cement hose and reciprocate 9,732.0 9,732.0 14:30 16:45 from 9,732'-9,724' MD. Staging pumps up to 8 BPM . 342 GPM = 408 PSI. UP WT=268K SWN WT=54K. 9.6 PPG in 19.8 out Vis 78 H2o @ 10. 4/4/2017 4/4/2017 0.75 INTRMI CASING HOSO P Challenges working pipe back down 9,732.0 9,732.0 16:45 17:30 after reciprocating this whole time. Setting down to 35k and slowly work through obstruction and land hanger on Ring. Continue to circulate at 8 BPM GPM = 342 PSI=408. 13,844 strokes pumped. Lost a total of 8 BELS while RIH with 9 5/8" casing. 4/4/2017 4/4/2017 0.50 INTRMI CEMENT SFTY P Pre job with rig crew and 9,732.0 9,732.0 17:30 18:00 Schlumberger crews for cement program. Included sim ops with W WT installing SS in pipe shed and loader loading DP. 4/4/2017 4/4/2017 4.50 INTRMI CEMENT CMNT P PT all lines to 4,500 PSI (passed). 9,732.0 9,732.0 1800 2230 Pump 60 BBLS 12.5 PPG mud push II @ 5 BPM. 260 PSI, 5% F/O. Drop bottom PLUG (9.34" OD). Pump 388 BBLS 15.8 PPG Class G cement @ 5.5 BPM. 250 PSI, 7% F/0. Drop top PLUG (9.16") OD. Chase with 10 BBLS fresh water @ 4 BPM , 90 PSI, 4%F/0. Changeover to rig pumps to displace cement with 9.5 PPG LSND @ 8 BPM, ICP = 193 6% F/O. Slow to 7 BPM, 192 PSI 9% F/O, @ 1550 Strokes. Observe 175 PSI pressure drop @ 6512 strokes. Slow rale to 5 BPM , 823 PSI @ 6690 Strokes. Slow rate to 4 BPM, 730 PSI @ 6,785 strokes. Slow rate to 2 BPM 785 PSI @ 7,030 strokes. Bump plug at 7,171 strokes (724 bbls). FCP =839. 3% F/0. Increase psi to 1,400 PSI and hold for 5 min. CIP @2216. Bleed down to 50 PSI and prep for final casing test. Lost a total of 24 BBLS during cement job. 4/4/2017 4/4/2017 1.00 INTRMI CEMENT PRTS P Test 9 518" casing L-80 40# hyddl 9,732.0 9,732.0 22:30 23:30 563 / 521 mix to 3,500 PSIG and charted for 30 min. (PASSED). 10.8 BBLS to pressure up /// 10.7 BELS bled back. RD Cement hose and blow down. 4/4/2017 4/5/2017 0.50 INTRMI CEMENT RURD P RD Volannt CRT, 9 5/8" landing joint 9,732.0 9,732.0 23:30 00:00 and casing elevators. 4/5/2017 4/5/2017 0.50 INTRMI CEMENT RURD P Clean rig Floor. BD Top drive drain 9,732.0 00:00 00:30 and flush stack. 4/5/2017 4/5/2017 2.50 INTRMI CEMENT W WSP P Rig up pack off running & testing tool 00:30 03:00 and RIH with same. Set packoff. Test to 5000 PSI for 20 min. (Passed). Sim ops of cleaning out cement valves and loading pipe shed with 5" DP Strap and install SS. Page 16150 Report Printed: 51212017 Operations Summary (with Timelog Uepths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hQ Phase Op Cotla ACWity Cotle Time RT -X Operation Start Depth (N(0) EM Depth rMS) 4/5/2017 4/5/2017 3.50 INTRMI CEMENT RURD P Contiue to move SS to rig floor and 03:00 06:30 stage. Continue to strap and install 5" DP in shed. Move HWDP and RIH with 19 STNDs DP and 5 STNDs HWDP. 4/5/2017 4/5/2017 5.50 INTRMI CEMENT RURD P RIH PU 30 jts of HWDP / drift t 2.625". 06:30 12:00 POOH standing back HWDP & 19 STNDS DP installing SS 4' above pin end on the fly. Finish loading pipe shed. Continuing to install SS in pipe shed. 4/5/2017 4/5/2017 10.50 INTRM1 CEMENT PULD P MU 62 stands of 5" DP via mousehole. 12:00 22:30 Sim ops confinue installing SS in pipeshed. Freeze protecting 13 3/8" X 9 5/8" ANN. LOT = 700 PSI hold 5 min bleed off to 560 PSI. LRS pumped 150 BBLS of H2O, @ 3.5 BPM / pump 131.1 BBLS Isotherm freeze protect @ 2.1 BPM . ICP 700 PSI. FCP = 1135. Monitor for 15 min then bled off to 720 PSI. 4/5/2017 4/6/2017 1.50 INTRMI WHDBOP RURD P Begin preparation for BOPE test. 22:30 00:00 Witness waived by Matt Herrera at 1045PM 4/5/2017 via email. MU test joints and TIW darts. Set test plug and perform shell test. 4/6/2017 4/6/2017 5.00 INTRMI WHDBOP BOPE P Perform BOPE test. Test BOP 00:00 05:00 250/3500 PSI, using 5" and 4 1/2" test joint. Uppers are dressed with 9 5/8" were not tested. Accum draw down Initial sec = 3,075. 1825 PSI after function of annular, 2# HCR's, 3X function of LPR's. 2,025 obtained in 8 sec. Full system pressure obtained in 48 sec. 6 BTL average = 2,593 PSI. BOP test witness waived by Matt Herrera w/ AOGCC on 4/5/2017 2248 hrs. 4/6/2017 4/6/2017 1.00 INTRMI WHDBOP RURD P Blow down and rig down all testing 05:00 06:00 equipment. Drain stack / pull test plug and install wear bushing. 4/6/2017 4/62017 2.00 INTRMI CEMENT BHAH P PJSM / PU BHA as per DO to 338' 0.0 338.0 06:00 08:00 MD. Monitor displacement via TT. 4/6/2017 4/6/2017 2.75 INTRMI CEMENT TRIP P RIH on DP to 6,455' MD monitor 338.0 6,455.0 08:00 10:45 displacement via TT. UP WT = 155K - -- DWN WT = 64K 4/6/2017 4/6/2017 1.25 INTRMI CEMENT DHEO P Fill pipe and test MWD. w/480 GPM 6,455.0 6,583.0 10:45 12:00 at 1,150 PSI. 16% F/O, + downlink. Press test new washpipe, BD TD. Confine RIH to 6,965' MS. 4/62017 4/6/2017 1.75 INTRMI CEMENT TRIP P Continue to RIH to 8,350' MD. 6,583.0 8,350.0 12:00 13:45 Observe OWN WT increwase to 48K. Kelly up fill pipe. Up WT 178K, Dwn WT 50K 4/6/2017 4/6/2017 1.75 INTRMI CEMENT SLPC P Slip and Cut 75' drill line. Simops 8,350.0 8,350.0 13:45 15:30 while circulating @ 3 BPM 127 GPM @244 PSI. 5% F/O. BD Top drive. 4/6/2017 4/6/2017 0.25 INTRMI CEMENT TRIP P RIH to 8450 MD. Monitor Disp via TT. 8,350.0 8,400.0 15:30 15:45 Up WT 178K, OWN WT=48K. Watch WT decrease to 42K. Page 17150 Report Printed: 5/212017 Operations Summary (with Timelog Depths) Eff- 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tme End Time Dw(he Phase Op Coda Adrvity Code Time e P -T -X O peration Stmt Depth (it De End Deem (nKa) 4/6/2017 4/6/2017 4.00 INTRMI CEMENT COCF P Wash down from 8,400' MD to cleacn 8,400.0 9,7T5-0- 15:45 19:45 above Float collar. No cement witnessed. 4/6/2017 4/6/2017 2.25 INTRMI CEMENT DRLG P Begin drilling Shoe track to 9,743' MD 9,715.0 9,763.0 19:45 22:00 then 20' of new hole to 9,763' MD 3,640' TVD. No indication of cement on top of plug. 500 GPM @ 1,419 PSI. 15% F/O. 50 RPM 20K TO. 7,854 strokes pumped. 4/6/2017 4/6/2017 1.00 INTRMI CEMENT FIT P BD top drive and dg up to perform FIT. 9,763.0 9,763.0 22:00 23:00 at 9,706' MD. Achieve 13.4 Mud WT Equivalent W7700 PSI. Pumped 17 Strokes and bled back 1.5 BBLS. 4/6/2017 4/7/2017 1.00 PROD1 DRILL DDRL P Drill 8 3/4" Lower Lateral Prod hole 9,763.0 9,803.0 23:00 00:00 from 9,763 to 9,803' MD 3,636' TVD. @ 500 GPM 1,473 PSI 16% F/O. 50 RPM to 7K TO. 7-16K WOB with ECD's 11.05 off bottom = 1,470 PSI, Up WT= 175K, Dwn WT=45K. ROT = 118K. 16K TQ. MW = 9.3+, 4/7/2017 4/7/2017 0.50 PROD1 DRILL CIRC P Continue to displace well to 9.3# Flo- 9,603.0 9,803.0 00:00 00:30 thu w 245 GPM, 1200 PSI, 15% F/O, 80 RPM, 9K TQ. Obtain TQ & Drag & SPR's P/U 168K, S/O 98K, ROT = 126K, 9K TO. SPR @ 9795' MD / 3,644' TVD MW= 9.3 PPG Time 00:25 MP -1 20 SPM -240 PSI 30 SPM - 300 PSI MP -2 20 SPM -240 PSI 30 SPM - 290 PSI OA 300 PSI 4/7/2017 4/7/2017 1.00 PRODI DRILL DDRL P Drill 8 3/4" hole from 9,803 MD 3,627' 9.803.0 9,879.0 00:30 01:30 TVD - 9,879' MD. , W 500 GPM, 1500 PSI, 16% F/O 80 RPM, 9K TO WOB ECD=11.16. Max gas units= 0, Up WT = 164K, Dwn WT = 101 K, ROT = 126K, 8K TQ. ADT = 1.61, Total bit hours 1.61, Total Jars = 1.61. 4/7/2017 4/7/2017 0.75 PROD1 DRILL SRVY P Obtain 30'surveys & roll test as per 9,879.0 9,896.0 01:30 02:15 1 1 1 MWD. 4/7/2017 4/7/2017 4.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from 9,896' MD - 9,896.0 10,214.0 02:15 06:15 10,214 MD --3,610 TVD., W 550 GPM, 1720 PSI, 17% F/O 150 RPM, 6K TQ WOB ECD=11.47. Max gas units = 0, Up WT = 158K, Dwn WT = 95K, ROT = 125K, 8K TQ. ADT = 2.41, Total bit hours 4.02, Total Jars = 4.02 4/7/2017 4/7/2017 5.75 PROD1 DRILL DDRL P Drill 8 3/4" hole from 10,214' MD - 10,214.0 10,569.0 06:15 12:00 10,569 MD —3,596 TVD., W 550 GPM, 1760 PSI, 17% F/O 150 RPM, 11 K TQ WOB ECD=11.54. Max gas units = 0, Up WT = 158K, Dwn WT = 95K, ROT = 125K, 8K TQ. ADT = 3.91, Total bit hours7.93, Total Jars = 7.93 Page 18150 Report Printed: 512/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time Entl Time Our h ( r) Phew Op Code Achviry Code Time P -T -X Operation Sfert pm (n De Entl Depth (RKa) 4/7/2017 4/7/2017 6.00 PROD1 DRILL DDRL P Drill 83/4" hole from10,569'MD- 10,569.0 11,107.0 12:00 18:00 11,107 MD --3,590 TVD. , W 550 GPM, 1847 PSI, 20% F/O 150 RPM, 5K TQ WOB ECD=11.67. Max gas units = 0, Up WT = 153K, Own WT = 88K, ROT = 121 K, 10.5K TO. ADT = 4.66, Total bit hours 12.59, Total Jars = 12.59 4/7/2017 4/8/2017 6.00 PROD? DRILL DDRL P Drill 8 3/4" hole from 11,107' MD - 11,107.0 11,550.0 18:00 00:00 11,550 MD —3,597 TVD., W 560 GPM, 1917 PSI, 18% F/O 180 RPM, 14K TO 7K-WOB ECD=11.77. Max gas units = 0, Up WT = 161 K, Own WT = 86K, ROT = 119K, 12.5K TO. ADT = 4.64, Total bit hours 17.23, Total Jars = 17.23 4/8/2017 4/8/2017 6.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from 11,550' MD - 11,550.0 12,073.0 00:00 06:00 12,073 MD --3,588' TVD. W570 GPM, 2,030 PSI, 17% F/O 180 RPM, 15K TQ 4K-WOB ECD=11.9. Max gas units = 0 , Up WT = 167K, Own WT = 84K, ROT = 122K, 12-13K TO. ADT = 4.32, Total bit hours 21.55, Total Jars = 21.55 SPR @ 11,876' MD / 3,584' TVD MW= 9.2 PPG Time 04:26 MP -1 30 SPM -400 PSI 40 SPM - 500 PSI MP -2 30 SPM -500 PSI 40 SPM - 500PSI OA 250 PSI 4/8/2017 4/8/2017 6.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from 12,073' MD - 12,073.0 12,600.0 06:00 1200 12,600' MD --3,588' TVD. W 570 GPM, 2,070 PSI, 18% F/O 180 RPM, 14-15K TO 4K-WOB ECD=11.98. Max gas units = 0 , Up WT = 168K, Dm WT = 85K, ROT = 120K, 13K TO. ADT = 4.73, Total bit hours 26.28, Total Jars = 26.28 SPR @ 12,352' MD / 3,589' TVD MW= 9.3 PPG Time 09:13 MP -1 30 SPM -480 PSI 40 SPM - 560 PSI MP -2 30 SPM -500 PSI 40 SPM - 560PSI OA 250 PSI 4/8/2017 4/8/2017 6.00 PROD1 DRILL DDRL P Drill 83/4" hole from 12,600' MD- 12,600.0 13,123.0 12:00 18:00 13,123' MD --3,592' TVD. W 570 GPM, 2,216 PSI, 19% F/O 180 RPM, 16K TQ 5K-WOB ECD=12.32. Max gas units = 0, Up WT = 172K, Dwn WT = 70K, ROT= 119K, 14.51K TQ. ADT = 4.42, Total bit hours 30.70, Total Jars = 30.70 Page 19/50 ReportPrinted: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tim EM Time Durno Phase Cp C.& A V Cade ry Time P -T -X O nation Pe Stan Depth Odor)nDe End Deptli (11Ka) 4/8/2017 4/9/2017 6.00 PRODt DRILL DDRL P Drill 9314" hole from13,123'MD- 13,123.0 13,615.0 18:00 00:00 13,615' MD —3,591' TVD. W 570 GPM, 2,290 PSI, 19% F/O 180 RPM, 16K TO 6K-WOB ECD=12.47. Max gas units = 0, Up WT = 175K, Dwn WT = 65K, ROT = 118K, 14.7K TO. ADT = 4.55, Total bit hours 35.25, Total Jars = 35.25 SPR @ 13,584' MD 13,592' TVD MW= 9.3 PPG Time 23:30 MP -1 30 SPM -520 PSI 40 SPM - 600 PSI MP -2 30 SPM -520 PSI 40 SPM - 600 PSI OA 250 PSI Total losses for 24 hr period = 91 BBLS 4/9/2017 4/9/2017 6.00 PROD1 DRILL DDRL P Drill 3/4" hole from 13,615' MD-- 13,615.0 14,200.0 00:00 06:00 3,591' TVD to 14,200' MD - 3,581 TVD. W 570 GPM, 2,310 PSI, 17% F/0 180 RPM, 18K To 4K-WOB ECD=12.48., Up WT = 194K, Own WT = N/A, ROT = 124K, 16K TO. ADT = 4.54, Total bit hours 39.79, Total Jars = 39.79 4/9/2017 4/912017 6.00 PRODt DRILL DDRL P Drill 8 3/4" hole from 14,200 MD - 14,200.0 14,722.0 06:00 12:00 3,581 TVD to 14,722'M - 3,578 TVD. W 570 GPM, 2,265 PSI, 19% F/O 180 RPM, 19K TO 8K-WOB ECD=12.32. , Up WT = 198K, Own WT = N/A, ROT = 123K, 15K To. ADT = 4.55, Total bit hours 44.34, Total Jars = 44.34 SPR @ 14,249' MD /3,580' TVD MW= 9.3 PPG Time 06:20 MP -1 30 SPM -560 PSI 40 SPM - 660 PSI MP -2 30 SPM -560 PSI 40 SPM - 660 PSI OA 210 PSI Page 20/50 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sfan Depth De SWd-rime End nm DX (hr) Phaw Op Code AOvdy Code Time P -T -X O peretion End DepN (itlCB) 4/9/2017 4/9/2017 6.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from 14,722' MD - 14,722.0 15,420.0 12:00 18:00 3,578 TVD to 15,420' MD - 3,575' TVD. W 570 GPM, 2,350 PSI, 19% F/O 180 RPM, 20K TO 5K-WOB ECD=12.48. , Up WT = 194K, own WT = N/A, ROT = 109K, 15K To. ADT = 4.46, Total bit hours 48.80, Total Jars =48.80 SPR @ 15,194' MD /3,574' TVD MW= 9.3 PPG Time 15:45 MP -1 30 SPM -520 PSI 40 SPM - 620 PSI MP -2 30 SPM -520 PSI 40 SPM - 620 PSI OA 200 PSI 4/9/2017 4/10/2017 6.00 PROD1 DRILL DDRL P Drill 83/4" hole from 15,420'MO- 15,420.0 16,031.0 18:00 00:00 3,575' TVD to 16,031' MD - 3,549- ,549'TVD. TVD.W 570 GPM, 2,500 PSI, 19% F/O 180 RPM, 22K To 8K-WOB ECD=12.29. , Up WT = 210K, Own WT = N/A, ROT = 115K, 18K To. ADT = 4.62, Total bit hours 53.42, Total Jars =53.42 4/10/2017 4/10/2017 4.50 PRODt DRILL DDRL P Drill 8 3/4" hole from 16,031' MD - 16,031.0 16,433.0 00:00 04:30 3,549' TVD to 16,433' TVD . W 500 GPM, 2,250 PSI, 16% F/O 150 RPM, 19K To 6K-WOB ECD=12.51. , Up Wi = 220K, Own WT = N/A, ROT = 135K, 17K To. ADT = 3.07, Total bit hours 56.49, Total Jars =56.49 SPR @ 16,035' MD /3,549' TVD MW= 9.2 PPG Time 00:17 MP -1 30 SPM -500 PSI 40 SPM - 600 PSI MP -2 30 SPM -500 PSI 40 SPM - 600 PSI OA 210 PSI 4/10/2017 4/10/2017 1.50 PROD1 CASING SRVY P Obtain bottom survey - RB stand @ 16,433.0 16,316.0 04:30 06:00 CBU with rot & Recip from 16,404'to 16,316' MD. 530 GPM, 2,510 PSI, 17% Flo 150 RPM, 16-19K To, ECD=12.51. Total stks pumped= 8,500. MW in = 9.3 Mud WT out = 9.3+. Obtain SPR's tq&Dreg. Up WT = 135K. Down link xceed 10/0. TO called. SPR @ 16,402' MD /3,515' TVD MW= 9.3 PPG Time 06:00 MP -1 30 SPM -650 PSI 40 SPM - 720 PSI MP -2 30 SPM -650 PSI 40 SPM - 720 PSI OA 200 PSI Page 21160 Report Printed: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time Entl Time Our (hr Phase Op cede Ad,,h Cede Time P -T -X Operation (rt De Start Depth Ertl Depth (ttKB) 4/10/2017 4/10/2017 1.50 PROD1 CASING OWFF P OWFF (Well Breathing) measure 16,316.0 16,404.0 06:00 07:30 quanity to a timed VIS cup. Initial time 3 sec. Final time 161 sec t fill 1 QT vis cup. Drop 2.38" drift with 107' tail on stand 170. (HWDP stand#11). 4/1012017 4/10/2017 4.50 PROD1 CASING BKRM P BROOH from 16,404' MD to 14,914' 16,404.0 14,914.0 07:30 12:00 MD. W/570 GPM @ 2,160 PSI, 17% F/O. 180 RPM, 1 S TO, ECD = 111.75. ROT 110. 4/10/2017 4/1012017 6.00 PROD1 CASING BKRM P BROOH from 14,914' MD to 12,500' 14,914.0 12,500.0 12:00 18:00 MD. W/570 GPM @ 21,950 PSI, 17% F/O. 180 RPM, 10.5K TQ, ECD = 11.38. ROT 109. 4/10/2017 4111/2017 6.00 PROW CASING BKRM P BROOH from 12,500' MD to 10,180' 12,500.0 10,180.0 18:00 00:00 MD. W/570 GPM @ 21,950 PSI, 17% F/O. 180 RPM, 10.5K TO, ECD = 11.38. ROT 109. Noted heavy pull at 10,554' MD worked area until no OP. 4/11/2017 4/11/2017 2.00 PROD1 CASING BKRM P BROOH from 10,180' MD to 9,706' 10,180.0 9,706.0 00:00 02:00 MD. Pumping 500 GPM @ 1350 PSI, 17% FIO. 80 RPM, 7-11 K TQ, ECD = 10.9 ppg PU wt 158k, SO wt 98k. 4/11/2017 4/11/2017 1.50 PROD1 CASING CIRC P Circulate two bottom's up while 9,706.0 9,706.0 02:00 03:30 reciprocate and rotate f/ 9706' to 9614'. Pumping 570 gpm w/ 1600 psi, 17% flow out. Rotate 80 rpm w/ 9k If lbs of torque. ECD's 10.85 ppg. Mud weight in 9.3+, mud weight out 9.4 ppg. Pumped 1036 bbls. 4/11/2017 4/11/2017 0.50 PROD1 CASING OWFF P Blow down the top drive. Monitor well- 9,706.0 9,706.0 03:30 04:00 static. 4/11/2017 4/11/2017 3.50 PROD1 CASING BKRM P BROOH from 9706' MD to 7150' MD. 9,706.0 7,150.0 04:00 07:30 Pumping 570 GPM @ 1300 PSI, 17% F/O. Rotate 80 RPM w/ 5K TQ, ECD = 10.9 ppg PU wt 158k, SO wt 98k. 4/11/2017 4/11/2017 1.25 PRODi CASING CIRC P Pump a 30 bbl hi vis sweep while 7,150.0 7,150.0 07:30 08:45 reciprotate and rotate from 7150' to 7059'. Pumping 570 gpm w/ 1360 psi, 17% flow out. Rotate 80 rpm w/ 4-6k ft lbs of torque. Pumped 710 bbis. PU wt 135k, SO wt 11 Ok. 4/11/2017 4/11/2017 0.25 PROD1 CASING OWFF P Blow down the top drive. Monitor well- 7,150.0 7,150.0 08:45 09:00 static. 4/11/2017 4111/2017 0.75 PRODi CASING TRIP P Trip out on elevators f/7150'to 6493'. 7,150.0 6,493.0 09:00 09:45 Monitor displacement on the trip tank- ok. 4/11/2017 4/11/2017 0.25 PROD1 CASING CIRC P Pump 20 bbl dry job. Install stipping 6,493.0 6,493.0 09:45 10:00 rubbers and air slips. Blow down top drive. 4/11/2017 4111/2017 2.00 PROD1 CASING TRIP P Trip out on elevators f/6493'to 2516'. 6,493.0 2,516.0 10:00 12:00 Monitor displacement with the trip lank. PU wt 112k. Outer annulus pressure 100 psi. 4/11/2017 4/11/2017 1.50 PRODi CASING TRIP P Continue pulling OOH on elevators f! 2,516.0 338.0 12:00 13:30 1 I 2516'- 338', monitoring displacement j j via trip tank. PUW 69k Page 22/50 Report Printed: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Tim our (hr) Phaee op Cade Activity Corte Time P -T -X Operation Stan Depen (flKB) Ertl DBPN dtKS) 4/11/2017 4/11/2017 0.25 PRODI CASING OWFF P Monitor well for flow at top of HWDP- 338.0 338.0 13:30 13:45 well static. 4/11/2017 4/11/2017 2.75 PROD1 CASING BHAH P Pull OOH f/ 338'to surface, racking 338.0 0.0 13:45 16:30 back jars and NMDC's and laying down remaining BHA per SLB. Bit graded 0 -1 -CT -S -X -1 -NO -TD. Note: Retrieved 2-3/8" rabbit on lop of jars, observed wire tangled up, had slight issue pulling out of pipe. 4/11/2017 4/11/2017 0.50 PROD1 CASING BHAH P Clean / clear rig floor of BHA 0.0 0.0 16:30 17:00 equipment. 4/11/2017 4/11/2017 1.75 COMPZI CASING RURD P Rig up to run 4-1/2" liner with GBR 0.0 0.0 17:00 18:45 double -stack tongs. Confirm pipe count and running order in shed. 4/11/2017 4/12/2017 5.25 COMPZI CASING PUTS P PJSM. RIH w/ 4-1/2" 12.6ppf L-80 0.0 3,124.0 18:45 00:00 TXP-m lower completion per tally to 3124' MD, PUW 771k, SOW 75k. Baker -lock pin and box end of float collar. Use JetLube Run -N -Seal dope and torque to 7400 fl -lbs. Install free- floating centralizer on every joint and install stop ring 6' above pin on joints directly above swell packers. OA pressure at midnight = 75 psi 4/12/2017 4/12/2017 3.75 COMPZ1 CASING PUTB P PJSM. RIH w/ 4-1/2" 12.6ppf L-80 3,124.0 6,448.0 00:00 03:45 TXP-m lower completion per tally from 3124' MD to 6448' MD. Use JetLube Run -N -Seal dope and torque to 7400 fl -lbs. Install free-floating centralizer on every joint and install stop ring 6' above pin on joints directly above swell packers. 4/12/2017 4/12/2017 1.50 COMPZI CASING PUTB P Rig up handling equipment. Pick up 6,448.0 6,512.0 03:45 05:15 Baker MLZXP liner hanger/pkr and Schlumberger slim MWD tool. Scribe MWD to liner hanger pre marked bottom mark of the liner hanger (matched to bottom index inside of liner top). Fill liner tieback sleeve with Xan-Plex. PU wt 89k, SO wt 81 k, block wt 43k. 4/12/2017 4/12/2017 0.50 COMPZI CASING RUNL P Pickup tat stand of 5" drill pipe. 6,512.0 6,603.0 05:15 05:45 Circulate 15 bbls, pumping 100 gpm wl 325 psi and 5% flow out. Blow down the top drive. 4/12/2017 4/12/2017 1.00 COMPZI CASING RUNL P Run 4-1/2" liner in the hole on total of 6,603.0 8,215.0 05:45 06:45 4 stands 5" rip, then 5" dp w/ Western Well Tools super sliders on the dp (4- 6' above pin end) from 6603' to 8215'. Total of 18 stands in the hole. Running speed 90'/minute. Monitor displacement on the trip lank. Page 23150 Report Printed: 61212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start pth Stan Time EM Time Our hr O Phase OpDaEe Activity code Time P-T-% Operation (MB) B) End Depth (ftKB) 4/12/2017 4/12/2017 3.75 COMPZI CASING DLOG P Fill pipe. Shallow hole test MWD, 8,215.0 8,363.0 06:45 10:30 pumping 110 gpm w/ 420 psi and 6% flow out. Start logging f/ 8215' (shoe depth) to find K-15 marker @ 1906' MD. Log to 8363'. Found K-15 @ -1905' MD. 4/12/2017 4/12/2017 1.00 COMPZI CASING RUNL P Slowdown topdrive and RIH liner on 5" 8,363.0 9,719.0 10:30 11:30 DP w/ Western Well Tools super sliders on the dip (4-6' above pin end) from 8363' to 9719'. Running speed 90'/minute. Pipe would not self-fill fast enough so rigged up fill-up hose and filled on the fly, monitoring displacement on pit #5. 4/12/2017 4/12/2017 1.00 COMPZI CASING CIRC P Circulate 70 x bbls (to top of first 9,719.0 9,719.0 11:30 12:30 slotted joint) at 3 bpm, 550 psi, 6% F/O. Obtain parameters at shoe. PUW 128k, SOW 1041k, ROT 117k @ 25rpm, 5.4k Tq. Blow down topdrive. 4/12/2017 4/12/2017 4.25 COMPZI CASING RUNL P RIH w/ liner on total of 4 x stands 5" 9,719.0 15,952.0 12:30 16:45 DP slick, 81 x stands 5" DP w/ super sliders, and 15 x stands 5" HWDP w/ super sliders to 15952' MD, filling pipe on the fly with fill-up hose, topping off every 5 x stands, and monitoring displacement on pit #5. 4/12/2017 4/12/2017 1.00 COMPZ1 CASING PACK P Pick up 1 x single 5" DP (31.58'), RIH 15,952.0 15,966.0 16:45 17:45 and mark pipe at set depth of 15966' MD. Break circulation w/ 110 gpm, 640 psi, 6%f/O. Orient MLZXP hanger to 22° left of highside. PUW 200k, SOW 114k,. 127 bbls pumped. 4/12/2017 4/12/2017 1.50 COMPZI CASING PACK P Drop 1.625" ball and pump down at 15,966.0 15,966.0 17:45 19:15 2.5 bpm, 615 psi, 6% F/O for 727 strokes. Reduce rate to 1.5 bpm, 380 psi, 4% F/O and seat ball at 1413 strokes. 4/12/2017 4/12/2017 0.75 COMPZI CASING PACK P Increase pressure to 1900 psi and 15,966.0 9,466.3 19:15 20:00 slack off 60k weight to set hanger - observe hanger set. Pressure up to 2500 psi and start staging up in 200 psi increments, holding for -30 seconds, to function pusher tool, up to 3400 psi. Hold at 3400 psi and then increase up to 4000 psi to release from liner, observing shear at -3600 psi. Bleed off pressure, and pick up With bleeder open to confirm released from liner- observe PUW 186k. Pick up 5' to expose dogs. Observe SOW 136k. Rotate at 25 rpm, 7.5k Tq, ROT 165k and slack off 60k on liner top to confirm set. Pick up and work out torque and slack off with no rotary to tag liner top - observe tag 1' deep. Liner top packer set at 9,466.28' MD 4/12/2017 4/12/2017 0.50 COMPZI CASING PRTS P Line up to pump down IA and 9,466.3 9,466.3 20:00 20:30 pressure test liner top packer to 3500 psi / 10 min, charted - good test. Bleed off pressure. Page 24150 Report Printed: 512/2017 Operations Summary (with Timelog Depths) 3R-101 k Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Time End Tame our (hr) Phase Op Code Adie Code nY Time P•T-x O operation start Depth rt De End Depth (tIKB) 4/12/2017 4/12/2017 1.00 COMPZt WELLPR RURD T Troubleshoot inability to function /BOP 9,466.3 9,466.3 20:30 21:30 to open position. Attempt to equalize pressure unsuccessfully. Set slips and slowly break out top drive and function IBOP open. 4/12/2017 4/12/2017 1.00 COMPZI WELLPR CIRC P Lay down 5" DP single and pick up to 9,466.3 9,466.3 21:30 22:30 high circulation point, total of 30'. Pump 25 bbl corrosion -inhibited brine and chase with 156 bbls 9.3ppg FloThru at 258 gpm, 510 psi, 9% F/O. 4/12/2017 4/12/2017 0.50 COMPZI WELLPR OWFF P Rack back stand of 5" HWDP, blow 9,466.3 9,466.3 22:30 23:00 down top drive, and monitor well for 10 minutes - well static. 4/12/2017 4/13/2017 1.00 COMPZ1 WELLPR TRIP P Pull OOH on elevators to 8414' MD, 9,466.3 8,414.0 23:00 00:00 racking back 5" HWDP w/ super sliders and monitoring displacement on pit #5. PUW 155k. Observed pipe pulling dry. OA pressure at midnight = 150 psi 4/13/2017 4/13/2017 0.50 COMPZI WELLPR TRIP P Continue to pull out of the hole on 8,414.0 8,041.0 00:00 00:30 elevators from 8414' MD to 8041', racking back 5" HWDP and 5" DP w/ super sliders and monitoring displacement on pit #5. PUW 155k. Observed pipe start pulling wet once on drill pipe. 4/13/2017 4/13/2017 0.25 COMPZ11 WELLPR CIRC P Pump a 20 bbl dry job. Blow down the 8,041.0 8,041.0 00:30 00:45 1 1 1 top drive. 4/13/2017 4/13/2017 3.75 COMPZI WELLPR TRIP P Continue to pull out of the hole on 8,041.0 91.0 00:45 0430 elevators from 8041' MD to 91', racking back 5" DP w/ super sliders and monitoring displacement on pit #5. Calculated displacement 74.8 bbls, Actual displacement 92 bbls. 4/13/2017 4/13/2017 0.75 COMPZ11 WELLPR BHAH P Lay down Baker liner running tools 91.0 0.0 04:30 0515 and Schlumberger MWD. Observe good indication on dog sub to confirm liner top packer is set. Observed ball on seat in running tool and all o -rings, etc. on tool. 4/13/2017 4/13/2017 1.25 COMPZI WELLPR DHEQ P Pick up Baker FJD tool. Test w/ pump 0.0 0.0 05:15 0630 rate to see when it disconnects. With 3 x 18's installed, stage up pumps and observe tool function at 500 gpm. Remove 18's and install 3 x 20's and re -test. Observe tool function at 500 gpm. Remove 20's and intsall 3 x 24's and re -test. Observe tool function at 500 gpm. Remove 24's and re -test with no nozzles installed. Stage up pumps w/ 400 gpm /375 psi, 450 gpm 1490 psi, 500 gpm 1588 psi, and 510 gpm / 655 psi - observe tool function at 510 gpm. Lay down tool and blow down the top drive. Sim Ops: Mobilize whipstock tools to rig floor. Page 25/50 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time per (hr) Phase Op Code AdN4 Code Time P -T -X Opetadon S' (ftKB)Pm End Deph (fd(B) 4/13/2017 4/13/2017 1.75 PROD2 WHPST BHAH P Pre job safety meeting on picking up 0.0 0.0 06:30 08:15 Whipstock assembly. Make up mills and MWD. Orient MWD to bolt hole of window mill. From bolt hole, mark 180 deg. MWD highside was left of mark. Calculated to be 121.04 deg clockwise to match mark on pipe. Set back in derrick. 4/13/2017 4/13/2017 2.00 PROD2 WHPST BHAH P Make up whipstock assembly: Gent 0.0 87.1 08:15 10:15 Whipstock, debris sub, string magnet, drain sub, blank sub, safety disconnect, unloader, seals, pup it and MLZXP Anchor = 87.09' to bottom of collet on anchor. Align lowest point of guide to match face of whipstock. Lower whipstock assembly in the hole. 4/13/2017 4/13/2017 1.25 PROD2 WHPST BHAH P Make up stand with mills and 87.1 210.0 10:15 11:30 Schlumberger MWD, Connect stand with mills to whipstock with 35k brass bolt. Lower milling assembly in the hole. Continue to build milling assembly BHA above the MWD with 3 x string magnets. RIH to 210'. 4/13/2017 4/13/2017 1.25 PROD2 WHPST TRIP P Run whipstock assembly in hole on 5" 210.0 1,621.0 11:30 12:45 DP / HWDP with super sliders installed at max 60 ft/min running speed, monitoring displacement via trip tank. SOW 88k. Note: Utilized same pipe for running whipstock as we did for running liner. 4/13/2017 4/13/2017 0.25 PROD2 WHPST DHEQ P Fill pipe and perform shallow hole test 1,621.0 1,621.0 12:45 13:00 w/ 450 gpm, 470 psi, 17% F/O - good test. SOW 93k with pipe full. 4/13/2017 4/13/2017 0.25 PROD2 WHPST TRIP P Continue RIH on 5" DP with super 1,621.0 1,948.0 13:00 13:15 sliders installed f/ 1621'- 1948' MD, monitoring displacement via pit #5, SOW 93k. 4/13/2017 4/13/2017 1.00 PROD2 WHPST DLOG P RIH on 5" DP with super sliders 1,948.0 2,078.0 13:15 14:15 installed logging f/ 1948'- 2078' MD (1860'- 1990' MWD sensor) across K- 15 marker at 200 R/hr running speed w/ 450 gpm, 460 psi, 17% F/O - observe K-15 marker at 1904' MD. SOW 96k. Blowdown topdrive. 4/13/2017 4/13/2017 5.75 PROD2 WHPST TRIP P RIH on 5" DP / HWDP with super 2,078.0 9,372.0 14:15 20:00 sliders installed f/ 2078'- 9372' MD, filling pipe every 20 x stands, monitoring displacement on pit #1. PUW 178k, SOW 130k. Note: Swapped rig to generator power at 20:00 hrs due to continuing issue of hi -line unable to supply enough power to rig while drilling. 4/13/2017 4/13/2017 0.75 PROD2 WHPST WPST P Make up topdrive to stand #98, fill 9,372.0 9,465.0 20:00 20:45 pipe, RIH to 9430', and orient whipstock assembly to 6° left of highside at 450 gpm, 1240 psi, 16% F/O, parameters with pumps on PUW 164k, SOW 124k. RIH to 9465'. Page 26150 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siad Time End Time Dur (hr) Phase Op Code Acbviq Cade Time P-T-X Operetidn Start Depth d De EM Dapld (ttKa) 4/13/2017 4/13/2017 0.75 PROD2 WHPST WPST P RIH and latch whipstock anchor into 9,465.0 9,392.0 20:45 21:30 MLZXP packer w/ 450 gpm, 1240 psi, 16% F/O, PUW 164k, SOW 125k, tagging up on depth at 9480.2' MD (9479.1' MD to collet latch point). Observe toolface shift to 20" left of highside once anchor latched in, confinning correct orientation. Pick up 10k overpull to 173k to confirm latched in. Slack off 35k weight to shear boll - no shear observed. Pick up and observe PUW decrease to 162k and pipe traveling, indicating bolt had sheared. Also observed toolface shift to 14° left of highside, further indicating bolt had sheared. Obtain parameters at 450 gpm, 1240 psi, 16% F/O, PUW 162k, SOW 123k, ROT 142k @ 5 rpm, 6k Tq. Kill rotary, RIH and position window mill at bolt, rotate at 5rpm and observe torque stall out quickly to 10k, confirming boll had sheared and whipstock set in place. Top of slide @ 9392' MD Bottom of slide @ 9409.6' MD 4/13/2017 4/14/2017 2.50 PROD2 WHPST MILL P Mill whipstock bolt and window in 9- 9,392.0 9,400.0 21:30 00:00 5/8" casing to 9400' MD @ 450 gpm, 1250 psi, 16% F/O, 80-90 rpm, 1-3k WOB, 8-10k Tq. Pumps off PUW 178k, SOW 130k. Pumps on PUW 162k, SOW 122k, ROT 140k w/ 7k Tq. Note: See increase in erratic torque as lower mill transitioned onto slide and then stabilized out after -2 ft OA at midnight = 250 psi 4/14/2017 4/14/2017 4.75 PROD2 WHPST MILL P Mill window f/ 9400'- 9409' MD w/ 450 9,400.0 9,409.0 00:00 04:45 gpm, 1280 psi, 16% F/O, 90-100 rpm, 8-11k Tq, 1-3k WOB, MW in/out 9.3/9.3+ with 50 vis, pumping 2 x 15 bbl 300-funnel vis sweeps per Baker. Minimal metal shavings seen across the shakers and no additional cuttings seen with sweeps. 4/14/2017 4/14/2017 0.50 PROD2 WHPST MILL P Observed ROP fall off to 50 minutes 9,409.0 9,409.0 04:45 05:15 for 1 ft just prior to upper mill transitioning onto slide and window mill coming off slide. Pick up 7ft and start reaming slowly back to bottom - observe string stall out at 17k tq. Pick up and wipe section to top of window, observing several short overpulls of 10 -20k. Slowly ream back to bottom. Note: Observe shakers blinding off and started seeing some clumps of metal shavings coming over scalpers. Page 27150 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 • Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM Time Ow (hr) Phase OP Cotla ActirvdY Cade Time P -T -X O Aeration Start Depth (fIKB) End Oexh (flKB) 4/1412017 4/14/2017 3.25 PROD2 WHPST DDRL P Mill window f/ 9409'- 9415' MD w/ 450 9,409.0 9,415.0 05:15 08:30 gpm, 1280 psi, 16% F/O, 90-100 rpm, 8-12k Tq, MW in/out 9.3ppg w/50 funnel vis, staging up WOB from 2k to 8k as window mill and lower mill transitioned off slide. Pumped 1 x 30 bbl 300 funnel -vis sweep, observing slight increase in shavings over shakers and temporary blinding off of screens. Note: Phase 1 conditions fieldwide at 08:00 hrs. 4/14/2017 4/14/2017 0.25 PROD2 WHPST REAM P Observe ROP not picking up it was 9,415.0 9,415.0 08:30 08:45 expected to once lower mill off slide. Pick up and wipe section to top of window and ream back to bottom w/ 450 gpm, 1230 psi off btm SPP, 16% F/0, 100 rpm, 7k off btm Tq. 4/14/2017 4/14/2017 1.25 PROD2 WHPST DDRL P Mill window If 9415'- 9425' MD w/ 450 9,415.0 9,425.0 08:45 10:00 gpm, 1280 psi, 16% F/0, 100-120 rpm, 8-13k Tq, WOB 6-9k. Observe ROP initially increase to 18 ft/hr then start falling off to 6 ft/hr w/ 9k WOB. 4/14/2017 4/14/2017 0.75 PROD2 WHPST DDRL P Pick up and wipe section to top of 9,425.0 9,429.0 10:00 10:45 window. Ream back to bottom and mill window f/ 9425'- 9429' MD w/ 450 gpm, 1280 psi, 16% F/O, 120 rpm, 9- 13k Tq. 3-6 Whir ROP w/ 9-1 Ok WOB. Upper mill transition off slide at 9429' MD. 4/14/2017 4/14/2017 0.50 PROD2 WHPST DDRL P Continue milling out gauge hole in 9,429.0 9,430.0 10:45 11:15 formation f/ 9429'- 9430' MD w/ 450 gpm, 1270 psi, 120 rpm, 9-12k Tq, 9- 10k WOB. 4/14/2017 4/14/2017 0.25 PROD2 WHPST REAM P Pick up and wipe section to top of 9,430.0 9,430.0 11:15 11:30 window. Circulate at top of window and pump 30 bbl 300 -vis sweep then ream down to bottom w/ 450 gpm, 1350 psi, 16% F/0, 100 rpm, 7-10k Tq. 4/14/2017 4/14/2017 2.75 PROD2 WHPST DDRL P Continue milling out gauge hole in 9,430.0 9,438.0 11:30 14:15 formation f/ 9430'- 9438' MD w/ 450 gpm, 1300 psi, 120-125 rpm, 9-12k Tq, 9-11k WOB. Total of 9' of 8-3/4" hole milled past bottom of window. 4/14/2017 4/14/2017 1.00 PROD2 WHPST CIRC P Pick up to top of window and circulate 9,438.0 9,377.0 14:15 15:15 hole clean w/ 450 gpm, 1300 psi, 16% Flo, 100 rpm, 7-11k Tq, reciprocating pipe above window, total of 781 bbls pumped, MW in/out 9.3ppg w/ 58 vis. Obtain parameters and take SPR's. PUW 188k, SOW 124k with pumps off SPRs @ 9377' MD 3601' TVD, MW=9.30 ppg, 15:15 hours MP#1: 30 spm=440 psi, 40 spm=500 psi. MP #2: 30 spm=440 psi, 40 spm=500 psi. Page 28/50 Report Printed: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SlAn Time End Time our (ho phase Op Code AcOvi Cade ty T X Time P-- Operation Sfart Depth q DK End Depth (flKa) 4/14/2017 4/14/2017 0.25 PROD2 WHPST TRIP P Trip milling assembly through window 9,377.0 9,377.0 15:15 15:30 to bottom and pull back to top of window at 600 f thr running speed, observing minimal drag across window of 1-3k, PUW 188k, SOW 124k. 4/14/2017 4/14/2017 0.50 PROD2 WHPST TRIP P Rack back 3 x stands to 9186', pick up 9,377.0 9,282.0 15:30 16:00 1 x stand slick 5" DP and RIH to 9282' MD. Blow down lop drive. Note: Swap rig to hi -line power at 16:00 his. 4/14/2017 4/14/2017 2.00 PROD2 WHPST FIT P Rig up lest equipment and line up to 9,282.0 9,282.0 16:00 18:00 pump down drill pipe and IA and purge air out of lines. Perform FIT at top of window, 9392' MD / 3602.9' TVD, with 9.3ppg to 805 psi surface pressure, giving a 13.6ppg EMW. 2 bbls pumped / 2 bbls returned using mud pump #2. Rig down test equipment and blow down lines. Note: On first lest using mud pump #1, required more than expected volume of 5.5 bbls to pressure up system. Lined up mud pump #2 and re -tested, only requiring 2 bbls to pressure up system. 4/14/2017 4/14/2017 1.50 PROD2 WHPST SLPC P Slip / cut drilling line and calibrate 9,282.0 9,282.0 18:00 19:30 amphion system. 4/14/2017 4/14/2017 0.50 PROD2 WHPST SVRG P Service and inspect topdrive and 9,282.0 9,282.0 19:30 20:00 blocks. 4/14/2017 4/14/2017 1.00 PROD2 WHPST TRIP P Pull OOH on elevators f/ 9282'- 8069', 9,282.0 8,069.0 20:00 21:00 racking back 5" HWDP, monitoring displacement via pit #1. 4/14/2017 4/14/2017 0.50 PROD2 WHPST CIRC P Pump dry job, blow down lop drive, 8,069.0 8,069.0 21:00 21:30 1 1 and install power slips. 4/14/2017 4/15/2017 2.50 PROD2 WHPST TRIP P Pull OOH on elevators f/ 8069'- 4676' 8,069.0 4,676.0 21:30 00:00 MD, adjusting top collars on each super slider as needed per W WT, monitoring displacement via pit #1. OA pressure at midnight = 150 psi 4/15/2017 4/15/2017 5.50 PROD2 WHPST TRIP P Pull OOH f/4676' - 122' MD, racking 4,676.0 122.0 00:00 05:30 back 5" DP and changing out wom super sliders per W WT, monitoring displacement on pit #1. Note: Adjust super slider top collars on stands #63 - 45 and swap placement of bottom / top super slider collars on stands #44 - 5. Replace total of 4 x collars and 1 x slider due to significant wear. 4/15/2017 4/15/20172.50 PROD2 WHPST BHAH P PJSM. Pull OOH and lay down milling 122.0 0.0 05:30 08:00 assembly. Observe pockets on each magnet full - clean off magnets, recovering -15 gallons of debris. Upper 8-3/4" watermelon mill was in - gauge. Clean/clear rig floor of BHA. Page 29150 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log 5fan Depih Sten Time End Time our (hr) Phase op Coda A Mty Cada Time P-T-X Opmation (ftMB) EM Oeplh (flxa) 4/15/2017 4/15/2017 1.00 PROD2 WHPST PULD P Lay down 9 x stands of 5' DP from off- 0.0 0.0 08:00 09:00 drillers side via mousehole. 4115/2017 4/15/2017 1.00 PROD2 WHPST WWWH P Make up stack washer and jet stack to 0.0 0.0 09:00 10:00 clear out any metal debris and cycle rams. Lay down stack washer. 4/15/2017 4/15/2017 2.50 PROD2 WHDBOP RURD P Pull wearbushing, Install test plug, and 0.0 0.0 10:00 12:30 Rig up to test BOPE. Rig up 5' test joint and purge all air out of system with water. Perform initial shell test 250/3500 psi. Service topddve and blocks and mobilize BHA equipment to floor while obtaining final confirmation from AOGCC rep whether or not witness is waived. 4/15/2017 4/15/2017 5.25 PROD2 WHDBOP BOPE P Test BOPE w/ 5" and 4-1/2" test joints, 0.0 0.0 12:30 17:45 25013500 psi for 5 / 5 min, witness waived by AOGCC rep Jeff Jones. Test Sequence as follows: With 5' Test joint 1) Annular, Choke valves #1,12,13, 14, 4" Kill line, and 4-1/7' IF Dar Valve 2) Annular, Choke valves #9, 11, Mezzanine Kill line valve, and 4-1/2" IF Full Open Safety Valve 3) Annular, Choke valves #8,10, and HCR Kill line 4) Annular, Choke valves #6, 7, and Upper IBOP 5) Annular, Super choke, and Manual Choke - tested to 2000 psi high 6) Annular, Choke valves #2, 5, Manual Kill, and Lower IBOP 7) 3-1/7' x 6" Lower pipe rams Pull 5" TJ 8) Blind rams, Choke valves #3 and 4 With 4-1/7' Test Joint 10) Annular and HCR choke 11) Annular and Manual choke 12) 3-1/2" x 6" Lower pipe rams System Pressure = 3,000 psi PSI after closure = 1,700 psi 200 psi Attained = 8 seconds with 2 x electric pumps Full Pressure attained = 57 seconds with 2 x electric pumps and 2 x air pumps 6 x bottle Nitrogen backup Average pressure = 2,542 psi Test all gas and pit sensors - pass. 4/15/2017 4/15/2017 1.00 PROD2 WHDBOP RURD P Blow down and rig down test 0.0 0.0 17:45 18:45 equipment. Pull test plug, Drain stack, and Install wearbushing. Page 30/50 Report Printed: 51212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Shirt Time End Time Our (Ar) Phase Op Cotle Amwly Code Time P -T -X Operation Start Depen n De End OepO (WS) 4/15/2017 4/15/2017 3.75 PROD2 WHPST BHAH P PJSM. Confirm pipe count and 0.0 398.0 18:45 22:30 running order in derrick. Pick up 8-3/4" Motor Drilling BHA #7 per SLB, picking up 8-314" Baker T606X PDC bit w/ 6 x 16's, 1.5" Mud Motor w/ 718 5 -stage power section (0.28 revs/gal) and 8-518" straight -bladed stabilizer, 8- 5/8" NM Integral spiral -bladed Stabilizer, NM XO, 6-314" Periscope, 6 -3/4" Telescope, and 6-3/4" GyroPulse. Scribe per SLB/Gyrodata. Pick up 1 x stand 6-3/4" NMDC's w/ 8- 9/16" NM stabilizer that was racked back in derrick and RIH. Pick up 3 x singles 5" HWDP from pipe shed followed by jar stand that was racked back in derrick (1 x 6-114" Hydraulic jar w/ 2 xjoints 5" HWDP). RIH to 398' MD. MWD to Motor offset = 42.67' GWD to Motor offset = 260.07° 4/15/2017 4/15/2017 0.50 PROD2 WHPST BHAH P RIH w/ 3 x stands 5" DP from off- 398.0 721.0 22:30 23:00 driller's side. Pick up Baker X-treme magnets from pipe shed (3 x magnets w/ 2 x crossovers left made up together after milling run) and RIH to 721' MD. 4/15/2017 4/16/2017 1.00 PROD2 WHPST TRIP P RIH w/ 5" DP stands f/ 721'- 2142' 721.0 2,142.0 23:00 00:00 MD, monitoring displacement via pit #1. PUW 107k, SOW 107k OA pressure at midnight = 100 psi 4/16/2017 4/16/2017 4.00 PROD2 WHPST TRIP P RIH w/ 5" DP from 2142'- 8956' MD, 2,142.0 8,956.0 00:00 04:00 monitoring displacement via pit #1. SIMOPS: Stage 4 x vac trucks by pits I rockwasher and prep for displacement. 4/16/2017 4/16/2017 1.50 PROD2 WHPST DISP P PJSM. Kelly up to stand #88 and 8,956.0 9,240.0 04:00 05:30 displace well from 9.3ppg FloThru to new 9.3ppg FloThru. Pump 30 bbl hi - vis pill followed by 822 bbis 9.3ppg FloThru w/ 545 gpm, 1750 psi, 17% F/O, initial ECD 11.33 ppg, Final ECD 10.77 ppg, 20 rpm, 8k Tq. While displacing, RIH slowly w/ 3 x stands to 9232' MD. After displacement finished on stand #90, kill rotary and orient to 20" left of highside. PUW 158k, SOW 94k, ROT 125k. 4/16/2017 4116/2017 0.50 PROD2 WHPST TRIP P Trip in through window with BHA f/ 9,240.0 9,418.0 05:30 06:00 9240'- 9418' MD. Observe brief 15k drag at top of window as bit passed through and then 2-5k drag across window. Tag up on gauge hole @ 9418' MD w/ 5k weight. 4/16/2017 4/16/2017 0.50 PROD2 WHPST WASH P Stage up pumps to 450 gpm, 1322 9,418.0 9,438.0 06:00 06:30 psi, 15% F/O, 10.57 ppg ECD, orient string per DD and wash to bottom. Page 31150 ReportPrinted: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log 91art Time End Imre Der(hp Phase Op Cole Actively Cole Time P -T -X Operation SM Deed, (flKB) End Depen (flKB) 4/16/2017 4/16/2017 2.50 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 9438' to 9548' MD 9,438.0 9,548.0 06:30 09:00 w/ 450 gpm, On btm SPP 1415 psi, Off btm SPP 1306 psi, 14% F/O, 10 rpm, 9.5k Tq, 3-12k WOB, PUW 158k, SOW 94k, ROT 122k w/ 8k Tq, MW 9.2+ ppg, AST 0.80, ART 0.17, ADT 0.97, Bit hrs 0.97, Jar hrs 57.46. Note: Swap rig to generator power at 08:00 hrs to allow for work on transformer for hi -line power. 4/16/2017 4/16/2017 1.50 PROD2 DRILL DDRL P Observe string start taking weight with 9,548.0 9,557.0 09:00 10:30 upper 8-9/16" stabilizer -8' down on the slide @ 9548' MD. Set down 15k weight, pick up and observe 30k overpull. Repeat two additional times with same results. Slack off to 125k HL and engage rotary at 5 rpm, 9k Tq and Drill f/ 9548'- 9557' MD w/ 450 gpm, On Btm SPP 1380 psi, Off Btm SPP 1330 psi, 14% F/O, 10.52ppg ECD, 5 rpm, 8-9k Tq 4/16/2017 4/16/2017 1.50 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 9557'to 9615'MD, 9,557.0 9,615.0 10:30 12:00 3617' TVD w/ 450 gpm, On btm SPP 1441 psi, Off btm SPP 1400 psi, 14% F/O, 10 rpm, 9k Tq, 3-15k WOB, PUW 157k, SOW 94k, ROT 125k w/ 8k Tq, MW 9.4 ppg, AST 0.29, ART 0.27, ADT 0.56, Bit hrs 1.53, Jar hrs 58.02. 4/16/2017 4/16/2017 1.25 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 9615'- 9660' MD, 9,615.0 9,660.0 12:00 13:15 3614' TVD w/ 450 gpm, On btm SPP 1460 psi, Off btm SPP 1400 psi, 14% F/O, 25 rpm, 10k Tq, 4k WOB, PUW 159k, SOW 95k, ROT 120k w/ 9k Tq, MW 9.2 ppg, AST 0, ART .25, ADT .25. SPRs @ 9615' MD 3617' TVD, MW=9.20 ppg, 12:35 hours MP#1: 30 spm=340 psi, 40 spm=420 psi. MP #2: 30 spm=320 psi, 40 spm=400 psi. Note: Interference on MWD surveys cleaned up after MWD sensor was -100' out from window (sensor depth of 9509' MD). 4/16/2017 4/16/2017 2.25 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 9660'- 9805' MD, 9,660.0 91805.0 13:15 15:30 3614' TVD w/ 450 gpm, On btm SPP 1460 psi, Off btm SPP 1400 psi, 14% F/O, 25 rpm, 1 O Tq, 4k WOB, PUW 159k, SOW 95k, ROT 120k w/ 9k Tq, MW 9.2 ppg, AST 0.77, ART 0.96, ADT 1.73, Bit hrs 3.51, Jar hrs 60.00. Page 32150 Report Printed: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dor (hr) Phew Op code Activity CDda Time P -T -X Operation Sian Depth (ftKB) End Depth (RKB) 4/16/2017 4/16/2017 2.00 PROD2 DRILL CIRC T Observe higher than expected motor 9,805.0 9,745.0 15:30 17:30 yields and projections indicate bit will be out of zone too much if we continue. Discuss path forward with town. Pick up off bottom and circulate / reciprocate pipe f/ 9787' to 9745' MD w/ 450 gpm, 1380 psi, 14% F/O, PUW 159k, SOW 95k, ROT 120k wl 9k Tq while waiting. Note: Rig swap to hi -line power at 16:20 hrs after modifications made to transformer - power is now being delivered correctly to rig and functioning well. 4/16/2017 4/16/2017 0.50 PROD2 DRILL TRIP T Decision made to perform open -hole 9,745.0 9,660.0 17:30 18:00 sidetrack. Pull OOH f/ 9745'- 9660' MD, monitoring displacement on pit #1. PUW 159k, SOW 95k, ROT 120k w/ 8k Tq. 4/16/2017 4/16/2017 0.75 PROD2 DRILL KOST T Begin troughing f/ 9660' to 9611' MD 9,660.0 9,660.0 18:00 18:45 wl 450 gpm, 1380 psi, 14% FIO. 4/16/2017 4/16/2017 1.00 PROD2 DRILL DDRL T Perform open hole sidetrack at 9660' 9,660.0 9,701.0 18:45 19:45 MD per DD. Slide 0.8 ft and begin - rotating @ 80 rpm, 10k Tq, Ok WOB, 450 gpm, 1380 psi (total bit revs = 206 rpms). Continue drilling to 9701' MD. Note: Decision was made to perform conservative open -hole sidetrack by rotating instead of sliding to minimize risk of obtaining too high of a dogleg and dropping us below plan. 4/16/2017 4/16/2017 0.75 PROD2 DRILL KOST T Ream through sidetrack section f/ 9,701.0 9,701.0 19:45 20:30 9701' to 9617'w/ 450 gpm, 1350 psi, 14% VO, 80 rpm, 9.5k Tq. Pick up above sidetrack point, kill rotary and RIH, lagging up at 9701' MD - sidetrack confirmed. 4/16/2017 4/16/2017 1.25 PROD2 DRILL DDRL T DDrill 8-3/4" hole f/ 9701'- 9805' MD, 9,701.0 9,805.0 20:30 21:45 3618' TVD wl 450 gpm, On Don SPP 1450 psi, Off btm SPP 1380 psi, 14% F/O, 30 rpm, 1 O Tq, 3k WOB, PUW 159k, SOW 98k, ROT 120k wl 9k Tq, MW 9.2 ppg, AST 0.46, ART 0.69, ADT 1. 15. Bit hrs 4.66, Jar hrs 61.15. 4/16/2017 4/16/2017 1.25 PROD2 DRILL SRVY P Perform multiple survey check shots 9,805.0 9,798.0 21:45 23:00 per SLB and Gyrodata and obtain SPR's. Downlink to set GWD into memory mode and perform calibration per Gyrodata. SPRs @ 9798' MD 3618' TVD, MW=9.20 ppg, 22:55 hours MP#1: 30 spm=310 psi, 40 spm=400 psi. MP #2: 30 spm=300 psi, 40 spm=390 psi. Page 33150 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our hr ( ) Phase OD Code Activity Cotle Tim P -T -X Operation 3tarl Dealt (nK a End Depth (fixe) 4/16/2017 4/17/2017 1.00 PROD2 DRILL TRIP P Pull OOH f/ 9798'- 9335' MD, 9,798.0 9,335.0 23:00 00:00 monbodng displacement via pit #1. PUW 159k, SOW 95k. Stop at 9630' MD and trip through sidetrack section with no pumps / no rotary to 9680' MD - no issues. At 9600' MD, orient to 20" lett of highside and continue pulling BHA through window and up into rasing - no issues. OA pressure at midnight = 200 4/17/2017 4/17/2017 7.50 PROD2 DRILL TRIP P Pull OOH on elevators f/9335'-721' 9,335.0 721.0 00:00 07:30 MD, monitoring displacement via pit #1. Obtain GWD surveys at every connection, ensuring string is stationary for 2 minutes starting from the when driller finished breaking out stand, as per GyroData hand. Perform sensor calibration every 1000' MD or 25° INC change (whichever comes first) as per GyroData hand. 4/17/2017 4/17/2017 1.25 PROD2 DRILL SHAH P Monitor well for flow at top of BHA and 721.0 682.0 07:30 08:45 hold PJSM - well static. Pull OOH f/ 721'- 682'. Clean and lay down 3 x Baker Xtreme magnets. Recover 1 x full 5 gallon bucket of debris off magnets. 4/17/2017 4/17/2017 0.25 PROD2 DRILL TRIP P Pull OOH f/ 682'- 398', racking back 3 682.0 398.0 08:45 09:00 stands of 5" drill pipe. 4/17/2017 4/17/2017 1.00 PROD2 DRILL TRIP P Stand back jar stand and 1 x stand of 398.0 111.0 09:00 10:00 5" HWDP H 398'to 211'. Stand back 1 x stand of 6-3/4" NMDC's to 111'. 4/17/2017 4/17/2017 0.50 PROD2 DRILL BHAH P Pull tools from the 6-3/4" Gyro Pulse 111.0 80.0 10:00 10:30 collar. Lay down BHA from 11110 80'. 4/17/2017 4/17/2017 0.75 PROD2 DRILL BHAH P Pull OOH f/ 80' to surface, breaking 80.0 0.0 10:30 11:15 out bit and laying down remaining BHA. Observed damaged gauge cutters, most likely attributed to circulating / displacing fluid inside casing. Bit graded 0 -3 -BT -S -X -1 -CT -TD. Calculated fill 86 bbls, actual 94.6 bbls. 4/17/2017 4/17/2017 0.75 PROD2 DRILL BHAH P Clean and clear floor of BHA tools. 0.0 0.0 11:15 12:00 4/17/2017 4/17/2017 0.50 PROD2 DRILL SVRG P Crew change. Prepare BHA. Service 0.0 0.0 12:00 12:30 rig. Open and inspect saver sub on the top drive. Needs changed, will do above the window. 4/17/2017 4/17/2017 0.25 PROD2 DRILL SFTY P Pre job safety meeting on picking up 8 0.0 0.0 12:30 12:45 -3/4" Rotary steerable BHA. Page 34150 Report Printed: 51212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Star) Tm* EM Time Our (no Phase Op Cade Aoerny Code Time PJA Operation Start Depth (UKS) End Depth (fFKB) 4/17/2017 4/17/2017 2.25 PROD2 DRILL SHAH P Make up BHA # 8 as per 0.0 370.0 12:45 15:00 Schlumberger Directional driller to 370'. Pick up 8-3/4" Smith X616 Axeblade PDC bit w/ 6 x 16's, Xoeed 675 RSS w/ dummy float and 8-5/6" stabilizer, 6-3/4" PeriScope, 6-3/4" Telescope, NM XO, 8-5/8" NM Stabilizer w/ ported flapper float, 1 x 6- 3/4" NMDC, 8-5/8 NM Stabilizer, 2 x 6- 3/4" NMDC's, Saver sub, 3 x 5" HWDP, 6-1/4" Hydraulic jar, and 2 x 5" HWDP. 4/17/2017 4/17/2017 5.00 PROD2 DRILL TRIP P RIH w/ BHA #8 on 5" DP stands with 370.0 8,890.0 15:00 20:00 no super sliders f/ 370'to 6901' MD and with 5" DP with super sliders f/ 6901'- 8890' MD, filling pipe every 20 x stands and monitoring displacement via pit #1. Shallow hole test MWD on first fill - good test. PUW 150k, SOW 100k. 4/17/2017 4/17/2017 1.50 PROD2 DRILL SVRG P PJSM. Change out wom 4-1/2" IF 8,890.0 8,890.0 20:00 21:30 saver sub for new one and service topddve, monitoring well via pit #1 - well static, no losses observed. 4/17/2017 4/17/2017 1.00 PROD2 DRILL TRIP P RIH w/ BHA #8 on 5" DP stands with 8,890.0 9,715.0 21:30 22:30 super sliders f/ 8890' to 9715' MD, monitoring displacement via pit #1. PUW 152k, SOW 100k. Observe 0-1k drag running bit across slide and out into open hole. Observe 5-15k drag f/ 9447'- 9517' MD. 4/17/2017 4/18/2017 1.50 PROD2 DRILL SRVY P Obtain surveys and roll -checks per 9,715.0 9,805.0 22:30 00:00 SLB at 9715', 9745', 9775', 9790', and 9800' MD to allow for effective batch corrections of surveys once we start drilling. Obtain SPR's. PUW 149k SOW 98k, ROT 115k. Continue to bottom at 9805' MD. SPRs @ 9800' MD 3618' TVD, MW=9.30 ppg, 23:45 hours MP#1: 30 spm=260 psi, 40 spm=340 psi. MP #2: 30 spm=260 psi, 40 spm=340 psi. OA pressure at midnight = 220 psi. 4/18/2017 4/18/2017 6.00 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 9805'to 10394' 9,805.0 10,394.0 00:00 06:00 MD, 3598' TVD w/ 550 gpm, 1670 psi, Off btm SPP 1600 psi, 17% F/O, ECD 11.10 ppg, 100-170 rpm, 12k Tq, 2-8k WOB, PUW 159k, SOW 91k, ROT 110k w/ 10k Tq, MW 9.3 ppg, Max gas 116 units, ADT 4.16, Bit hrs 4.16, Jar hrs 69.2. 980'- Concretions @ 9971'- 9976', 9980'- 9982',1006V 9982',10061' - 10065%10389' - 10394' MD. Note: Al 10210' MD, observed shakers start trying to blind off and running wet with 200 API screens on all three shakers. Page 35150 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 16 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Time End Time our (h) Phase Op code Activity Code Time P -T -x Operation Stan Depth Inks) End Depth (M(8) 4/18/2017 4/18/2017 6.00 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 10394' to 10920' 10,394.0 10,920.0 06:00 12:00 MD, 3598' TVD w/ 550 gpm, 1730 psi, Off blm SPP 1700 psi, 18% F/O, ECD 11.43 ppg, 100-180 rpm, 14-17k Tq, 2 -8k WOB, PUW 160k, SOW 77k, ROT 105k w/ 16k Tq, MW 9.3 ppg, Max gas 521 units, ADT 4.22, Bit hrs 8.38, Jar his 73.42. Concretions @ 10394'- 10401', 10460' - 10470', and 10717'- 10722', Crossed 12' DTW fault @ 10406' MD and 13' DTE fault @ 10585' SPRs @ 10788' MD 3611' TVD, MW=9.30 ppg, 11:30 hours MP#1: 30 spm=340 psi, 40 spm=440 psi. MP #2: 30 spm=340 psi, 40 spm=420 psi. 4/18/2017 4/18/2017 0.50 PROD2 DRILL CIRC T Observed fluid loss over shakers 10,920.0 10,920.0 12:00 12:30 increasing significantly. Pick up off bottom at 10920' MD, drop flow rate to 174 gpm, 463 psi, and circulate / reciprocate while screening down shakers to 170 API screens and moving mud. Recycle fluid from rockwasher to pits per mud engineer and add in new fluid. Stage pumps up to 500 gpm, 1446 psi and ream back to bottom. 4/18/2017 4/18/2017 5.50 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 10920'to 11348' 10,920.0 11,348.0 12:30 18:00 MD, 3605' TVD w/ 550 gpm, 1665 psi, Off btm SPP 1650 psi, 17% F/O, ECD 11.22 ppg, 100-180 rpm, 15k Tq, 5k WOB, PUW 160k, SOW 79k, ROT 119k w/ 12k Tq, MW 9.3 ppg, Max gas 101 units, ADT 2.68, Bit hrs 11.06, Jar hrs 76.10. Concretions drilled at 11315'- 11330'. Page 36150 Report Printed: 512/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) PhaseStan OP Code ActivM1y Code Tima P-T-% Operetion Depth PN End Depth (idCa) 4/18/2017 4/19/2017 6.00 PROD2 DRILL DDRL P DDrill 8-314" hole f/ 11348'to 11619' 11,348.0 11,819.0 18:00 00:00 MD, 3576' TVD w/ 550 gpm, 1730 psi, Off btm SPP 1700 psi, 18% F/O, ECD 11.48 ppg, 120-180 rpm, 18k Tq, 5- 10k WOB, PUW 167k, Unable to get slackoff weight, ROT 11 Ok w/ 16k Tq, MW 9.2 ppg, Max gas 160 units, ADT 5.06, Bit hrs 16.12, Jar hrs 81.16. Concretions drilled at 11442'- 11452', 11546'- 11557', 11586'- 11590', and 11638'- 11641'. Crossed -30' DTE fault at 11522' MD. Note: Lost ability to get slackoff weight at midnight at 1181 9'MD. Fluid continue to run wet off the shakers. Recycle Fluid from rockwasher and perform new mud dilutions per mud engineer. Observe sticky / oily cuttings coming over shakers. SPRs @ 11725' MD 3585' TVD, MW=9.20 ppg, 23:05 hours MP#1: 30 spm=360 psi, 40 spm=440 psi. MP #2: 30 spm=360 psi, 40 spm=440 psi. OA pressure at midnight = 280 psi 4/19/2017 4119/2017 6.00 PROD2 DRILL DDRL P DDrill 8-314" hole f/ 11819'to 12293' 11,819.0 12,293.0 00:00 06:00 MD, 3566' TVD wl 550 gpm, 1770 psi, Off btm SPP 1750 psi, 18% F/O, ECD 11.51 ppg, 180 rpm, 20-23k Tq, 2-1 Ok WOB, PUW 157k, Unable to get slackoff weight, ROT 108k w/ 19k Tq off , MW 9.3 ppg, Max gas 160 units, ADT 4.41, Bit hrs 20.53, Jar hrs 85.57. Concretions drilled at 11826' -11829', 11830'- 11837', 11961'- 11967', 11981', 11984', 12008'-12010' and 12093'- 12104'. Increased lube concentration to 1.5% with Lo-Torq at 12150' due to high torque. Page 37150 Report Printed: 51212017 `- Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur Mr) Phase Op Code Activity Code Time P -T -X O Pesti Start Depth (tlKa) End Depth MR) 4/19/2017 4/19/2017 6.00 PROD2 DRILL DDRL P DDrill 8-314" hole V 12293' MD to 12,293.0 12,946.0 06:00 12:00 12946' MD, TVD= 3571. Pump @ 550 gpm= 1915 psi on, 1890 psi off w/ 18 % flow out. Rotate @ 180 rpm's w/ 20- 21 K Tq on, 20K Tq off, 2-1 OK WOB, ECD= 11.88 ppg, Max gas= 210. P/U= 164K, Unable to slack off, ROT= 104K. ADT= 4.54, Bit hrs = 25.07, Jar hrs = 90.11 Concretions drilled at 12361'-12366', 2378'-12385', 12404'-12413'.12896'- 2404'-12413',12896'- 12900', 12900', and 12943' SPRs @ 12296' MD 3781' TVD, MW=9.3 ppg, 07:00 hours MP#1: 30 spm=380 psi, 40 spm=460 psi. MP #2: 30 spri psi, 40 spm=460 psi. 4/19/2017 4119/2017 6.00 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 12946' MD to 12,946.0 13,581.0 12:00 18:00 13581' MD, TVD= 3576. Pump @ 550 gpm= 1920 psi on, 1915 psi off w/ 18 % flow out. Rotate @ 180 rpm's wl 18- 22K Tq on, 16K Tq off, 6K WOB, ECD= 11.73 ppg, Max gas= 81. P/U= 175K, Unable to slack off, ROT= 108K. ADT= 4.68, Bit hrs = 29.75, Jar hrs = 94.79 Concretions drilled at 12946'- 12948', 13350'- 13354', 13359' - 13370', 13514'- 13525', and 13581'. Increased lube concentration to 2.0% with Lo-Torq at 13500' MD due to high torque. SPRs @ 13334' MD 3578' TVD, MW=9.25 ppg, 14:50 hours MP#1: 30 spm=460 psi, 40 spm=540 psi. MP #2: 30 spm=480 psi, 40 spm=560 psi. 4/19/2017 4/20/2017 6.00 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 13581' MD to 13,581.0 13,922.0 18:00 00:00 13922' MD, TVD= 3571. Pump @ 550 gpm= 1955 psi on, 1940 psi off w/ 18 % flow out. Rotate @ 120-180 rpm's w/ 18-20K Tq on, 16K Tq off, 2-10K WOB, ECD= 11.83 ppg, Max gas= 93. P/U= 181 K, Unable to slack off, ROT= 109K. ADT= 4.79, Bit hrs = 34.54, Jar hrs = 99.58 Concretions drilled at 13581' - 13595', 13650' - 13667',13678- - 13684', 13696' - 13706, 13718' - 13724', 13726'- 13731', 13735'- 13770', 13867'- 13878', and 13896- 13898'. Performed 290 bbl dump/dilute @ 13850' MD OA pressure at midnight = 200 psi Page 38/50 Report Printed: 51212017 Operations Summary (with Timelog Uepths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Ti Start me End Time Our Phase OP Code Activity Code Time P -T -X OP exon De Steri En (n End Depth (ftKa) 4/20/2017 4/20/2017 6.00 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 13922' MD to 13,922.0 14,739.0 00:00 06:00 14739' MD, TVD= 3560. Pump @ 550 gpm= 2010 psi on, 2000 psi off w/ 18 % flow out. Rotate @ 180 rpm's w/ 19- 21K Tq on, 18K Tq off, 2-1 OK WOB, ECD= 12.00 ppg, Max gas= 210. P/U= 205K, Unable to slack off, ROT= 99K. ADT= 4.78, Bit hrs = 39.32, Jar hrs = 104.36 Concretions drilled at 14055'- 14065' and 14082'- 14090'. SPRs @ 14477' MD 3565' TVD, MW=9.3 ppg, 04:00 hours MP#1: 30 spm=460 psi, 40 spm=540 psi. MP #2: 30 spm=460 psi, 40 spm=540 psi. Note: Started picking up HWDP stands w/ super sliders @ 14567' MD onwards. 4/20/2017 4/20/2017 6.00 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 14739' MD to 14,739.0 15,375.0 06:00 12:00 15375' MD, TVD= 3598. Pump @ 550 gpm= 2200 psi on, 2185 psi off w/ 18 % flow out. Rotate @ 180 rpm's w/ 20- 22K Tq on, 20K Tq off, 4-81K WOB, ECD= 12.10 ppg, Max gas= 60. P/U= 21 OK, Unable to slack off, ROT= 111 K. ADT= 4.17, Bit hrs = 43.49, Jar him = 108.53 Concretions drilled at 14740'- 14750', 14976'- 14980', 15286'- 15291', and 15319'- 15328'. 4/20/2017 4/20/2017 5.75 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 15375' MD to TD 15,375.0 15,896.0 12:00 17:45 of 15896' MD, TVD= 3542'. Pump @ 550 gpm= 2290 psi on, 2285 psi off w/ 16 % flow out. Rotate @ 180 rpm's w/ 21 K Tq on, 19K Tq off, 12K WOB, ECD= 12.03 ppg, Max gas= 155. P/U= 217K, Unable to slack off, ROT= 127K. ADT= 4.75, Bit hrs = 48.24, Jar him = 113.28 Concretions drilled at 15468'- 15480', 15670'- 15673', 15704'- 15709', 15732' - 15736',16750- - 15755', 15760'- 15770', and 15872'- 15879'. SPRs @ 15495' MD 3556' TVD, MW=9.25 ppg, 12:50 hours MP#1: 30 spm=540 psi, 40 spm=620 psi. MP #2: 30 spm=540 psi, 40 spm=620 psi. Page 39150 Report Printed: 5/212017 . - Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation start Depth (MB) EM Depth (WS) 4/20/2017 4/20/2017 1.50 PROD2 CASING CIRC P Obtain final survey and SPR's at TO 15,896.0 15,865.0 17:45 19:15 and circulate 1 x bottoms up f/ 15894' - 15810' MD w/ 570 gpm, 2400 psi, 17% F/O, 160 rpm, 21 k Tq, Initial ECD 12.06 ppg, Final ED 11.87 ppg. Obtain final parameters of PUW 218k, SOW 91 k, ROT 135k at 30 rpm w/ 18k Tq. SPRs @ 15896' MD 3541' TVD, MW=9.20 ppg, 17:50 hours MP#1: 30 spm=520 psi, 40 spm=620 psi. MP #2: 30 spm=520 psi, 40 spm=620 psi. Note: After reaming stand while CBU, we were able to regain slackoff weight. 4/20/2017 4/20/2017 0.75 PROD2 CASING OWFF P Lay down 5" DP single and monitor 15,865.0 15,865.0 19:15 20:00 well for flow for 30 minutes while rotating 10 rpm, 15k Tq -well showing static losses of -3.5 bbls/hr. Clean out air intake vents for traction motors on lop hive. Drop 2.375" OD hollow rabbit w/ 110' of wire on stand # HW14. 4/20/2017 4/21/2017 4.00 PROD2 CASING BKRM P Backream OOH f/ 15866- 14938' MD 15,865.0 14,938.0 20:00 00:00 w/ 550 gpm, 2140 psi, 16% F/O, 180 rpm, 18k Tq, ROT 117k, pulling speed 300-700 fUhr, monitoring displacement via pit #5. Note: Observed packoff tendencies at 15643' MD with SPP increase 150 psi and torque increase 3k. Drop down and wipe stand. Pull slowly through section and cotinue backreaming observing pressure and torque dropping back to normal with no further issues. OA pressure at midnight = 200 psi 4/21/2017 4/21/2017 12.50 PROD2 CASING BKRM P BROOH f/ 14938' MO to 9829' MD, 14,938.0 9,829.0 00:00 12:30 Pump @ 550 gpm, Initial 1900 psi, Final 1645 psi, 16% FO, Rotate 180 rpm's, Initial 18k Tq, Final 13k Tq, Initial ROT weight= 117k, Final ROT weight= 106K, monitoring displacement via pit #5. 4/21/2017 4/21/2017 1.00 PROD2 CASING BKRM P Reduced rotary RPMs to 80 rpm's 9,829.0 9,629.0 12:30 13:30 while Jars and NMFC go across slide and cont to BROOH it 9829' MD to 9629' MD, reduce pulling speed to 500 fph. From TO to window: Calculated displacement = 67.5 bbls Actual displacement = 199.1 bbls Total volume lost downhole while backmaming OOH = 127 MIS (lost -5 bbls to rockwasher while trying 230 API screen size on shakers) Page 40150 Report Printed: W21201171 - Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log n De Stan Depth Slat Time EM Time Dur (re) Phase Op code Acti Code vily Time P -T -X O re w pe End Depth (flKa) 4/21/2017 4/21/2017 1.00 PROW CASING PMPO P Pull from 9629'- 9360' MD wl no 9,629.0 9,360.0 13:30 14:30 rotary at 370 gpm, 854 psi, 13% F/O, PUW 145k - no overpull observed pulling BHA through window. 4/21/2017 4/21/2017 1.50 PROD2 CASING CIRC P Circulate 2.5 bottoms w/ 550 gpm, 9,360.0 9,266.0 14:30 16:00 1553 psi, 16% F/O, 80 rpm, 6k Tq, PUW 144k, SOW 103k, ROT 120k. 4/21/2017 4121/2017 0.25 PROD2 CASING OWFF P Monitor well for flow - well static. 9,266.0 9,266.0 16:00 16:15 4121/2017 4/21/2017 4.00 PROD2 CASING TRIP P Pump dry job and pull OOH on 9,266.0 370.0 16:15 20:15 elevators f/ 9266'- 370' MD, monitoring displacement via trip tank. Note: Observe minimal to zero hardbanding left on 5" DP from stands #30 - surface. All super sliders in place and do not need modification for completion operations. 4/21/2017 4/21/2017 0.25 PROD2 CASING OWFF P Monitor well for flow - well static. 370.0 370.0 20:15 20:30 PJSM for laying out BHA. 4121/2017 4/21/2017 2.00 PROD2 CASING BHAH P Lay down BHA #8 per DD, racking 370.0 0.0 20:30 22:30 back 1 x stand HWDP for use on whipstock retrieval run. Observe top 8- 5/8" NM stabilizer 1/4" undergauge and middle 8-5/8" NM stabilizer 3/16" undergauge. Observed hardbanding wom down smooth on new saver sub. 8-5/8" stabilizers on Xceed RSS were in gauge. Bit graded 0 -0 -NO -A -X -0 - NO -TD Note: Found 2-3/8" OD hollow drift on top of jar mandrel with no wire on it - connection piece on top of drift was partially washed out. Wire was found at top of NMDC's and was stuck in the float sub above the Telescope MWD. From window to surface: Calculated displacement 83.2 bbls Actual displacement 100.8 bbls 4/21/2017 4/21/2017 0.50 PROD2 CASING BHAH P Clean and clear rig floor of BHA 0.0 0.0 22:30 23:00 equipment. 4/21/2017 4/22/2017 1.00 COMPZ2 FISH SLPC P PJSM. Slip / cut 88' of drilling line. 0.0 0.0 23:00 00:00 Note: Observe -1 bbVhr static losses. OA pressure at midnight = 100 psi 4/22/2017 4/22/2017 1.00 COMPZ2 FISH SLPC P Cont to slip and cul drilling line. 0.0 0.0 00:00 01:00 4/22/2017 4/22/2017 1.00 COMPZ2 FISH BHAH P Mobilize BHA components and sub to 0.000 01:00 02:00 dg floor via beaver slide. 4/22/2017 4/22/2017 1.00 COMPZ2 FISH BHAH P WU whipstock retrieval BHA as per 0.0 283.0 02:00 03:00 Baker fishing rep to 283' MD Page 41160 ReportPrinted: 5/2/2017 ff Operations Summary (with Timelog Depths) t. 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start re Time End Time Dur (hr) Phase Op Code AMM, Code Time P -T -X Operation Del Stan Oepm EM OepN (flKa) 4/22/2017 4/22/2017 5.50 COMPZ2 FISH TRIP P RIH w/ whipstock retrieval BHA f/ 283' 283.0 9,338.0 03:00 08:30 MD to 9338' MD. Shallow hole test tools @ 2000' MD , pump @ 430 gpm W/ 735 psi, good test. Actual Displacement for trip in= 88.4 bbls Calculated displacement trip in= 96.3 bbls 4/22/2017 4/22/2017 1.00 COMPZ2 FISH WASH P Establish circulation @ 450 gpm w/ 9,338.0 9,407.0 08:30 09:30 1504 psi. Orient to 160°R ( placing circ hole @ 20° L) to wash whipstock and retrieval slat down to 9405' MD. Observed fill/cuttings being washed clear of slide, pump pressure varied from 1100 psi to 2300 psi as material was being washed clean. P/U= 165K, S/O= 122K. 4/22/2017 4/22/2017 0.75 COMPZ2 FISH FISH P Pump @ 375 gpm w/ 1068 psi. Orient 9,407.0 9,307.0 09:30 10:15 to 20°L, slack off to 9397' MD and observed hook set down in retrieval slot, set down 1 O Pick up to 195K ( 25K over) and observed unloatler shear. Once unloatler sheared lost returns until fluids equalized between laterals, 11 bbls lost. Picked up to 210K ( 45K over) and observed anchor release. Stand back one stand and single to 9307' MD. Observed 1 O extra drag after hooking whipstock, P/U= 175K. 4/22/2017 4/22/2017 0.75 COMPZ2 FISH CIRC P Circulate BU @ 635 gpm= 2500 psi. 9,307.0 9,307.0 10:15 11:00 Did not reciprocate string while CBU. 4/22/2017 4/22/2017 0.25 COMPZ2 FISH OWFF P Blow down top drive and monitor well 9,307.0 9,307.0 11:00 11:15 for flow - static to slight loss. 4/22/2017 4/22/2017 2.25 COMPZ2 FISH TRIP P Pull OOH racking back 5" HWDP and 9,307.0 6,298.0 11:15 13:30 5" DP f/ 9307'- 6298' MD, monitoring displacement via trip tank, PUW 144k. 4/22/2017 4/22/2017 0.25 COMPZ2 FISH CIRC P Pump 20 bbl dry job @ 6298' MD and 6,298.0 6,298.0 13:30 13:45 blow down top drive. 4/22/2017 4/22/2017 3.75 COMPZ2 FISH TRIP P Pull OOH racking back 5" DP f/ 6298'- 6,298.0 238.0 13:45 17:30 238' MD, monitoring displacement via trip tank. Page 42160 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time Erb Time our (hr) Phase op Cede Activity Code Time PJA operation Start Depth (BKS) Erb Depth (1CKa) 4/22/2017 4/22/2017 2.50 COMPZ2 FISH BHAH P Lay down Baker retrieval BHA and 238.0 0.0 17:30 20:00 whipstock BHA f/ 238'to surface, monitoring displacement via trip tank. Observe small amount of metal debris on magnet above and below whipstock. Observe mill track follow center of whipstock slide and start tracking off slighty clockwise of high - side at the bottom of the slide (1.5" off center). Observe seal assembly with several damaged seals but all were recovered. Confirm anchor still aligned with highside of whipstock - no offset observed. Clean off magnets and lay out tools. Actual displacement for trip out = 117.3 bbls Calculated displacement for trip out = 89.7 bbls 4/22/2017 4/22/2017 1.00 COMPZ2 FISH BHAH P Clean and clear floor of BHA 0.0 0.0 20:00 21:00 equipment. Note: Static losses of -2 bbl/hr observed. 4/22/2017 4/22/2017 0.75 COMPZ2 RLED RURD P Rig up GBR casing tongs and 4-1/2" 0.0 0.0 21:00 21:45 handling equipment for running seal bore diverter. 4/22/2017 4/2212017 1.25 50MPZ2 RLED BHAH P PJSM. Pick up seal bore diverter 0.0 130.0 21:45 23:00 assembly to 130' MD, baker -locking each connection. Align anchor point with seal bore diverter per Baker. 4/22/2017 4/22/2017 0.50 COMPZ2 RLED DHEQ P Set slips and dog collar and function 130.0 130.0 23:00 23:30 test FJD running tool per Baker. Stage up pumps 400 gpm/379 psi, 452 gpm/494 psi, 475 gpm/552 psi. Pick up and confirm still latched. Stage up to 500 gpm/608 psi, pick up and confirm still latched. Stage up to 510 gpm/620 psi, pick up and observe tool still latched. Stage up to 520 gpm/640 psi, pick up and observe tool still latched. Stage up to 540 gpm/690 psi, pick up and observe tool still latched. Drop flow rale to 400 gpm and inspect tool at surface. Stage up to 550 gpm/715 psi, pick up and observe tool released. Drop flow rate to 475 gpm/530 psi allowing tool to re- engage. Pick up and confirm latched in. Stage up pumps to 550 gpm/710 psi and re -confirm tool released. Kill pumps and pick up to confirm tool re- engaged in seal bore diverter. Note: No jets installed in nozzles on FJD tool per previous flow test. 4/22/2017 4/22/2017 0.25 COMPZ2 RLED BHAH P Pick up Telescope MWD w/ XO's and 130.0 162.0 23:30 23:45 scribe MWD to anchor point - measure 332.67° offset (clockwise) from MWD highside to anchor point. Page 43/50 Report Printed: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON U2 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (no Phase Op Code AeUvity Code Time me PJA O perefion Start Depm rt De Entl Depth (RKS) 4/22/2017 4/23/2017 0.25 COMPZ2 RLED TRIP P Run in hole on 5" DP f/ 162'- 351' MD, 162.0 351.0 23:45 00:00 monitoring displacement via trip tank. OA pressure at midnight = 140 psi Total downhole losses for 24 hours = 69 bbls 4/23/2017 4/23/2017 5.75 COMPZ2 RLED TRIP P Cont to RIH with Baker Seal Bore 351.0 9,428.0 00:00 05:45 Diverter f/ 351' MD to 9428" MD. Pumps off PUW 176K, SOW 130k, Actual displacement= 108.6 bbls, Calculated displacement= 93.5 bbls. 4/23/2017 4/23/2017 0.75 COMPZ2 RLED OTHR P Install Baker SBD as follows: Establish 9,428.0 9,507.0 05:45 06:30 circulation@ 400 gpm= 1104 psi, Pumps on PUW 165K, SOW 124K. Orient to 8'L and slack off to 9507' MD, set down 20K. Observe toolface roll to 13'L . Pick up to 185K (20K over) observe toolface roll to 17°L. Set down 20K and pick up to 200K (35K over) observe toolface roll to 20°L. Set down 20K and increase pumps to 550 psi= 1780 psi to release. Pick up to 175K, no release. Set down 20K and increase pump to 600 gpm=2000 psi, pick up to 175K, no release. Set down 30K and increase pumps to 650 gpm= 2300 psi. Pick up and confirm release, free travel at 165K. Wash out top of seal bore diverter while pulling out running tool. 4/23/2017 4/23/2017 0.50 COMPZ2 RLED OWFF P Stand back 1 stand and UD single to 9,507.0 9,390.0 06:30 07:00 9390' MD. OWFF, static. 4/23/2017 4/23/2017 5.00 COMPZ2 RLED TRIP P POOH w/ FJD running tool from 9390' 9,390.0 351.0 07:00 12:00 MD to 351' MD. W WT rep inspected super sliders while POOH. 4/23/2017 4/23/2017 0.75 COMPZ2 RLED BHAH P UD MWD tools, XO and Baker FJD 351.0 0.0 12:00 12:45 running tool from 351' MD to Surface. Actual displacement= 91.5 bbls, Calculated displacement= 91.5 bbls. 4/23/2017 4/23/2017 1.00 COMPZ2 RLED RURD P Clean and clear dg floor. 0.0 0.0 12:45 13:45 4/23/2017 4/23/2017 0.50 COMPZ2 CASING SVRG P Service rig, grease blocks and top 0.0 0.0 13:45 14:15 drive. 4/23/2017 4/23/2017 0.50 COMPZ2 CASING RURD P Rig up casing handling equipment for 0.0 0.0 14:15 14:45 running 4-1/2" liner. 4/23/2017 4/23/2017 7.00 COMPZ2 CASING PUTS P PJSM. Make up 5-1/2" guide shoe and 0.0 6,444.0 14:45 21:45 float collar and run in hole on 4-1/2" 12.6 Ib/ft L-80 TXP-m slotted / blank liner per tally to 6444' MD, installing 4- 1/2" x 6-1/8" hydroform centralizers free floating every joint, monitoring displacement via trip tank. Calculated displacement = 28.4 bbls Actual displacement = 14.3 bbls Page 44150 Report Printed: 51212017 III Operations Summary (with Timelog Depths) z 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sred Tme End Time our (hr) PhaseOp Code Activity Code Time P-T-X Operation SWrt Depth (fl Ke) End Depth (flKB) 4/23/2017 4/232017 1.00 COMPZ2 CASING PUTB P Make up 3-1/2" inner string, change 6,444.0 6,489.0 21:45 22:45 out handling equipment, and make up RAM hanger assembly per Baker to 6489' MD. PUW 92k, SOW 75k 4/232017 4/232017 0.50 COMPZ2 CASING RUNL P Make up 1 x stand 5" DP and RIH to 6,580.0 6,580.0 22:45 23:15 6580' MD. Makeup topdrive and establish circulation, 2 bpm / 68 psi / 4% F/O, staging up to 4 bpm / 147 psi / 6% F/O, total 14 bbis pumped. PUW 92k, SOW 75k, ROT 80k w/ 25 rpm, 3k Tq. Blow down topdrive. 4/23/2017 424/2017 0.75 COMPZ2 CASING RUNL P RIH on 5" DP f/ 6580'- 8098' MD at 90 6,580.0 23:15 00:00 ft/min per Baker, monitoring displacement via trip tank, PUW 116k, SOW 88k. Total downhole losses for 24 hours = 50 bbls OA pressure = 100 psi 4/24/2017 4/24/2017 1.00 COMPZ2 CASING RUNL P Cont to RIH w/ 4-12" liner on 5" DP f/ 8,098.0 9,385.0 00:00 01:00 8098' MD to 9385' MD, 4/24/2017 4242017 0.50 COMPZ2 CASING CIRC P Obtain parameters before exiting the 9,385.0 9,385.0 01:00 01:30 window @ 9392' MD. Pump @ 4 bpm=190 psi, Rotate @ 15 rpms with 5K tq. P/U= 130K, S/O= 99K, ROT=130K. 4/24/2017 4242017 3.50 COMPZ2 CASING RUNL P Cont to RIH wl4-12" liner on 5" 9,385.0 15,745.0 01:30 05:00 DP/HWDP to 15745' MD. Actual displacement = 105 bbls, Calculated displacement= 121 bbis. 4/24/2017 4242017 0.75 COMPZ2 CASING RUNL P Snap RAM hanger into collet on SBD 15,745.0 15,863.9 05:00 05:45 easy as follows: Establish circulation @ 15745' pump @ 4 bpm= 500 psi, MD, P/U= 200K, S/O= 115K. Wash down to 15834' MD. Break off top drive and RIH and tag collet @ 15864' MD, RAM collet depth @ 9388' MD. Slack off to 80K ( 35K down) and snap into collet. P/U to 220K (20K over) to confirm latch. Attempted to unsnap from collet by pulling 30K over, 50K over and 60K over, unsuccessful. Set down 20K on collet then attempted to unsnap again. Pulled 60K over and 65K over, no success. Set down 35K on collet and discuses options with town. 4/24/2017 4/242017 1.75 COMPZ2 CASING RUNL T Confer with town on issues and 15,863.9 15,863.0 05:45 07:30 options about not being able to un snap from SBD assy. Decision made to continue forward and release from RAM liner hanger. Page 45150 ReportPrinted: 6/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our(hn Phase Op Code Am ity Coda Time P-T-XOperetion Start Depm (fll®) End Deplh(WB) 4/24/2017 4/24/2017 2.50 COMPZ2 CASING PACK P Release from RAM Liner hanger as 15,863.0 9,450.0 07:30 10:00 follows. Drop 29/32" ball and pump down @ 3 bpm= 367 psi, reduce to 2 bpm=300 psi @ 700 strokes, reduce to 1.5 bpm= 200 psi @ 1290 strokes. Ball landed on seal late @ 2050 strokes ( 1450 calculated). Pressure up to 2800 psi and hold for 1 min, PIU to 180K did not release. Slack off to 80K and pressure up to 3400 psi, hold for 1 min. Pick up out of RAM hanger and confirmed release. P/U= 185K. Pick up until guide nose above seal bore diverter, RIH and set down 10k on 3.71" shoulder inside seal bore diverter to confirm correct orientation and access to main bore - good tag. 4/242017 4/24/2017 0.75 COMPZ2 CASING PACK P Shear ball seat on running tool as 9,450.0 9,380.0 10:00 10:45 follows. Set down to 100K and pressure up to 4200 psi, no success. Bleed off pressure and line up to use test pump along with mud pumps. Pressure up to 4200 psi with mud pumps, shut in mud pumps and pressure up to 4900 psi with test pump. Observed shear @ 4900 psi. 4/242017 4/24/2017 4.00 COMPZ2 RWRID TRIP P Blow down top drive and pull OOH 9,380.0 97.0 10:45 14:45 racking back 5" DP / HWDP f/ 9380' - 97' MD, PUW 137k, SOW 105k, monitoring displacement via trip tank. 4/24/2017 4/242017 0.50 COMPZ2 RWRID SHAH P Lay down RAM hanger running tools f/ 97.0 0.0 14:45 15:15 97'to surface, monitoring displacement via trip tank. Actual displacement = 111.2 bbls. Calculated displacement = 91.8 bbls 4/24/2017 4/242017 1.00 COMPZ2 RWRID BHAH P Clean and clear rig floor. 0.0 0.0 15:15 16:15 4/24/2017 4/24/2017 0.50 COMPZ2 RWRID SVRG P Service crown. Simops: Rig up GBR 0.0 0.0 16:15 16:45 and handling equipment and confirm order in pipeshed. 4/24/2017 424/2017 3.00 COMPZ2 RWRID PUTB P PJSM. Pick up LEM assembly w/ 3 x 0.0 195.0 16:45 19:45 joints 4-12" IBTm tubing, 3.75" nipple, Sealbore extension, and SLZXP Liner top packer. Make up inner string with Slimpulse MWD and scribe - measure offset to LEM at 305.06° clockwise from MWD highside. 424/2017 4/25/2017 4.25 COMPZ2 RWRID RUNL P RIH w/ LEM assembly on 5" DP / 195.0 7,501.0 19:45 00:00 HWDP stands w/ super sliders installed to 7501' MD, filling pipe every 20 x stands and shallow hole testing MWD on first fill - good test. Monitor displacement via trip tank. PUW 137k, SOW 103k. OA pressure at midnight = 120 psi Total downhole losses for 24 hours = 59 bbls Page 46/50 Report Printed: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Star) Time EW Time Dur (hr) Phase Op CoCe ActivityCode Time P-T-X operation Stan mK1 Depth EWDep1h(ItKB) 4/25/2017 4/25/2017 2.25 COMPZ2 RWRID RUNL P RIH w/ LEM assembly on 5" DP / 7,501.0 9,354.0 00:00 02:15 HWDP stands w/super sliders installed to f/ 7501'- 9354' MD, filling pipe every 20 x stands - good test. Monitor displacement via trip tank. PUW 173k, SOW 128k. 4/25/2017 4/25/2017 1.50 COMPZ2 RWRID OTHR P Pick up space out pups to be spaced 9,354.0 9,407.0 02:15 03:45 out for blowing down top drive prior to pressure test. Orient LEM to 7°L w/ 109 gpm, 550 psi and RIH to snap in LEM. Set down t Ok at 9204', work pipe up to PUW 169k w/ no overpull. RIH and snap LEM collet into RAM, setting 17k down at 9405' and seeing it breakover to 124k and continue in and tag up at 9407' w/ 20k, seeing toolface roll to 107°R as LEM slabbed in. Pick up to 18K and confirm latch, pick up 27K over pull and unlatch from collet. Set down 20K again to latch in, obverted exact same toolface roll ( 107'R) when latching into collet. Discussed unexpected orientation, discovered that the scribe had been carried up incorrectly form the XO, not SLZXP. 4/25/2017 4/25/2017 1.75 COMPZ2 RWRID PACK P Set SLZXP as follows: Drop 1-5/8" ball 9,407.0 9,407.0 03:45 05:30 and pump down @ 2 bpm=415 psi, slow pumps to 1.5 bpm= 329 psi at 1110 strokes. Observed ball seat @ 1370 strokes. Pressure up to 2600 psi hold for 1 min,observed packer set, continue walking pressure up to 4000 psi holding for 1 min every 200 psi to release. Confirmed release. 4/25/2017 4/25/2017 0.50 COMPZ2 RWRID RURD P P/U to confirm release ( 174K up) and 9,407.0 9,400.0 05:30 06:00 1 1 1 rig up to pressure test IA. 4/25/2017 4/25/2017 0.50 COMPZ2 RWRID PRTS P Pressure test 9-5/8" production 9,400.0 9,400.0 06:00 06:30 annulus to 3500 psi for 30 min on chart, good test. 4/25/2017 4/2512017 0.50 COMPZ2 RWRID TRIP P POOH, removing running tool and 9,400.0 9,292.0 06:30 07:00 MWD from tie-back sleeve to 9292' MD. P/U= 172K 4/2512017 4/25/2017 3.50 COMPZ2 RWRID DISP P Displace well to 9.4 ppg NaCl brine as 9,292.0 9,292.0 07:00 10:30 follows: Pump 30 bbis of high viscosity spacer followed by 955 bbls of NaCl brine. Bring pumps up to 150 gpm=255 psi to confirm MWD tool bypass. Cont to stage pumps up to 410 gpm=800 psi. Brine observed @ shakers at 8000 strokes and continue to dump fluid until clean brine was observed @ 9855 strokes. 4/25/2017 4/25/2017 0.50 COMPZ2 RWRID PULD P POOH, laying down 14 jnts of HWDP. 9,292.0 8,922.0 10:30 11:00 1 4/25/2017 4/25/2017 0.50 COMPZ2 RWRID PULD P RIH with 3 stands HWDP from derrick 8,922.0 8,922.0 11:00 11:30 I and lay down same. Page 47150 ReportPrinted: 51212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) Phase Op Cotle Activity Ootle Time P -T -X Operation Stan Depth (WR) End Depth (ftKB) 4/25/2017 4/25/2017 10.50 COMPZ2 RWRID PULD Continue POOH laying down 5" 8,922.0 80.0 11:30 22:00 HWDP and 5" DP to completion running tools. Calculated Displacement = 67.2 bbls Actual Displacement = 92.5 bbls 4/25/2017 4/25/2017 0.75 COMPZ2 RWRID PULD P LD SLZXP running tools and SLB 80.0 0.0 22:00 22:45 MWD BHA. 4/25/2017 4/25/2017 0.75 COMPZ2 RPCOMP RURD P MU bushing puller and pull wear 0.0 0.0 22:45 23:30 bushing. 4/25/2017 4/26/2017 0.50 COMPZ2 RPCOMP WWWH P MU stack washer and flush stack. 850 0.0 0.0 23:30 00:00 GPM, 136 PSI, 21% Flow Out, 40 RPM, 1.5k TO. BD TD. Total downhole losses over 24 hrs = 29 bbls OA Pressure = 100 psi 4/26/2017 4/26/2017 4.50 COMPZ2 RPCOMP PULD P Rig up Centrilift to run ESP. Mobilze 0.0 0.0 00:00 04:30 tools to rig floor, rig up sheave, snake line over windwalls to rig floor, unload and count cannon clamps. 4/26/2017 4/26/2017 3.50 COMPZ2 RPCOMP PULD P MU ESP motor and fill with mineral oil. 0.0 0.0 04:30 08:00 Make up seals and service ESP. 4/26/2017 4/26/2017 2.00 COMPZ2 RPCOMP T Penetrator for ESP determined to be 0.0 0.0 08:00 10:00 incorrect, confer with town and wait on decision before beginning to RIH with ESB assembly. 4/26/2017 4/26/2017 0.50 COMPZ2 RPCOMP SVRG P Service blocks, crown and wash pipe. 0.0 0.0 10:00 10:30 4/26/2017 4/26/2017 1.50 COMPZ2 RPCOMP SLPC P Slip and cut drill line. 72' of drill line cut 0.0 0.0 10:30 12:00 off and replaced. Total Losses to Formation for Tour = 19 bbl 4/26/2017 4/26/2017 0.50 COMPZ2 RPCOMP SVRG Clean and clear rig floor, calibrate 0.0 0.0 12:00 1230 block weight. 4/26/2017 4/26/2017 2.00 COMPZ2 RPCOMP PULD Hold PJSM, PU ESP receiver, RCVG 0.0 48.0 12:30 14:30 Gas DISSP 512 Seal and MU to ESP motor as per Centrilift. RIH V48' installings cannon clamps as directed. 4/26/2017 4/26/2017 0.25 COMPZ2 RPCOMP PULD M/U 4-1/2" 12.6# L-80 TXP-m pups, 1 48.0 111.0 14:30 14:45 full jnt and centrilift discharge unit f/48' V110'. Monitor displacement on trip tanks and install cannon clams on each coupling. 4/26/2017 1412612017 1.00 COMPZ2 RPCOMP PULD Splice motor lead as per Centrilift. 111.0 111.0 14:45 15:45 Page 48/50 Report Printed: 5/2/2017 Operations Summary (with Timelog uepths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time Entl lima Dur (hr) Phew Op Catle A01" rode Time P -T -X Operation smn Depth(WB) End Depth(flKB) 4/26/2017 4/27/2017 8.25 COMPZ2 RPCOMP PUTB RIH with 4-1/2" 12.6# L-80 TXP-m 111.0 5,010.0 15:45 00:00 completion as per tally f/111' to 5010' MD. Cannot: clamps installed on each connection, ESP cable tested every 1000'. Displacement monitored on trip tank. UP WT = 86K, SIO WT = 79K, CALC DIPS = 22.4 BBL, ACTUAL DISP. _ 13.1 BBL Total Losses to formation for tour = 20 bbls 4/27/2017 4/27/2017 3.50 COMPZ2 RPCOMP PUTS P Continue RIH w/ 4 1/2" 12.6# L-80 5,010.0 00:00 03:30 TXP-m completion f/5010 t/7288' MD intallings cannon clamps on each connection. ESP cable function tested every 1000' MD. UP WT = 105K, DWN WT = 75K 4/27/2017 4/27/2017 1.00 COMPZ2 RPCOMP THGR P MU tubing hanger and orient, install 03:30 04:30 penetrator and space out ESP cable for cut. SIMOPS: Tail excess ESP cable back to spooling unit. 4/27/2017 4/27/2017 2.50 COMPZ2 RPCOMP THGR P Splice ESP cablewith connector as 04:30 07:00 per Centrilift. SIMOPS: RD GBR rasing equipment. 4/27/2017 4/27/2017 1.00 COMPZ2 RPCOMP THGR P Terminate ESP cable on penetrator 07:00 08:00 and check conductivity as per centrilift. Land tubing hanger as per Vetco. UP WT = 122K, DWN WT = 79K 182 cannon clamps total installed. 4/27/2017 4/27/2017 1.00 COMPZ2 RPCOMP THGR P Run in LDS and TO to spec as per 08:00 09:00 Vecto. Rig down centrilift. RD sheave and demob tools, job box and extra cannon damps from rig floor. 4/27/2017 4/27/2017 0.50 COMPZ2 RPCOMP THGR P Test hager void to 5000 psi for 15 min 09:00 09:30 as per Vetco. Test good, witnessed by CPAI. 4/27/2017 4/27/2017 2.50 COMPZ2 WHDBOP NUND P ND BOPE. Pull flow riser, remove 09:30 12:00 choke and kill lines, rack back BOP stack and RD spacer spools. Total losses to formation for tour = 15 bbls Calculated displacement for tour = 33 bbls, actual displacement = 19 bbis. 4/27/2017 4/27/2017 1.75 COMPZ2 WHDBOP NUND P NU tree. Re -test ESP cable 12:00 13:45 conductivity via penetrator as per Centrilift. SIMOPS: Install mouse hole and LD flow nipple riser. 4/27/2017 4/27/2017 0.25 COMPZ2 WHDBOP PRTS P Test void U 250/5000 psi f/ 10 min as 13:45 14:00 per Vecto. Test good. Page 49150 ReportPrinted: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Tome End Time Dur (hr) Phase Op code Aclrviry Code Time P -T -x Openstion (KKS) End Depth Po l) 4/27/2017 4/27/2017 0.25 COMPZ2 WHDBOP PRTS P Install test dart with dry rod in 'HP' 14:00 14:15 BPV. Fill tree with diesel and test tree to 250/5000 psi f/15 min. Test good. 4/27/2017 4/27/2017 0.50 COMPZ2 WHDBOP MPSP P Pull test dart and BPV with dry rod 14:15 14:45 (annulus valve open and no psi confirmed). 4/27/2017 4/27/2017 2.50 COMPZ2 WHDBOP FRZP P RU to freeze protect LRS. PT lines to 14:45 17:15 3500 psi, pump 140 bbls of diesel down IA taking returns through the tubing at 2 bpm. ICP = 500psi, FCP = 800psi. Returns observed at surface after 19 bbls diesel pumped. SIMOPS: Begin LD 64 stands 5" DP via mouse hole. 4/27/2017 4/27/2017 1.00 COMPZ2 WHDBOP FRZP P Line up tubing and IA, allow well to U- 17:15 18:15 tube. SIMOPS: LD 5" DP via mousehole. IA = 200 psi, Tubing = 200 psi 4127/2017 4/27/2017 0.75 COMPZ2 WHDBOP MPSP P PU lubricator and set'H' BPV as per 18:15 19:00 Vecto. LD lubricator. IA = 125 psi, Tubing = 125 psi 4/27/2017 4/27/2017 3.50 DEMOB MOVE PULD P LD remaining 33 stands of 5" DP via 19:00 22:30 mousehole. SIMOPS: B/D water, pits. Disconnect interconnect lines in pump and pit complexes. C/o upper rams f/ 9 5/8" U 3 1/2" x 6" VBRs. 4/27/2017 4/28/2017 1.50 DEMOB MOVE RURD P Empty freese protect returns in rock 22:30 00:00 washer. SIMOPS: L/D mousehole, lower beaver slide and and remove steam traps on sub. 4/28/2017 4/28/2017 2.00 DEMOB MOVE RURD P Blow down steam, disconnect mud 00:00 02:00 lines in sub, rig down pipe skate, disconnect electrical in all interconnects. Release rig @ 02:00 Page 50/50 Report Printed: 5/2/2017 Cement Detail Report 3R-101 String: CONDUCTOR CEMENT Job: DRILLING ORIGINAL, 3/23/2017 03:30 Cement Details Description CONDUCTOR CEMENT Cementing Start Date 12/16/2016 16:00 Cementing End Date 12/16/2016 16:30 Wellbore Name 3R-101 Comment AFC poured 5-1/2 sacks portland cement down backside to cement conductor. Ambient temperature of -10°F. Cement Stages Stage # 1 Description CONDUCTOR CEMENT Objective Top Depth (ftKB) Cement conductor in 39.0 Place Bottom Depth (ftKB) 119.0 Full Return? Vol Cement... Top Plug? Btm Plug? 777" Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (In) Comment AFC poured 5-1/2 sacks portland cement down backside to cement conductor. Ambient temperature of -10`F. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (Pas) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1l1 ReportPrinted: 5/25/2017 Cement Detail Report 3R-101 String: Surface Casing Cement Job: DRILLING ORIGINAL, 3/231201703:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 3/26/2017 16:15 3/2612017 19:45 3R-101 Comment Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug SIM PlugT Surface Casing Cement Cement Surface casing 41.6 2,254.0 No 86.0 Yes Yes O Pump Init (bbpm... O Pump Final (bbl/... O Pump Avg (bbll... P Pump Final (psi)Plug Bump (psi) RecipT Stroke pu Rotated? Pipe RPM (rpm) 4 7 7 IP 210.D 476.0 Yes 20.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drill" Out To (ftKB) Drill Out Diameter (in) Comment Pump 40.3 bbls of 8.3ppg CW100 at 6.5 bpm, 135 psi, followed by 80 We of 10.5ppg Mudpush II spacer at 5.5 bpm, 90 psi. Shut down and drop bottom plug. Pump 316.6 bbls 11.Oppg Litecrete lead cement at 6.5 bpm, ICP 200 psi, FCP 180 psi, 10% F/O, followed by 75.9 bbls 12.Oppg Deeperete tail cement at 6.5 bpm, 200 psi, 8% F/O. Observe hole suddenly get sticky, losing 40k down weight with 50 bbls of tail pumped so landed pipe for remaining part of job. Shut down and drop top plug. Line up to rig pump and displace cement at 7 bpm, ICP 166 psi, FCP 455 psi, 9% F/O. Slow down to 3 bpm, 290 psi, 5% F/O 10 bbls prior to bumping plug. Bump plug at 3090 strokes and pressure up to 800 psi. Hold for 5 minutes, bleed off and check floats - floats holding. Total of 86 bbls of cement returned to surface. Cement in place @ 19:39 hrs. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bum (ftKB) Amount (sacks) Class Volume Pumped (bbl) Pre Flush CW -100 I I 1 40.3 Yieltl (ft /sack) Mix H2O Ratio (gagsa... Free Water (%) Density (Iblgal) Plastic Viscosity (Pars) Thickening Time (hr) CmprStr 1 (psi) 8.34 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description 1 Estimated Top (ftKB) 1 Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push II 80.0 Yieltl tWisack) Mix H2O Ratio (gal/es... Free Water (%) Density (Iblgal)Plastic Viscosity (Pars) Thickening Time (hr) CmprStr t (psi) 10.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluitl Description Estimated Top (ftKB)Est Btm (ftKB) Amount(sacks) Class Volume Pumped (bbl) Lead Cement 44.0 1,730.0 932 G 317.0 Yieltl (ft/sack) Mix H2O Ratio (gallas... Free Water (%) Density (Iblgal) Plastic Viscosity (Para) Thickening Time (hr) CmprStr 1 (psi) 1.91 6.83 11.00 82.0 0.00 Additives Additive Antifoam Type ConcentrationConc Unit label D046 0.2 °kBWOC Additive Retarder Type Concentration Conc Und label D177 0.02 gal/sx Additive Type Concentration Cone Unit label Dispersant D185 0.08 gal/sx Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bbn (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,730.0 2,254.0 260 G 75.9 Yield (k'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pars) Thickening Time (hr) CmprStr 1 (psi) 1.64 5.63 12.00 115.0 0.00 Additives Additive Type Concentration one Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Cone Unit label Retarder D177 0.02 gal/sx Additive Type Concentration Cone Unit label Dispersant D230 0.1 gatlsx Page 1/1 Report Printed: 5/25/2017 Cement Detail Report 3R-101 d. I - ..- String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 3123/201703:30 Cement Details Description Cementing Skirt Date Cementing End Date Wellbore Name Intermediate Casing Cement 4/4/2017 18:00 4/4/2017 23:00 3R-101 Comment "MU hanger and landing joint / pull spiders and RIH to 9,732' MD. Reciprocate casing from 9,732'-9,724'10D conditioning mud. Stage pumps to 7 BPM. 296 GPM = 389 PSI, Up WT = 268K. DWN WT = 54K. Pumped total 22 BBls. 9.5 PPG in / 10.3 out VIS 250 H2O @ 20. Install cement hose and reciprocate from 9,732'-9,724' MD. Staging pumps up to 8 BPM . 342 GPM = 408 PSI. UP WT = 268K SWN WT = 54K. 9.6 PPG in / 9.8 out Vis 78 1-12o @ 10. Challenges working pipe back down after reciprocating this whole time. Setting down to 35k and slowly work through obstruction and land hanger on Ring. Continue to circulate Sift BPM GPM = 342 PSI=408. 13,844 strokes pumped (1398 bbls). Lost a total of 8 BBLS while RIH with 9 5/8"" casing. Pre job with rig crew and Schlumberger crews for cement program. Included Sim ops with W WT installing SS in pipe shed and loader loading DP. PT all lines to 4,500 PSI ( passed). Pump 60 BBLS 12.5 PPG mud push II @ 5 BPM. 260 PSI, 5% F/O. Drop bottom PLUG (9.34"" OD). Pump 388 BBLS 15.8 PPG Class G cement @ 5.5 BPM. 250 PSI, 7% F/O. Drop top plug (9.16"" OD). Chase with 10 BBLS fresh water @ 4 BPM , 90 PSI, 4% F/O. Change over to dg pumps to displace cement with 9.5 PPG LSND @ 8 BPM, ICP = 193 6% F/0. Slow to 7 BPM, 192 PSI 9% F/O, @ 1550 Strokes. Observe 175 PSI pressure drop @ 6512 strokes. Slow rate to 5 BPM, 823 PSI @ 6690 Strokes. Slow rate to 4 BPM , 730 PSI @ 6,785 strokes. Slow rate to 2 BPM 785 PSI @ 7,030 strokes. Bump plug at 7,171 strokes (724 bbls). FCP =839. 3% F/O. Increase psi to 1,400 PSI and hold for 5 min. CIP @2216. Bleed down to 50 PSI and prep for final casing test. Lost a total of 24 BBLS during cement job. Test 9 5/8"" casing L-80 406 hydril 5631521 mix to 3,500 PSIG and charted for 30 min. (PASSED). 10.8 BBLS to pressure up /1110.7 BBLS bled back. RD Cement hose and blow down. " Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 4,943.0 9,743.0 No Yes Cement Q Pump Init (bbl/m.. Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) RotatetlT Pipe RPM (rpm) 5 3 7 900.0 1,400.0 Tagged Depth (ftKB) Tag Method Depth Plug Dnled Out To (ftKB)Drill out Diameter (in) Comment MU hanger and landing joint/ pull spiders and RIH to 9,732' MD. Reciprocate casing from 9,732'-9,724' MD conditioning mud. Stage pumps to 7 BPM. 296 GPM = 389 PSI, Up WT = 268K. DWN WT = 54K. Pumped total 22 BBIs. 9.5 PPG in / 10.3 out VIS 250 H2O @ 20. Install cement hose and reciprocate from 9,732'-9,724' MD. Staging pumps up to 8 BPM . 342 GPM = 408 PSI. UP WT = 268K SWN WT = 54K. 9.6 PPG in / 9.8 out Vis 78 H2o @ 10. Challenges working pipe back down after reciprocating this whole time. Setting down to 35k and slowly work through obstruction and land hanger on Ring. Continue to circulate at 8 BPM GPM = 342 PSI=408. 13,844 strokes pumped (1398 bbls). Lost a total of 8 BBLS while RIH with 9 5/8" casing. Pre job with dg crew and Schlumberger crews for cement program. Included Sim ops with W WT installing SS in pipe shed and loader loading DP. PT all lines to 4,500 PSI ( passed). Pump 60 BBLS 12.5 PPG mud push II @ 5 BPM. 260 PSI, 5% F/O. Drop bottom PLUG (9.34" OD). Pump 388 BBLS 15.8 PPG Class G cement @ 5.5 BPM. 250 PSI, 7% F10. Drop top plug (9.16" OD). Chase with 10 BBLS fresh water @ 4 BPM , 90 PSI, 4% F/O. Change over to rig pumps to displace cement with 9.5 PPG LSND @ 8 BPM, ICP = 193 6% F/O. Slow to 7 BPM, 192 PSI 9% F/O, @ 1550 Strokes. Observe 175 PSI pressure drop @ 6512 strokes. Slow rate to 5 BPM , 823 PSI @ 6690 Strokes. Slow rate to 4 BPM , 730 PSI @ 6,785 strokes. Slow rate to 2 BPM 785 PSI @ 7,030 strokes. Bump plug at 7,171 strokes (724 bbls). FCP =839. 3% F/O. Increase psi to 1,400 PSI and hold for 5 min. CIP @2216. Bleed down to 50 PSI and prep for final casing test. Lost a total of 24 BBLS during cement job. Test 9 5/8" rasing L-80 40# hydril 563 / 521 mix to 3,500 PSIG and charted for 30 min. (PASSED). 10.8 BBLS to pressure up /// 10.7 BBLS bled back. RD Cement hose and blow down. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB)Est Btm (ftKB) Amount (sacka) Class Volume Pumped (bbl) MudPush II 4,137.0 4,943.0 60.0 Yield (ft /sack) Mix H2a Ratio (gausa... Free Water (%) Density (lb/ga1) Plastic Viscosity (Pa•s) Thickening Time (hr) CmprStr 1 (psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluitl Description Estimated Top (ftKB) Est Bt- (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 4,943.0 9,743.0 1,8781G' 1 388.0 Yield (ft /sack) Miz H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal)Plastic Viscosity (Pa•s) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.11 15.80 6.95 Additives Additive D046 Type ConcentrationConc Unit label Antifoam 0.2 %BWOC Additive D065 Type Concentration Conc Unit label Disspersant 0.3 %BWOC Additive D255 Type Concentration lConc Unit label Fluid Loss 0.4 %BWOC Page 1/2 Report Printed: 512512017 Cement Detail Report 3R-101 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 3/23/201703:30 Additives Additive D177 Type Retarder Concentration 0.03 Conc Unit label gal/sx Page 212 ReportPrinted: 5/25/2017 NADConversion Kuparuk River Unit Kuparuk 3R Pad 3R-101 Definitive Survey Report 05 May, 2017 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project Kuparuk River Unit TV 0 Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 Norm Reference: True Wellbore: 3R-101 Survey Calculation Method; Minimum Curvature Design: 3R-101 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States 39.10 Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) MWD+IFRAKCAZSCC Using Well Reference Point Map Zone: Alaska Zone 04 MWD+IFR-AK-CAZSC Using geodetic scale factor 4/12017 2:48:0 9,759.17 16,369.033R-101 Srvy 6-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC Well 3R-101 0.74 47.48 Well Position +NIS 0.00 usft Northing: 6,031,732.16 usft Latitude: 70° 29'52.272 N 6,031,732.83 +E/ -W 0.00 usft Easting: 520,625.98 usft Longitude: 149' 49'52.775 W Position UnoertaiMy 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usft 358.19 262.71 21371 2.03 Wellborn 3R-101 520,827.21 0.95 Magnetics Model Name Sample Date Declination Dip Angie Field Strength 356.51 307.51 C) (') (nT) 6,031,736.85 BGGM2016 4/1/2017 1772 8104 57,551 Design 3R-101 Date Azi TVD TVDSS Audit Notes: To Map Northing Map Easting DLS Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 Vertical Section: Depth From (TVD) +N/ -S +EI -W Direction 676.74 (usft) (usft) (usft( 1 C)) 2,208.44 39.10 0.00 0.00 270.00 Survey Program Date Azi TVD TVDSS From To Map Northing Map Easting DLS (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 135.69 638.81 3R-101 Srvy 1 - SUB_GYD-GC-SS (3R-1 GYD-GC-SS Gyrodata gyro single shots 3/24/2017 8:28:, 676.74 2,153.783R-101 Srvy 2- SLB _MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/24/2017 8:31:• 2,208.44 2,206.44 3R-101 Srvy 3- SLB_GYD-GC-SS (3R-1 GYD-GC-SS Gyrodata gyro single shots 325/2017 8:33:. 2,297.00 8,026.553R-101 Srvy 4-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/29/2017 8:47+ 8,102.69 9,661.163R-101 Srvy 5- SLB _MWD+GMAG(3R- MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 4/12017 2:48:0 9,759.17 16,369.033R-101 Srvy 6-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 4/92017 8:10:0 Survey MD Inc Azi TVD TVDSS +N/.R +E/ -W Map Northing Map Easting DLS vertical Section (usft) C) C) (usft) (usft) (usft) (usft) (it) (ft) CM00l (ft) Survey Teol Name 39.10 0.00 0.00 39.10 -9.90 0.00 0.00 6,031,732.16 520,625.98 0.00 0.00 UNDEFINED 135.69 0.74 51.62 135.69 86.69 0.39 0.49 6,031,732.55 520,626.47 0.77 -049 GYD-GC-SS(1) 169.59 0.74 47.48 169.58 120.58 0.67 082 6,031,732.83 520,626.80 0.16 -0.82 GYD-GC-SS(1) 262.73 1.17 358.19 262.71 21371 2.03 1.24 6,031,734.19 520,827.21 0.95 -1.24 GYD.GC-SS(1) 356.57 2.27 336.68 356.51 307.51 4.69 0.47 6,031,736.85 520,626.44 1.34 -0.47 GYD-GCSS(1) 451.76 3.38 327.54 451.58 402.58 8.79 -178 6,031,740.95 520,624.17 1.25 178 GYD-GC-SS(1) 545.32 3.75 318.73 544.96 495.96 13.42 528 6,031,745.56 520,620.66 0.71 5.28 GYD-GCSS(1) 63881 5.49 307.39 638.15 589.15 18.43 -10.85 6,031,750.56 520,615.08 2.09 10.85 GYD-GC-SS(1) 676.74 6.24 302.09 67588 626.88 20.63 -14.04 6,031,75275 520,611.88 2.44 14.04 MWD+IFR-AK-CAZ-SC(2) 770.88 7.30 300.95 769.36 720.36 26.42 -23.50 6,031,758.52 520,602.40 1.13 23.50 MWD+IFR-AK-CAZSC(2) yrzol / 213'54PM Page 2 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kupamk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101 Database: OAKEDMP2 Survey MD Inc Azi TVD TVDSS +N/S +E/ -W Map Northing Map Easting DLS Vertical (usft) (°) (% (ueft) (usft) (ush) (usft) Section (f) (ft) (0/100') (ft) Survey Tool Name 863.73 9.86 309.12 861.17 812.17 34.47 -34.73 6,031,766.53 520,591.15 3.05 34.73 MWD+IFR-AK-CAZ-SC(2) 959.68 9.96 317.32 955.69 906.69 45.76 -46.73 6,031,777.78 520,579.13 1.47 46.73 MWD+IFR-AK-CAZ-SC (2) 1,053.73 12.30 328.76 1,047.98 998.98 60.31 57.44 6,031,792.30 520,568.37 3.41 57.44 MWD+IFR-AK-CAZ-SC(2) 1,149.13 13.66 WAS 1,140.98 1,091,98 79.99 65.22 6,031,811.96 520,560.55 4.54 65.22 MWD+IFR-AK-CAZ-SC(2) 1,243.57 14.34 355.31 1,232.62 1,183.62 102.52 68.65 6,031,834.48 520,557.05 2.20 68.65 MWD+IFR-AK-CAZSC(2) 1,338.60 14.97 357.92 1,324.56 1,275.56 126.52 -70.06 6,031,858.47 520,555.58 0.96 70.06 MWD+IFR-AK-CAZSC(2) 1,433.41 15.24 359.78 1,416.09 1,367.09 151.21 -70.55 6,031,883.16 520,555.02 0.59 70.55 MWD+IFR-AK-CAZ-SC(2) 1,52763 14.50 0.11 1,507.16 1,458.16 175.39 -70.57 6,031,907.34 520,554.93 079 70.57 MWD+IFR-AK-CAZ-SC(2) 1,620.81 17.27 0.21 1,596.77 1,547.77 200.89 -70.50 6,031,932.84 520,554.93 2.97 70.50 MWD+IFR-AK-CAZSC(2) 1,716.88 16.84 1.37 1,688.62 1,639.62 229.07 -70.12 6,031,961.01 520,555.24 0.57 70.12 MWDAFR-AK-CAZ-SC(2) 1,811.40 19.06 358.74 1,778.53 1,729.53 258.19 -70.13 6,031,990.13 520,555.14 2.50 70.13 MWD+IFR-AK-CAZ-SC(2) 1,906.14 20.91 356.99 1,867.56 1,818.56 290.54 -71.36 6,032,022.47 520,553.83 2.05 71.36 MWD+IFR-AK-CAZ-SC(2) 2,000.30 24.98 355.65 1,954.26 1,90526 327.16 -73.75 6,032,059.08 520,551.33 4.35 73.75 MWD+IFR-AK-CAZ-SC(2) 2,094.43 28.81 355.00 2,038.19 1,989.19 36959 -77.23 6,032,101.50 520,547.73 4.08 77.23 MWD+IFR-AK-CAZSC(2) 2,153.78 30.11 355.47 2,08986 2,040.86 398.68 -79.66 6,032,130.57 520,545.23 2.22 7966 MWD+IFR-AK-CAZ-SC(2) 2,208.44 33.91 357.04 2,136.21 2,087.21 427.58 61.53 6,032,159.47 520,543.28 7.12 81.53 GYD-GCSS(3) 2,243.00 34.53 357.36 2,164.78 2,11578 446.99 52.48 6,032,17888 520,54227 1.88 82.48 MWD+IFR-AK-CAZ-SC(4) 13 3/8" 2,297.00 35.51 357,84 2,209.00 2,160.00 477.96 -83.77 6,032,209.84 52Q540.89 1.88 83.77 MWD+IFR-AK-CAZ-SC(4) 2,353.55 3724 358.70 2,254.53 2,205.53 511.48 54.78 6.032,243.35 520,539.79 3.19 84.78 MWD+IFR-AK-CAZSC(4) 2.448.05 41.36 358.32 2,327.65 2,278.65 571.31 -86.34 6,032,303.17 520,538.06 4.37 86.34 MWD+IFR-AK-CA7-SC(4) 2.543.56 45.79 0.39 2,396.83 2,347.83 637.11 57.04 6,032,368.96 520,537.19 4.87 8704 MWD+IFR-AK-CAZSC(4) 2,637.75 49.08 0.59 2,460.53 2,411.53 70647 66.44 6,032,438.31 520,537.59 3.50 86.44 MWD+IFR-AK-CAZ-SC(4) 2,732.27 54.02 1.62 2,519.29 2,470.29 780.45 54.99 6,032,51229 520,538.83 5.30 84.99 MWD+IFR-AK-CAZ-SC(4) 2,826.93 58.92 0.47 2,571.56 2,522.56 85932 -83.57 6,032,591.16 520,540.03 5.27 83.57 MWD+IFR-AK-CAZ-SC(4) 2,919.52 63.48 0.11 2,616.16 2,567.16 940.43 53.17 6,032,67227 520,540.21 4.94 83.17 MWD+IFR-AK-CAZSC(4) 3,015.11 67.32 358.34 2,655.94 2,606.94 1,027.32 59.36 6,032,759.14 52Q538.77 4.36 84.35 MWD+IFR-AK-CAZSC(4) 3,110.07 71.37 35759 2,689.43 2,640.43 1,116.10 -8T53 6,032,847.90 520,535.37 4.33 8753 MWD+IFR-AK-CAZ-SC(4) 3,204.89 75.87 355.15 2,716.17 2,667.17 1,206.86 -93.31 6,032,938.63 520,529.33 5.35 93.31 MWD+1FR-AK-CAZSC(4) 3,300.84 80.10 354.91 2,736.14 2,687.14 1,300.33 -101.44 6,033,032.07 520,520.95 4.42 101.44 MWD+IFR-AK-CAZ-SC(4) 3,395.53 80.99 355.26 2,751.69 2,702.69 1,393.39 -109.44 6,033,125.10 520,51269 1.01 109.44 MWD+IFR-AK-CAZ-SC(4) 3,490.19 81.39 356.24 2,786.19 2,717.19 1,486.67 -116.37 6,033,218.36 520,505.50 1.11 116.37 MWD+IFR-AK-CAZ-SC(4) 3,582.99 81.43 356.62 2,780.05 2,731,05 1,578.25 -122.08 6,033,309.91 520,499.53 0.41 122.06 MWD+IFR-AK-CAZSC(4) 3,679.39 81.52 355.89 2,794.34 2,74534 1,673.38 -128.31 6,033,405.02 520,493.04 0.75 12831 MM+IFR-AK-CAZ-SC(4) 3,774.67 81.52 35432 2,808.39 2,759.39 1,767.28 -136.35 6,033,498.88 520,484.74 1.63 136.35 MWD+IFR-AK-CAZSC(4) 3,869.26 81.14 354.65 2,82265 2,773.65 1,860.35 -145.34 6,033,591.92 520,475.49 0.53 145.34 MWD+IFR-AK-CAZ-SC(4) 3,963.62 81.59 354.57 2,836.82 2,787.82 1,953.23 -154.10 6,033,684.76 520,466.47 0.48 154.10 MWD+IFR-AK-CAZSC(4) 4,058.18 81.39 354.86 2,850.81 2,801.81 2,046.35 -162.72 6,033,777.85 520,457.60 0.37 162.72 MWD+IFR-AK-CA7-SC(4) 4,153.32 81.31 355.47 2,865.12 2,816.12 2,140.07 -170.64 6,033,871.54 520,44941 0.64 170.64 MWD+IFR-AK-CAZSC(4) 4,247.21 81.19 356.30 2,879.41 2,830.41 2,232.63 -177.30 6,033,964.07 520,442.50 0.88 177.30 MWD+IFR-AK-CA7-SC(4) 532017 2.13:54PM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 3R-101 Project Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Well: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) (1 3R-101 North Reference: True Wellbore: 3R-101 Survey Calculation Method: Minimum Curvature Dears" 3R-101 Database: OAKEDMP2 Survey MD Ine ANTVD TVDSS •N!-3 +Ej-W Map Northing Map Easting Vertical (usft) (1 (1 (usft) (usft) (usft) (u�) DLS Section (ft) (ft) (-7100') (ft) Survey Tool Name 4,341.81 81.29 35742 2,893.81 2,844.81 2,325,99 -182.42 6,034,057.40 520,437.12 1.17 18242 MWD+IFR-AK-CAZ-SC(4) 4,436.87 81.31 358.76 2,908.19 2,859.19 2,419.90 -185.56 6,034,15129 520,433.73 1.39 185.56 MWD+IFR-AKCAZSC(4) 4,532.86 81.46 359.12 2,922.57 2,873.57 2,514.79 -187.31 6,034,246.17 520,431.71 0.40 187.31 MWD+IFR-AK-CAZ-SC(4) 4,627.23 81.49 358.61 2,936.56 2,887.56 2,608.10 489.16 6,034,339.46 520429.60 0.54 189.16 MWD+IFR-AK-CAZSC (4) 4,72252 81.62 358.05 2,950.56 2,901.56 2,702.31 -191.91 6,034,433.66 520,426.59 0.60 191.91 MWD+IFR-AK-CAZSC (4) 4,816.15 81.17 357,64 2,964.57 2,915.57 2,794.82 -195.39 6,034,526.15 520,422.86 0.65 195.39 MWD+IFR-AKCU-SC(4) 4,910.05 81.65 357.59 2,978.59 2,929.59 2,887.59 -199.25 6,030618.90 520,418.74 0.51 199.25 MWD+IFR-AK-CAZ-SC(4) 5,005.50 81.45 357.34 2,992.62 2,943.62 2,981.91 -203.43 6,034,713.20 520,414.30 0.33 20343 MWD+IFR-AK-CA7-SC(4) 5,099.31 80.43 356.19 3,007,39 2,958.39 3,074.40 -20865 6,034,805.66 520,408.82 1.63 208.65 MWD+IFR-AK-CAZSC(4) 5,194.23 79.74 356.96 3,023.73 2,974.73 3,16773 -214.24 6,034,898.97 520,402.97 1.08 214.24 MWD+IFR-AK-CAZ-SC(4) 5,288.73 80.17 357.41 3,040.22 2,991.22 3,260.67 -218.81 6,03,991.89 520,398.14 065 218.81 MWD+IFR-AK-CAZSC(4) 5,384.03 80.16 355.86 3,055.49 3,007.49 3,354.41 -224.32 6,035,085.60 520,392.37 1,60 224.32 MW/D+IFR-AKCAZSC (4) 5,478.50 80.16 355.01 3,072.64 3,023.64 3,447.19 -231.73 6,035,178.35 520,384.71 0.89 231.73 MMD+IFR-AK-CAZ-SC(4) 5,574.37 79.88 352.33 3,089.26 3,040.26 3,541.03 -242.14 6,035,272.15 520,374.04 2.77 242.14 MWD+IFR-AK-CAZ-SC(4) 5,668.19 80.05 35229 3,105.61 3,056,61 3,632.58 -254.50 6,035,363.66 520,361.43 0.19 254.50 MWD+IFR-AKCAZ-SC(4) 5,762.98 79.70 350.63 3,122.27 3,073.27 3,724,85 -268.36 6,035,455.89 520,347.32 1.76 268.36 MWD+IFR-AK-CAZ-SC(4) 5,858.90 79.93 350.94 3,139.23 3,090.23 3,81804 -283.48 6,035,54902 520,331.94 0.40 283.48 MWD+IFR-AK-CAZ-SC(4) 5,953.58 79.83 352.59 3,155.87 3,105.87 3,910.29 -296.83 6,035,641.22 520,318.34 1.72 296.83 MWD+IFR-AKCAZSC(4) 8,048.38 79.78 353.57 3,172,65 3,123.65 4,002.91 -30607 6,035,733.80 520,306.84 1.02 308.07 MWD+IFR-AK-CAZ-SC(4) 6,142.31 8065 351.82 3,188.61 3,139.61 4,094.72 -319.84 6,035,82557 520,294.81 2.06 319.84 MWD+IFR-AK-CAZ-SC(4) 6,237.62 80.49 349.05 3,204.23 3,155.23 4,187.42 -335.45 6,035,918.22 520,278.95 2.86 335.45 MWD+IFR-AKCAZSC(4) 6,332.89 80.84 348.35 3,219.69 3,170.69 4,27981 -353.86 6,036,010.35 520,260.28 0.82 353.86 MWD+IFR-AKCAZSC(4) 6,427.09 80.50 345.89 3,234.96 3,185.96 4,370.22 -374.58 6,036,100.89 520,239.31 2.60 374.58 MMD+IFR-AK-CAZ-SC(4) 6,521.45 80.15 344.77 3,250.82 3,201.82 4,460.20 -398.14 6,036,19060 520,215.51 1.23 398.14 MWD+IFR-AKCAZ-SC(4) 6,615.67 79.69 343.22 3,267.31 3,218.31 4,549.37 -423.71 6,036,279.88 520,189.69 1.69 423.71 MWD+IFR-AK-CAZSC(4) 6,710.05 80.09 339.00 3,283.88 3,234.88 4,637.26 -453.79 6,038,367.68 52Q 159.37 442 453.79 MMD+IFR-AK-CAZ-SC(4) 6,802.95 79.71 338.08 3,300.18 3,251.18 4,722.38 -487.25 6,036,45210 520,125.68 1.06 487.25 MWD+IFR-AK-CAZ-se(4) 6,898.97 7947 335.69 3,317.53 3,268.53 4,809.23 -524.32 6,036,53944 520,088.37 2.46 524.32 MWD+IFR-AKCA2SC(4) 6,993.80 7857 334.02 3,335.59 3,286.59 4,893.50 563.87 6,036,623.59 520,048.59 1.97 563.87 MWD+IFR-AK-CAZ-SC(4) 7,088.66 77.01 334.51 3,355.65 3,306.65 4,977.01 504.13 6,036,708.98 520,008.10 1.72 604.13 MWD+IFR-AKCAZSC(4) 7,183.15 78.05 332.54 3,378.06 3,327.06 5,059.59 545.26 6,036,789.44 519,96615 2.31 64526 MWD+IFR-AK-CAU-SC(4) 7.277.04 7865 332.66 3,395.02 3,346.02 5,141.23 587.58 6,038,870.95 519,924.21 0.65 687.58 MWD+IFR-AKCAZ-SC(4) 7,370.87 79.07 330.57 3,413.15 3,364.15 5,222.22 -731.34 6,036,951.81 519,880.22 2.23 731.34 MW/D+IFR-AK-CAZ-SC (4) 7,466.77 81.05 330.18 3,429.70 3,380.70 5,304.33 -77803 6,037,03318 519,633.31 2.10 778.03 MWD+IFR-AKCAZ-SC(4) 7,561,29 82.67 327,76 3,443.09 3,394.09 5,384.49 -826.27 6,037,113.80 519,784.86 3.06 826.27 MWD+IFR-AK-CAZ-SC (4) 7,654.42 83.63 323.12 3,454.20 3,40520 5,460.62 578.71 6,037,189.77 519,732.21 5.05 878.71 MWD+IFR-AKCAZ-SC(4) 7,749.17 83.29 318.54 3,465-00 3,416.00 5,533.58 -938.15 6,037,262.56 519,672.58 4.82 938.15 MWD+IFR-AKCAZSC(4) 7,843.93 83.31 316.31 3,476.05 3,427.05 5,602.88 -1,001.81 6,037,331.68 519,608.72 2.34 1.01.81 MWD+IFR-AK-CAZSC (4) 7,937.29 83.12 313.16 3,487.09 3,438.09 5,668.12 -1,067.66 6,037,396.73 519,542.70 3.36 1,067.66 MWD+IFR-AKCAZ-SC (4) 7.980.65 82.66 310.87 3,492.45 3,44345 5,695.91 -1,099.63 6,037,425.43 519,510.66 5.35 1,099.63 MWD+IFR-AKCAZ-SC(4) 5/52017 2:13:54PM Page 4 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project Kuparuk River Unit TVD Reference: 3R-101 actual Q 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142 ) Well: 3R-101 Norm Reference: True Wellbore: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101 Database: OAKEDMP2 Survey MD Inc Azl TVD TVDSS +N/ -S +E/•W Map Northing Map Eastlng Vertical (usft) (°) (°) (us") (usft) With) (um) MLS Section (@) (>U (°M00') (ft) Survey Tool Name 8,026.55 82.82 310.75 3,498.26 3,499.26 5,728.67 -1,134.09 6,037,455.09 519,476.12 0.43 1,134.09 MWD-IFR-AK-CAZSC(4) 8,102.69 84.02 308.30 3,506.98 3,457.98 5,774.60 -1,19243 6,037,503.06 519,417.65 3.56 1,19243 MWD+IFR-AI(-SC 8,196.27 83.30 307.17 3,517.32 3,468.32 5,831.72 -1,265.98 6,037,559.77 519,343.95 1.43 1,265.98 MWD+IFR-AK-CAZ-SC(5) 8,290.64 80.09 306.79 3,530.94 3,481.94 5,887.89 -1,340.57 6,D37,615.72 519,269.22 3.42 1,340.57 MWD+IFR-AK-CAZ-SC(5) 8,385.81 78.59 302.73 3,548.56 3,499.56 5,941,21 -1,417.38 6,037,668.82 519,192.26 4.48 1,417.38 MWD+IFR-AI(-CAZSC(5) 8,450.48 82.05 284.76 3,564.50 3,515.50 5,986.01 -1,499.13 6,037,713.39 519,110.39 9.07 1,499.13 MWD+IFR-AK-CAZ-SC 8,575.24 8675 290.20 3,573.75 3,524.75 6,022.04 -1,58623 6,037,749.17 519,023.20 6.89 1,586.23 MWD+IFR-AK-CAZ-SC 8.669.02 86.22 286.91 3,579.50 3,530.50 6,051.82 -1,674.96 6,037,778.71 518,934.40 3.55 1,674.96 MWD+IFR-AK-SC 8,763.77 8934 281.26 3,583.17 3,534.17 6,074.84 -1,766.74 6,037,801.47 518,842.56 6.81 1,766.74 MWD+IFR-AK-CAZ-SC 8,859.11 89.82 275.16 3,583.87 3,534.87 6,088.45 -1,851.06 6,037,814.82 518,748.22 842 1,861.06 MWD+IFR-AK-CAZ-SC(5) 8,954.08 89.52 271.80 3,584.42 3,535.42 6,094.21 -1,955.84 6,037,820.32 518,653.43 3.55 1,955.84 MWD+IFR-AK-CAZSC(5) 9,047.67 85.64 271.51 3,587.55 3,538.55 6,096.92 -2,049.33 6,037,822.76 518,559.95 3.09 2,049.33 MWD+IFR-AK-CAZSC(5) 9,141.11 87.22 269.20 3,592.56 3,543.56 6,097.49 -2,142.63 6,037,823.06 518,466.66 2.55 2,142.63 MWD+IFR-AK-CAZ-SC(5) 9,234.58 88.14 268.86 3,596.34 3,547.34 6,095.91 -2,236.00 6,037,82124 518,373,29 1.05 2,236.00 MWD+IFR-AK-CAZSC(5) 9,32748 88.28 269.08 3,599.24 3,550.24 6,094.24 -2,328.84 6,037,81931 518,280.47 0.28 2,328.84 MWD+IFR-AK-CAZSC(5) 9,420.78 85.20 269.92 3,604.55 3,555.55 6,093.43 -2,421.98 6,037,818.24 518,187.35 3.42 2,421.98 MWD+IFR-AK-CAZ-SC(5) 9,516.25 84.52 269.32 3,613.10 3,584.10 6,092.80 -2,517.06 6,037,817.35 518,092.27 0.95 2,517.06 MWD+IFR-AK-CAZ-SC(5) 9,60889 84.05 270.04 3,622.24 3,573.24 6,092.29 -2,60844 6,037,816.58 518,000.90 D.93 2,606.44 MWD+IFR-AKCAZSC(5) 9,661.16 83.25 270.35 3,628.10 3,579.10 6,092.47 -2,661.19 6,037,816.61 517,948.16 1.63 2,661.19 MWD+IFR-AK-CAZSC(5) 9,732.00 87.88 269.09 3,633.58 3,584.58 6,092.12 -2,731.79 6,037,816.07 517,877.57 6.77 2,731.79 MWD+IFR-AK-CAZ-SC(6) 9 618^ 9,759.17 89.65 268.61 3,634.17 3,585.17 6,091,58 -2,758.95 6,037,815.45 517,85041 6.77 2,758.95 1OWD+IFR-AKCAZSC(6) 9,833.36 94.14 269.20 3,631.72 3,582.72 6,090.16 -2,833.07 6,037,81383 517,776.31 6.10 2,833.07 MWD+IFR-AK-CAZSC(6) 9,866.63 94.14 269.73 3,629.31 3,580.31 6,089.85 -2,866.25 6,037,81343 517,743.13 1.59 2,866.25 MWD•IFR-AK-CAZ-SC(6) 9,897.97 92.76 270.04 3,627.43 3,578.43 6,089.79 -2,897.53 6,037,813.28 517,711.85 4.51 2,897.53 MWD+IFR-AKCAZSC(6) 9,92822 92.08 270.31 3,626.15 3,577.15 6,089.88 -2,927.75 6,037,81329 517,681.63 2.42 2,927.75 MWD+11FR-AK-CAZ-SC(6) 10,023.41 92.76 26953 3,622.13 3,573.13 6,099.75 5,022,86 6,037,812.89 517,550.54 1.09 3,022.86 MWD+IFR-AKCAZSC(6) 10,117.85 93.50 270.13 3,616.73 3,567.73 6,089.47 5,117.14 6,037,812.35 517,492.27 1.27 3,117.14 MWD+IFR-AK-CAZ-SC(6) 1Q21279 93.29 270.25 3,610.86 3,561.66 6,08978 5,211.90 6,037,812.40 517,397.52 0.55 3,211.90 MWD+IFR-AK-CAZ-SC(6) 10,307.57 93.79 269.90 3,605.01 3,556.01 6,089.90 5,306.50 6,037,812.26 517,302.93 0.64 3,306.50 MWD+IFR-AK-CAZSC(6) 10,401.81 91,64 269.15 3,600.54 3,551.54 6,089.12 5,400.62 6,037,811.22 517,208.81 242 3,400.82 MWD+IFR-AK-CAZSC(6) 10,496.69 91.51 270.21 3,597.93 3,548.93 6,088.59 -3,49546 6,037,810.42 517,113.98 1.13 3,495.48 MWD+IFR-AKCAZ-SC(6) 10,590.58 92.80 26942 3,594.40 3,545.40 6,088.29 -3,58928 6,037,509.50 517,020.17 161 3,589.28 MWD+IFR-AK-CAZ-SC(6) 16,685.98 92.53 268.72 3,589.97 3,540.97 6,086.74 -3,684.57 6,037,808.05 516,924.91 079 3,684.57 MWD+IFR-AKCAZSC(6) 10,750.52 89.80 267.93 3,588.05 3,539.05 6,083.98 5,779.04 6,037,805.03 516,830.45 3.01 3,779.04 MWD+IFR-AK-CAZ-SC(6) 10,875.11 89.74 266.77 3,588.43 3,539.43 6,079.61 5,873.52 6,037,800.39 516,735.99 1.23 3,873.52 MWD+IFR-AK-CAZ-SC(6) 10,970.04 8949 265.88 3,589.06 3,54086 6,074.35 5,968,30 6,037,794.87 516,641.23 0.29 3,968.30 MWD+IFR-AK-CAZSC(6) 11,064.25 90.36 266.63 3,589.19 3,640.19 6,069.02 4,062.35 6,037,789.28 516,547,20 0.96 4,062.36 MWD+IFR-AK-CAZ-SC(6) 11,159.90 90.13 267.31 3,588.78 3,539.78 6,063.96 4,15288 6,037,783.96 516,451.71 0.75 4,157.88 MWD+IFR-AK-CAZ-SC(6) 11,254.04 88.93 268.33 3,589.55 3,540.55 6,060.38 4,251.94 6,037,780.12 516,357.66 1.67 4,251.94 MWD+IFR-AKCAZSC(6) SWO17 2.13:54PM Page 5 COMPASS 5000.1 BuW 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usit (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual 0 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101 Database: OAKEDMP2 5/64017 2:13:5417M Page 6 COMPASS 5000.1 Build 74 Inc Azi TVD TVDSS +WS +E/ Map Vertical FSumeyMap 1°) 0 (usft) (usft) (heft) -W (usft) Northing Easting DLS Section (ft) (ft) (°/1001 (ft) Survey Tool Name87.87 267.89 3,592.20 3,54320 6,057.25 4,346.80 6,037,776.72 516,262.82 1.21 4,346.80 MWD+IFR-AK-CAZSC(6) 8868 266.91 3,595.03 3,54603 6,052.99 4,440.64 6,037,772.20 516,169.00 1.35 4,440.64 MWD+IFR-AK-CAZ-SC(6) ,.89.12 266.46 3,596.84 3,547.84 6,047.54 4,534.67 6,037,766.50 516,07500 0.67 4,534.67 MWD+IFR-AK-CAZ-SC(6) 11,630.87 91.76 266.29 3,596.12 3,547.12 6,041.62 4,628.17 6,037,760.31 515,981.53 2.82 4,628.17 MWD+IFR-AK-CAZ-SC(6) 11,726.12 93.05 264.57 3,592.12 3,543.12 6,034.04 4.723.03 6,037,752.47 515,886.70 226 4,723.03 MWD-IFR-AK-;AZ-SC(6) 11,820.25 91.43 265.91 3,588.44 3,539.44 6,026.23 4,816.75 6,037,744.41 515,793.00 2.23 4,816.75 MWD+IFR-AK-CAZ-SC(6) 11,915.43 89.63 266.37 3,587.56 3,538.56 6,019.83 -0,911.71 6,037,737.74 51508.07 1.95 k911.71 MWD+IFR-AK-CAZSC(6) 12,010.04 89.02 267.30 3,588.68 3,539.68 6,014.60 5,006.17 6,037,73225 515,603.64 1.18 5,006.17 MWD+IFR-AK-CAZSC(6) 12,105.17 89.89 26821 3,589.58 3,540.58 6,010.88 -5,101.22 6,037,728.26 515,508.61 1.32 5,10122 MWD+IFR-AK-CAZ-SC(6) 12,198.99 9023 269.01 3,589.48 3,540.48 6,006.60 5,195.01 6,037,725.73 515,414.83 0.93 5,195.01 MWD+IFR-AK-CAZSC(6) 12,293.90 90.36 269.37 3,589.00 3,540.00 6,007.26 -5,289.91 6,037,724.12 515,319.95 0.40 5,289.91 MWD+IFR-AK-CAZ-SC(6) 12,388.39 90.87 269.16 3,587.98 3,536.98 6,006.05 -5,384.39 6,037,72265 515,22549 0.58 5,384.39 MWD+IFR-AK-CAZSC(6) 12,482.54 90.29 27149 3,587.03 3,538.03 6,006.58 5,478.52 6,037,722.92 515,131.36 2.55 5,478.52 MWD+IFR-AK-CAZSC(6) 12,577.56 90.38 270.88 3,586.47 3,537.47 6,008.55 5,573.52 6,037,724.62 515,036.36 0.65 5,573.52 MWD+IFR-AK-CA7-SC(6) 12,672.32 89.54 270.66 3,586,54 3,537.54 6,009.82 -5,658.27 6,037,725.63 514,941.62 0.92 5,66827 MWD+IFR-AK-CAZSC(6) 12,766.67 88.68 269.52 3,588.00 3,539.00 6,009.97 5,762.61 6,037,725.52 514,847.29 1.51 5,762.61 MWD+IFR-AK-CAZ-SC(6) 12,851.96 89.29 269.09 3,589.69 3,540.69 6,008.81 5,857.87 6,037,724.10 514,752.04 0.78 5,857.87 MWO+IFR-AK-CAZ-SC(6) 12,956.58 89.37 267.85 3,590.80 3,541.80 6,006.29 -5,95245 6,037,72731 514,657.48 1.31 5,952.45 MWD+IFR-AK-CAZSC(6) 13,051.01 89.39 267.13 3,591,82 3,542.82 6,002.15 6,046.79 6,037,716.91 514,563.17 0.76 6046.79 MWD+IFR-AK-CAZ-SC(6) 13,145.43 89.62 268.35 3,59264 3,543.64 5,996.78 6,141.05 6,037,711.28 514,468.93 0.86 6,141.05 MWD+IFR-AK-CAZSC(6) 13,239.35 89.78 267.20 3,593.13 3,544.13 5,991.50 6,234.82 6,037,705.74 514,375.18 0.92 6,234.82 MWD+IFR-AK-CAZ-SC(6) 13,334.20 90.50 267,64 3,592.90 3,543.90 5,987.23 6,329.57 6,037,701.21 514,280.45 0.89 6,329.57 MWD+IFR-AK-CAZSC(6) 13,428.00 90.15 26686 3,592.36 3,543.35 5,984.37 6,423.32 6,037,698.08 514,186.72 1.35 6,423.32 MWD+IFR-AK-CAZSC(6) 13,523.58 90.56 269.81 3,591.77 3,542.77 5,983.26 5,518.89 6,037,696.71 514,091.16 1.08 6,518.89 MWD+IFR-AK-CAZSC(6) 13,617.44 91.34 270.31 3,590.22 3,541.22 5,983.35 6,61214 6,037,696.55 513,997.32 0.99 6,612.74 MWD+IFR-AK-CAZ-SC(6) 13,711.39 91.76 270,50 3,587.67 3,538.67 5,984.02 6,706.65 6,037,696.95 513,903.42 0.49 6,706.65 MWD+IFR-AK-CAZ-SC(6) 13,806.55 91.01 27008 3,585.37 3,536.37 5,984.50 6,801]8 6,037,697.17 513,808.30 0.90 6,801.78 MWD+IFR-AK-CAZ-SC(6) 13,90228 90.69 268.97 3,583.95 3,534.95 5,983.71 $897.50 6,037,696.11 513,712.59 1.21 6,897.50 MWD+IFR-AK-CA7-SC(6) 13,997.29 91,04 269.35 3,582.52 3,533.52 5,982.31 6,992,49 6,037,694.45 513,617.62 0.54 6,992.49 MWD+IFR-AK-CAZ-SC(6) 14,091.98 90.45 269.72 3,58129 3,53229 5,981.54 -7,087.16 6,037,693.42 513,522.95 0.74 7,087.16 MWD+IFR-AK-CAZSC(6) 14,186.89 89.93 269.32 3,550.97 3,531.97 5,980.75 -7,182.07 6,037,692.36 513,428.06 0.69 7,182.07 MWD+IFR-AK-CAZ-SC(6) 14,281.03 89.93 268.32 3,581.09 3,532.09 5,978.81 -7,276.19 6,037,690.16 513,333.95 1.06 7,276.19 MWD+IFR-AK-CAZ-SC(6) 14,37564 90.47 268.91 3,580.76 3,531.76 5,976.52 -7,370.77 6,037,687.61 513,239.39 0.85 7,37077 MWD+IFR-AK-CAZSC(6) 14,470.32 90.19 26712 3,583.21 3,531.21 5,973.74 -7,46540 6,037,684.57 513,144.77 129 7,465.40 MWD+IFR-AK-CAZ-SC(6) 14,564.91 90.33 267.19 3,579.78 3,530.78 5,969.54 -7,559.90 6,037,650.11 513,050.30 0.58 7,559.90 MWD+IFR-AK-CAZSC(6) 14,659.01 90.98 267.33 3,578.71 3,529.71 5,965.04 -7,653.89 6,037,675.35 512,956.33 0.71 7,653.89 MWD+IFR-AK-CAZ-SC(6) 14,753.97 90.95 267.32 3,577.11 3,528.11 5,960.61 -7,748.73 6,037,670.65 512,861.51 0.03 7,748.73 MWD+IFR-AK-CAZSC(6) 14,848.83 90.44 265.64 3,575.96 3,526.96 5,955.53 -7,843.44 6,037,665.31 512,766.82 0.98 7,843.44 MWD+IFR-AK-CAZSC(6) 14,943.45 90.36 267.19 3,575.30 3,526.30 5,950.36 -7,937.92 6,037,659.88 512,672.37 0.69 7,937.92 MWD+IFR-AK-CAZ-SC(6) 15,038.10 90.37 268.50 3,574.69 3,525.69 5,946.80 -8,032.50 6,037,656.05 512,577.81 1.38 8,032.50 MWD+IFR-AK-CAZ-SC(6) 5/64017 2:13:5417M Page 6 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Weil: 3R-101 North Reference: True Wellbore: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101 Database: OAKEDMP2 Survey E,] Surface Coordinates O Declination & Convergence CI GRS Survey Corrections Survey Tool Codes SLB DE Brandon Temple Client Representative: 0tdlmy WW IN Ben ToMan Ben Tolman t&j TOS��` °°2017g�105 aero Date: 5/812017 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E1 -W Northing Easting OLS section (usft) P) (°) (usft) (usft) (usft) (usft) (ft) (ft) (1/1001) (ft) Sumay Tool Name 15,131.86 90.37 268.67 3,574.09 3,525.09 5,944.65 5,126.23 6,037,653.64 512,484.09 0.39 8,126.23 MWD+IFR-AK-CAZSC(6) 15,226.78 89.93 269.42 3,573.64 3,524.80 5,943.23 -8,221.14 6,037,651.96 512,389.20 0.74 8,221.14 MWD+1FR-AK-CAZSC(6) 15,321.30 89.75 269.65 3,574.10 3,525.10 5,942.46 5,315.66 6,037,650.93 512,294.69 0.31 8,315.66 MWD+IFR-AK-CAZ-SC (6) 15,414.45 90.07 270.01 3,574.25 3,525.25 5,942.19 5,408.81 6,037,650.40 512,201.55 0.52 8,406.81 MWD+IFR-AK-CAZSC(6) 15,507.31 93.64 270.12 3,571.25 3,522.25 5,942.29 5,501.60 6,037,650.25 512,108.77 3.85 8,501.60 MWD+IFR-AK-CAZ-SC(6) 15,600.28 93.65 271.36 3,565.34 3,516.34 5,943.49 5,594.35 6,037,651.19 512,016.02 1.33 8,594.36 MWD+IFR-AK-CAZSC(6) 15,693.42 92.61 270.85 3,560.25 3,511.25 5,945.28 5,687.36 6,037,652.72 511,923.02 1.24 8,687.35 MWD+IFR-AK4;A7SC(6) 15,787.08 92.32 269.46 3,556.22 3,507.22 5,945.54 -8,780.93 6,037,652.72 511,829.46 1.51 8,780.93 MWD+IFR-AK-CA7-SC(6) 15,880.15 91.54 268.90 3,553.09 3,504.09 5,944.20 5,873.93 6,037,651.13 511,736.47 1.03 8,873.93 MWD+IFR-AK-CAZSC(6) 15,966.00 90.67 268.96 3,551.43 3,502.43 5,942.61 5,959.75 6,037,649.29 511,650.66 1.01 8,959.75 MWD+IFR-AK-CAZ-SC(6) 4.1/2" 15,973.38 90.60 268.97 3,551.35 3,502.35 5,942.47 5,967.11 6,037,649.14 511,643.31 1.01 8,967.11 MWD+IFR-AK-CAZSC(6) 16,067.10 91.94 268.09 3,549.27 3,500.27 5,940.07 -9,06).79 6,037,646.47 $11,549.64 1.71 9,050.79 MWD+IFR-AK-CAZSC(6) 16,160.48 94.61 268.39 3,543.93 3,494.93 5,937.21 5,153.97 6,037,643.35 511,456.48 2.88 9,153.97 MWD+IFR-AK-CAZSC(6) 16,253.74 96.61 269.15 3,534.82 3,485.82 5,935.21 -9,246.76 6,037,641.10 511,363.71 2.29 9,246.76 MWO+IFR-AK-CAZSC(6) 16,346.30 98.19 270.30 3,522.90 3,473.90 5,934.77 -9,338.54 6,037,640.40 511,271.94 2.11 9,338.54 MWD+IFR-AK-CAZ-SC(6) 16,369.03 97.80 270.86 3,519.74 3,470.74 5,935.00 -9,361.05 6,037,640.57 511,249.43 2.98 9,361.05 MWD+IFR-AK-CAZSC(6) 16,433.00 97.80 270.86 3,511.05 3,462.05 5,935.95 -9,424.42 6,037,641.34 511,186.07 0.00 9,424.42 PROJECTED to To Final Definitive Survey 'verified and Signed -&1 All targets and/or we11 position objectives have been achieved. L] Yes [] No I have checked to the best of my ability that the following data is correct- orrectO E,] Surface Coordinates O Declination & Convergence CI GRS Survey Corrections Survey Tool Codes SLB DE Brandon Temple Client Representative: 0tdlmy WW IN Ben ToMan Ben Tolman t&j TOS��` °°2017g�105 aero Date: 5/812017 &12017 2.13:54PM Page 7 COMPASS 5000.1 Build 74 Loepp, Victoria T (DOA) From: Sullivan, Michael <Michael.Sullivan@conocophillips.com> Sent: Wednesday, May 17, 2017 10:53 AM To: Regg, James B (DOA); Loepp, Victoria T (DOA) Cc: CPF3 Prod Engrs; Pessetto, Scott T; Driscoll, Michael D Subject: RE: KRU 3R-102i(PTD 216-157) Request for Permission to resume manned production Follow Up Flag: Follow up Flag Status: Completed Jim, I am told the surface safety systems were tested and passed all tests Michael Sullivan Viscous Petroleum Engineer ConocoPhillips Alaska Office: 907-263-4123 Cell: 907-231-9953 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, May 17, 2017 10:51 AM To: Sullivan, Michael <Michael.Sullivan@conocophillips.com>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: CPF3 Prod Engrs <n1223@conocophillips.com>; Pessetto, Scott T <Scott.T.Pessetto@conocophillips.com>; Driscoll, Michael D <Michael.D.Driscoll@conocophillips.com> Subject: [EXTERNAL]RE: KRU 3R-102i(PTD 216-157) Request for Permission to resume manned production Was the entire SVS tested or just the Kvalve? Jim Regg Supervisor, Inspections AOGCC 333 W.7 1h 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.reeg@alaska gov. From: Sullivan, Michael [ma iIto: Michael Sullivan@conocophillips com] Sent: Wednesday, May 17, 2017 10:45 AM To: Regg, James B (DOA) <iim.rggg@alaska.gov>; Loepp, Victoria T (DOA) <victoria.loepp@alaska gov> Cc: CPF3 Prod Engrs <n1223@conocophillips com>; Pessetto, Scott <Scott.T Pessetto@conocophillips com>, Driscoll, Michael D <Michael D.Driscoll@conocophillips com> Subject: KRU 3R-102i(PTD 216-157) Request for Permission to resume manned production Importance: High Victoria/Jim, 311-102 failed a state witnessed test of the type K SSSV this morning. I am told the surface safety system passed its test. We had chosen to install and test a type K valve because it appeared the well would fail a no -flow test. We would like to return the well to "24 hour manned" production until the end of our scheduled 30 day test period. We will be pursuing the installation of another type K valve, and if we are successful in installing another K valve before the end of the test period we will request another state witnessed test. Because the well now has a failed SSSV, we want to specifically confirm that it is acceptable to the AOGCC to return the well to production under manned operation. The well is currently shut in and will not be returned to manned production until we receive a response from you. Thanks in advance, Michael Sullivan Viscous Petroleum Engineer ConocoPhillips Alaska Office: 907-263-4123 Cell: 907-231-9953 From: Regg, James B (DOA) [mailto:iim.reee@alaska gov] Sent: Wednesday, May 03, 2017 9:09 AM To: Loepp, Victoria T (DOA) <victoria.loeop alaska aov>; NSK Prod Engr Specialist <n1139@conocoPhiIIiPs com> Subject: [EXTERNAL]RE: KRU 3R-102i(PTD 216-157) SSSV Requirement during pre -production This is predicated on a passing performance test of the LPS and SSV per regulation for a new well — refer to 20 AAC 25.265(h)(4). From: Loepp, Victoria T (DOA) Sent: Wednesday, May 3, 2017 8:36 AM To: NSK Prod Engr Specialist <n1139@conocoohillios com> Cc: Regg, James B (DOA) <jim.regg@alaska.eov> Subject: RE: KRU 3R-102i(PTD 216-157) SSSV Requirement during pre -production Darrell, The No Flow Test procedure outlined in your attached document is consistent with Guidance Bulletin 10-004 and is approved. The well may be unmanned for the 14 days after the well is put into service while conducting a NFT and/or installing a K valve. After 14 days, the well must be manned if the well is capable of unassisted flow and the SSSV is not operable. 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 LoeooCdalaskagov 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 Loeoo@alaska gov From: NSK Prod Engr Specialist [mailto:n1139CcDconocophillips comj Sent: Tuesday, May 02, 2017 6:08 PM To: Loepp, Victoria T (DOA) <victoria.loepp(@alaska 9ov>; Regg, James B (DOA) <jim.regg@alaska.gov> Cc: Coberly, Jonathan <lonathan.Coberly conocophillips.com>; Driscoll, Michael D <Michael. D.Driscoll@conocophillips com>; NSK POP Lead <n2490@conocophill ips com>; Sullivan, Michael <Michael.Sullivan(aconocophillips com>; CPF3 Prod Engrs <n1223na conocophillips com>; CPF3 Ops Supv <n2070(aconocophillips com> Subject: RE: KRU 3R-102i(PTD 216-157) SSSV Requirement during pre -production Victoria, Please review and provide written approval for the No Flow Test procedure enclosed. We would like to conduct this test on Saturday 5/6/17 and we will provide the State Inspector 24hr notice of the planned test. In regards to your note below; AOGCC regulations state that a subsurface safety valve can be temporarily blocked or removed from a well and but has to be made operable and tested within 14 days from the date the well is returned to service. I was wondering if this would apply to 311-102 and we would not have to man the well for 14 days while we conduct the No Flow Test and the SVS test. If the well does not obtain an acceptable No Flow Test then it would be manned for the continuation of the 30 day pre -production period or a K valve installed. Please let us know if this is acceptable. Thanks, Darrell Humphrey/ Matthew Raiche Production Engineering Specialist ConocoPhillips Alaska Ph: 907.659.7535 1 Pg: 924 1 Mail: NSK 69 From: Sullivan, Michael Sent: Tuesday, May 02, 2017 2:54 PM To: CPF3 Prod Engrs <n1223@conocophillips com> Cc: NSK Prod Engr Specialist <n1139(aconocophillips com>; Coberly, Jonathan <Jonathan Coberlv(raconocophillips com>; Driscoll, Michael D <Michael. D. Driscoll@conocophillips.com>; NSK POP Lead <n2490@conocophillips.com> Subject: FW: KRU 3R-102i(PTD 216-157) SSSV Requirement during pre -production All, See below the AOGCC response regarding our concerns with the 3R-102 pre -production period. Toon, Please relay this to Operations and move forward with your preferred option. Thanks in advance, Michael Sullivan Viscous Petroleum Engineer ConocoPhillips Alaska Office: 907-263-4123 Cell: 907-231-9953 From: Loepp, Victoria T (DOA) [mailto:victoria Ioepo@alaska eov] Sent: Tuesday, May 02, 2017 2:49 PM To: Sullivan, Michael <Michael Sullivan@conocoohillips com> Cc: Regg, James B (DOA) <jim.reeF@alaska.Rov> Subject: [EXTERNAL]KRU 3R-102i(PTD 216-157) SSSV Requirement during pre -production Michael, We discussed several options concerning pre -producing KRU 311-102i without a SSSV for 30 days. 1. Produce the well several days and perform a NFT. If the well passes a NFT, then it is acceptable to produce the well without a SSSV. If the well flows on its own, install a K valve OR produce the well with manned surveillance during the 30 day pre production period. 2. Produce the well for 30 days with manned surveillance. Please refer to AOGCC Guidance Bulletin No 10-004 concerning No Flow Testing(NFT). 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 Loeoo(a)alaska goy 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 Loeoo@alaska gov From: Sullivan, Michael[mailto:Michael.Sullivan@conocoohillios coml Sent: Sunday, April 30, 2017 3:10 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Driscoll, Michael D <Michael D.Driscoll@conocoohillios com>; CPF3 Prod Engrs <n1223@conocoohillios.com> Subject: 311-102 Pre -Production Clarification Importance: High Victoria, We are prepared to bring online injection well 311-102 on Tuesday May 2"", but would like some clarification before we do so. Our plan is to pre -produce well 311-102 without a SSSV for a total of 30 days. The SSV and LPP will be in service and tested per AOGCC requirements. The pre -production will be manned during the initial startup of the well, which is expected to last approximately 12 ,,,urs. After the initial startup, the manned o,eration will be terminated but extra surveillance will be provided for the remainder of the pre -production period. After the pre -production period has completed, well 3R-102 will be converted to injection service and a SSSV will be installed. 1. Is pre -producing the well with the LPP and SSV in service and without a SSSV for 30 days acceptable? 2. Is having the pre -production period un -manned (without a SSSV) after the initial startup acceptable? Thanks in advance, Michael Sullivan Viscous Petroleum Engineer ConocoPhillips Alaska Office: 907-263-4123 Cell: 907-231-9953 RECLIVE® MAY 10 2017 SchlumheruerA 0GC(; Drilling & Measurements /`1 IWD/LWD Log Product Delivery Customer: Conoco Phillips Alaska Dispatched To: Well No: 3R-101 Date Dispatched: Job#: 16AKAOI10 Dispatched By: L i /ii7%j 28 18 4 Transmittal#: 10MAY17-SP01 DATA LOGGED 5 �'K1 ODS I. K. t`iE2 7 AOGCC: Makana Bender 10-Mav-17 Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E -Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Resistivity 2" MD x x Scope Resistivity 2' TVD x x Scope Resistivity 5" MD x x Scope Resistivity 5" TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As -Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: HIS /ASCII x Graphics: pdf/tiff x Surveys: pdf / txt x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkam p(a)conocophillips.com AlaskaPTSPrintCenter(o)slb.com Tom Osterkamp Attn: Stephanie Pacillo 907-263-4795 Received By: v LFINAL NADConversion Kuparuk River Unit Kuparuk 3R Pad 3R-101 NAD 27 Definitive Survey Report 05 May, 2017 Z 1 TO T3 28 18 4 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States GYD-GC-SS Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) 3/29/2017 8:47 : Using Well Reference Point Map Zone: Alaska Zone 04 MWD+IFRAKCAZSCC Using geodetic scale factor Well 3R-101 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Well Position +N/S 0.00 usft Northing: 6,031,732.16 usft Latitude: 70° 29'52.272 N 135.69 +E/ -W 0.00 usft Easting: 520,625.98 usft Longitude: 149'49'52.775 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usft wellbore 3R-101 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) PI (nT) BGGM2016 4/1/2017 17.72 81.04 57,551 Design 3R-101 Audit Notes: Version: 1.0 Vertical Section: Phase: ACTUAL Tie On Depth: 39.10 Depth From (TVD) +N/ -S +EI -W Direction (usft) (usft) (usft) (°) 39.10 0.00 0.00 270.00 Survey Program Date From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 135.69 638.81 3R-101 Srvy 1 - SLB _GYD-GC-SS (3R-1 GYD-GC-SS Gyrodata gyro single shots 3/24/2017 8:28' 676.74 2,153.783R-101 Srvy 2-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/24/2017 8:31: 2,208.44 2,208 44 3R-101 Srvy 3 - SLB_GYD-GC-SS (3R-1 GYD-GC-SS G rodata y gyro single shots 3/25/2017 8:33: 2,297.00 8,026,553R-101 Srvy 4- SLB _MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/29/2017 8:47 : 8,102.69 9.661A6 3R-101 Srvy5-SLBWD+GN1AG(3R- M MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 4/1/20172:48:0 9,759.17 16,369.033R-101 Srvy 6-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 4/9/2017 8:10:0 survey YO ZUT 12.13:54PM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (R) (°/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -9.90 0.00 0.00 6,031,732.16 520,625.98 0.00 0.00 UNDEFINED 135.69 074 51.62 13569 W69 0.39 0.49 6,031,732.55 520,626.47 0.77 -0.49 GYD-GC-SS(1) 169.59 0.74 47.48 169.58 120.58 0.67 0.82 6,031,73283 520,626.80 0.16 -0.82 GYD-GC-SS(1) 26273 1.17 358,19 262.71 213.71 2.03 1.24 6,031,734.19 520,627.21 0.95 -1.24 GYD-GC-S$(1) 356.57 2.27 336.68 356.51 307.51 4.69 0.47 6,031,736.85 520,626.44 1.34 -0.47 GYD-GC-SS(1) 451,76 3.38 327.54 451.58 402.58 8,79 -1.78 6,031,740.95 520,624.17 125 1.78 GYD-GC-SS(1) 545.32 3.75 318.73 544.96 495.96 13.42 -5.28 6,031,745.56 520,62066 0.71 528 GYD-GC-SS(1) 638.81 5.49 307.39 638.15 589.15 1843 -10.85 6,031,750.56 520,615.08 2.09 10.85 GYD-GC-SS(1) 676.74 6.24 302.09 675.88 626.88 2063. -14.04 6,031,75275 520,611.88 2.44 14.04 MWD+IFR-AK-CAZ-SC(2) 77088 7.30 300.95 769.36 720.36 26.42 -23.50 6,031,758.52 520,602.40 1.13 23.50 MWD+IFR-AK-CAZ-SC(2) YO ZUT 12.13:54PM Page 2 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConverston Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00ush (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +14/4 +El -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 863.73 9.86 309.12 861.17 812.17 34.47 -34.73 6,031,766.53 520,591.15 3,05 U 73 MWD+IFR-AK-CAZ-SC (2) 95988 9.% 31732 955.69 906.69 45.76 46.73 6,031.777 78 520,579.13 147 46.73 MWDHFR-AK-CAZ-SC(2) 1,053.73 12.30 32876 1,047.98 998.98 60.31 -57.44 6,031,792.30 520,568.37 3.41 57.44 MWD+IFR-AK-CAZ-SC(2) 1,149.13 13.65 347.18 1,140.98 1,091.98 79.99 6522 6,031 811 95 520,560.55 4.54 65.22 MWD+IFR-AK-CAZ-SC(2) 1,243.57 14.34 355.31 1,232.62 1,183.62 102.52 -68.65 6,031,834.48 520,557.05 2.20 68.65 MW1)+1FR-AK-CAZ-SC(2) 1,338.60 14.97 357.92 1,324.56 1,275.56 126.52 -70.06 6,031,65847 520555.58 0.96 70.06 MWD+IFR-AK-CAZ-SC(2) 1,433.41 15.24 359.78 1,41809 1,36789 151.21 -70.55 6,031,883.16 520,555.02 0.59 70.55 MWD+IFR-AK-CAZ-SC (2) 1,52763 14.50 0.11 1,507.16 1,458.16 17539 -7057 6,031,907.34 520,554.93 0.79 70.57 MWDHFR-AK-CAZ-SC(2) 1,620.81 1727 0.21 1,596.77 1,54777 200.89 -70.50 6,031,93284 520,554.93 2.97 7050 MWD+1FR-AK-CAZ-SC(2) 1,716.88 16.64 1.37 1,688.62 1,639.62 229.07 70.12 6,031,961.01 520,55524 0.57 70.12 MWD+IFR-AK-CAZ-SC (2) 1,811.40 19.06 35874 1778.53 1,729.53 258.19 -70.13 6,031,99013 520,555.14 2.50 70.13 MWD+IFR-AK-CAZ-SC(2) 1,906.14 20.91 356.99 1,857.56 1,818.56 290.54 -71.36 6,032,022.47 520,553.83 2.05 71.36 MWD+IFR-AK-CAZ-SC (2) 2,000.30 24.98 355.65 1,950.26 1,905.26 327.16 -73.75 6,032,05908 520,551.33 436 7315 MWD+IFR-AK-CAZ-SC(2) 2,094.43 28.81 355.00 2,038.19 1,989.19 36959 -77.23 6,032,101.50 520.547.73 4.08 77.23 MWD+IFR-AK-CAZ-SC(2) 2,153.78 30.11 355.47 2,08986 2,040.86 398.68 -79.66 6,032,130.57 520,545.23 2.22 7966 MWD+IFR-AK-CAZ-SC(2) 2,20844 33.91 357.04 2,136.21 2,087.21 427.58 61.53 6,032,15947 520,543.28 7.12 81.53 GVD-GC-SS(3) 2,243.00 34.53 357.36 2,164.78 2,115.78 446.99 -82.48 6,032,178.88 520,54227 1.88 82.48 NOT eR AdY01 $Ylylly 13 378" 2,297.00 35.51 357.84 2,209.00 2,160.00 477.96 -83.77 6,032,209.84 520.540.89 1.88 83.77 MWD+IFR-AK-CAZ-SC(4) 2,353.55 37.24 358,70 2,254.53 2,205.53 511.48 -84.78 6,032,24335 520,539.79 3.19 84.78 MWD+IFR-AK-CAZ-SC(4) 2,44888 41.36 358.32 2,327.65 2,278.65 571.31 -86.34 6,032,303.17 520,538.06 4.37 86.34 MWD+IFR-AK-CAZ-SC (4) 2,543.56 45.79 0.39 2,39883 2,347.83 637.11 -87.04 6,032,368.96 520,537.19 4.87 87U MWD+1FR-AK-CAZ-SC(4) 2,63735 49.08 0.59 2.460.53 2,411.53 706.47 -86.44 6,032,43831 520,537.59 3.50 86.44 MWD+IFR-AK-CAZ-SC (4) 2,73227 54.02 1.62 2,519.29 2,47029 78045 44.99 6,032,512.29 520,538.83 5.30 84.99 MWD+IFR-AK-CAZ-SC(4) 2,826.93 58.92 0.47 2,571.56 2.522.56 859.32 -83.57 6,032,591.16 520,54093 5.27 83.57 MWD+IFR-AK-CAZ-SC(4) 2,919.52 6348 (r11 2,616.16 2.567.16 94043 -83.17 6,032,672.27 520,540.21 4.94 83.17 MWD+IFR-AK-CAZ-SC 14) 3,015.11 67.32 358.34 2,655.94 2,606.94 1,027.32 -84.36 6,032,759.14 520,538.77 4.36 84.36 MWD+IFR-AK-CAZ-SC (4) 3,110.07 71.37 357.59 2,689.43 2,640.43 1,116.10 -8753 6,032,84790 520,535.37 L33 87.53 MWD+1FR-AK-CAZ-SC(4) 3,200.89 75.87 355.15 2,716.17 2,657.17 1,206.86 -93.31 6,032,938.63 520,52933 5.35 93.31 MWD+IFR-AK-CAZ-SC(4) 3,300.84 80.10 354.91 2,735.14 2,687.14 1,300.33 -101.44 6,033,032.07 520,520.95 4.42 101.44 MWD+IFR-AK-CAZ-SC (4) 3,395.53 80.99 35526 2,751.69 2,702.69 1,393.39 -10944 6,033,125.10 520,512.69 1.01 109.44 MWD+IFR-AK-CAZ-SC(4) 3,490.19 81.39 356.24 2,766.19 2.717.19 1486.67 -116.37 6,033,218.36 520,505.50 1.11 116.37 MWD+IFR-AK-CAZ-SC(4) 3,582.99 8143 35682 2,78095 2,731.05 1,578.25 -122,08 6,033,30991 520,499.53 041 122.08 MWD+1FR-AK-CAZ-SC(4) 3,679.39 81.52 355.89 2,794.34 2,745.34 1,673.38 -128.31 6,033,405.02 520,493.04 0.75 128.31 MWD+IFR-AK-CAZ-SC (4) 3,774.67 81.52 354.32 2,808.39 2.759.39 1,767.28 -136.35 6,033,498.88 520,484.74 1.63 136,35 MWD+IFR-AK-CAZ-SC(4) 3,869.26 81.14 354.65 2,822.65 2,773.65 1860.35 -145.34 6,033,591.92 520,475.49 0.53 145.34 MWD+IFR-AK-CAZ-SC(4) 3,96382 81.59 354.57 2,836.82 2,787.82 1,953.23 -154.10 6,033,684.76 520,466.47 0.48 154.10 MWD+IFR-AK-CAZ-SC(4) 4,058.18 81.39 354.86 2,850.81 2,801.81 2,046.35 -162.72 6.033,777 85 520,457.80 0.37 162.72 MWD+1FR-AK-CAZ-SC(4) 4,153.32 81.31 355.47 2,865.12 2,816.12 2,140.07 -170.64 6,033,871.54 520,449.41 0.64 17064 MWD+IFR-AK-CAZ-SC(4) 4,247.21 81.19 356.30 2,879.41 2,830.41 2,232.63 -177.30 6,033,96407 520,442.50 088 177.30 MWD+IFR-AK-CAZ-SC(4) 5/5/2017 2,13: 54PM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConverslon Local Co-ordinate Reference: Well 3R-101 Project: Kupamk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101 Database: OAKEDMP2 Survey MD Inc (usft) V) 4,341.81 81.29 4,436.87 81.31 4,532.86 81.46 4.627.23 81.49 4,722.52 81.62 4,816.15 81.17 4,910.05 81.65 5,005.50 81.45 5,099.31 80.43 5,194.23 79.74 5,288.73 80.17 5,384.03 80.16 5,47850 80.16 5,574.37 79.88 5,668.19 80.05 5,762.98 79.70 5,85890 79.93 5,953.58 79.83 6,048.38 79.78 6,142.31 8065 6,237.62 80.49 6,33269 80.84 6,427.09 80.50 6,521.45 80.15 6,615.67 79.69 6,710.05 80M 6,80295 79.71 6,898.97 79.47 6,993.80 78.57 7,08866 77.01 7.183.15 78.05 7,277.04 78.65 7,370.87 79.07 7,466.77 81.05 7,561.29 8267 7,651.42 83.63 7,749.17 83.29 7,843.93 83.31 7,937.29 83.12 7,980.65 82.66 Map Map Vertical Art TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) Survey Tool Name 357.42 2,893.81 2,844.81 2,325.99 -182.42 6,034,057.40 520,437.12 1.17 182.42 MWD+IFR-AK-CAZ-SC(4) 358.76 2,908.19 2,859.19 2,419.90 -165.56 6,034,151.29 520,433.73 1.39 185.56 MWD+IFR-AK-CAZ.SC(4) 359.12 2,92257 2,873.57 2,514.79 ,187.31 6,03,246.17 520,431.71 0.40 187.31 MW1)+1FR-AK-CAZ-SC(4) 358.61 2,935.58 2,887.56 2,608.10 -189.16 6,034,339.46 520,429.60 0.54 189.16 MWD+IFR-AK-CAZ.SC(4) 358.05 2.950.56 2,901.56 2,702.31 -191.91 6,03,433 .65 520,426.59 0.60 191.91 MWD+1FR-AK-CAZ-SC(4) 357.64 2,964.57 2,915.57 2,794.82 -195.39 6,034,526.15 520,422.86 0.65 195.39 MWD+IFR-AK-CAZ-SC (4) 357.59 2,97859 2,929.59 2,887.59 -199.25 6,03,618 .90 520,418.74 0.51 199.25 MWD+IFR-AK-CAZ-SC(4) 357.34 2,992.62 2,943.62 2,981.91 -203.43 6,03,71320 520,414.30 0.33 203.43 MWD+1FR-AK-CAZ-SC(4) 356.19 3,00.39 2,958.39 3,074.40 -208.65 6,034,805.66 520,408.82 1.63 20865 MWD+IFR-AK-CAZ-SC(4) 356.96 3,023.73 2,974.73 3,167.73 -214.24 6,03,89897 520,402.97 1.08 214.24 MWD+IFR-AK-CAZ-SC(4) 357.41 3,040.22 2,991.22 3,260.67 218.81 6,03 ,991.89 520,398.14 0.65 218.81 MWD+IFR-AK-CAZ-SC(4) 355.86 3,056.49 3,007.49 3,354.41 -224.32 6.035,085 60 520,392.37 1.60 224.32 MWD+IFR-AK-CAZ-SC(4) 355.01 3,072.64 3,023.64 3,447.19 -231.73 6,035,178.35 520,384.71 0.89 231.73 MWD+1FR-AK-CAZ-SC(4) 35233 3,089.26 3,040.26 3.541.03 -242.14 6,035,272.15 520,374.04 2.77 242.14 MWD+IFR-AK-CAZ-SC(4) 35229 3,105.61 3,056.61 3,632.58 -254.50 6,036363.66 520,361.43 0.19 254.50 MWD+1FR-AK-CAZ-SC(4) 350.63 3,122.27 3,073.27 3,724.85 -268.36 6.03545569 520,347.32 176 268.36 MWD+IFR-AK-CAZ-SC (4) 350.94 3,139.23 3,090.23 3,818.04 -283.48 6,035,549.02 520,331.94 040 28348 MWD+IFR-AK-CAZ-SC(4) 352.59 3,155.87 3,108.87 3,910.29 -296.83 6,035,641.22 520,318.34 1.72 298.83 MWD+1FR-AK-CAZ-SC (4) 353.57 3172.65 3,123.65 4,00291 -308.07 6.035,733.80 520,306.84 1.02 308.07 MWD+IFR-AK-CAZ-SC(4) 351.82 3,18861 3,139.61 4,094]2 -319.84 6,035.825.57 520,294.81 2.06 319.84 MWD+IFR-AK-CAZ-SC(4) 349.06 3.204.23 3,155.23 4,187.42 -335.45 6,035,918.22 520,278.95 2.85 33545 MWD+IFR-AK-CAZ-SC(4) 348.35 3,219.69 3,170.69 4,279.61 -353.86 6,036,010.35 520.260.28 0.82 353.86 MWD+IFR-AK-CAZ-SC(4) 345.89 3,234.96 3,185.96 4,370.22 -374.58 6,036,100.89 520,239.31 2.60 374.58 MWD+IFR-AK-CAZ-SC (4) 344.77 3,250.82 3,201.82 4,460.20 -398.14 6,03619060 520,215.51 1.23 398.14 MWD+IFR-AK-CAZ-SC 14) 343.22 3,267.31 3,218.31 4,549.37 -423.71 6,036,279.88 520,189.69 169 423.71 MWD+IFR-AK-CAZ-SC(4) 339.00 3,283.88 3,234.88 4637.26 -453.79 6,036367,68 520,159.37 4.42 453.79 MWD+IFR-AK-CAZ-SC(4) 338.08 3,300.18 3.251.18 4,722.38 -487.25 6,036,452.70 520,12568 1.06 487.25 MWD+IFR-AK-CAZ-SC(4) 33569 3,317.53 3,268.53 4,809.23 -524.32 6,036,539.44 520,088.37 246 524.32 MWD+IFR-AK-CAZ-SC(4) 334.02 3,335.59 3,286.59 4,893.50 -563.87 6,036623 .59 520,048.59 1.97 663.87 MWD+IFR-AK-CAZ-SC(4) 334.51 3,355.65 3,306.65 4,977.01 -604.13 6,036.706.98 520,008.10 1.72 604.13 MWD+IFR-AK-CAZ-SC (4) 332.54 3,376.06 3,327.06 5,059.59 645.26 6,036,789.44 519,966.75 2.31 645.26 MWD+IFR-AK-CAZ-SC(4) 332.66 3,395.02 3,346.02 5,141.23 -687.58 6,036870.95 519,92421 0.65 687.58 MWD+IFR-AK-CAZ-SC(4) 330.57 3,413.15 3,364.15 5,222.22 -731.34 6.036,951.81 519,880.22 223 731.34 MWD+IFR-AK-CAZ-SC(4) 330.18 3,429.70 3,380.70 5,304.33 -776.03 6,037,033.78 519,833.31 2.10 778.03 MWD+IFR-AK-CAZ-SC(4) 327.76 3,443.09 3,394.09 5,384.49 826.27 6.037,113.80 519,784.86 366 82627 MWD+IFR-AK-CAZ-SC(4) 323.12 3,454.20 3,405.20 5,460.62 -678.71 6,037,189.77 519,732.21 5.05 878.71 MWD+IFR-AK-CAZ-SC(4) 318.54 3,465.00 3,416.00 5,533.58 -938.15 6.037 262,56 519,672.58 4.82 938.15 MWD+IFR-AK-CAZ-SC (4) 316.31 3,476.05 3,427.05 5,602.88 -1,001.81 6,037,331.68 519,606.72 2.34 1,001.81 MWD+IFR-AK-CAZ-SC(4) 313.16 3,487.09 3,43809 5,668.12 -1,06766 6,037,396.73 519,542.70 3.36 1,067.66 MWD+IFR-AK-CAZ-SC 14) 310.87 3,492.45 3,443.45 5;698.91 -1,099.63 6,037,42543 519,510.66 5.35 1,099.63 MWD+1FR-AK-CAZ-SC(4) 5/5/2017 2:13:54PM Page 4 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConverslon Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit ND Reference: 3R-101 actual @ 49.00ustt (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101 Database: OAKEDMP2 Survey MD (usft) 8,026.55 Inc 0 82.82 AN V) 310.75 TVD (usft) 3,49826 NDSB (usft) 3,449.26 +N7 -S (usft) 5,726.67 +E/ -W (usft) -1.134.09 Map Northing (ft) 6,037,45569 EastingSection (ft) 519,476.12 MaptMWD+lFR-AK-CAZ-SC Vertical (ft) Survey Tool Name 1,134.09 MWD+IFR-AK-CAZ-SC(4) 8,10269 8,196.27 8,290.64 8,385.81 8,480.48 84.02 83.30 80.09 78.59 82.05 308.30 307.17 306]9 302.73 294.76 3,506.98 3.517.32 3.530.94 3,548.56 3,564.50 3,457.98 3,468.32 3,481.94 3,499.56 3,515.50 5,774.80 5,831.72 5,88789 5,941,21 5,986.01 -1,192.43 -1,265.98 -1,340.57 -1,417.38 -1,499.13 8,037,503.06 6,037,559.77 6,037,615.72 6,037,666%2 6,037,713.39 519,41]65 519,343.95 519,269.221,340.57 519,192.26 519,110.391,499.13 1,19243 MWD+IFR-AK-CAZ-SC 1265.98 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZSC(5) 1,417.38 MWD+IFR-AK-CAZ-SC (5) MWD+IFR-AK-CAZ-SO 8,575.24 8,66902 8,763.77 8,859.11 8,954.08 86.75 88.22 89.34 89.62 89.52 290.20 286.91 281.26 275.16 271.80 3,573.75 3.579.50 3,583.17 3,583.87 3,584.42 3,524.75 3.530.50 3,534.17 3,534.87 3,535.42 6,022.04 6,051.82 6,074.84 6,088.45 6,D94.21 -1,586.23 -1,674.96 -1,766.74 -1,861.06 -1,955.84 6,037,749.17 6,037,77871 6,037,801.47 6,037,814.82 6,037,82032 519,023.201,586.23 518,934.401,674.96 518,842.561,766]4 518,748.22 518,653.43 6.42 3.55 MWD+IFR-AK-CAZ-SC(5) MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC(5) 1,861.06 MWD+IFR-AK-CAZ-SC(5) 1,955.84 MWD+IFR-AK-CAZ-SC(5) 9,047.67 9,141.11 9,234.58 9,327.48 9,420.78 8664 87.22 88.14 88.28 85.20 271.51 269.20 268.86 269.08 269.92 3,587.55 3,592.56 3.596.34 3,599.24 3,604.55 3,538.55 3,543.56 3,547.34 3,550.24 3,555.55 6,096.92 6,097.49 6,095.91 6,I)NI 24 6,093.43 -2,049.33 -2,142.63 -2,236.00 -2,328.84 -2,421.98 6,037,82276 6,037,823.08 6,037,821.24 6,037,819.31 6,037,818.24 518.559.95 518,46866 518,373.29 518,280.47 518,187.35 3.09 2.55 1.05 0.28 3.42 2,049.33 MWD+IFR-AK-CAZ-SC(5) 2,142.63 MWD+IFR-AK-CAZ-SC(5) 2,236.00 MWD+IFR-AK-CAZ-SC(5) 2,328.84 MWD+IFR-AK-CAZ-SC(5) 2,421.98 MWD+IFR-AK-CAZ-SC(5) 9,516.25 9.608.09 9,681,16 9,732.00 84.52 84b5 83.25 87.88 269.32 270.04 270.35 269.09 3,613.10 3,622.24 3,628.10 3,633.58 3.564.10 3,573.24 3,579.10 3,584.58 6,D92.80 6,092.29 6,092.47 6,092.12 -2,517.06 -2,60844 -2,661,19 -2,731.79 6,037,817.35 6,037,816.58 6.037,816.61 6,037,816.07 518,092.27 518,000.90 517,948.16 517,877.57 0.95 0.93 1.63 8.77 2,517.06 MWD+IFR-AK-CAZ-SC(5) 2,608.44 MWD+IFR-AK-CAZ-SC (5) 2,661.19 MWD+IFR-AK-CAZ-SC(5) 2,73171 - NOT Actual 9618.1 an Survey 9,759.17 89.65 268.61 3,634.17 3,585.17 6,091.58 -2,758.95 6,037,815.45 517,85041 677 2,758.95 MWD+IFR-AK-CAZ-SC(6) 9,833.36 9,868.63 9,897.97 9,928.22 10,023.41 94.14 94.14 92.76 92.08 92.76 269.20 269.73 270.04 270.31 269.53 3,631.72 3,629.31 3,627.43 3,626.15 3,622.13 3,582.72 3,580.31 3,578.43 3,577.15 3,573.13 6,090.16 6,08985 6,089.79 6,089.88 6.08975 -2,833.07 -2,866.25 -2,897.53 -2,92775 -3,022.86 6,037,813.83 6,037,813.43 6,037,81328 6,037,813.29 6,037,812.89 517,776.31 517,743.13 517,711.85 517,68163 517,586.54 6.10 1.59 4.51 2.42 1.09 2,833.07 MWD+IFR-AK-CAZ-SC(6) 2,866.25 MWD+IFR-AK-CAZ-SC(6) 2,897.53 MWD+IFR-AK-CAZ-SC(6) 2,927.75 MWD+IFR-AK-CAZ-SC(6) 3,022.86 MWD+IFR-AK-CAZ-SC(6) 10,117.85 10,212.79 10,307.57 10,401.81 10,496.69 93.80 93.29 93.79 91.64 91,51 270.13 270.25 26990 269.15 270.21 3,616.73 3,610.86 3,605.01 3,600.54 3,597.93 3,567.73 3,561.86 3,556.01 3,551.54 3,548.93 6,089.47 6,089.78 6,069.90 6,089.12 6,088.59 -3.117.14 3,211.90 -3,306.50 -3,40062 -3,495.46 6,037,812.35 6,037,812.40 6,037,812.26 6,037,811.22 6,037,81042 517,492.27 517,39].52 517,302.93 517,208.81 517,113.98 1.27 0.55 064 2.42 1.13 3,117.14 MWD+IFR4K-CAZ-SC(6) 3,211.90 MWD+IFR-AK-CAZ-SC (6) 3,306.50 MWD+1FR-AK-CAZ-SC(6) 3,40062 MWD+IFR-AK-CAZ-SC(6) 3,495.46 MWD+IFR-AK-CAZ-SC(6) 10,590.58 10,68598 10,780.52 10,875.11 10,970.04 92.80 92.53 89.80 89.74 89.49 269.42 266.72 267.93 266.77 266.88 3,594.40 3,589.97 3,588.05 3,588.43 3,589.06 3,545.40 3,540.97 3,539.05 3,539.43 3,540.06 6,088.29 6,086.74 6,083.98 6,079.61 6,074.35 -3,589.28 -3,684.57 -3,779.04 -3,873.52 -3,968.30 6,037,809.86 6,037,80865 6,037,80503 6,037,800.39 6,037,79487 517,020.17 516,924.91 516,830.45 516,735.99 516,641,23 1.61 079 3.01 1.23 029 3,589.28 MWD+IFR-AK-CAZ-SC(6) 3,684.57 MWD+IFR-AK-CAZ-SC(6) 3,779.04 MWD+IFR-AK-CAZ-SC(6) 3,873.52 MWD+IFR-AK-CAZ-SC (6) 3,968.30 MW0+IFR-AK-CAZ-SC(6) 11,064.25 11,159.90 11,254.04 90.36 90.13 88.93 266.63 267.31 268.33 3,589,19 3,588.78 3,589.55 3,540.19 3,539.78 3,540.55 6,069.02 6,063.96 6,060.38 -4,062.36 -4,157.88 -4,251.94 6,037,789.28 6,037,783.96 6,037,780.12 516,547.20 516,451.71 51Q357.66 0.96 0.75 1.67 4,062.36 MWD+IFR-AK-CAZ-SC(6) 4,157.88 MWD+IFR-AK-CAZ-SC(6) 4,251.94 MWD+IFR-AK-CAZ-SC(6) 51&1917 2.13:54PM Page 5 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Cc -ordinate Reference: Well 3R-101 Project: Kupamk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Well: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.O0usft (Doyon 142) 3R-101 North Reference: hue Wellborn: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101 Database: OAKEDMP2 Survey MD Inc Azi TVD TVDSS +N/ -S +E1 -W Map Map Vertical Northing Easting DLS Section (usR) (1) V) (usR) (usft) (usR) (usR) (ft) (R) (°1100') (R) Survey Tool Name 11348.99 87.87 267.89 3,592.20 3,543.20 6,057.25 -0,346.80 6,037,77672 516,262.82 1.21 4,346.80 MWD+IFR-AK-CAZ-SC(6) 11,442.97 88.68 266.91 3.595.03 3,546.03 6,052.99 -4440.64 6,037,77220 516,169.00 1.35 4,440.64 MWD+IFR-AK-CAZ-SC(6) 11,537.17 89.12 266.46 3,59664 3,547.84 6,047.54 -4,534.67 6,037,766.50 516,075.00 0.67 4,534.67 MWD+IFR-AK-CAZ-SC(6) 11,630.87 91.76 266.29 3,596.12 3,547.12 6,041.62 -4,628.17 6,037,760.31 515,981.53 2.82 4,628.17 MWD+IFR-AK-CAZ-SG(6) 11,726.12 9305 264.57 3,592.12 3,543.12 6,034.04 -4,723.03 6,037,752.47 515,886.70 2.26 4,723.03 MWD+IFR-AK-CAZ-SC(6) 11,820,25 91.43 26591 3,58844 3,539.44 6,026.23 -4,816.75 6,037,74441 515,793.00 2.23 4,816.75 MWD+IFR-AK-CAZ-SC(6) 11,915.43 8963 266.37 3,587.56 3,538.56 6,019.83 4,911.71 6,037,737.74 515,698.07 1.95 4,911.71 MWD+IFR-AK-CAZ-SC(6) 12,010.04 89.02 267.30 3,588.68 3,539.68 6,01460 -5,006.17 6,037,732.25 515,603.64 1.18 5.006.17 MWD+IFR-AK-CAZ-SC(6) 12,105.17 89.89 268.21 3,589.58 3,540.58 6,010.86 -5,101.22 6,037,728.26 515,508.61 1.32 5,101.22 MWD+IFR-AK-CAZ-SC(6) 12,198.99 90.23 269.01 3,589,48 3,540,48 6,008.60 -5,195.01 6,037,72573 515,414.83 0.93 5,195.01 MWD+IFR-AK-CAZ-SC(6) 12,293.90 90.36 269.37 3,589.00 3,540.00 8,007.26 -5,289.91 6,037,724.12 515,319.95 0.40 5,289.91 MWD+IFR-AK-CAZ-SC(6) 12,388.39 90.87 269.16 3.587.98 3,538.98 6,008.05 -5,384.39 6,037,72265 515,225.49 0.58 5,384.39 MWD+IFR-AK-CAZ-SC(6) 12,482.54 90.29 271.49 3,587.03 3,538.03 6,006.58 -5,478.52 6,037,722.92 515,131.36 2.55 5,478.52 MWD+IFR-AK-CAZ-SC(6) 12,577.56 90.38 270.88 3.586.47 3,53747 6,008.55 -5,573.52 6,037,72462 515,036.35 0.65 5.573.52 MWD+IFR-AK-CAZ.SC(6) 12,672.32 89.54 270.% 3,586.54 3,537.54 6,009.82 -5.666.27 6,037,725.63 514,941.62 0.92 5.668.27 MWD+IFR-AK-CAZ-SC(6) 12,766,67 88.68 269.52 3.588.00 3,539.00 6,009.97 -5,76261 6.037,725 52 514,847.29 1.51 5,762.61 MWD+IFR-AK-CAZ-SC(6) 12,861.96 89.29 269.09 3,589.69 3,540.69 6,008.81 -5,857.87 6,037,724.10 514,752.04 0.78 5,857.87 MWD+IFR-AK-CAZ-SC(6) 12,956.58 89.37 267.85 3,590.80 3,54180 6.006.29 -5,952.45 6,037,721.31 514,657.48 1.31 5,952.45 MWD+IFR-AK-CAZ-SC(6) 13,051.01 89.39 267.13 3,591.82 3,542.82 6,002.15 -6,046.79 6,037.716.91 514,563.17 0,76 6,046]9 MWD+IFR-AK-CAZ-SC (6) 13,145.43 8962 266.35 3,592.64 3,543.64 5.996.78 -6,141.05 6,037,711.28 514,468.93 0.86 6,141.05 MWD+IFR-AK-CAZ-SC(6) 13,239.35 89.78 267.20 3,59313 3.544.13 5,991.50 -6,234.82 6,037,705.74 514,375.18 0.92 6,234.82 MWD+IFR-AK-CAZ-SC(6) 13,334.20 90.50 267.64 3.592.90 3,543.90 5,98723 -6,329.57 6,037,701.21 514,28065 0.89 6,329.57 MWD+IFR-AK-CAZ-SC 16) 13,428.00 90.15 268.86 3,592.36 3,543.36 5.984.37 -,423.32 6,037,69808 514,186.72 1.35 6,423.32 MWD+IFR-AK-CAZ-SC(6) 13,523.58 90.56 269.81 3,591.77 3,542.77 5,983.26 -6,518.89 6,037 696.71 514,091.16 1.08 6,518.89 MWD+IFR-AK-CAZ-SC(6) 13,617.44 91.34 270.31 3,590.22 3,541.22 5,98335 -6,612.74 6,037,696.55 513,997.32 0.99 6.612.74 MWD+IFR-AK-CAZ-SC(6) 13,711.39 9116 270.50 3,587.67 3,538.67 5,984.02 -6,706.65 6,037,69695 513,903.42 0.49 6,706.65 MWD+IFR-AK-CAZ-SC(6) 13,808.55 91.01 270.08 3,585.37 3,536.37 5,984.50 -6,80178 6,037,697.17 513,808.30 0.90 6,801.78 MWD+IFR-AK-CAZ-SC(6) 13,902.28 Wee 268.97 3,583.95 3,534.95 5,983.71 -6,897.50 6,037,696.11 513,712.59 121 6,897.50 MWD+IFR-AK-CAZ-SC(6) 13,997.29 91.04 269.35 3,562.52 3,533.52 5,982.31 $,992.49 6,037,69445 513,617.62 0.54 6,992.49 MWD+IFR-AK-CAZ-SC(6) 14,091.98 90.45 269.72 3,58129 3,532.29 5,981.54 -7,087.16 6,037,693.42 513,52295 0.74 7,087.16 MWD+IFR-AK-CAZ-SC(6) 14,185.89 89.93 269.32 3,580.97 3,531.97 5,980.75 -7,182.07 6,037,692.36 513,428.06 0.69 7,182.07 MWD+IFR-AK-CAZ-SC(6) 14,281.03 89.93 268.32 3,581.09 3,532.09 5,978.81 -7,276.19 6,037,690.16 513,333.95 1.06 7,276.19 MWD+IFR-AK-CAZ-SC(6) 14,375.64 9,47 268.91 3,58076 3,531.76 5,976.52 -7,370.77 6,037,68761 513,239.39 0.85 7,370.77 MWD+IFR-AK-CAZ-SC(61 14,470.32 90.19 26772 3,580.21 3,531.21 5,973.74 -7,465.40 6,037,684.57 513,144.77 1.29 7,465.40 MWD+IFR-AK-CAZ-SC(6) 14,564.91 9D.33 267.19 3,579.78 3,530.78 5,969.54 -7,559.90 6,037,680.11 513,050.30 ).58 7,559.90 MW0+1FR-AK-CAZ-SC(6) 14,659.01 90.98 267.33 3,578.71 3,529.71 5,985.04 -7,653.89 6,037,675.35 512,956.33 0.71 7,653.89 MWD+IFR-AK-CAZ-SC(6) 14,753.97 90.95 267.32 3,577.11 3,528.11 5,960.61 -7,748.73 6,037,670.65 512,881.51 0.03 7,748.73 MWD+IFR-AK-CAZ-SC (6) 14,848.83 90.44 266.54 3,575.96 3,526.96 5,955.53 -7643.44 6,037,665.31 512,766.82 0.98 7,843.44 MWD+IFR-AK-CAZ-SC (6) 14,943.45 90.36 267.19 3,575.30 3,526.30 5,950.36 -7,937.92 6,037,65888 512.672.37 0.69 7,937.92 MWD+IFR-AK-CAZ-SC(6) 15,038.10 90.37 268.50 3,574.69 3,525.69 5,946.80 -8,032.50 6,037,656.05 512,577.81 1.38 8,032.50 MWD+1FR-AK-CAZ-SC(6) 532017 2:13:54PM Page 6 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101 Database: OAKEDMP2 Survey O Surface Coordinates El Declination & Convergence O GRS Survey Corrections E) Survey Tool Codes SLB DE Brandon Temple a+ay�B� j MD Inc Azf TVD TVDSS +N7S +E/ -W Map Map Vertical (usft) (•) (•) Northing Easting DLS Section (usft) (usft) (usft) (usft) (ft) (ft) (•/100') (ft) Survey Tool Name 15,131.86 90.37 268.87 3.574.09 3,525.09 5,94465 -8,126.23 6,037,653.64 512,484.09 0.39 8,126.23 MWD+IFR-AK-CAZ-SC(6) 15,226.78 89.93 26942 3,573.84 3,524.84 5,943.23 -8,221.14 6,037,651.96 512,389.20 074 8,221.14 MWD+IFR-AK-CAZ-SC(6) 15,321.30 89.75 26965 3.574.10 3,525.10 5,942.46 -8,315.66 6,037,650.93 512.294.69 0.31 8,315.66 MWD+IFR-AK-CAZ-SC(6) 15,414.45 90.07 270.01 3,574.25 3,525.25 5,942.19 -8,408.81 6,037,650.40 512,201.55 0.52 8,408.81 MWD+IFR-AK-CAZ-SC (6) 15,507.31 9364 270.12 3,571.25 3,522.25 5,94229 -8,501.60 6,037,650.25 512,108.77 3.85 8,50160 MWD+IFR-AK-CAZ-SC(6) 15,600.26 93.65 271.36 3,565.34 3,516.34 5,943.49 .8,594.36 6,037,651.19 512,016.02 1.33 8,594.36 MWD+IFR-AK-CAZ-SC(6) 15,69342 9261 270.85 3,560.25 3,511.25 5,94528 -8,687.36 6,037,652.72 511,923.02 1.24 8,687.36 MWD+IFR-AK-CAZ-SC (6) 15,787.08 92.32 269.46 3,556.22 3,507.22 5,945.54 -8,780.93 6,037,652.72 511,829.46 1.51 8,78093 MWD+IFR-AK-CAZ-SC(6) 15,880,15 91.54 268.90 3,553.09 3,504.09 5,944.20 -8,873.93 6,037,651.13 511,736.47 1.03 8,873.93 MWD+IFR-AK-CAZ-SC(6) 15,966.00 90.67 268.96 3,551.43 3,50243 5,942.61 -8,959.75 6,037,649.29 511,650.66 1.01 8.959.75 ImTanActualSurvey 4-1/2" 15,973.36 9060 268.97 3,551.35 3,502.35 5,94247 -8,967.11 6,037,649.14 511.643.31 1.01 8,967.11 MWD+IFR-AK-CAZ-SC 16) 16,067.10 91.94 268.09 3,549.27 3,50.27 5,940.07 -9,06079 6,037,646.47 511,549.64 1.71 9,060]9 MWD+IFR-AK-CAZ-SC(6) 16,16048 9461 268.39 3,54393 3,494.93 5,937.21 -9,15397 6,037,643.35 511,456.48 2.88 9,153.97 MWD+IFR-AK-CAZ-SC(6) 16,253.74 96.61 269.15 3,534.82 3,485.82 5,935.21 -9,246.76 6,037,641.10 511,363.71 2.29 9,24676 MWD+IFR-AK-CAZ-SC (6) 16,346.30 98,19 270.30 3,522.90 3,473.90 5,93417 -9,338.54 6,037,640.40 511,271.94 2.11 9,338.54 MWD+IFR-AK-CAZ-SC (6) 16,359.03 97.80 270.86 3,51974 3,470.74 5,935.00 -9,361.05 6,037,640.57 511.24943 2.98 9,361.05 MWD+IFR-AK-CAZ-SC(6) 16,433,00 9780 270.86 3,511.05 3,462.05 5,935.95 -9,42442 6,037.641.34 511,186.07 0.00 9,424.42 PROJECTED to TD Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. El Yes n No I have checked to the best of my ability that the following data is correct: O Surface Coordinates El Declination & Convergence O GRS Survey Corrections E) Survey Tool Codes SLB DE Brandon Temple a+ay�B� j Client Representative. o 0 917r10 by a,.t0610. 112 ' Ben Tolman �,E VowA^' Cmate.¢2017110610,0112 osm Date: 5!812017 552017 2.13:54PM Page 7 COMPASS 5000.1 Build 74 �EDEIVED MAY 10 2017 FINAL A®GCC ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk 3R Pad 3R-101 Definitive Survey Report 03 May, 2017 -Kup2 21 70 13 28184 Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -KUP2 Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual Q 49.00usf1 (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 39.10 0.00 Map Zone: Alaska Zone 4 -9.90 Using Well Reference Point 0.00 (usft) (usft) Survey (Wellbore) Using geodetic scale factor 3R-101 3R-101 AN TVD +N/ -S 0.00 usft +E/ -W 0.00 usft LP..It..nrtainty 0.00 usft Northing: Easting: Wellhead Elevation: 6,031,484.21 usft 1,660,657.38 usft 0.00 usft Latitude: 70° 29' 51.231 N Longitude: 149° 50'4.099 W Ground Level: 9.90 usft Nellbore 3R-101 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 4/1/2017 17.72 81.04 57,551 Design 3R-101 AN TVD TVDSS Audit Notes: +E/ -W Map Map Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 (usft) Vertical Section: Depth From (TVD) (usft) +N/ -S (usft) +E/ -W Direction (usft) 1°1 Easting DLS 39.10 0.00 0.00 270.00 (ft) Survey Program Date 5/3/2017 (ft) Survey Tool Name 39.10 0.00 From To -9.90 0.00 0.00 (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 135.69 676.74 2,208.44 2,297.00 8,102.69 9,759.17 638.81 3R-101 Srvy 1 - SLB_GYD-GC-SS (3R-1 2,153.783R-101 Srvy 2 -SLB MWD+GMAG(3R- 2,208.44 3R-101 Srvy 3 - SLB_GYD-GC-SS (3R-1 8,026.553R-101 Srvy4-SLB MWD+GMAG(3R- 9,661,163R-101 Srvy 5-SL8_MW13+GMAG(3R- 16,369.033R-101 Srvy 6-SLB_MWD+GMAG(3R- GYD-GC-SS MWD+IFR-AK-CAZ-SC GYD-GC-SS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC Gyrodata gyro single shots MWD+IFRAKCAZSCC Gyrodata gyro single shots MWD+IFR AK CAZ SCC MWD+IFR AK CAZ SCC MWD+IFRAKCAZSCC 3/24/2017 8:28: 3/24/2017 8:31: 3/25/2017 8:33: 3/29/2017 8:47:. 4/1/2017 2:48:5 4/9/2017 8:10:3. Survey MD Inc AN TVD TVDSS +N/ -S +E/ -W Map Map Vertical (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting DLS Section (ft) (ft) (°/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -9.90 0.00 0.00 6,031,484.21 1,660,657.38 0.00 0.00 UNDEFINED 135.69 0.74 51,62 13569 86.69 0.39 0.49 6,031,484.60 1,660,65787 077 -0.49 GYD-GC-SS(1) 189.59 0.74 4748 169.58 12058 0.67 0.82 6,031,484.89 1,660,658.20 0.16 -0.82 GYD-GC-SS(1) 262.73 1.17 358.19 262.71 213.71 2.03 1.24 6,031,48625 1,660,658.61 0.95 -1.24 GYD-GC-SS(1) 356.57 2,27 336.68 356.51 307.51 469 0.47 6,031,488.91 1,660,65784 1.34 -0.47 GYD-GPSS(1) 451.76 3.38 327.54 451.58 402.58 8.79 -1,78 6,031,493.00 1,660,655.57 1.25 1.78 GYD-GC-SS(1) 545.32 375 318.73 544.96 495.96 13.42 -5.28 6,031,497.62 1,660,652.06 0.71 5.28 GYD-GCSS(1) 638.81 5.49 307.39 638.15 589.15 1643 -10.85 6,031,502.62 1,660,646.48 2.09 10.85 GYD-GC-SS(1) 676.74 6.24 302.09 675.88 626.88 20.63 -14.04 6.031.5U 80 1,660,643.28 2.44 14.04 MWD+IFR-AK-CAZ-SC(2) 770.88 7.30 300.95 769.36 720.36 26.42 -23.50 6,031,510.57 1,660,633.81 1.13 23.50 MWD+IFR-AK-0AZ-SC (2) --l' ,,.,,c ucrm Page 2 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConoccPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 31R-101 actual @ 49,OOusft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101 Database: OAKEDMP2 Survey MD (usft) Inc (°) Azi (°) TVD (usft) TVDSS (usft) +N/ -S (usft) +E/ -W (usft) Map Northing (ft) Map Easting (ft) DLS (°/100') Vertical Section (ft) Survey Tool Name 863.73 959.68 1,05373 1,149.13 1,243.57 9.86 9.96 12.30 13.66 14.34 309.12 317.32 328.76 347.18 355.31 861.17 955.69 1,047.98 1,140.98 1,232.62 812.17 906.69 998.98 1,091.98 1,183.62 34.47 45.76 60.31 79.99 102.52 -34.73 -46.73 -57.44 -65.22 -6865 6,031,518.59 6,031,529.84 6,031,544.36 6,031,564.02 6,031,586.54 1,660,622.56 1,660,61053 1,650,599]8 1,660,591.95 1.660, 588 46 3.05 1.47 341 4.54 2.20 34.73 MWD+IFR-AK-CAZ-SG(2) 46.73 MWD+IFR-AK-CAZ-SC(2) 57.44 MWD+IFR-AK-CAZ-SC(2) 65.22 MWD+IFR-AK-CAZ-SC(2) 6865 MWD+IFR-AK-CAZ-SC(2) 1,338.60 1433.41 1,527.63 1,620.81 1,716.86 14.97 15.24 14.50 17.27 16.84 357.92 359.78 0.11 021 1.37 1,324.55 1,416.09 1,507.16 1,596]7 1,688.62 1.275.56 1,367.09 1,458.16 1,547.77 1,639.62 126.52 151.21 175.39 200.89 229.07 -70.06 -70.55 -70.57 -70.50 -70.12 6,031,610.53 6,031,635.22 6.031,65940 6,031,684.90 6,031,713.07 1,660,58689 1,660,586.43 1,660,586.34 1,660,586.34 1,660,58665 0.96 0.59 0.79 2.97 0.57 70.06 MWD+IFR-AK-CAZ-8C(2) 70.55 MWD+IFR-AK-CAZ-SC(2) 70.57 MWD+IFR-AK-CAZ-SC(2) 70.50 MW0HFR-AK-CAZ-SC(2) 70.12 MWD+IFR-AK-CAZ-SC(2) 1,811.40 1,906.14 2,000.30 2,094.43 2,153.78 1906 20.91 24.98 28.81 30.11 358,74 356.99 35585 355.00 355.47 1,778.53 1,86756 1,954.26 2,038.19 2,089.86 1,729.53 1,818.56 1,905.26 1,989.19 2,040.85 258.19 290.54 327.16 369.59 398.68 -70.13 -71.36 -73.75 -77.23 -79.66 6,031,742.18 6,031,774.53 6,031,811.14 6,031,853.55 6,031,88263 1,660,586.56 1,660,585.24 1,660,582.75 1,660,579.15 1,660,576.65 2.50 2.05 436 4.08 2.22 70.13 MM+IFR-AK-CAZ-SC(2) 71.36 MWD+IFR-AK-CAZ-8C(2) 7375 MWD+IFR-AK-CAZ-SC(2) 77.23 MWD+IFR-AK-CAZ-SC (2) 79.66 MWDHFR-AK-CAZ-SC(2) 2,208.44 2,243.00 33.91 34.53 357.04 357.36 2,13621 2,164.78 2,087.21 2,115.78 427.58 446.99 -81.53 -82.48 6,031,911.53 6,031,930.94 1,660,57410 1,660,573.70 7.12 1.88 81.53 GYD-GC-SS(3) 82.48 NpT an AcfuY Survey 13 3/8" 2,297.00 2,353.55 2,448.06 35.51 37.24 41.36 357.84 35870 358.32 2,209.00 2,254.53 2,327.65 2,160.00 2,205.53 2.278.65 477.96 511.48 571.31 -83.77 -8438 -86.34 6,031,961.89 6,031,995.41 6,032,055.23 1,660,572.32 1,660,571.22 1,660.569 49 1.88 3.19 4.37 83.77 MWD+IFR-AK-CAZ-SC(4) 8438 MWDHFR-AK-CAZ-SC 14) 86.34 MWD+IFR-AK-CAZ-SC (4) 2,543.56 2,637.75 2,73227 2,826.93 2,919.52 45.79 49.08 54.02 58.92 63.48 0.39 0.59 162 0.47 0.11 2,396.83 2,460.53 2,519.29 2,571.56 2,616.16 2,347.83 2.411.53 2,470.29 2,522.56 2,567.16 637.11 706.47 780.45 859.32 940.43 -87.04 -8644 -84.99 -83.57 43.17 6,032,121.02 6,032,190.37 6,032,264.35 6,032,34322 6,032,424.33 1,660,56862 1,660,569.03 1,660,570.27 1,660,57147 1,660,571.66 4.87 3.50 5.30 527 4.94 87.W MWDHFR-AK-CAZ-SC(4) 8644 MWD+IFR-AK-CAZ-SC(4) 84.99 MWD+IFR-AK-CAZ-SC(4) 83.57 MWD+IFR-AK-CAZ-SC(4) 83.17 MWD+IFR-AK-CAZ-SC(4) 3,015.11 3,110.07 3,204.89 3,300.84 3,395.53 67.32 7137 7587 80.10 80.99 358.34 357.59 355.15 354.91 355.26 2,655.94 2,68943 2,716.17 2,736.14 2,751.69 2,606.94 2,640.43 2,667.17 2,687.14 2,702.69 1,027.32 1,116.10 1,206.86 1,300.33 1,393.39 -84.36 -87.53 -93.31 -101.44 -109.44 6,032,511.20 6,032,599.96 6,032,690.69 6,032,784.13 6,032,877.16 1,650,570.23 1,660,56682 1,6W 560.80 1,660,552.41 1,660,544.16 4.36 4.33 5.35 4.42 1.01 84.36 MWD+IFR-AK-CAZ-SC(4) 87.53 MWD+IFR-AK-CAZ-SC(4) 93.31 MWD+IFR-AK-CAZ-SC(4) 10144 MWD+IFR-AK-CAZ-SC (4) 109.44 MWD+IFR-AK-CAZ-SC(4) 3,490,19 3,582.99 3,679.39 3,774.67 3,869.26 61.39 8143 81.52 81.52 81.14 356.24 356.62 355.89 354.32 354.65 2,766.19 2,780.05 2,794.34 2,808.39 2,822.65 2,717.19 2.731.05 2,745.34 2,759.39 2,773.65 1,486.67 1,578.25 1,673.38 1,767.28 1,860.35 -116.37 122.08 -128.31 -136.35 -14534 6,032,970.42 6,033,061.97 8.033,15708 6,033,250.94 6,033,343% 1,660,536.97 1,660,531.01 1,660,524.52 1660,51623 1,660,506.99 1.11 0.41 0.75 1.63 0.53 116.37 MWD+IFR-AK-CAZ-SC(4) 122.08 MWD+IFR-AK-CAZ-SC(4) 128.31 MWD+IFR-AK-CAZ-SC(4) 136.35 MWD+IFR-AK-CAZ-SC(4) 145.34 MWD+IFR-AK-CAZ-SC(4) 3,963.62 4,058.18 4,153.32 4.247.21 81.59 81.39 81.31 81,19 354.57 354.86 355.47 356.30 2,836.82 2,850.81 2,855.12 2,879.41 2,787.82 2,801.81 2.816.12 2,830.41 1,953.23 2,046.35 2.140.07 2,232.63 -154.10 -162.72 -170.64 -177.30 6,03343682 8,033,529.91 6,033,623.60 6,033,716.13 1,660,497.97 1,050 489. 11 1,660,480.93 1,660474.01 0.48 0.37 0.64 0.88 154,10 MWD+IFR-AK-CAZ-SC(4) 162.72 MWD+IFR-AK-CAZ-SC(4) 170.64 MWD+IFR-AK-CAZ-SC (4) 177.30 MWD+IFR-AK-CAZ-SC(4) 532017 3:02:52PM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: 3R-101 North Reference: Wellbore: 3R-101 Survey Calculation Method: Design: 3R-101 Database: Well 3R-101 3R-101 actual @ 49,OOusft (Doyon 142) 3R-101 actual @ 49.00usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey MD Inc Azi TVD TVDSS +N/ -S +E/ Map Map Vertical (usft) (1) (1 -W Northing Easting DLS Section (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,341.81 81.29 357.42 2,893.81 2,844.81 2,325.99 -182.42 6,033,80946 1,660.468.64 1.17 182.42 MWD+IFR-AK-CAZ-SC(4) 4,436.87 81 31 358.76 2.908.19 2,859.19 2,419.90 -185.56 6,033,903.36 1,660,465.25 1.39 185.56 MWD+IFR-AK-CAZ-SC (4) 4,532.86 81.46 359.12 2,922.57 2,873.57 2,51479 -187.31 6,033,998.23 1,660,463.24 0.40 187.31 MWD+IFR-AK-CAZ-SC(4) 4,627.23 81.49 358.61 2,936.56 2,887.56 2,608.10 -189.16 6,034,091.53 1,660,461.14 0.54 189.16 MWD+IFR-AK-CAZ-SC 14) 4,722.52 81.62 358.05 2,950.56 2,901.56 2,702.31 -191.91 6,034,185.73 1,660,458.13 0.60 191.91 MWD+IFR-AK-CAZ-SC (4) 4,816.15 81.17 357.64 2,964.57 2,915.57 2,794.82 -195.39 6,034,278.22 1,660,454.40 0.65 195.39 MWD+IFR-AK-CAZ-SC(4) 4,910.05 81.65 357.59 2,978.59 2,929.59 2,887.59 -199.25 6,034,370.96 1,660,45028 0.51 199.25 MWD+IFR-AK-CAZ-SC(4) 5.005.50 81.45 357.34 2,992.62 2,943.62 2,981.91 -203.43 6,034,465.26 1,660,445.85 033 203.43 MWD+IFR-AK-CAZ-SC (4) 5,099.31 8043 356.19 3,007.39 2,958.39 3,07440 -208.65 6,034,557.73 1,660,440.37 1.63 208.65 MWD+IFR-AK-CAZ-SC(4) 5,194.23 79.74 356.96 3,023.73 2,974.73 3,167.73 -214.24 6,D34,651.04 1,660,434.53 1.08 214.24 MWD+IFR-AK-CAZ-SC(4) 5,28813 80.17 357.41 3,040.22 2,991.22 3,260.67 -218.81 6,034,743.95 1,660,429,71 0.65 218.81 MWD+IFR-AK-CAZ-SC(4) 5,384.03 80.16 355.85 3,D55A9 3,007.49 3,354.41 -224.32 6,034,837.66 1,660,423.95 1.60 224.32 MWD+IFR-AK-CAZ-SC(4) 5,478.50 80.16 355.01 3,072.64 3,023.64 3,447.19 -231.73 6,034,93042 1,660,41629 0.89 231.73 MWD+IFR-AK-CAZ-SC(4) 5,574.37 79.88 352.33 3,089.26 3,040.26 3,541.03 -242.14 6,035,024.21 1,660,40562 2.77 242.14 MWD+IFR-AK-CAZ-SC(4) 5,668.19 80.05 352.29 3,10561 3,056.61 3,632.58 -254.50 6,035,115.73 1,660,39301 0.19 254.50 MWD+IFR-AK-CAZ-SC(4) 5,762.98 79.70 350.63 3,122.27 3,07327 3,724.85 -268.36 6.035,207.95 1,660,378.91 1.76 268.36 MWD+IFR-AK-CAZ-SC(4) 5,858.90 79.93 350.94 3,13923 3,090.23 3,818.04 -283.48 6,035.301.09 1,660,363.54 0.40 283.48 MWD+IFR-AK-CAZ-SC(4) 5.953.58 79.83 352.59 3.155.87 3,106.87 3,910.29 -296.83 6,035,39329 1,650,349.94 1,72 296.83 MWD+IFR-AK-CAZ-SC(4) 6,048.38 7938 35357 3,172.65 3,123.65 4,002.91 308.07 6,035,485.87 1,660,336.44 1.02 308.07 MWD+IFR-AK-CAZ-SC(4) 6,142.31 80.65 351.82 3,188.61 3,139.61 4,09432 -319.84 6.035 577,64 1,660.32643 2.06 319.84 MWD+IFR-AK-CAZ-SC(4) 6,237.62 80.49 349.06 3,204.23 3,155.23 4,187.42 -335.45 6,035,670.29 1,660,310.56 2.86 33545 MWD+IFR-AK-CAZ-SC(4) 6,332.89 80.84 348.35 3,21969 3,170.69 4,279.61 -35386 6,035.762.42 1,660,291.90 0.82 353.86 MWD+IFR-AK-CAZ-SC(4) 6,427.09 80.50 345.89 3,234.96 3,185.96 4,370.22 -374.58 6,035,852.96 1,660,270.94 2.80 374.58 MWD+IFR-AK-CAZ-SC (4) 6,521.45 80.15 344.77 3,250.82 3,201.82 4,460.20 -398.14 6,035,942.87 1,660,247.14 1.23 398.14 MWD+IFR-AK-CAZ-SC(4) 6,615.67 79.69 34322 3,267.31 3,218.31 4,549.37 -423.71 6,036,031.96 1,6W,221 32 1.69 423.71 MWD+IFR-AK-CAZ-SC(4) 6,710.05 80.09 339.00 3,283.88 3,234.68 4,637.26 -053.79 6,036,11978 11660,191.01 4.42 45339 MW0+1FR-AK-CAZ-SC(4) 6,802.95 79.71 338.08 3,300.18 3,251.18 4,722.38 -487.25 6,036,204.78 1,660,157.32 1.06 487.25 MWD+IFR-AK-CAZ-SC(4) 6,898.97 79.47 335.69 3,317.53 3,268.53 4,809.23 -524.32 6,036,291.52 1,660,120.02 2.46 524.32 MWD+1FR-AK-CAZ-SC (4) 6,993.80 78.57 334.02 3,335.59 3,286.59 4,893.50 -563.87 6,036,375.67 1,660,08024 1.97 563.87 MWD+IFR-AK-CAZ-SC(4) 7,088.66 77.01 334.51 3,355.65 3,306.65 4,977.01 -604.13 6,03,45907 1,66,039.76 172 604.13 MWD+IFR-AK-CAZ-SC(4) 7,183.15 78.05 332.54 3,376.06 3327.06 5.059.59 $1526 6,036,541.52 1,659,998.41 2.31 645.26 MWD+IFR-AK-CAZ-SC(4) 7,277.04 78.65 332.66 3,395.02 3,346.02 5,141.23 -687.58 6,036,623.04 1,659,955.87 0.65 687.58 MWD+IFR-AK-CAZ-SC(4) 7,370.87 79.07 330.57 3,413.15 3,364.15 5,222.22 -731.34 6,036,703.90 1,659,911.89 2.23 731.34 MWD+IFR-AK-CAZ-SC(4) 7,466.77 81.05 330.18 3,429.70 3,380.70 5.304.33 -778.03 6,036,785.87 1,859,864.98 2.10 778.03 MWD+IFR-AK-CAZ-SC(4) 7,561.29 82.67 327.76 3,443.09 3,394.09 5,364.49 -826.27 6,036,865.90 1,659,816.54 3.06 826.27 MWD+IFR-AK-CAZ-SC (4) 7,654.42 8363 323.12 3,454.20 3,40520 5,460.62 -878.71 6,036,941.87 1,659,763.90 5.05 878.71 MWD+IFR-AK-CAZ-SC(4) 7,749.17 83.29 318.54 3,465.00 3,416.00 5,533.58 -938.15 6,037,014.66 1.659,70426 4.82 938.15 MWD+IFR-AK-CAZ-SC(4) 7,843.93 83.31 316.31 3,476.05 3,427.05 5,602.88 -1,001.81 6,037,083.78 1,659,640.41 2.34 1.001.81 MWD+IFR-AK-CAZ-SC (4) 7,937.29 83.12 31316 3,487.09 3,43809 5,668.12 -1,067.66 6,037,148.84 1,659,57439 3.36 1,067.% MWD+IFR-AK-CAZ-SC(4) 7.9W,65 82.66 310.87 3,492.45 3,443.45 5,696.91 -1,099.63 6,037,177.55 1,659,542.35 535 1,099.63 MWD+IFR-AK-CAZ-SC (4) 53/2017 3:02:52PM Page 4 COMPASS 5000.1 Build 74 Company: ConowPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3R Pad Well: 3R-101 Wellbore: 3R-101 Design: 3R-101 Survey Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3R-101 3R-101 actual @ 49.00usft (Doyon 142) 3R-101 actual @ 49.00usft (Doyon 142) True Minimum Curvature OAKEDMP2 MD Inc Azi TVDNDSS +N/S +E/ -W Map Map Vertical (usft) V) Northing Easting DLS Section (1) (usft) (usft) (usft) (usft) (ft) (ft) (x/100') (ft) Survey Tool Name 8,026.55 82.82 31075 3,498.26 3,449.26 5.726.67 -1,134.09 6,037,207.21 1,659,507.82 0.43 1,134.09 MWD+IFR-AK-CAZ-SC(4) 8,10269 84.02 308.30 3,506.98 3,457.98 5,774.80 -1,19243 6.037,255.17 1,659,44935 3.56 1,192.43 MWD+1FR-AK-CAZ-SC(5) 8,196.27 83.30 307.17 3,517.32 3,468.32 5,831.72 -1,265.98 6,037,311.89 1,659,375.65 1.43 1,265.98 MWD+IFR-AK-CAZ-SC(5) 8,290.64 80.09 306.79 3,530.94 3,481.94 5,887.89 -1,340.57 6,037,367,84 1,659,300.92 3.42 1,340.57 MWD+IFR-AK-CAZ-SC(5) 8,38581 78.59 302.73 3,548.56 3,499.56 5,941.21 -1,417.38 6,037,420.95 1,659,223.97 448 1,417.38 MWD+IFR-AK-CAZ-SC(5) 8,480.48 82.05 294.76 3.564.50 3,515.50 5,986. D1 -1,499.13 6,037.465.52 1,659,142.10 9.07 1,499.13 MWD+IFR-AK-CAZ-SC(5) 8,575.24 8675 290.20 3,573.75 3,524.75 6,022.04 -1,586.23 6,037,501.31 1,659,054.91 689 1,586.23 MWD+IFR-AK-CAZ-SC(5) 8,669.02 86.22 286.91 3,579.50 3,530.50 6,051.82 -1,674.96 6,037,530.85 1,658,966.11 3.55 1,674.96 MWD+IFR-AK-CAZ-SC(5) 8,76377 89.34 281.26 3,583.17 3,534.17 6,074.84 -1766.74 6,037,553.62 1,658,874.28 6.81 1766.74 MWD+IFR-AK-CAZ-SC(5) 8,859.11 89.82 275.16 3,583.87 3,534.87 6,088.45 -1,861.06 6,037,566.97 1,658,779.93 6.42 1,861,06 MWD+IFR-AK-CAZ-SC(5) 8,954.08 89.52 271.80 3,584.42 3,535.42 6,094.21 -t%5.84 6,037,572.47 1,656,685.15 3.55 1,955.84 MWD+IFR-AK-CAZ-SC (5) 9,047.67 86.64 271.51 3,587.55 3,538.55 6,096.92 -2,049.33 6,037,57492 1.658591 66 3.09 2,049.33 MWDHFR-AK-CAZ-SC (5) 9,141.11 87.22 269.20 3,592.56 3,543.56 6,097.49 -2.14263 6,037,575.24 1,658,498.37 2.55 2,142.63 MWD+IFR-AK-CAZ-SC(5) 9,234.58 88.14 268.86 3,596.34 3,547.34 6,095.91 -2.236.00 6,037,57341 1,658,405.01 1.05 2,236.00 MWD+IFR-AK-CAZ-SC(5) 9.327.48 88.28 269.08 3,599.24 3,550.24 6,094.24 -2,328.84 6,037,571.49 1,658,312.18 0.28 2,328.84 MWD+1FR-AK-CAZ-SC(5) 9,420.78 85.20 269.92 3.604.55 3,555.55 6,09343 -2,421.98 6,037,570.42 1,658,219.06 3.42 2,421.98 MWD+IFR-AK-CAZ-SC(5) 9,516.25 84.52 269.32 3,613.10 3,564.10 6,092.80 -2,517.06 6,037,569.53 1.658,123.99 0.95 2,517.06 MWD+IFR-AK-CAZ-SC(5) 9,608.D9 84W 270.04 3,622.24 3,573.24 6,092.29 -2,60844 6,037,56877 1,658,032.62 0.93 2,608.44 MWDHFR-AK-CAZ-5C(5) 9,661.16 83.25 270.35 3,628.10 3,579.10 6,092.47 -2,661.19 6,037,568.81 1,657,979.88 1.63 2,661.19 MWD+IFR-AK-CAZ-SC(5) 9732.00 87.88 26909 3,633.58 3,584.58 6,092.12 -2,73139 6,037,56827 1657.909.28 6.77 2,731.79 NOT an ACdlal Survey 96181, 9,759.17 89.65 268.61 3,634.17 3,585.17 6.091.58 -2,758.95 6,037,567.65 1,657,882.13 6.77 2,758.95 MWD+IFR-AK-CAZ-SC(6) 9,833.36 94.14 26920 3,631.72 3,582.72 6.090.16 -2,833.07 6,037,566.03 1,657,808.02 6.10 2,833.07 MW0+1FR-AK-CAZ-SC(6) 9,866.63 94.14 269.73 3,629.31 3,580.31 6,089.85 -2,866.25 6,037,56563 1,657,774.84 1.59 2,866.25 MWD+IFR-AK-CAZ-SC (6) 9,897.97 92.76 270.04 3,627.43 3,578.43 6.08939 -2.897.53 6,037,565.48 1,657,743.57 4.51 2,897.53 MWD+1FR-AK-CAZ-SC(6) 9,928.22 92.08 270.31 3.626.15 3,577.15 6,089.88 -2,927.75 6,037,565.49 1,657,713.35 242 2,927.75 MWD+1FR-AK-CAZ-SC(6) 10,023.41 92.76 269.53 3,622.13 3,573.13 6,08975 -3,022.86 6,037,565.10 1,657,618.25 1.09 3,022.86 MWDHFR-AK-CAZ-SC(6) 10,117.85 93.M 270.13 3,616.73 3,567.73 6,089.47 -3,117.14 6,037,564.56 1,657,523.98 1.27 3,117.14 MWDHFR-AK-CAZ-SC(6) 10,212.79 93.29 270.25 3,610.86 3,561.86 6,089.78 -3,2119D 6,037,564.62 1,657,42923 0.55 3,211.90 MWD+IFR-AK-CAZ-SC(6) 10,307.57 9339 26990 3,605.01 3,556.01 6,089.90 -3,306.50 6,037,56449 1,657,33464 0.64 3,306.50 MWD+IFR-AK-CAZ-SC(6) 10,401.81 91.64 269.15 3,600.54 3,551.54 6,089.12 -3,400.62 6,037,56345 1,657,240.53 2.42 3,40062 MWD+1FR-AK-CAZ-SC(6) 10,496.69 91.51 270.21 3,597.93 3,548.93 6,068.59 -3,49546 6,037,562.66 1,657.145.70 1.13 3,495.46 MWD+IFR-AK-CAZ-SC(6) 10,590.58 9280 269.42 3,594.40 3,545.40 6,088.29 -3,589.28 6,037,562.10 1,657,051.89 1.61 3,589.28 MWD+IFR-AK-CAZ-SC(6) 10,685.98 92.53 268.72 3,589.97 3,540.97 6,086.74 -3,684.57 6,037,560.30 1,656,956.62 0.79 3,684.57 MWD+IFR-AK-CAZ-SC(6) 10,780.52 89.80 267.93 3,588.05 3.539.05 6,083.98 -3,779.04 6,037,557.28 1,656,862.17 3.01 3,779.04 MWD+1FR-AK-CAZ-SC (6) 10,875.11 89.74 266.77 3,58843 3,539.43 6,079.61 -3,873.52 6,037.55265 1,656,767.70 123 3,873.52 MWD+IFR-AK-CAZ-SC (6) 10,970.04 89.49 26688 3,589.06 3,540.06 6,074.35 -3,968.30 6,037,547.13 1,656,67294 0.29 3,968.30 MWD+IFR-AK-CAZ-SC(6) 11,064.25 90.36 266.63 3,589.19 3,540.19 6,069.02 4.062.36 6,037,541.54 1,658,578.91 0.96 4,062.36 MWD+IFR-AK-CAZ-SC(6) 11,159.90 90.13 26731 3,588.78 3,539.78 6,063.96 -4,157.88 6,037,53623 1,656,483.42 015 4,157.88 MWD+1FR-AK-CAZ-SC(6) 11,254.04 88.93 268.33 3,589.55 3,540.55 6,060.38 -4,251.94 6,037,53239 1,656,389.37 1.67 4,251.94 MWD+1FR-AK-CAZSC(6) 5!32017 3:02:52PM Page 5 COMPASS 5000 1 Build 74 Definitive Survey Report Company: ConowPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: 3R-101 North Reference: Wellbore: 3R-101 Survey Calculation Method: Design: 3R-101 Database: Well 3R-101 3R-101 actual @ 49.00usft (Doyon 142) 3R-101 actual @ 49,00usft (Doyon 142) True Minimum Curvature OAKEDMP2 711,348,9987�87 Azi TVD TVOSS +N/ -S +E/ -W Map Map Vertical Northing Easting DLS Section (°) (usft) (usft) (usft) (waft) (ft) (ft) (°/100') (ft) Survey Tool Name 267.89 3,59220 3,543.20 605725 4,346.80 6,037,529.00 1,656,294.53 1.21 4,34680 MWD+IFR-AK-CAZ-SC(6) 266.91 3,59503 3,546.03 6,052.99 -4,440.64 6,037,524.49 1,656,200.71 1.35 444064 MWD+IFR-AK-CAZ-SC(6),.266.46 3,596.84 3,547.84 6,047.54 -4,534.67 6,037,518.78 1,656,106,71 0.67 4,53467 MWD+IFR-AK-CAZ-SC(6) 11,630,87 91.76 266.29 3,596.12 3,547.12 6,041.62 -4,628.17 6,037,512.61 1,656,013.24 2.82 4,628.17 MWD+IFR-AK-CAZ-SC(6) 11,726.12 93,05 26457 3,592.12 3,543.12 6,034.04 4,723.03 6,037,504.77 1,655,918,41 2.26 4,723.03 MWD+IFR-AK-CAZ-SC(6) 11,82025 91.43 265.91 3,588.44 3,539.44 6.026.23 -0,816.75 6,037,496.71 1,655,824.71 2.23 4,816.75 MWD+IFR-AK-CAZ-SC(6) 11,915.43 89.63 266.37 3,587.56 3,538.56 6,019.83 -4,91171 6,037,490.05 1,655,729.78 1.95 4,91171 MWD -IFR -AK-CAZ-SC(6) 12,010.04 89.02 267.30 3,588.68 3,53968 6,014.60 -5,006.17 6,037,484.57 1,655,635.35 1.18 5,006.17 MWD+1FR-AK-CAZ-SC(6) 12,105.17 89.89 268.21 3,58958 3,540.58 6,010.88 5,101.22 6,037,480.58 1,655,540.32 1.32 5,101.22 MWD+IFR-AK-CAZ-SC(6) 12,198.99 90.23 269.01 3,589.48 3,54D.48 6,008.60 -5,195.01 6,037,478.05 1,655,446.54 0.93 5,195.01 MWD+IFR-AK-CAZ-SC(61 12,293.90 90.36 269.37 3,589.00 3,540.00 6,007.26 -5,289.91 6,037,476.45 1,655,351.66 0.40 5,289.91 MWD+IFR-AK-CAZ-SC (6) 12,388.39 9087 269.16 3,587.98 3.538.98 6,006.05 -5,384.39 6,037,474.98 1,655,257.20 0.58 5,384.39 MWD+IFR-AK-CAZ.SC(6) 12,482.54 9029 271.49 3,587.03 3.538.03 6,006.58 -5,478.52 6,037,475.26 1,655.163.07 2.55 5,478.52 MWD+IFR-AK-CAZ-SC(6) 12,577.56 90.38 270.88 3,586.47 3,537.47 6,008.55 -5,573.52 6,037,476.96 1.655,06807 0.65 5,573.52 MWD+IFR-AK-CAZ-SC(6) 12,672.32 89.54 270.66 3,586.54 3,537.54 6,00982 -5,668.27 6,037.477.98 1,654,973.33 0.92 5,668.27 MWD+IFR-AK-CAZ-SC(6) 12,766.67 88.68 269.52 3,588.00 3,539.00 6,009.97 -5,762.61 6,037,477.87 1,654,879.00 1.51 5.76261 MWD+IFR-AK-CAZ-SC(6) 12,881.96 89.29 269.09 3,589.69 3,540.69 6,008.81 -5,857.87 6,037,476.46 1,654,783.75 0.78 5,857.87 MWD+IFR-AK-CAZ-SC(6) 12,956.58 89.37 267.85 3,590.80 3,541,80 6,006.29 -5,952.45 6,037,473.67 1,654,689.19 1.31 5.952.45 MWD+IFR-AK-CAZ-SC(6) 13,051.01 89.39 267.13 3,591.82 3,542.82 6,002.15 -6,046]9 6.037,469.28 1,654.59487 0.76 6,046.79 MWD+IFR-AK-CAZ-SC 16) 13,145.43 8962 266.35 3,592.64 3,543.64 5,996.78 -6,141.05 6,037,463.66 1,654,50064 0.86 6,141.05 MWD+IFR-AK-CAZ-SC(6) 13,239.35 89.78 267.20 3,593.13 3,544.13 5,99150 -6,234.82 6,037,458.12 1,654,406.89 0.92 6,234.82 MWD+IFR-AK-CAZ-SC(6) 13,334.20 90.50 267.64 3,592.90 3,543.9D 5,987.23 -6,329.57 6.037,453.59 1,654,312.16 0.89 6,329.57 MWD+IFR-AK-CAZ-SC(6) 13,428.00 90.15 268.86 3,592.36 3,543.36 5,984.37 -6,423.32 6,037,45047 1.6U.218 42 1.35 6,423.32 MWD+IFR-AK-CAZ-SC 16) 13,523.58 90.56 269.81 3,59117 3,54237 5,983.26 -6,518.89 6,037,449.10 1,654,12287 1.08 6,518.89 MWD+IFR-AK-CAZ-SC(6) 13.617.44 91.34 270.31 3,590.22 3,541.22 5,983.35 -6,612.74 6,037,448.94 1,654,029.03 0.99 6,612.74 MWD+IFR-AK-CAZ-SC (6) 13,711.39 91.76 270.50 3,587.67 3,538.67 5,98402 -6,70665 6,037,449.35 1,653,935.13 0.49 6,706.65 MWD+IFR-AK-CAZ-SC(6) 13,806.55 91.01 270.08 3,585.37 3,536.37 5,984.50 -6,801.78 6,037,449.57 1,653,84000 0.90 6,80178 MWD+IFR-AK-CAZ-SC(6) 13,902.28 90.69 268.97 3.583.95 3,534.95 5,983.71 -6,897.50 6,037,448.52 1,653,744.30 1.21 6,897.50 MWD+IFR-AK-CAZ-SC(6) 13,99729 91.04 269.35 3,582.52 3,533.52 5,982.31 -6,992.49 6,037,446.87 1,653,649.33 0.54 6,992.49 MWD+IFR-AK-CAZ-SC(6) 14,091.98 90.45 269.72 3,581.29 3,532.29 5,981.54 -7,087.16 6,037,445.84 1,653,554.66 074 7.087.16 MWD+IFR-AK-CAZ-SC(6) 14,186.89 89.93 269.32 3,580.97 3,531.97 5,980.75 ,7,182.07 6,037,44479 1,653.459.77 0.69 7,182.07 MWD+IFR-AK-CAZ-SC(6) 14,281.03 89.93 268.32 3,581.09 3,532.09 5,978.81 -7,276.19 6,037,442.59 1,653,355.66 106 7,276.19 MWD+IFR-AK-CAZ-SC (6) 14,375.64 90.47 268.91 3,580.76 3,531.76 5,976.52 -7,370.77 6,037,440. 05 1,653,271.10 0.85 7,370.77 MWD+IFR-AK-CAZ-SG(6) 14,470.32 90.19 267.72 3,580.21 3,531.21 5,973.74 -7,465.40 6,037,437.01 1653.176.46 1.29 7,465.40 MWD+IFR-AK-CAZ-SC(6) 14,564.91 90.33 267.19 3,579.78 3,53078 5,969.54 -7,559.90 6,037,432.55 1,653,082.00 0.56 7,559.90 MWD+IFR-AK-CAZ-SC(6) 14,659.01 90.98 267.33 3,57871 3,529.71 5,965.04 -7,653.89 6,037,42780 1,652,98804 0,71 7,653.89 MWD+IFR-AK-CAZ-SC 16) 14,753.97 90.95 267.32 3,577.11 3,528.11 5,960.61 -7,748.73 6,037,423,11 1,652,893.22 0.03 7,748.73 MWD+IFR-AK-CAZ-SC(6) 14,848.83 90.44 266.54 3,575.96 3,526.96 5,955.53 -7,843.44 5037,417.77 1,652,798.53 0.98 7,843.44 MWD+IFR-AK-CAZ-SC(6) 14,943.45 90.M 267.19 3,575.30 3,526.30 5,950.36 -7,937.92 6,037,412.34 1.652,704.08 0.69 7,93].92 MWD+IFR-AK-CAZ-SC(6) 15,038.10 90.37 268.50 3,57469 3,52569 5,946.80 -8,032.50 6,037,40853 1,652,609.52 1.38 8,032.50 MWD+IFR-AK-CAZ-SC(6) 5,32017 3:02:52PM Page 6 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConowPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit ND Reference: 3R-101 actual @ 49.00usn (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101 Database: OAKEDMP2 Survey MD Inc Azi ND NDSS +N/ -S +E/ Map Map Vertical (usft) (°) (°) -W Northing Easing OLS Section (usft) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) Survey Tool Name 15,131.86 90.37 268.87 3,574.09 3,525.09 5,944.65 -8,126.23 6,037,406.12 1,652,515.80 0.39 8,12623 MWD+IFR-AWCAZ-SC(6) 15,226.78 89.93 269.42 3,573.84 3,524.84 5,943.23 -8,221.14 6,037,404.44 1,652,420.90 0.74 8,221.14 MWD+1FR-AK-CAZ-SC (6) 15,321.30 89.75 269.65 3,574.10 3,525.10 5,942.46 -8,315.66 6.037,403.42 1,652,326.10 0.31 8,315.66 MWD+1FR-AK-C42-SC(6) 15,414.45 90.07 270.01 3,574.25 3,525.25 5,942.19 -8,408.81 6,037,402.89 1,652,233.26 0.52 8,408.81 MWD+IFR-AK-CAZ-SC 16) 15,507.31 9364 270.12 3,571.25 3,522.25 5,942.29 -8,501.60 6,037,402.74 1,652,140.47 385 8,50160 MWD+IFR-AK-CAZ-SC(6) 15,600.26 9365 271.36 3,565.34 3,516.34 5,943.49 -8,594.36 6,037,403.69 1.652,047.73 1.33 8,594.36 MWD+IFR-AK-CAZ-SC(6) 15,69342 92.61 27085 3,560.25 3,511.25 5,945.28 -8,687.36 6,037,405.23 1,651,954.73 124 8,687.36 MWD+IFR-AK-CAZ-SC 16) 15.787.08 9232 269.46 3,556.22 3,50722 5,945.54 -8,780.93 6,037,405.23 1,651,861.17 1.51 8,780.93 MWD+IFR-AK-CAZ-SC (6) 15,880.15 9154 268.90 3,553.09 3,504.09 5,944.20 ,8,873.93 6,037,40364 1,651,768.17 1.03 8,873.93 MWD+IFR-AK-CAZ-SC(6) 15,966.00 90.67 268.96 3,55143 3,502.43 5,942.61 -8,959.75 6,037,401.81 1,651.68237 1.01 8,959.75 NOT an AdualSwvey 4-1/2" 15,973.36 90.60 268.97 3,551.35 3,502.35 5.942.47 -8,967.11 6,037,40166 1,651,675.01 1.01 8.967.11 MWD+IFR-AK-CAZ-SC(6) 16,067.10 91.94 268.09 3,549.27 3,500.27 5,940.07 -9,060.79 6,037,399.00 1,651,581.35 171 9,060.79 MWD+IFR-AK-CAZ-SC(6) 16,160.48 94.61 268.39 3,543.93 3,494.93 5,93721 -9,153.97 6,037,395.88 1,651,488.19 2.88 9,153.97 MWD+IFR-AK-CAZSC(6) 16,253.74 96.61 269.15 3,534.82 3,485.82 5,935.21 -9,246.76 6,037,39363 1,651,395.42 2.29 9,246.76 MWD+IFR-AK-CAZ-SC(6) 16,346.30 98.19 270.30 3,522.90 3,473.90 5,934.77 -9,338.54 6,037,392.94 1,651,303.64 2.11 9,338.54 MWD+IFR-AK-CAZ-SC (6) 16,369.03 97.80 270.86 3,519.74 3,470.74 5,935.00 -9,351.05 6,037,393.11 1,651,281.14 2.98 9,361.05 MWD+IFR-AK-CAZ-SC (6) 16,433.00 97.80 270.86 3,511.05 3,462.05 5,935.95 -9,424.42 6,037,39389 1,651,217.77 0.00 9,424.42 PROJECTED to TD Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved, Yes ❑ No I have checked to the best of my ebitity that the followkg dee is correct A Surface Coordinates _7 Declination & Convergence 0 GRS Survey Corrections p Survey Tool Codes SLB DE Brandon Temple aty 9b Id!516I 4n TOMm Client Representative: Ben Tolman tba � ^' °SNA°"e102°°aa9'Dgrp 4W7 Date: 502017 513/2017 3:02-52PM Page 7 COMPASS 5000.1 Build 74 P7P 717—D/3 Loepp, Victoria T (DOA) From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Friday, April 07, 2017 11:34 AM To: Loepp, Victoria T (DOA); Schwartz, Guy L (DOA) Cc: Bearden, J Daniel; Alvord, Chip; Hayden, Philip Subject: RE: PTD: 217-013 Follow Up Flag: Follow up Flag Status: Flagged Victoria and Guy, I hope your Friday is going well Along the same lines as our previous email/communication; we wanted to pre-emptively reach out prior to the weekend and inform the AGOCC of our plans forward over the weekend. We have just started drilling ahead in our lower lateral section and anticipate reaching TD sometime over the weekend or early Monday morning. Our current plan is to drill the production lateral with the same target objectives and bottom hole location as previously proposed / permitted (no change in x, y, or TVD). However; due to the longer directional profile in our intermediate section; reaching those objective targets / bottom hole location will require a greater measure depth than our originally proposed / permitted measure depths (greater than 500' MD). If there are any questions/comments, please do not hesitate to reach out and contact us. I hope you have a great weekend. Thanks, Ben Tolman Drilling Engineer 1 ConocoPhillips, Alaska (907)265-6828(o)1(307) 231-3550(m) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov) Sent: Sunday, April 02, 2017 12:17 AM To: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Cc: Schwartz, Guy L (DOA) <guy.schwa rtz@alaska.gov> Subject: [EXTERNAL]Re: PTD: 217-013 (Resent due to incorrect email) Ben, We have received your notification and understand your target BHL has not changed although the directional profile has changed. Approval is granted to drill ahead. Victoria Sent from my iPhone On Apr 1, 2017, at 10:52 PM, Tolman, Ben V <Ben V Tolman(aDconocophillips com> wrote: Good evening Victoria and Guy, I apologize if you are getting a duplicate email. I received automated undelivered emails on my original email; so I resending to all. Please see original email below. Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907) 265-6828 (o) 1 (307) 231-3550 (m) From: Tolman, Ben V Sent: Saturday, April 01, 2017 10:42 PM Subject: PTD: 217-013 Good evening Victoria and Guy, Due to our interpretation of 20 AAC 25.015 "Changes to a program in a permit to drill"; we want to pre- emptively inform the AOGCC of our plans to drill ahead to approved PTD target this evening. We are currently drilling the intermediate hole section of the 311-101. Due to formation and steering difficulties we have needed to adjust our directional profile as we approach our objective formation/targets. Although our targets through the lateral or bottom hole location have not changed (X,Y, or TVD); we do anticipate landing our intermediate hole section 100'— 200' north of our planned line (with the intent to drill back to our planned line through the production hole lateral), and potentially a measured depth greater than our proposed/permitted intermediate setting depth (potentially greater than 500' MD). In short, our targets have not changed; however, due to the steering difficulties in soft formations, it has taken us a longer path (measured depth) to get there. Please contact us with any questions or clarifications. Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907) 265-6828 (o) 1 (307) 231-3550 (m) Victoria T From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Saturday, April 01, 2017 10:53 PM To: Loepp, Victoria T (DOA); Schwartz, Guy L (DOA) Cc: Alvord, Chip; Bearden, 1 Daniel; Hayden, Philip Subject: RE: PTD: 217-013 (Resent due to incorrect email) Follow Up Flag: Follow up Flag Status: Flagged Good evening Victoria and Guy, I apologize if you are getting a duplicate email. I received automated undelivered emails on my original email; so I resending to all. Please see original email below. Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(0)1(307) 231-3550(m) From: Tolman, Ben V Sent: Saturday, April 01, 2017 10:42 PM Subject: PTD: 217-013 Good evening Victoria and Guy, Due to our interpretation of 20 AAC 25.015 "Changes to a program in a permit to drill"; we want to pre-emptively inform the AOGCC of our plans to drill ahead to approved PTD target this evening. We are currently drilling the intermediate hole section of the 311-101. Due to formation and steering difficulties we have needed to adjust our directional profile as we approach our objective formation/targets. Although our targets through the lateral or bottom hole location have not changed (X,Y, or TVD); we do anticipate landing our intermediate hole section 100' — 200' north of our planned line (with the intent to drill back to our planned line through the production hole lateral), and potentially a measured depth greater than our proposed/permitted intermediate setting depth (potentially greater than 500' MD). In short, our targets have not changed; however, due to the steering difficulties in soft formations, it has taken us a longer path (measured depth) to get there. Please contact us with any questions or clarifications. Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(0)1(307)231-3550(m) rb 2152 -0 13 Victoria T From: Sullivan, Michael <Michael.Sullivan@conocophillips.com> Sent: Tuesday, May 02, 2017 4:23 PM To: Loepp, Victoria T (DOA) Cc: CPF3 Prod Engrs; Driscoll, Michael D Subject: 311-101 SSSV and No Flow Test Question Follow Up Flag: Follow up Flag Status: Flagged Victoria, We recently drilled production well 311-101 and completed it with a packer -less ESP. Before pre -production starts, we would like some clarification regarding the SSSV and NFT. Our plan is to bring well 311-101 on production without a SSSV. It is our interpretation from AOGCC 20 AAC.25.265 that production wells with ESP's do not require SSSV's. Because of this, we do not plan to perform a NFT on well 3R-101. Can you clarify our interpretation? Is our proposed plan acceptable? Thanks in advance, Michael Sullivan Viscous Petroleum Engineer ConocoPhillips Alaska Office: 907-263-4123 Cell: 907-231-9953 AOGCC 20 AAC 25.265 states that production wells completed with electric submersible pumps are not required to have SSSV's (d) Ill addition to meeting the other requirements of this section. the followit must be equipped witil a fail-safe automatic surface controlled substuface safety vale preventing all uncontrolled flow of fluid from the well's tubing: (1) a well that is capable of tutassisted flow of hydrocarbons to sti fat has all offshore surface location: (2) a well that is capable of mlassisted flow of hydrocarbons to surfa, has an onshore surface location that is 660 feet or less of (A) a pertimnent dwelling intended for Unman occupancy. inc billeting camp or private residence: (B) an occupied commercial building. excluding a structure h within an existing oil or gas field: (C) a road accessible to the public: (D) all operating railway. (E) a govermnent maintained airport runway: (F) a coast line ureasured at mean high water: (G) a public recreational facility: or (H) navigable waters as defined by the United States Army Cot Engineers in 33 C.F.R. Part X29.4 with boundaries defined in 353 C.F.R. (1) a well that the conuuission determines. after notice and all oppomu hearing in accordance wit1120 AAC 25.540. must be equipped with a substuface safetN (4) an onshore well ill a location described tulder (2) of this subsection equipped with an electric submersible ptuup or capillary string run within the tttbiva is 0 required to be equipped with a substuface safety valve: THE STATE Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR BILL WALKER Graham Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Re: Kuparuk River Field, West Sak Oil Pool, KRU 3R-101 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-013 Surface Location: 1630.5' FNL, 2959.2' FEL, Sec. 9, T13N, R9E, UM Bottomhole Location: 894.73' FNL, 2207.21' FEL, Sec. 6, TI 3N, R9E, UM Dear Mr. Alvord: Enclosed is the approved application for 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, Cathy 1Y Foerster Chair DATED this N6 day of March, 2017. STATE OF ALASKA M A OIL AND GAS CONSERVATION COMMS )N PERMIT TO DRILL 20 AAC 25 005 urir.Ir.IvCv JAN 2 5 2017 AOGCC 1a. Type of Work: Proposed Well Class: Exploratory - Gas Service- WAG ❑ Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑✓ Lateral fb. StratigraphicTest ❑ Development -Oil ❑� Service - Winj ❑ Single Zone ❑� Coalbed Gas ❑ Gas Hydrates ❑Redrill❑ Reentry Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑� . Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • V4LU 3R-101 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 16313' • ND: 3502' Kuparuk River Field West Sak Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): j,.oj Surface: 1630.5' FNL, 2959.2' FEL, Sec9, T13N, R9E, UM ADL. 355023, ADL355024 M Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 908.64' FNL, 360.57' FEL, Sec5, T13N, R9E, UM 931933000/931934000 3/1/2017 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 894.73' FNL, 2207.21' FEL, Sec6, T13N, R9E, UM 3255, 1800 895' to ADL391283 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 48.9' . 15. Distance to Nearest Well Open Surface: x-520,625.98' y- 6,031,732.16' Zone -4 . GL Elevation above MSL (ft): 9.9' . to Same Pool: 985'toNIKOPI2-01 16. Deviated wells: Kickoff depth: 400 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 94.53 degrees , Downhole: 1660 . ✓ Surface: 1289 r 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) 20" 78.7# H-40 Welded 78' JSurf Surf 117' 117' Existing 16 13-3/8" 68# L-80 HYD563 2313' Surf Surf 2351' 2200' 1193 sx 11 ppg 1235 sx 12 ppg 12.25 9-5/8" 40# L-80 HYD563 9150' Surf Surf 9188' 3615' 1605 sx 15.8 ppg Class G . 5 4-1/2" 12.6# L-80 TXP 7193' 9120' 3613' 16313' 3502' N/A Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (tt): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑✓ Seabed Report ❑ Drilling Fluid Program ❑� 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 1/24/2017 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not Scoff Brunswick 263-4249 be deviated from without prior written approval. Contact scott.a. brunswick(okop.com Email Printed Name Graham (Chip) Alvord Title Alaska Drilling Manager Signature A, �_ Phone 265-6120 Date 1 2cr( Y.n t 7 Commission Use Only Permit to Drill q API Number: Permit Approval See cover letter for other Number: ^013 5p-oa.9 ai35 -vo"a� Date: Ireouirements. Conditions of approval : If box is checked, well may not be used to ��,rr explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: 6D r0 f'CS'fPrC$5U✓G f0 560 p 5 /�<r Samples req'd: Yes ❑ N,g ,IJ Mud log req'd: Yes❑ Nou fi ✓i n (('74✓ o !-C VC ✓r tC i �r54 ✓ HzS measures: Yes g No[] Directional Directional svy req'd: Yes Wr Nonr�-, tD Spacing exception req'd: Yes ❑ N.4 Inclination -only svy req'd: Yes ❑ No L+U 25-0/-0 yl 72 5 Post initial injection MIT req'd: Yes ❑ NoEr Approved by APPROVED BY QQ - COMMISSIONER THE COMMISSION Date: -S-/6-Z7 ��'� A�r�I Submit Form and Form 10-407 (Revised 71/2015) T i r� I INAL, the from the date of appFyVal (20 AAC 25.005(8)) Attachments in Duplicate Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone(907)263-4249 Email: scott.a.brunswick(a)conocophillips.com January 24, 2017 Alaska Oil and Gas Conservation Commission 333 West 7`^ Avenue, Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill, Well 3R-101 Saved: 1 -Mar -17 0 ConocoPhillips Re: Application for Permit to Drill Well 311-101 West Sak D Sand Multi -Lateral Producer. Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore producer well from the 3 R pad. The expected spud date for this well is March 1, 2017. It is planned to use rig Doyon 142. 3R-101 is planned to be a dual lateral horizontal well in the West Sak D sand. When 3R-101 will drill a 16" surface hole & run 13-3/8" surface casing to +/-2,35 VMD / 2,200' TVD cemented to surface. The intermediate hole section will drill a 12-1/4" hole to a depth of +/-9,188' MD / 3,615' TVD with 9-5/8" casing run & cemented in place. The 3R-101 lower lateral will be an 8-3/4" hole geo-steered to 16,313' MD / 3,502' TVD in the lower West Sak D sand package & completed with a 4-1/2" slotted liner. A separate PTD application will be submitted for the 3R-101 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 Scott Brunswick at 263-4249 (Scott.a.brunswick(&,conocophillips.com) or Chip Alvord at 265-6120. Sincerely, Scott Brunswick Drilling Engineer Application for Permit to Drill Document Kuparuk Well 3R-101 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 3R-101 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dr ill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the proper! and the property's owners and Showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objectiveformation, and at fatal depth. referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system far this slate as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well a1 the top of each objective formation and at total depth; Location at Surface 1630.5' FNL, 2959.2' FEL, Sec 9, T 13N R009E, l M NGS Coordinates Northings: 6,031,732.16' Eastings: 520,615.98' RKB Elevation 48.9' AMSL Pad Elevation 9.9'AMSL Location at Surface asin 1019.38' FNL, 3090.7' FEL, Sec 9, TON, R009E, UM NGS Coordinates Northings: 6,032,342.84' Eastings: 520,491.31' i MeasuredDe th, RKB: 2,351' Total Vertical De th,RKB: 2,200' Total Vertical De th, SS: 2,151' Location at Intermediate Casing NGS Coordinates Northings: 6,037,726.09' Eastings: 510,787.11' 908.64' FNL, 360.57' FEL, Sec 5, T1 3N, R009E, UM NGS Coordinates Northings: 6,037,725.95' Eastings: 517,913.11' MeasuredDepth, RKB: 9,188' Total Vertical Depth, RKB: 1 3,615' Total Vertical De th, SS: 1 3,566' Location at Total De th 894.73' FNL, 2207.21' FEL, Sec 6, TI 3N, R009E, UM NGS Coordinates Northings: 6,037,726.09' Eastings: 510,787.11' Measured De th, RKB: 16,313' Total Vertical De th, RKB.• 3,502' Total Vertical De th, SS: 3,453' and (D) other information required by 10 AAC 25.050(6); Requirements of 20 AAC 25.050(b) 1j'a well is to be intentionally deviated, The application for a Permit to Drill (Form 10-401) must (I) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200feet at any portion of the proposed well: Please see Attachment: Directional Plan And (2) for all wells within 200.feel of the proposed wellbore (A) list the names oj'The operators ofihose wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application In, certified mail: or (B) stale that The applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except.for an item already on,file with the commission and ;dent fed in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035. 20 AAC 25.036, or 20 AAC 15.037, as applicable. Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each ofthe following items, except for an item already on file with the commission and ideni fed in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that mar be encountered, criteria used to determine it, and maximum potential sur/ace pressure based on a melhanegradienG The maximum potential surface pressure (MPSP) while drilling 3R-101 is calculated using an estimated maximum reservoir pressure of 1,660 psi (8.6 ppg, based Kigun 1 MDT pressure at a 3708' TVD reference datum), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A3 sand at 6,220' TVD: D Sand Estimated. BHP D Sand estimated depth Gas Gradient Hydrostatic of full gas column MPSP = BHP — gas column (B) data on potential gas zones: = 1,660 psi = 3,708' TVD = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) = 371 psi (3,708' TVD * 0.10 psi/ft) =1,289 psi (1,660 psi — 371 psi) The wellbore is not expected to penetrate any shallow gas zones. And (C) data concerning potentia( causes of hole problems such as abnormally geopressured strata, lost circulation zones, and zones that have a propensity for dillen'ential sticking; See attached 3R-101 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 fallowing items, except. for an item already of file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 15.030(9: 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 on file with the commission and ideni fled in the application.: (6) a complete proposed casing and cementing program as required by 20 AAC 25.031), and a description of any slotted liner, pre -perforated liner, or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg Hole Sne Weigh Grade Conn. C Length Top MD/TVD Btm MD1TVD Cement Program OD (in) t (ib//t) (h) (0) 00 20 78.7 H-40 Welded 78 Surf 117/117 Existing Hydril Cement to Surface with 13-3/8 16 68 L-80 563 2,313 Surf 2,351 / 2,200 1,193 sx DeepCRETE Lead 11.0 ppg, 235 sx Dee CRETE Tail Slurry 12.0 ppg I 9-5/8 12-1/4 40 L-80 ydril9150 13-3/8" Casing Surf 9,188 / 3,615 1605 sx 15.8 ppg Class G 7-5/8" Casing Mud System Spud Mud LSND (WBM) Flo-Thru (WBM Density 8.5-9.5 4-1/2 8-3/4 12.6 L-80 UP 7,193 9,120/ 3,613 16,313 / 3,502 N/A Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applicalion far a Permit to Drill must be accompanied by each of the following items, except.lor an item already on file with the commission and identified in the application: (7) a diagram and desorption of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2),• Please reference attachment for diverter schematic. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An applicalion for a Permit to Drill must be accompanied by each ol'thefollowing items, except for an item already on file with the commission and identified in the application.' (8) a dd/ling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25033,• 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. Surface 16" Hole Intermediate Production 13-3/8" Casing 9-7/8" Hole 8-3/4" Hole 7-5/8" Casing Mud System Spud Mud LSND (WBM) Flo-Thru (WBM Density 8.5-9.5 9.0-10.0 9.0-9.5 PV ALAP 10-20 25-30 lrp 30-80 20-30 15-20 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 160F N/A <10 <10 g 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 (e)(11) N/A - Application is not for an offshore well. Evidence of Bonding Reauirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Reauirements of 20 AAC 25.005 (c)(13) An application fora Permit to Drill must be accompanied by each ofthe following items, except for an item already on file with the commission and identified in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. 1. Move in / rig up Doyon Rig 142. Install 21-1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 16" hole to casing point at +/- 2,351 MD / 2,200' TVD as per directional plan. Survey & log with MWD, gyro, Gamma, & Resistivity. 3. Run and cement 13-3/8", 689, L80, Hyd-563 casing to surface. Displace cement with mud & check floats upon bumping plug. Perform top job if required after notifying AOGCC. Evacuate top 2 feet of cement from annulus for sealant job (post rig.) 4. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP'S to 3500 psi (annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. 5. PU 12-1/4" PDC bit and directional drilling assembly, with MWD/LWD (Gamma, resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3000 psi for 30 minutes. 6. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 12.5 ppg, maximum of 16 ppg EMW LOT/FIT, record results. 7. Directionally drill to intermediate hole TD of 9,188' MD / 3,615' TVD landing in the West Sak D sand package. 8. Circulate & rotate at maximum rates until shakers are clean with minimum of 3 bottoms up. 9. POOH on elevators racking back 5" drill pipe. 10. Laydown intermediate BHA. 11. Run 9-5/8", 40# L80, Hydril 563 casing from surface to TD. 12. Pump cement job as per Schlumberger proposal. Top cement to be placed @ +/- 4,900' MD (500' minimum above Ugnu B formation). �� %a vYti t C G� C ✓x'f j U 6 GK'S t -e r} 0 Lz LC 13. Install 9-5/8" packoff & test to 5000 psi. 14. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel or isotherm to freeze protect. 15. PU 8-3/4" bit, and drilling assembly with MWD/LWD (Gamma, resistivity, Periscope) 16. RIH on 5" DP to top of float equipment. Clean out cement to top of float equipment & test casing to 3500 psi for 30 minute 17. Drill out shoe track & 20 ft formation. Perform LOT to a minimum of 12.0 ppg EMW maximum of 13.0 ppg, recording results. 18. Directionally drill 8-3/4" hole geo-steering through the West Sak D sand to TD -16,313' MD / 3,502' TVD as per directional plan. 19. Circulate 1 BU after TD and BROOH, at 9-5/8" shoe CBU to flush casing & POOH on elevators. 20. Lay down Production BHA. 21. PU and run 4-1/2", 12.6# slotted liner w/MLZXP liner hanger & packer. The top of liner will be placed at -9,000' MD, allowing for +/-120' of overlap in the 7-5/8" casing & proper spacing for the whipstock assembly. 22. Set liner hanger & packer using MWD to orient hanger. 23. PT liner top packer to 2,500 psi at surface for 10 minutes, chart results. 24. Flow check well for 30 minutes. 25. POOH with liner running tools and lay down. 26. Run & set Baker W indowMaster whipstock system, at window point of top of window +/8,975' MD / 3,609' TVD,just below the top of the D sand orienting with MWD. 27. Mill 8-3/4" window until top mill across face & clean up window. 28. Perform formation integrity test to minimum of 12.0 ppg, maximum of 13.0 ppg EMW, recording results. 29. POOH with milling BHA. 30. PU 8-3/4" bit, motor, MWD, & magnets to perform a clean out run & land the well. (GR, Res) 31. RIH, orient through window, & tag bottom. 32. End 3R-101 PTD & begin 3R-101 Ll PTD. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application (or a Permit to Drill music be accompanied by each ofthe Jollowing items, except for an item 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 authorization under 20 AAC 15.080,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 II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the 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 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary Attachment 5 Cement Summaries Attachment l — Proposed Well Schematic 2 DRILL SITE 3R N.fyK• 0 �9! amcv� ❑ '� ❑ 10 11 12 M 14 11551 25 17 16 1 10 71 ax ° 23 31 3 r! 5 , ij ,a0� Y- y 1 3 2' c j YESpp,& P17 MW SCALF LEGE%Q 100 0 SD t00 ® 7HERNOSPHONS WIIOC43r illi s RE 05R LOWT sgl WS 1'= 100' 461sw Inc. RWR rr.n• w.r: Se rixa w arz v_m_sm1 ar Attachment 3 — 311-101 Directional Plan Attachment 4 — 3R-101 Drilling Hazards Summary 16" Open Hole / 13-3/8" Casine Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin 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 12-1/4" Open Hole / 9-5/8" Casin¢ 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 Anti -Collision Moderate Follow real time surveys very closely. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 8-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy 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 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. Getting Liner to Bottom Moderate Maintain solids free water based mud properties and lubricity while running liner lower completion, monitor torque and drag. Attachment 5 — 3R-101 Cement Summary 13-3/8" Surface Casine run to 2351' MD / 2200' TVD Cement from 2351' MD to 1851'(500' of fill) with 12.0 ppg DeepCRETE, and from 1851' to surface with ASL @ 11.0 ppg DeepCRETE. Assume 200% excess annular volume in permafrost and 50% excess below the permafrost (1799' MD). Lead slurry: (1851 - 1799') X 0.4202 ft'/ft X 1.5 (50% excess) = 33 ft' below permafrost 1799' X 0.4202 ft'/ft X 3.0 (200% excess) = 2268 ft' above permafrost Total volume = 33 + 2268 = 2301 ft' => 1193 Sx @ 1.93 ft3/sk Tail slurry: 500' X 0.4202 ft'/ft X 1.5 (50% excess) = 316 ft' annular volume 80' X 0.8177 ft3/ft = 66 ft3 shoejoint volume Total volume = 316 + 66 = 382 ft3 => 235 Sx @ 1.63 ft3/sk System: 235 Sx 12.0 ppg DeepCRETE & 1193 Sx ASL 11.0 ppg DeepCRETE 9-5/8" Intermediate Casine run to 9.188' MD / 3.615' TVD Cement from 9,188' MD to 5,100'(500' minimum above Ugnu B) with 15.8 ppg Class G w/GasBlok. Assume 40% excess annular volume. Tail slurry: (9,188' — 5,100') X 0.3219 ft3/ft X 1.4 (40% excess) = 1843 ft' annular volume 80' X 0.4172 ft'/ft = 34 ft'shoejoint volume Total volume = 1843 + 34 = 1877 ft' => 1605 Sx @ 1.17 ft'/sk System: 1605 Sx 15.8 ppg Class G w/ adds n 3 O f) O, v S �h broadened W', 94Conductor caring,Kssx 34"4", 0.312' WT Q ,,2 13-38", 6M,1.80, Hydril-563 Wellhend /Tubing Head /Tree, 13-3/8• x 4Y',5,000pai Tubing String. 12.6 d, L-80, TXP Connections n 3R-101 Dual Lateral Produce r (WP13) @ 2,351 MD / 2,200' @ 45.7 degrees TD 16" hole A b o Gas Lift Mandrel, 0.12"xI-LI' w/ dummy valve _ Gas Lift Mandrel, 41Y2" x I-12" w/SOV (XX deg) m � Downhole Gauge- Discharge and Intake Beck up Conventional ESP- wireline retrievable pump /robing conveyed motor. Set @ ],]00'MD, 3,483TVD, -80deg Baker Sl=P Packer setQ-8,80tlMD, 3603'TVD-87.9deg� Top or West SakD Q 8,828'MD/ 3,603' TVD y D sand lateral L1 Window Top@8,995' MD 13.609'TVD-88deg4112°, 126p LBo, TXP, Slotted Liner TO 16.318'MD/3,485'TVD Level) WJunction System 7,343', ft lateral length A e Lateral Entry Module POS-1 �- x ------------- Smlbore Diverter (SBD)POS-1 _ .........................................-------------.--------.---a.� ems.. ___________ _________________________________________________ ;. Tubing Seal Assembly �`�.... ............. _--..................................................A �/�a. Oil& Water Tracer Cartridge- - k/ al 3562" Lending nipple profile „6dN' sand latent as 7a MLHRProd Anchor �� .� Packer for main bore `. ... ........... 41/2", 126H LN,TXP, Stoked liner M 16,313' MD/ 3502' TVD ],125'ftLetemllength ........-..... �a 9-VB', 40, 480, Hydri1563 ___ ...................--.- -----.--- --- _-- ---- 13,61 S' ______________________ - TO 12-1/42-1/4' hole Oil &Water Tmcer Cartridge ai DRILL SITE 311 LEGEN'I�n So 100 Y © THERM051-HONS � Conoa Phillips ll� orae LAY= %MA 1"= :00' Aksw Inc. Attachment 3 — 3R-101 Directional Plan 3R-101wp13 E Plan Summary 0 SURVEY PROGRAM qh From Depth To Survey/Plan 39.00 950.00 3R-IO1wp13 (Plan: 3R-101 960.00 1950.00 3&101wp13 (Plan: 3R-101) 950.00 2350.35 3R-10Iwp13 (Ran: 3R-101) 2350.35 3850.35 3R-lotwpl3 (Plan: 3R-101) 2350.35 9187.84 3R-101wp13 (Plan: 3R-101) 9167.84 10887.84 3R -101M13 (Plan: 3R-101) 916284 16312.85 311 Surface LOwtlon Geodec DalUm: Tool )• DePth Rtieference: Plan: 394.9 @ 48.90us8 (D0y0n142) East / X. 19318"x15 Rig: DoyoM42 jppD 9.90 MWD+IFR-AK-CAZ-SC Zp"�m CASING DETAILS MWD MWD,lFR-AK-CAU-SC TVD 9518'0 124/4ON -101wp13 (Plan: 3R-101) g o MWDAFR-AK-CAZSD 1 2350.35 E Plan Summary 0 SURVEY PROGRAM qh From Depth To Survey/Plan 39.00 950.00 3R-IO1wp13 (Plan: 3R-101 960.00 1950.00 3&101wp13 (Plan: 3R-101) 950.00 2350.35 3R-10Iwp13 (Ran: 3R-101) 2350.35 3850.35 3R-lotwpl3 (Plan: 3R-101) 2350.35 9187.84 3R-101wp13 (Plan: 3R-101) 9167.84 10887.84 3R -101M13 (Plan: 3R-101) 916284 16312.85 311 Prepared by: B Temple Surface LOwtlon 13883 Tool Nodh / Y: 151M GYD-GC-SS East / X. MWD Pad Elevation: 9.90 MWD+IFR-AK-CAZ-SC 13318" x 16" CASING DETAILS MWD MWD,lFR-AK-CAU-SC TVD MD -101wp13 (Plan: 3R-101) Prepared by: B Temple 39 400 400 — 590 590 — n0 no — 960 980 — 1140 1140 — 1330 Inc — 1510 1510 — 17M i7w — 2310 2310 2R10 2930 — 3590 3540 — 4150 50 — 4)60 4760 — 5370 5370 — 59M 5990 MW 6600 — 7810 ]810 — 9600 90M — 10 10240 — n 11460 — 1 26]0 1 9118'x12-1/4 Surface LOwtlon 13883 Tool Nodh / Y: 151M GYD-GC-SS East / X. MWD Pad Elevation: 9.90 MWD+IFR-AK-CAZ-SC 13318" x 16" CASING DETAILS MWD MWD,lFR-AK-CAU-SC TVD MD 11].90 11].90 MWDAFR-AK-CAZSD 2200.00 2350.35 3615.05 9187.84 �+ourm 1]415 ..e.16312.65 39 400 400 — 590 590 — n0 no — 960 980 — 1140 1140 — 1330 Inc — 1510 1510 — 17M i7w — 2310 2310 2R10 2930 — 3590 3540 — 4150 50 — 4)60 4760 — 5370 5370 — 59M 5990 MW 6600 — 7810 ]810 — 9600 90M — 10 10240 — n 11460 — 1 26]0 1 9118'x12-1/4 160 13883 15100 151M — 1631 Name 2P x42" Ma9iMlic Mcdel: IMM2616 .) 13318" x 16" Mapnvic F Gale: O1 Mar -1) Ifi Declination: 4 1/Y'X 63/4" To wnved auaelic aTwe 9netio Direolion la aTme 012dipn, Atltl D.n•Eaal t By5,9 �+ourm 1]415 N. Acictld by: Apl by: Beck by. I I E Ste I Bnmewi Base Almel 1987,2 K15 Tap UOnu C 3087.4 Top Upnu 8 1315c Top Ognu A 3424A Top N Sands Spider View m Essting (2000 usfVin) :04wp01 Plan View FM r� 3R-1 OA - e�l�%!f TA��9,s"��I��—�- �i�•,y' leddli�i� �.s�j=i��la. i V �c,�; '' 11 � .111 111 111 111 11 111 1 11 •111 11 .111 � 11 111 11 1 11 11 FM r� 3R-1 OA Section View a `m 0 0 LO � 1 ca - Q) 0 U 7 C Q) I` 3R-101wp13 -------20" x 42" 0° T3 1000 13-3/8" x 16" Base Pfrost 9 5/8" x 12-1/4 K15 Top Ugnu C®O�p " O O �--Top Ugnu B_ R� _ = — — —OCI—o — _ _ _ 091i—co Top N Sandi a — —i -- Top Ugnu A y o o° o ®' C) d o Top West Sak D 3R-101 00. Pump Section View 13R-101 T10 101017 A 1313-101 T11 101017 SN 13R-101 T12 101017 Si 4 1/2" x 6-3/4" JTD W 3R-101 T9 101017 313-101 T8 101017 6000 3R-101 T C 10101,7 B 3R-101 T2 101Q17 S 313-101 T4 101017 S 3R-101 T6.101017 S 3R-101 01. Top D 110816 M 313-101 T1 101017 S 313-101 T3 101017 S 313-101 T5 101017 S 3R-101 T7 101017 -1500 0 1500 3000 4500 6000 7500 9000 10500 Vertical Section at 270.00° (1500 usft/in) Plan Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad Plan: 3R-101 Plan: 3R-101 Plan: 3R-101wp13 Report 18 January, 2017 Company: Con000Phillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupawk 3R Pad Well: Plan: 3R-101 Wellbore: Plan: 3R-101 Design: 3R-101wpl3 Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 3R Pad Plan: 3R-101 Site Position: Northing: 6,031,398.78usft Latitude: 70° 29'50.390 N From: Map Easting: 1,660,687.47usft Longitude: 1490 50'3.220 W Position Uncertainty: 0.00 usft Slot Radius; 0" Grid Convergence: 0.16 ° Well Plan: 3R-101 Audit Notes: Well Position -NIS 0.00 usft Northing: 6,031,484.21 usft Latitude; 70° 29'51 .23i N Vertical Section: +E/ -W 0.00 usft Easting: 1,660,657.38 usft Longitude; 149° 50'4.099 W Position Uncertainty (usft) (I 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usft Wellbore Plan: 3R-101 Magnetics Model Name Sample Date Declination Dip Angle Field Strength f9 (I (nn BGGM2016 3/1/2017 17.77 81.04 57,552 Design 3R-101wp13 Audit Notes: Survey Tool Program Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) -NIS +EI -W Direction (usft) (usft) (usft) (I 39.00 0.00 0.00 270.00 1/182017 1:30:22PM Page 2 COMPASS 5000.1 Build 74 Survey Tool Program Date 1/18/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 950.00 3R-101wpl3 (Plan: 3R-101) GYD-GC-SS Gyrodata gyro single shots 950.00 1,950.00 3R-101wp13(Plan: 3R-101) MWD MWD -Standard 950.00 2,350.35 3R-101wp13 (Plan: 3R-101) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 2,350.35 3,850.35 3R-101wpl3(Plan: 3R-101) MWD MWD -Standard 2,350.35 9,187.84 3R-101wpl3(Plan: 3R-101) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,187.84 10,687.84 3R-101wp13(Plan: 3R-101) MWD MWD -Standard 9,187.84 16,312.85 3R-101wpl3(Plan: 3R-101) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Let Error (usft) (°) (I (usft) (usft) (Villousft) (°) (usft) 39.00 0.00 0.00 39.00 -9.90 0.00 0.00 0.00 100.00 0.00 0.00 100.00 51.10 0.00 0.00 0.04 117.90 0.00 0.00 117.90 69.00 0.00 0.00 0.19 20^ x 42" 200.00 0.00 0.00 200.00 151.10 0.00 0.00 0.19 300.00 0.00 0.00 300.00 251.10 0.00 0.00 0.33 1/182017 1:30:22PM Page 2 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Project Kuparuk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 Survey Calculation Method: Design: 3R-101wp13 Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyonl42) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Let Error (usR) (°) V) (usft) Waft) f/100usft) (I (usft) 400.00 0.00 0.00 400.00 351.10 0.00 0.00 0.48 KOP: Start 1.5°/100' DLS, 347.72° TF, for 200.09' 500.00 1.50 347.72 499.99 451.09 1.50 347.72 0.62 600.00 3.00 347.72 599.91 551.01 1.50 0.00 0.77 600.09 3.00 347.72 600.00 551.10 1.50 0.00 0.77 Start 2°/100' DLS, 0° TF, for 1142.21' 700.00 5.00 347.72 699.66 650.76 2.00 0.00 0.91 800.00 7.00 347.72 799.11 750.21 2.00 0.00 1.06 900.00 9.00 347.72 898.13 849.23 2.00 0.00 1.22 1,000.00 11.00 347.72 996.61 947.71 2.00 0.00 1.31 1,100.00 13.00 347.72 1,094.42 1,045.52 2.00 0.00 1.38 1,200.00 15.00 347.72 1,191.44 1,142.54 2.00 0.00 1.55 1,300.00 17.00 347.72 1,287.56 1,238.66 2.00 0.00 1.82 1,400.00 19.00 347.72 1,382.66 1,333.76 2.00 0.00 2.17 1,500.00 21.00 347.72 1,476.63 1,427.73 2.00 0.00 2.61 1,600.00 23.00 347.72 1,569.34 1,520.44 2.00 0.00 3.12 1,700.00 25.00 347.72 1,660.69 1,611.79 2.00 0.00 3.69 1,738.97 25.78 347.72 1,695.90 1',647.00 2.00 0.00 3.95 T3 1,742.31 25.85 347.72 1,698.90 1,650.00 2.00 0.00 3.95 Hold for 111.11' 1,794.08 25.85 347.72 1,745.50 1,696.60 0.00 0.00 4.32 Base Pfrost 1,800.00 25.85 347.72 1,750.82 1,701.92 0.00 0.00 4.32 1,853.42 25.85 347.72 1,798.90 1,750.00 0.00 0.00 4.66 Start 4°/100' DLS, 0° TF, for 496.93' 1,900.00 27.71 347.72 1,840.48 1,791.58 4.00 0.00 4.97 2,000.00 31.71 347.72 1,927.32 1,878.42 4.00 0.00 2.66 2,071.52 34.57 347.72 1,987.20 1,938.30 4.00 0.00 2.96 K116 2,100.00 35.71 347.72 2,010.49 1,961.59 4.00 0.00 2.96 2,200.00 39.71 347.72 2,089.59 2,040.69 4.00 0.00 3.29 2,300.00 43.71 347.72 2,164.23 2,115.33 4.00 0.00 3.66 2,350.35 45.72 347.72 2,200.00 2,151.10 4.00 0.00 3.86 Hold for 20'- 13-3/8" z 16" 2,370.35 45.72 347.72 2,213.97 2,165.07 0.00 0.00 3.95 Start 4°/100' DLS, 3.04° TF, for 821.15' 2,400.00 46.91 347.81 2,234.44 2,185.54 4.00 3.04 4.09 2,500.00 50.90 348.07 2,300.16 2,251.26 4.00 2.98 4.77 2,600.00 54.90 348.31 2,360.47 2,311.57 4.00 2.80 5.66 2,700.00 58.89 348.53 2,415.08 2,366.18 4.00 2.66 6.72 2,800.00 62.89 348.73 2,463.71 2,414.81 4.00 2.54 7.91 2,900.00 66.89 348.91 2,506.14 2,457.24 4.00 2.44 9.20 3,000.00 70.88 349.09 2,542.16 2,493.26 4.00 2.37 10.55 3,100.00 74.88 349.25 2,571.59 2,522.69 4.00 2.30 11.96 1/18/2017 1:30.22PM Page 3 COMPASS 5000.1 Build 74 I Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TW Reference: Site: Kupawk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 Survey Calculation Method: Design: 313-101wp13 Database: 9 Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azl (azimuth) TVD TVDSS DLeg TFace Let Error (usft) (°) (I (usft) (usft) (°1100usft) (I (usft) 3,191.50 78.54 349.40 2,592.62 2,543.72 4.00 2.25 13.28 Hold for 3656.42' 3,200.00 78.54 349.40 2,594.31 2,545.41 0.00 0.00 13.41 3,300.00 78.54 349.40 2,614.19 2,565.29 0.00 0.00 14.88 3,400.00 76.54 349.40 2,634.06 2,585.16 0.00 0.00 16.36 3,500.00 78.54 349.40 2,653.94 2,605.04 0.00 0.00 17.84 3,600.00 78.54 349.40 2,673.81 2,624.91 0.00 0.00 19.34 3,700.00 78.54 349.40 2,693.68 2,644.78 0.00 0.00 20.84 3,800.00 78.54 349.40 2,713.56 2,664.66 0.00 0.00 22.34 3,900.00 78.54 349.40 2,733.43 2,684.53 0.00 0.00 10.34 4,000.00 78.54 349.40 2,753.30 2,704.40 0.00 0.00 10.89 4,100.00 78.54 349.40 2,773.18 2,724.28 0.00 0.00 11.43 4,200.00 78.54 349.40 2,793.05 2,744.15 0.00 0.00 11.99 4,300.00 78.54 349.40 2,812.93 2,764.03 0.00 0.00 12.54 4,400.00 78.54 349.40 2,832.80 2,783.90 0.00 0.00 13.10 4,500.00 78.54 349.40 2,852.67 2,803.77 0.00 0.00 13.66 4,514.22 78.54 349.40 2,855.50 2,806.60 0.00 0.00 14.22 Top Ugnu C 4,600.00 78.54 349.40 2,872.55 2,823.65 0.00 0.00 14.22 4,700.00 78.54 349.40 2,892.42 2,843.52 0.00 0.00 14.78 4,800.00 78.54 349.40 2,912.30 2,863.40 0.00 0.00 15.35 4,900.00 78.54 349.40 2,932.17 2,883.27 0.00 0.00 15.91 5,000.00 78.54 349.40 2,952.04 2,903.14 0.00 0.00 16.48 5,100.00 78.54 349.40 2,971.92 2,923.02 0.00 0.00 17.05 5,200.00 78.54 349.40 2,991.79 2,942.89 0.00 0.00 17.62 5,300.00 78.54 349.40 3,011.66 2,962.76 0.00 0.00 18.19 5,400.00 78.54 349.40 3,031.54 2,982.64 0.00 0.00 18.76 5,500.00 78.54 349.40 3,051.41 3,002.51 0.00 0.00 19.33 5,600.00 78.54 349.40 3,071.29 3,022.39 0.00 0.00 19.91 5,681.08 78.54 349.40 3,087.40 3,038.50 0.00 0.00 20.48 Top Ugnu B 5,700.00 78.54 349.40 3,091.16 3,042.26 0.00 0.00 20.48 5,800.00 78.54 349.40 3,111.03 3,062.13 0.00 0.00 21.05 5,900.00 78.54 349.40 3,130.91 3,082.01 0.00 0.00 21.63 6,000.00 78.54 349.40 3,150.78 3,101.88 0.00 0.00 22.20 6,100.00 78.54 349.40 3,170.66 3,121.76 0.00 0.00 22.78 6,200.00 78.54 349.40 3,190.53 3,141.63 0.00 0.00 23.35 6,300.00 78.54 349.40 3,210.40 3,161.50 0.00 0.00 23.93 6,400.00 78.54 349.40 3,230.28 3,181.38 0.00 0.00 24.50 6,500.00 78.54 349.40 3,250.15 3,201.25 0.00 0.00 25.08 6,600.00 78.54 349.40 3,270.02 3,221.12 0.00 0.00 25.66 6,700.00 78.54 349.40 3,289.90 3,241.00 0.00 0.00 26.23 6,800.00 78.54 349.40 3,309.77 3,260.87 0.00 0.00 26.81 6,826.30 78.54 349.40 3,315.00 3,266.10 0.00 0.00 27.09 Top Ugnu A 1/182017 1:30:22PM Page 4 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kupawk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 Survey Calculation Method: Design: 3R-101wp13 Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyonl42) Plan: 39+9.9 @ 48.90usft (Doyonl42) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (I (usft) Waft) ('1100usft) (I (usft) 6,847.92 78.54 349.40 3,319.30 3,270.40 0.00 0.00 27.09 Start 4.6'/100' OLS, -91.34' TF, for 808' 6,900.00 78.49 347.01 3,329.67 3,280.77 4.50 -91.34 27.31 7,000.00 78.46 342.42 3,349.66 3,300.76 4.50 -90.87 27.48 7,100.00 78.50 337.83 3,369.64 3,320.74 4.50 -89.95 27.49 7,200.00 78.61 333.24 3,389.49 3,340.59 4.50 -89.03 27.36 7,300.00 78.80 328.65 3,409.09 3,360.19 4.50 -88.12 27.06 7,379.46 78.99 325.01 3,424.40 3,375.50 4.50 -87.22 26.61 Top N Sands 7,400.00 79.05 324.07 3,428.31 3,379.41 4.50 -86.52 26.61 7,500.00 79.37 319.50 3,447.05 3,398.15 4.50 -86.34 26.01 7,600.00 79.76 314.94 3,465.17 3,416.27 4.50 -85.48 25.27 7,655.91 80.00 312.40 3,475.00 3,426.10 4.50 -84.66 24.79 Hold for 200' 7,700.00 80.00 312.40 3,482.66 3,433.76 0.00 -84.21 25.01 7,800.00 80.00 312.40 3,500.02 3,451.12 0.00 0.00 25.56 7,855.91 80.00 312.40 3,509.73 3,460.83 0.00 0.00 25.86 Start 4.6'1100' DLS, -72.2' TF, for 196.17' 7,900.00 80.61 310.49 3,517.15 3,468.25 4.50 -72.20 25.52 8,000.00 82.04 306.17 3,532.24 3,483.34 4.50 -71.88 24.60 8,052.08 82.80 303.93 3,539.12 3,490.22 4.50 -71.23 24.08 Hold for 2.28' 8,054.36 82.80 303.93 3,539.40 3,490.50 0.01 -70.93 24.09 Start 4.5'1100' DLS, .82.87' TF, for 756.68' 8,100.00 83.06 301.88 3,545.03 3,496.13 4.50 -82.87 23.58 8,200.00 83.66 297.39 3,556.60 3,507.70 4.50 -82.61 22.33 8,300.00 84.29 292.91 3,567.10 3,518.20 4.50 -82.09 20.96 8,400.00 84.97 288.44 3,576.47 3,527.57 4.50 -81.62 19.49 8,500.00 85.67 283.98 3,584.64 3,535.74 4.50 -81.20 17.94 8,600.00 86.40 279.53 3,591.56 3,542.66 4.50 -80.84 16.31 8,700.00 87.15 275.08 3,597.20 3,548.30 4.50 -80.53 14.63 8,800.00 87.91 270.65 3,601.51 3,552.61 4.50 -80.28 12.94 8,811.05 88.00 270.16 3,601.90 3,553.00 4.50 -80.09 12.76 Hold for 376.8' 8,828.24 88.00 270.16 3,602.50 3,553.60 0.00 0.00 13.18 Top West Sak D 8,900.00 88.00 270.16 3,605.00 3,556.10 0.00 0.00 13.18 9,000.00 88.00 270.16 3,608.49 3,559.59 0.00 0.00 13.67 9,100.00 88.00 270.16 3,611.98 3,563.08 0.00 0.00 14.17 9,187.84 88.00 270.16 3,615.05 3,566.15 0.00 0.00 14.72 Adjust TF to 0', for 20' - 9 618" z 12-114 9,200.00 88.00 270.16 3,615.47 3,566.57 0.00 0.00 14.62 9,207.84 88.00 270.16 3,615.75 3,566.85 0.00 0.00 14.88 Start 1.5'/100' DLS, 0' TF, for 189.98' 9,300.00 89.38 270.16 3,617.85 3,568.95 1.50 0.00 15.71 1/18/2017 1:30:22PM Page 5 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 Survey Calculation Method: Design: 3R-101wp13 Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyon142) Tme Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 9,397.82 90.85 270.16 3,617.65 3,568.75 1.50 0.00 16.70 Hold for 483.64' 9,400.00 90.85 270.16 3,617.62 3,568.72 0.00 0.00 16.73 9,500.00 90.85 270.16 3,616.14 3,567.24 0.00 0.00 17.85 9,600.00 90.85 270.16 3,614.66 3,565.76 0.00 0.00 19.06 9,700.00 90.85 270.16 3,613.17 3,564.27 0.00 0.00 20.34 9,800.00 90.85 270.16 3,611.69 3,562.79 0.00 0.00 21.68 9,881.66 90.85 270.16 3,610.48 3,561.56 0.00 0.00 22.82 Start 1°/100' DLS, -180° TF, for 44.96' 9,900.00 90.67 270.16 3,610.24 3,561.34 1.00 -180.00 23.07 9,926.62 90.40 270.16 3,609.99 3,561.09 1.00 -180.00 23.44 Adjust TF to 180°, for 37.62' 9,964.24 90.02 270.16 3,609.85 3,560.95 1.00 -180.00 23.96 Hold for 568.22' 10,000.00 90.02 270.16 3,609.84 3,560.94 0.00 180.00 24.47 10,100.00 90.02 270.16 3,609.79 3,560.89 0.00 0.00 25.93 10,200.00 90.02 270.16 3,609.75 3,560.85 0.00 0.00 27.42 10,300.00 90.02 270.16 3,609.71 3,560.81 0.00 0.00 28.93 10,400.00 90.02 270.16 3,609.67 3,560.77 0.00 0.00 30.47 10,500.00 90.02 270.16 3,609.63 3,560.73 0.00 0.00 32.02 10,532.46 90.02 270.16 3,609.61 3,560.71 0.00 0.00 32.53 Start 2.5°/100' OLS, 0° TF, for 179.05' 10,600.00 91.71 270.16 3,608.59 3,559.69 2.50 0.00 33.58 10,700.00 94.21 270.16 3,603.42 3,554.52 2.50 0.00 19.66 10,711.51 94.50 270.16 3,602.55 3,553.65 2.50 0.00 19.70 Adjust TF to 0°, for 1.07' 10,712.58 94.53 270.16 3,602.47 3,553.57 2.51 0.00 19.71 Hold for 310.18' 10,800.00 94.53 270.16 3,595.57 3,546.67 0.00 0.00 20.09 10,900.00 94.53 270.16 3,587.67 3,538.77 0.00 O.DO 20.53 11,000.00 94.53 270.16 3,579.78 3,530.88 0.00 0.00 20.98 11,022.76 94.53 270.16 3,577.98 3,529.08 0.00 0.00 21.08 Start 2.5°/100' DLS, -180° TF, for 1.07' 11,023.83 94.50 270.16 3,577.90 3,529.00 2.50 -180.00 21.09 Adjust TF to 180°, for 119.07' 11,100.00 92.60 270.16 3,573.19 3,524.29 2.50 180.00 21.41 11,142.90 91.52 270.15 3,571.65 3,522.75 2.50 -180.00 21.60 Hold for 465.81' 11,200.00 91.52 270.16 3,570.13 3,521.23 0.00 180.00 21.85 11,300.00 91.52 270.16 3,567.47 3,518.57 0.00 0.00 22.32 11,400.00 91.52 270.16 3,564.81 3,515.91 0.00 0.00 22.79 11,500.00 91.52 270.16 3,562.16 3,513.26 0.00 0.00 23.27 11,600.00 91.52 270.16 3,559.50 3,510.60 0.00 0.00 23.75 11,608.72 91.52 270.16 3,559.27 3,510.37 0.00 0.00 23.80 Start 2.6°/100' DLS, 180° TF, for 60.93' 1/182017 1:30..22PM Page 6 COMPASS 5000.1 Build 74 Report Company: ConowPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kupawk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 Survey Calculation Method: Design: 3R-101wp13 Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyonl42) Plan: 39+9.9 @ 48.90usft (Doyonl42) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (I (°) (usft) (usft) (°1100usft) (°) (usft) 11,669.65 90.00 270.16 3,558.46 3,509.56 2.50 180.00 24.08 Adjust TF to -180°, for 48.51' 11,700.00 89.24 270.16 3,558.66 3,509.76 2.50 -180.00 24.22 11,718.15 88.79 270.16 3,558.97 3,510.07 2.50 -180.00 24.30 Hold for 388.1' 11,800.00 88.79 270.16 3,560.71 3,511.81 0.00 180.00 24.69 11,900.00 88.79 270.16 3,562.82 3,513.92 0.00 0.00 25.19 12,000.00 88.79 270.16 3,564.94 3,516.04 0.00 0.00 25.69 12,100.00 88.79 270.16 3,567.05 3,518.15 0.00 0.00 26.19 12,106.26 88.79 270.16 3,567.19 3,518.29 0.00 0.00 26.22 Start 0.5°/100' DLS, 180° TF, for 13.46' 12,119.71 88.72 270.16 3,567.48 3,518.58 0.50 -180.00 26.28 Adjust TF to -180°, for 11.94' 12,131.65 88.66 270.16 3,567.75 3,518.85 0.50 180.00 26.34 Hold for 448.81' 12,200.00 88.66 270.16 3,569.35 3,520.45 0.00 180.00 26.67 12,300.00 88.66 270.16 3,571.69 3,522.79 0.00 0.00 27.18 12,400.00 88.66 270.16 3,574.03 3,525.13 0.00 0.00 27.70 12,500.00 88.66 270.16 3,576.36 3,527.46 0.00 0.00 28.21 12,580.46 88.66 270.16 3,578.25 3,529.35 0.00 0.00 28.63 Start 1.5°1100' DLS, 0° TF, for 89.31' 12,600.00 88.95 270.16 3,578.65 3,529.75 1.50 0.00 28.73 12,669.77 90.00 270.16 3,579.29 3,530.39 1.50 0.00 29.09 Adjust TF to 0°, for 7.59' 12,677.36 90.11 270.16 3,579.28 3,530.38 1.50 0.00 29.13 Hold for 508.66' 12,700.00 90.11 270.16 3,579.24 3,530.34 0.00 0.00 29.25 12,800.00 90.11 270.16 3,579.04 3,530.14 0.00 0.00 29.77 12,900.00 90.11 270.16 3,578.84 3,529.94 0.00 0.00 30.30 13,000.00 90.11 270.16 3,578.64 3,529.74 0.00 0.00 30.83 13,100.00 90.11 270.16 3,578.44 3,529.54 0.00 0.00 31.36 13,185.91 90.11 270.16 3,578.27 3,529.37 0.00 0.00 31.81 Start 0.5°/100' DLS, 180° TF, for 22.76' 13,200.00 90.04 270.16 3,578.25 3,529.35 0.50 180.00 31.89 13,206.67 90.00 270.16 3,578.25 3,529.35 0.50 -180.00 31.93 Adjust TF to 0°, for 0'- Hold for 410.81' 13,300.00 90.00 270.16 3,578.25 3,529.35 0.00 -90.00 32.42 13,400.00 90.00 270.16 3,578.25 3,529.35 0.00 0.00 32.95 13,500.00 90.00 270.16 3,578.25 3,529.35 0.00 0.00 33.49 13,600.00 90.00 270.16 3,578.25 3,529.35 0.00 0.00 34.03 13,619.48 90.00 270.16 3,578.25 3,529.35 0.00 0.00 34.14 Adjust TF to 0°, for 63.89'- Start 1°/100' DLS, 0° TF, for 0' 13,683.37 90.64 270.16 3,577.89 3,528.99 1.00 0.00 34.48 Hold for 422.46' 13,700.00 90.64 270.16 3,577.71 3,528.81 0.00 0.00 34.57 13,800.00 90.64 270.16 3,576.59 3,527.69 0.00 0.00 35.12 11182017 1:30:22PM Page 7 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 Survey Calculation Method: Design: 3R-101wp13 Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS Usti TFace Lat. Error (usft) (I (°) (usft) (usft) (°NOOusft) (°) (usft) 13,900.00 90.64 270.16 3,575.48 3,526.58 0.00 0.00 35.66 14,000.00 90.64 270.16 3,574.36 3,525.46 0.00 0.00 36.21 14,100.00 90.64 270.16 3,573.25 3,524.35 0.00 0.00 36.75 14,105.83 90.64 270.16 3,573.18 3,524.28 0.00 0.00 36.79 Start 0.6°/100' DLS, 0° TF, for 12.21' 14,118.05 90.70 270.16 3,573.04 3,524.14 0.50 0.00 36.85 Adjust TF to 0°, for 22.81' 14,140.85 90.81 270.16 3,572.74 3,523.84 0.50 0.00 36.98 Hold for 639.85' 14,200.00 90.81 270.16 3,571.90 3,523.00 0.00 0.00 37.30 14,300.00 90.81 270.16 3,570.48 3,521.58 0.00 0.00 37.85 14,400.00 90.81 270.16 3,569.06 3,520.16 0.00 0.00 38.40 14,500.00 90.81 270.16 3,567.64 3,518.74 0.00 0.00 38.96 14,600.00 90.81 270.16 3,566.22 3,517.32 0.00 0.00 39.51 14,700.00 90.81 270.16 3,564.79 3,515.89 0.00 0.00 40.06 14,780.70 90.81 270.16 3,563.65 3,514.75 0.00 0.00 40.51 Start 1°/100' DLS, 0° TF, for 38.6' 14,800.00 91.01 270.16 3,563.34 3,514.44 1.00 0.00 40.62 14,819.30 91.20 270.16 3,562.97 3,514.07 1.00 0.00 40.73 Adjust TF to 0°, for 49.24' 14,868.54 91.69 270.16 3,561.73 3,512.83 1.00 0.00 41.00 Hold for 187.89' 14,900.00 91.69 270.16 3,560.80 3,511.90 0.00 0.00 41.17 15,000.00 91.69 270.16 3,557.84 3,508.94 0.00 0.00 41.73 15,056.43 91.69 270.16 3,556.17 3,507.27 0.00 0.00 42.05 Start 1°/100' DLS, 0° TF, for 45.76' 15,100.00 92.13 270.16 3,554.72 3,505.82 1.00 0.00 42.29 15,102.19 92.15 270.16 3,554.64 3,505.74 1.00 0.00 42.30 Adjust TF to 0°, for 35.46' 15,137.65 92.50 270.16 3,553.20 3,504.30 1.00 0.00 42.50 Hold for 660.23' 15,200.00 92.50 270.16 3,550.48 3,501.58 0.00 0.00 42.85 15,300.00 92.50 270.16 3,546.11 3,497.21 0.00 0.00 43.41 15,400.00 92.50 270.16 3,541.74 3,492.64 0.00 0.00 43.97 15,500.00 92.50 270.16 3,537.37 3,488.47 0.00 0.00 44.53 15,600.00 92.50 270.16 3,533.00 3,484.10 0.00 0.00 45.09 15,700.00 92.50 270.16 3,528.63 3,479.73 0.00 0.00 45.65 15,787.88 92.50 270.16 3,524.79 3,475.89 0.00 0.00 46.15 Start 0.6°/100' DLS, 180° TF, for 0.36' 15,788.23 92.50 270.16 3,524.77 3,475.87 0.49 180.00 46.15 Hold for 524.62' 15,800.00 92.50 270.16 3,524.26 3,475.36 0.00 0.00 46.21 15,900.00 92.50 270.16 3,519.89 3,470.99 0.00 0.00 46.78 16,000.00 92.50 270.16 3,515.52 3,466.62 0.00 0.00 47.34 16,100.00 92.50 270.16 3,511.16 3,462.26 0.00 0.00 47.91 16,200.00 92.50 270.16 3,506.79 3,457.89 0.00 0.00 48.47 1/182017 1:30:22PM Page 8 COMPASS 5000.1 Build 74 Company: ConocoPhillips(Alaska) Inc.-Kup2 Project: Kuparuk River Unit Site: Kuparuk 3R Pad Well: Plan: 3R-101 Wellbore: Plan: 3R-101 Design: 3R-101wp13 Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 3R-101 Plan: 39+9,9 (oj 48.90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Let Error (usR) (•) (•) (usft) (usft) (•1100usft) (I (usR) 16,300.00 92.50 270.16 3,502.42 3,453.52 0.00 0.00 49.04 16,312.85 92.50 270.16 3,501.86 3,452.96 0.00 0.00 49.11 TD: 16312.85' MD, 3501.66' TVD .4 1/2" x 6-31V 1/182017 1:30:22PM Page 9 COMPASS 5000.1 Build 74 Company: ConocoPhillips(Alaska) Inc.-Kup2 Project: Kuparuk River Unit Site: Kuparuk 3R Pad Well: Plan: 3R-101 Wellbore: Plan: 3R-101 Design: 3R-101wp13 Report Local Co-ordinate Reference: Well Plan: 3R-101 TVD Reference: Plan: 39+9.9(0 48.90usft(Doyon142) MD Reference: Plan: 39+9.9 @ 48.90usft (Doyonl42) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Casing Points Measured Vertical Measured Vertical Depth Casing Hole Depth Depth 5,826.30 Diameter Diameter (usft) (usft) Name 7,379.46 3,424.40 117.90 117.90 20"x42" 20 42 2,350.35 2,200.00 13-3/8" x 16" 13-3/8 16 9,187.84 3,615.05 95/8"x12-1/4 9-5/8 12-1/4 16,312.85 3,501.86 41/2'x6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Depth Depth (usft) (usft) Name 5,826.30 3,315.00 Top UgnuA 1,738.97 1,695.90 T3 7,379.46 3,424.40 Top N Sands 5,681.08 3,087.40 Top Ugnu B 8,828.24 3,602.50 Top West Bak D 1,794.08 1,745.50 Base Pfrost 2,071.52 1,987.20 K15 4,514.22 2,855.50 Top Ugnu C Lithology Dip Dip Direction 0.00 0.00 0.00 1/1812017 1:30:22PM Page 10 COMPASS 5000.1 Build 74 Company: ConocoPhillips(Alaska) Inc.-Kup2 Project: Kupamk River Unit Site: Kupanrk 3R Pad Well: Plan: 3R-101 Wellbore: Plan: 3R-101 Design: 3R-101wpl3 Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 3R-101 Plan: 39+9,9 @ 48.90usft (Doyonl42) Plan: 39+9.9 @ 48.90usft (Doyonl42) True Minimum Curvature OAKEDMP2 Casing Points Measured Measured Vertical Dip Casing Hole Depth Depth (usft) Diameter Diameter (usft) (usft) Name Top UgnuA 400.00 117.90 117.90 20"x42" 20 42 2,350.35 2,200.00 13-3/8" x 16" 13-3/e 16 9,187.84 3,615.05 9 5/8"x 12-1/4 9-5/8 12-1/4 16,312.85 3,501.86 41/2"x6-3/4" 4-1/2 6-314 Formations Measured Vertical Vertical Dip Depth Depth Depth Dip Direction (usft) (usft) Name Lithology (") (°) 6,826.30 3,315.00 Top UgnuA 400.00 1,738.97 1,695.90 T3 0,00 7,379.46 3,424.40 Top N Sands -1.11 5,681.08 3,087.40 Top Ugnu B 281.29 8,828.24 3,602.50 Top West Sak D 1,798.90 1,794.08 1,745.50 Base Pfrost 0.00 2,071.52 1,987.20 K15 0.00 4,514.22 2,855.50 Top Ugnu C -136.07 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +El -W (usft) (usft) (usft) (usft) Comment 400.00 400.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 347.721 TF, for 200.09' 600.09 600.00 5.12 -1.11 Start Tit 00' DLS, 0° TF, for 1142.21' 1,742.31 1,698.90 281.29 -61.23 Hold for 111.11' 1,853.42 1,798.90 328.62 -71.53 Start 4-/100' DLS, 0° TF, for 496.93' 2,350.35 2,200.00 611.12 -133.02 Hold for 20' 2,370.35 2,213.97 625.11 -136.07 Start 4.1100' DLS, 3.04" TF, for 821 AV 3,191.50 2,592.62 1,327.20 -276.46 Hold for 3656.42' 6,847.92 3,319.30 4,849.55 -935.55 Start 4.5'/100' DLS, -91.34' TF, for 808' 7,655.91 3,475.00 5,530.00 -1,315.00 Hold for 200' 7,855.91 3,509.73 5,662.81 -1,460.44 Start 4.5"/100' DLS, -72.2° TF, for 196.17' 8,052.08 3,539.12 5,782.50 -1,612.82 Hold for 2.28' 8,054.36 3,539.40 5,783.76 -1,614.69 Start 4.5'/100' DLS, -82.87" TF, for 756.68' 8,811.05 3,601.90 6,000.74 -2,325.28 Hold for 376.8' 9,187.84 3,615.05 6,001.76 -2,701.84 Adjust TF to 0°, for 20' 9,207.84 3,615.75 6,001.82 -2,721.83 Start 1.5.1100' DLS, 0° TF, for 189.98' 9,397.82 3,617.65 6,002.33 -2,911.78 Hold for 483.84' 9,881.66 3,610.48 6,003.65 -3,395.57 Start 1'/100' DLS, -180° TF, for 44.96' 9,926.62 3,609.99 6,003.77 -3,440.52 Adjust TF to 180°, for 37.62' 9,964.24 3,609.85 6,003.88 3,478.14 Hold for 568.22' 10,532.46 3,609.61 6,005.42 -4,046.36 Start 2.5°/100' DLS, 0` TF, for 179.05' 10,711.51 3,602.55 6,005.91 -4,225.23 Adjust TF to 0°, for 1.07' 10,712.58 3,602.47 6,005.91 -4,226.29 Hold for 310.18' 11,022.76 3,577.98 6,006.76 -4,535.50 Start 2.5-1100-DLS,-180' TF, for 1.07' 11,023.83 3,577.90 6,006.76 -4,536.57 Adjust TF to 180°, for 119.07' 11,142.90 3,571.65 6,007.08 4,655.46 Hold for 465.81' 11,608.72 3,559.27 6,008.35 -5,121.12 Start 2.5-/100-DLS, 180* TF, for 60.93' 11,669.65 3,558.46 6,008.52 -5,182.04 Adjust TF to -180°, for 48.51' 11,718.15 3,558.97 6,008.65 -5,230.53 Hold for 388.1' 12,106.26 3,567.19 6,009.71 -5,618.56 Start 0.5.1100' DLS, 180° TF, for 13.46' 12,119.71 3,567.48 6,009.74 -5,632.00 Adjust TF to -180°, for 11.94' 12,131.65 3,567.75 6,009.77 -5,643.94 Hold for 448.81' 1/182017 1:30.'22PM Page 11 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well Plan: 3R-101 Project: Kuparuk River Unit TVD Reference: Plan: 39+9.9 @ 48.90usft (Doyonl42) Site: Kuparuk 3R Pad MD Reference: Plan: 39+9.9 @ 48.90usft (Doyonl42) Well; Plan: 3R-101 North Reference: True Wellbore: Plan: 3R-101 Survey Calculation Method: Minimum Curvature Design: 3R-101wp13 Database: OAKEDMP2 Casing Points Formations Measured Vertical 6,011.00 Casing Hole Depth Depth (usft) Diameter Diameter (usft) (usft) Name 1,695.90 T3 117.90 117.90 20"x42" 20 42 2,350.35 2,200.00 13-3/8"x16" 13-3/8 16 9,187.84 3,615.05 9 5/8"x 12-1/4 9-5/8 12-1/4 16,312.85 3,501.86 41/2"x6-3/4" 4-1/2 6-3/4 Measured Vertical 6,011.00 Depth Depth 12,669.77 (usft) (usft) Name Lifhology 6,826.30 3,315.00 Top UgnuA 1,738.97 1,695.90 T3 7,379.46 3,424.40 Top N Sands 5,681.08 3,087.40 Top Ugnu B 8,828.24 3,602.50 Top West Sak D 1,794.08 1,745.50 Base Pfrost 2,071.52 1,987.20 K15 4,514.22 2,855.50 Top UgnuC Dip Dip Direction (`) 11 0.00 0.00 0.00 i�,00u 40 a,o re.ze 6,011.00 -6,092.62 Start 1.5°/100' DLS, 0° TF, for 89.31' 12,669.77 3,579.29 6,011.24 -6,181.93 Adjust TF to 0', for 7.59' 12,677.36 3,579.28 6,011.26 -6,189.52 Hold for 508.55' 13,185.91 3,578.27 6,012.65 -6,698.06 Start 0.5°/100' DLS, 180° TF, for 22.76- 13,208.67 3,578.25 6,012.71 -6,720.82 Adjust TF to 0°, for 0' 13,208.67 3,578.25 6,012.71 -6,720.82 Hold for 410.81' 13,619.48 3,578.25 6,013.83 -7,131.63 Adjust TF to 0', for 63.89' 13,619.48 3,578.25 6,013.83 -7,131.63 Start 1°/100' DLS, 0° TF, for 0' 13,683.37 3,577.89 6,014.00 -7,195.52 Hold for 422.46' 14,105.83 3,573.18 6,015.15 -7,617.95 Start 0.5°/100' DLS, 0° TF, for 12.21' 14,118.05 3,573.04 6,015.18 -7,630.17 Adjust TF to 0°, for 22.81' 14,140.85 3,572.74 6,015.25 -7,652.97 Hold for 639.85' 14,780.70 3,563.65 6,016.99 -8,292.75 Start 1°/100' DLS, 0° TF, for 38.6- 14,819.30 3,562.97 5,017.09 -8,331.35 Adjust TF to 0", for 49.24' 14,868.54 3,561.73 6,017.23 -8,380.57 Hold for 187.89' 15,056.43 3,556.17 6,017.74 -8,568.38 Start 1°/100' DLS, 0° TF, for 45.76- 15,102.19 3,554.64 6,017.86 -8,614.11 Adjust TF to 0% for 35.46' 15,137.65 3,553.20 6,017.96 -8,649.54 Hold for 650.23' 15,787.88 3,524.79 6,019.73 -9,299.15 Start 0.5°/100' DLS, 180' TF, for 0.35- 15,788.23 3,524.77 6,019.73 -9,299.50 Hold for 524.62' 16,312.85 3,501.86 6,021.16 -9,823.62 TD: 16312.85' MD, 3501.86' TVD Checked By: Approved By: Date: 1 1/18/2017 1:30.22PM Page 12 COMPASS 5000.1 Build 74 AC Summary ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad Plan: 3R-101 Plan: 3R-101 50103xxxxx00 3R-101wp13 Clearance Summary Anticollision Report 18 January, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3R Pad - Plan: 3R -101 -Plan: 3R-101-3R-101wp13 Well Coordinates: Datum Height: Plan: 39+9.9@ 48,90usft(Doyon142) Scan Range: 0.00 to 16,312.85 usft. Measured Depth. Scan Radius is 1,827.39 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED. All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 Anticollision Report for Plan: 3R-101 - 3R-101wp13 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3R Pad - Plan: 3R-101 - Plan: 3R-101-3R-101wp13 Scan Range: 0.00 to 16,312.85 usft. Measured Depth. Scan Radius is 1,827.39 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Site Name Measured Minimum @Measured Ellipse @AMeasured Clearance Summary Based on Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 3R Pad 3R -10 -3R -10-3R-10 3R -10 -3R -10-3R-10 421.30 89.61 421.30 79.32 425.00 8.709 Centre Distance Pass - Major Risk 3R-10 - 3R -10A- 3R -10A 518.82 91.03 518.82 78.24 525.00 7.121 Clearance Factor Pass - Major Risk 3R -10 -3R -10A -3R -10A 421.30 89.61 421.30 79.32 425.00 8.709 Centre Distance Pass - Major Risk 3R -11D -3R -11D -3R -11D 518.82 91.03 518.82 78.24 525.00 7.121 Clearance Factor Pass - Major Risk 3R-11 D - 3R-11 D - 3R-11 D 396.90 113.93 396.90 107.15 400.00 16.817 Centre Distance Pass - Major Risk 445.54 114.27 445.54 106.70 450.00 15.089 Clearance Factor Pass - Major Risk 3R -12D -3R -12A -3R -12A 421.14 138.23 421.14 3R -12D -3R -12A -3R -12A 127.93 425.00 13.429 Centre Distance Pass - Major Risk 3R -12D -3R -12D -3R -12D 517.65 139.49 517.65 126.72 525.00 10.922 Clearance Factor Pass - Major Risk 3R -12D -3R -120 -3R -12D 421.14 138.23 421.14 127.93 425.00 13.429 Centre Distance Pass - Major Risk 3R-14 - 3R-14 - 3R-14 517.65 139.49 517.65 126.72 525.00 10.922 Clearance Factor Pass - Major Risk 3R -14 -3R -14-3R-14 46.90 255.02 46.90 252.46 50.00 99.532 Centre Distance Pass -Major Risk 2,480.47 299.35 2,480.47 242.81 2,750.00 5.294 Clearance Factor Pass - Major Risk 3R -26 -3R -26-3R-26 371.40 228.02 371.40 221.64 3R -26 -3R -26-3R-26 375.00 35.762 Centre Distance Pass - Major Risk 3R-26 - 3R-26PB1 - 3R-26PB1 419.66 228.39 419.66 221.05 425.00 31.108 Clearance Factor Pass - Major Risk 3R-26-3R-26PB1-3R-26PB1 371.40 228.02 371.40 221.55 375.00 35.243 Centre Distance Pass - Major Risk Plan: 3R -102 -Plan: 3R-102-3R-102wp09 419.66 228.39 419.66 220.95 425.00 30.715 Clearance Factor Pass - Major Risk Plan: 3R-102 - Plan: 3R-102 - 3R-102wp09 474.41 29.42 474.41 21.02 475.00 3.499 Centre Distance Pass - Major Risk 573.56 30.26 573.56 20.17 575.00 2.999 Clearance Factor Pass - Major Risk Kuparuk 011ktok Oliktok Point State 1 - Oliktok Point State 1 - Oliktok P 507.92 61.64 Oliktok Point State 1 - Oliktok Point State 1 - Oliktok P 507.92 53.00 500.00 7.138 Centre Distance Pass - Major Risk 556.82 62.07 556.82 52.52 550.00 6.498 Clearance Factor Pass - Major Risk Oliktok Point 0106-05 - 0106-05 - 0106-05 7,070.50 213.58 7,070.50 121.72 0106-05 - 0106-05 - 0106-05 4,950.00 2.325 Centre Distance Pass - Major Risk 0106-05 - 0106-05PB1 - 0106-05PB1 7,081.00 219.52 7,081.00 116.20 5,000.00 2.125 Clearance Factor Pass - Major Risk 0I06-05 - 0I06-05PB1 - 0106-05PBI 7,070.50 213.58 7,070.50 121.72 4,950.00 2.325 Centre Distance Pass - Major Risk 7,081.00 219.52 7,081.00 116.20 5,000.00 2.125 Clearance Factor Pass - Major Risk 18 January, 2017 - 10.:57 Page 2 of 8 COMPASS Anticollision Report for Plan: 3R-101 - 3R-101wp13 7ray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3R Pad - Plan: 3R-101 - Plan: 3R-101-3R-101wp13 Scan Range: 0.00 to 16,312.85 usft. Measured Depth. Scan Radius is 1,827.39 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited OP03-PO5-OP03-P05L1-OP03-PO5LI Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Centre Distance Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 8,245.05 521.97 0107-04 - 0107-04 - 0107-04 9,450.73 342.65 9,450.73 243.35 3,950.00 3.451 Clearance Factor Pass - Major Risk 0111-01-0111-01-0111-01 10,989.07 888.82 10,989.07 788.29 3,475.00 8.841 Centre Distance Pass - Major Risk 0111-01-0111-01-0111-01 10,995.85 889.27 10,995.85 787.72 3,500.00 8.757 Clearance Factor Pass - Major Risk 0111-01 - 0111-01 PBI -0111-01 PBI 10,989.07 888.82 10,989.07 788.08 3,475.00 8.822 Centre Distance Pass - Major Risk 0111-01-0111-01 PBI -0111-01 PB1 10,995.85 889.27 10,995.85 787.50 3,500.00 8.738 Clearance Factor Pass - Major Risk 0115-S4 - 0115-54 - 0115-S4 11,518.09 865.44 11,518.09 768.59 3,525.00 8.936 Centre Distance Pass - Major Risk 0115-S4-0115-54-0115-54 11,527.75 866.50 11,527.75 768.47 3,550.00 8.839 Clearance Factor Pass - Major Risk 0120-07 - 0120-07 - 0120-07 16,299.72 782.85 16,299.72 222.43 7,375.00 1.397 Clearance Factor Pass - Major Risk 0120-07-0120-07PB1-0120-07PB1 16,299.72 782.85 16,299.72 222.28 7,375.00 1.397 Clearance Factor Pass - Major Risk 0120-07 - 0120-07PB2 - 0120-07PB2 16,299.72 782.85 16,299.72 222.43 7,375.00 1.397 Clearance Factor Pass -Major Risk 0124-08 - 0124-08 - 0124-08 15,900.76 224.40 15,900.76 62.82 7,275.00 1.389 Centre Distance Pass - Major Risk 0124-08 - 0124-08 - 0124-08 16,082.06 243.18 16,082.06 36.48 7,475.00 1.177 Clearance Factor Pass - Major Risk Oliktok Point 1-1 - Oliktok Point 1-1 - Oliktok Paint 1-1 7,511.97 936.35 7,511.97 847.63 4,250.00 10.553 Centre Distance Pass - Major Risk Oliktok Point 1-1 - Oliktok Point 1-1 - Oliktok Point 1-1 7,500.00 936.91 7,500.00 847.25 4,275.00 10.450 Clearance Factor Pass - Major Risk Oliktok Point 1-2 - Oliktok Point 1-2 - Oliktok Point 1-2 12,976.66 835.53 12,976.66 698.97 4,650.00 6.119 Centre Distance Pass - Major Risk Oliktok Point 1-2 - Oliktok Point 1-2 - Oliktok Point 1-2 13,052.01 837.67 13,052.01 694.96 4,750.00 5.870 Clearance Factor Pass - Major Risk Oliktok Point 1-2 - Oliktok Point 1-2PB1 - Oliktok Point 1 12,982.99 846.93 12,982.99 708.64 4,650.00 6.124 Centre Distance Pass - Major Risk Oliktok Point l-2-Oliktok Point l-2PB1-Oliktok Point 13,040.47 849.25 13,040.47 706.09 4,725.00 5.932 Clearance Factor Pass - Major Risk Oliktok Point 1-2 - Oliktok Point 1-2PB2 - Oliktok Point 1 12,976.66 835.53 12,976.66 698.97 4,650.00 6.118 Centre Distance Pass - Major Risk -� Oliktok Point 1-2 - Oliktok Point 1-2PB2 - Oliktok Point 1 13,052.01 837.67 13,052.01 694.96 4,750.00 5.870 Clearance Factor Pass - Major Risk OP03-P05-OP03-P05-OP03-PO$ 8,245.05 521.97 8,245.05 423.10 4,425.00 5.280 Centre Distance Pass - Major Risk OP03-PO5-OP03-P05-OP03-P05 8,243.98 524.38 8,243.98 421.54 4,475.00 5.099 Clearance Factor Pass - Major Risk OP03-PO5-OP03-P05L1-OP03-PO5LI 8,245.05 521.97 8,245.05 422.91 4,425.00 5.269 Centre Distance Pass - Major Risk OP03-P05-OP03-P05L1-OP03-P051-1 8,243.98 524.38 8,243.98 421.32 4,475.00 5.088 Clearance Factor Pass - Major Risk OP03-PO5-OP03-P05PB1-OP03-P05PB1 8,245.05 521.97 8,245.05 422.99 4,425.00 5.274 Centre Distance Pass - Major Risk OP03-P05-OP03-P05PB1-OP03-PO5PB1 8,243.98 524.38 8,243.98 421.44 4,475.00 5.094 Clearance Factor Pass - Major Risk OP03-PO5-OP03-P05PB2-OP03-PO5PB2 8,245.05 521.97 8,245.05 423.10 4,425.00 5.280 Centre Distance Pass - Major Risk OP03-PO5-OP03-P05PB2-OP03-P05PB2 8,243.98 524.38 8,243.98 421.54 4,475.00 5.099 Clearance Factor Pass - Major Risk OP05-06 - OPO5-06 - OP05-06 7,210.53 545.96 7,210.53 452.21 4,725.00 5.824 Centre Distance Pass - Major Risk OP05-06 - OPOS-06 - OPOS-06 7,206.17 547.19 7,206.17 451.22 4,750.00 5.702 Clearance Factor Pass - Major Risk 18 January, 2017 - 10:57 Page 3 of 8 COMPASS Anticollision Report for Plan: 311-101 - 3R-101wp13 Trev. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kupamk 3R Pad - Plan: 3R-101 - Plan: 3R-101 - 3R-101wp13 Scan Range: 0.00 to 16,312.85 usft. Measured Depth. Scan Radius is 1,827.39 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited OP09-SO1 - OP09-SO1 L1 PB1 -OP09-SO1 L1 PBI Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Pass - Major Risk --� Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft 11.164 Centre Distance Pass - Major Risk OP05-06 - OP05-061-1 - OP05-061-1 7,210.53 545.96 7,210.53 452.13 4,725.00 5.819 Centre Distance Pass - Major Risk OPOS-06-OP05-06L1-OP05-0611 7,206.17 547.19 7,206.17 451.14 4,750.00 5.697 Clearance Factor Pass - Major Risk OP05-06-OP05-06PBI-OP05-06PB1 7,210.53 545.96 7,210.53 452.10 4,725.00 5.817 Centre Distance Pass - Major Risk OP05-06 - OP05-06PBI - OP05-06PB1 7,206.17 547.19 7,206.17 451.12 4,750.00 5.696 Clearance Factor Pass - Major Risk OP05-06-OP05-06PB2-OP05-06PB2 7,210.53 545.96 7,210.53 452.21 4,725.00 5.824 Centre Distance Pass - Major Risk OP05-06 - OP05-06PB2 - OP05-06P62 7,206.17 547.19 7,206.17 451.22 4,750.00 5.702 Clearance Factor Pass - Major Risk OP08-04 - OP08-04 - OPOB-04 10,464.32 550.47 10,464.32 433.80 3,625.00 4.718 Centre Distance Pass - Major Risk OP08-04-OPOB-04-OP08-04 10,464.74 551.31 10,464.74 432.35 3,650.00 4.635 Clearance Factor Pass - Major Risk OPOB-04-OP08-0411-OP08-041-1 10,464.32 550.47 10,464.32 433.81 3,625.00 4.718 Centre Distance Pass - Major Risk OP08-04 - OP08-04L1 - OP08-041-1 10,464.74 551.31 10,464.74 432.36 3,650.00 4.635 Clearance Factor Pass - Major Risk OPOB-04-OP08-04L1 PB1 -OPO8-041-1 PB7 10,464.32 550.47 10,464.32 433.81 3,625.00 4.718 Centre Distance Pass - Major Risk OP08-04 - OP08-04LI PB1 -OP08-04L1 PBI 10,464.74 551.31 10,464.74 432.36 3,650.00 4.635 Clearance Factor Pass - Major Risk OP08-04 - OP08-04PB1 - OP08-04PB1 10,464.32 550.47 10,464.32 433.80 3,625.00 4.718 Centre Distance Pass - Major Risk OP08-04 - OP08-04PB1 - OP08-04PB1 10,464.74 551.31 10,464.74 432.35 3,650.00 4.635 Clearance Factor Pass - Major Risk OP09-S01 - OP09-S01 - OP09-S01 10,237.95 1,026.75 10,237.95 932.65 3,250.00 10.911 Centre Distance Pass - Major Risk OP09-S01-OP09-S01-OP09-SOt 10,236.17 1,027.21 10,236.17 932.10 3,275.00 10.801 Clearance Factor Pass - Major Risk OP09-SO1 - OP09-SO1 L7-OP09-SO1 L1 10,237.95 1,026.75 10,237.95 932.65 3,250.00 10.911 Centre Distance Pass - Major Risk OP09-S01-OP09-S011-7-OP09-S01L1 10,236.17 1,027.21 10,236.17 932.10 3,275.00 10.801 Clearance Factor Pass - Major Risk OP09-SO1 - OP09-SO1 L1 PB1 -OP09-SO1 L1 PBI 10,237.95 1,026.75 10,237.95 932.65 3,250.00 10.911 Centre Distance Pass - Major Risk --� OP09-SOI - OP09-SO1 Li PB1 -OP09-SO1 L1 PB1 10,236.17 1,027.21 10,236.17 932.10 3,275.00 10.801 Clearance Factor Pass - Major Risk Opt 0-09- Opt 0-09- Opt 0-09 11,086.85 1,120.30 11,086.85 1,019.95 3,250.00 11.164 Centre Distance Pass - Major Risk Opt 0-09-OP70-09- Opt 0-09 11,100.00 1,120.69 11,100.00 1,019.80 3,275.00 11.108 Clearance Factor Pass - Major Risk OP10-09-OPIO-09L1-OP10-091-1 11,086.85 1,120.30 11,086.85 1,019.95 3,250.00 11.164 Centre Distance Pass - Major Risk OP10-09-OP10-091-1-OP10-091-1 11,100.00 1,120.69 11,100.00 1,019.80 3,275.00 11.108 Clearance Factor Pass - Major Risk OP12-01 - Opt2-02- OP12-02 11,433.76 747.99 11,433.76 620.99 3,800.00 5.890 Centre Distance Pass - Major Risk Opt 2-01-OPI2-02-OP12-02 11,451.69 749.65 11,451.69 619.33 3,850.00 5.753 Clearance Factor Pass - Major Risk OP1 B-03- Opt 6-03- Opt 6-03 16,302.86 385.10 16,302.86 266.03 7,700.00 3.234 Clearance Factor Pass - Major Risk OP16-03-OP16-0311-OP16-0311 16,302.13 385.21 16,302.13 266.17 7,700.00 3.236 Clearance Factor Pass - Major Risk Opt 6 -03 - Opt 6-031-1 PB1 -OP16-03L1 PB1 16,302.13 385.21 16,302.13 266.38 7,700.00 3.242 Clearance Factor Pass - Major Risk OP17-02-OP17-02- Opt 7-02 14,181.28 340.11 14,181.28 213.31 6,050.00 2.682 Centre Distance Pass - Major Risk 16 January, 2017 - 10:57 Page 4 of 8 COMPASS Anticollision Report for Plan: 3R-101 - 3R-101wp13 Trev. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3R Pad - Plan: 3R-101 - Plan: 3R-101-311-101wp13 Scan Range: 0.00 to 16,312.85 usft. Measured Depth. Scan Radius is 1,827.39 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited SurveV tool OrOOran, From Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on 39.00 Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 2,350.35 9,187.84 3R-101wp13 OP17-02 - OP17-02 - OP17-02 14,403.79 356.16 14,403.79 195.77 6,300.00 2.221 Clearance Factor Pass - Major Risk OP77-02- Opt 7-02PB1-Opt 7-02PB1 14,181.28 340.11 14,181.28 213.18 6,050.00 2.680 Centre Distance Pass - Major Risk OP17-02- Opt 7-02PB1-OP77-02PB1 14,403.79 356.16 14,403.79 195.64 6,300.00 2.219 Clearance Factor Pass - Major Risk OP19-T1N- Opt 9-T1N-OP19-T1N 11,415.49 366.62 11,415.49 269.73 4,100.00 3.784 Centre Distance Pass - Major Risk Opt 9-T1N-OP79-T1N-OP19-T1N 11,442.20 369.01 11,442.20 267.28 4,150.00 3.627 Clearance Factor Pass - Major Risk OP19-T1N-OP79-T1 NPB1- Opt 9-T1 NPB1 11,415.49 366.62 11,415.49 269.73 4,100.00 3.784 Centre Distance Pass - Major Risk OP19-TlN- Opt 9-T1 NPB1-OP19-T1 NPBi 11,442.20 369.01 11,442.20 267.28 4,150.00 3.627 Clearance Factor Pass - Major Risk OP21-WW01-OP21-WW01-OP21-WWV01 9,719.87 495.21 9,719.87 383.61 4,325.00 4.437 Clearance Factor Pass - Major Risk OP21-WW01-OP21-WW01-OP21-WW01 9,711.69 494.34 9,711.69 383.86 4,350.00 4.474 Centre Distance Pass - Major Risk OP22-VM03-OP22-WNV03-OP22-WA03 10,992.55 458.95 10,992.55 346.57 4,200.00 4.084 Clearance Factor Pass - Major Risk OP23-WW02-OP23-WW02-OP23-VAW2 10,483.65 337.49 10,483.65 215.98 3,925.00 2.777 Centre Distance Pass - Major Risk OP23-WW02-OP23-WW02-OP23-VAW2 10,481.48 338.92 10,481.48 213.89 3,950.00 2.711 Clearance Factor Pass - Major Risk OP26-DSP02 - OP26-DSP02 - OP26-DSP02 11,000.47 677.56 11,000.47 567.36 3,850.00 6.148 Centre Distance Pass - Major Risk OP26-DSP02 - OP26-DSP02 - OP26-DSP02 11,003.33 678.22 11,003.33 566.99 3,875.00 6.098 Clearance Factor Pass - Major Risk SurveV tool OrOOran, From To Survey/Plan Survey Tool (usft) (usft) 39.00 950.00 3R-101wp13 GVD-GC-SS 950.00 1,950.00 3R-101wpt3 MWD 950.00 2,350.35 3R-101wp13 MWD+IFR-AK-CAZ-SC 2,350.35 3,850.35 3R-101wpi3 MWD 2,350.35 9,187.84 3R-101wp13 MWD+IFR-AK-CAZ-SC 9,187.84 10,687.84 3R-101wp13 MWD 9,187.84 16,312.85 3R-101wp13 MWD+IFR-AK-CAZ-SC 18 January, 2017 - 10:57 Page 5 of 8 COMPASS Anticollision Report for Plan: 3R-101 - 3R-101wp13 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles /(Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method, 18 January, 2017 - 10:57 Page 6 of 8 COMPASS Ladder View 9:56, January 18 2B1 Ladder View 3 R- 1 0 1 w p 1 3 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. y $ r � dim O 11 00 300— 0 .0 `m n d U m I 150 U 0 Z c m I U Equlvtlanl Ml,l DI.. e 0 2500 5000 7500 10000 12500 15000 Displayed interval could be less than entire well:Measured Depth 39.00 To 16312.85 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 950.00 3R-101wpl3 (Plan: 3R-101) GYD-GC-SS 117.90 117.90 20" x 42" 950.00 1950.00 3R-101wp13 (Plan: 3R-101) MWD 2200.00 2350.35 13-3/8" x 16" 950.00 2350.35 3R-101wp13(Plan: 3R-101) MWD+IFR-AK-CAZ-SC 3615.05 9187.84 95/8"x12-1/4 2350.35 3850.35 3R-101 wpl 3(Plan: 3R-101) MWD 3501.86 16312.85 41/2"x6-3/4" 2350.35 9187.84 311-101 wpl3 (Plan: 3R-101) MWD+IFR-AK-CAZ-SC 9187.84 10687.84 3R-101 wpl3 (Plan: 3R-101) MWD 9187.84 16312.85 3R-101wpl3 (Plan: 3R-101) MWD+IFR-AK-CAZ-SC s s E s o ' so c 0 `m n m N m 30 U 0 T c 11 U 0 CE,Wl V.M M,g I. DMt."Mo 1000 1500 2000 2500 3000 3500 Partial Measured Depth TC View 3R-101 wp13 39.00 To 16312.85 11:35. January 18 2017 w. •wmea. mm .,,31, .,b1 aPoe. m aon 9rm �ss w p,•;ml ,� r.0 +mzes w,m..nlw.,w+mi .rwo.ee.x<.�sc cnswc DErAius ND No Name Size 117.90 117.90 20' x42' 20 2200.00 2350.35 13 W x 16' 133/8 3615.05 9187.84 95/8'x12-1/4 93x8 3501.86 16312.85 41/2'x63+4' 4-12 azaoa -60 1300 -90/270 -120/240 . rwo++aem ew ,.ioo+ i.u•+o,o,rsa .1.1 T, imm11 sa ]IF+O+R+U+O+)89 ax,mnm+on se ,enerta omn sB MOVESO j .� MVTIys"-,r 4'El"Ill MAIN -150/210 1_50 210 225 -F fi-1250 -180 / 180 3fl-11D 120 alktok Point State 1 E 3fl40A — 3&10 -� , 39 400 400 590 590 — 770 770 — 960 960 1140 o�w, 1140 — 1330 1330— 1510 1510 1700 1700 2310 2310 2930 2930 — 3540 3540 4150 4150 — 4760 4760 — 5370 5370 5990 5990 - 6600 6600 7810 7810 9030 9030 10240 10240 — 11460 11460 — 12670 12670 13880 13880 15100 60 15100 — 16313 120 alktok Point State 1 E 3fl40A — 3&10 -� , -►- a a ....... -a- v �- •, -il- m -t- wa -g- n w -t- omen -9- as a wru an,w y m a� im.mnmrew m-�%- o�w, AC Wells Only AC Flipbook 3R-101wp73 39.0o To 1500.00 39.00 0.00 casingnemils 3R-lozwpo9 400.00 0.00 14140.85 270.16 TVD 600.09 347-72 Name Depth From 174231 347-72 127.90 17.90 185342 34772 39.00 95omo 235035 34772 2350.35 13318" '61 2370.35 347-72 1950.-0 36,.05 319150 349.40 9518"x 11414 4150 684792 349.40 3501.86 163+2.85 7655.91 312.40 2950.00 350.35 385.35 7855.91 312-40 6600 6600 8052.08 30393 9187.64 9030 805436 30393 10240 9187.84 8811.05 270.16 11460 -6o/300 9187.84 270.16 13880 13880 9207.84 270.16 15100 16313 939782 270.16 9881.66 270.16 9926.62 270.16 9964.24 270.16 10532.46 270.16 10711.51 270.16 10712.58 270.16 11022.76 27oA 11023.83 270.16 11142.90 270.16 -C 0 270 / 11608.72 270.16 11669.65 270.16 11718.15 27o.t6 12106.26 270.16 12119-71 27o.t6 12131.65 270.16 12580.46 270.16 12669.77 27o.t6 12677.36 27oA 13185.91 27oA 13208.67 270.16 -120/240 13208.67 270.16 13619.48 270.16 13619.48 270.[6 13683.37 270.16 -30/ 14to5.83 270.16 14118.05 270.16 casingnemils 3R-lozwpo9 �\ 14140.85 270.16 TVD MD Name Depth From Depth To 127.90 17.90 x0"x42" 39.00 95omo 220..-- 2350.35 13318" '61 950.00 1950.-0 36,.05 9187.84 9518"x 11414 4150 2350.35 3501.86 163+2.85 4'he x6-314" 2950.00 350.35 385.35 5990 6600 6600 235-35 9187.64 9030 9030 10240 9187.84 io687.84 -30/ 14to5.83 270.16 14118.05 270.16 400 3R-lozwpo9 �\ 14140.85 270.16 770 770 960 14780.70 27o.t6-- 14819.30 27o.t6 -150 / 210 14868.54 270.16 1330 15056.43 270.16 1510 11:37, January 18 2017 0/36o 90 Me U IJ Es Tool GYDSL55 MWD M NIFR-AMCA2-SC MWD MWOrIFR.AK{A -SC MWD Es OM Oliktok Point State 1 20 39 400 400 590 590 770 770 960 960 1140 1140 1330 1330 1510 1510 1700 1700 2310 2310 2930 2930 3540 3540 4150 4150 4760 4760 5370 5370 5990 5990 6600 6600 7810 7810 9030 9030 10240 10240 11460 11460 12670 12670 13880 13880 15100 15100 16313 3R-1o1wp13 • 1500 00 TO 15000 00 • Caeing De[allz TVD MDName 1,.w 7.90 2200.00 x35-.35 3615.o5 9187,8, 01.86 16312.85 zo"x 9x" 13319"216" 9518"x1011, R"*6-314" Depth From 3900 950.00 950.00 2350.35 x350.35 918),89 1313).84 Depth To 95000 1950.00 2350.35 3850.35 9197.84 1068).84 1631x.85 Survey Program Surve,/Plan 3R-10' pW3(Plan;5RnaQ 3R-1mwg3(Plan: 3R-ion) 3R-01wP13(Plan: 3R-1031 3R-lmwp313 (Plan;3R-1.31 3RI-I1 Pf3(Plan:3R-110) 3R1o1wpf3 (PIan:3R-1103 Rto1w (Plan: 3R Tool DYDGCSS MWD MWDrIFFAK.C9-SC MWD MWDrIFRAKt92-SC MWD MM.IFRAK{ALSC 39 400 - 400 590 39.00 0.00 400.00 0.00 / 360 600.09 347.72 590 770 1742.31 347.72 1853.42 347.72 770 960 2350.35 347-72 -30/33 0 2370.35 347.72 960 1140 319150 34940 6847.92 34940 1140 1330 7655.91 312-40 7855.91 312.40 1330 1510 8052.08 303.93 0 805436 30393 8811.05 27D.16 -6o/300 300 60 1510 1700 9187.84 270.16 1700 2310 9207.84 270.16 9397.82 270.16 2310 2930 9881.66 270.16 9926.62 270.16 6 0 2930 3540 9964.24 270.16 10532.46 270.16 3540 4150 10711.51 270.16 10712.58 27o.16 4150 4760 11022.76 27o.16 11123.83 270.16 4760 1042.90 27o.ffi - o / 270 A0 5370 116o8.72 270.16 7 11669.65 270.16 5370 5990 11718.15 270.16 _ - 121o6.26 270.16 5990 - 6600 12119.71 27o.16 1x13165 270.16 G o 6600 7810 12580.46 270.16 V 12669-77 270.16 7810 9030 1267736 270.16 13185.91 270.16 9030 10240 13zo8.67 270.16 -120/240 120 13zo8.67 270.16 10240 11460 13619.48 270.16 1361948 270.16 120 11460 12670 13683.37 270.16 1410583 270.16 12670 13880 14118.05 270.16 14140.85 270.16 13880 15100 14780.70 270.16 14819.30 270.16 -150/210 150 15100 16313 14868.54 270.16 1 Q 0 15056.43 270.16 C7 151112.113 270.16 -18o/180 11:38, January 18 2017 3 R-� o • X50000o To w p 3 • �63�2 85 Casing Detaft ND MD zp.g0 0 '17.90 2350.35 3615.05 9507.84 0t86 63'305 Name 0"x 42" 13918"x16" 9518"xt311b p"x6 4" Depth ROm 3900 95..00 95..00 2350.35 235035 9187.84 9187.84 Depth To 950.00 '950.00 235035 385035 918184 +o687.84 1612.6 SUN" Pmgmm Survey/Plan 30. mtwpt3 (Plan: 311101) 3R4mwp13(Plan: 30.' 101) 3R'10n P13(Plan: 30.'101 3R-1mw Plan: 311 IM) 30.aotwpf3(PIan:3R-1.Q 3R-101wp13(Plan: 3R-101) 9 3R -101w Plan: 11101 T..[ CYD a SS MWD MWD�IFR AK{ Z. MWD SC MWDNFR AK{ -SC MWD MWpIFRAK{A2-SC 39 --- 4°° 400 '- p 590 39.00 0.00- 400.00 0.00 0 / 360 600.09 347.72 59° 770 1742.31 347.72 185342 34772 770 960 2350.35 347-72 -30/33 0 2370.35 347.72 96o 1140 3191.50 34940 6847.92 34940 1140 1330 7655.91 312.40 7855.91 312.40 133° 1510 8052.o8 30393 0 805436 30393 8811.05 270.16 -6o/300 6 0 1510 1700 918784 270.16 1700 2310 9207.84 270.16 939782 27o.16 2310 2930 9881.66 27o.16 9926.62 27o.i6 6 0 2930 3540 9964.24 27o.16 10532.46 27o.16 10711.51 270.16 3540 4150 10712.58 270.16 11022.76 270.16 4150 476o 11123.83 270.16 mgz.90 -C o / 270 4760 5370 x7006 A o 116o8.72 27o.16 7 11669.65 270.16 5370 5990 11718.15 270.16 121o6.26 270.16 jo 5990 - - - 6600 12119.71 x70.16 12131.65 27o.16 66°0 7810 12580.46 270.16 12669-77 270-16 )120 ]810 9°3° 1� 12677.36 270.16 13185.91 270.16 9030 10240 13208.67 270.16 /� -120 240 13208.67 270.16 10240 1146o 13619.48 270.16 13619.48 27o.16 120 1146° 12670 13683.37 270.16 14105.83 27o.16 12670 13880 14118.05 270.16 14140.85 27o.16 1388° 15100 14780.70 270.16 1481g.3o 270.16 -150/210 150 15100 16313 14868.54 27o.16 180 15056.43 270.16 _ 1310x09 z7o.ffi -18o/180 11:39, January 18 2017 Errors Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad Plan: 3R-101 Plan: 3R-101 Plan: 3R-101wp13 Errors Report 18 January, 2017 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 3R Pad Well: Plan: 31R-101 Wellbore: Plan: 3R-101 Design: 3R-101wpl3 Errors Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyonl42) Plan: 39+9.9 @ 48.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 3R Pad Plan: 3R-101 Survey Tool Program Date 1118/2017 Site Position: Northing: 6,031,398.78usft Latitude: 70°29'50.390N From: Map Easting: 1,660,687.47 usft Longitude: 149" 50'3.220 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.16 ° Well Plan: 3R-101 Survey Tool Program Date 1118/2017 Audit Notes: To (usft) (usft) Survey (Wellborn) Version: Well Position +N/S 0.00 usft Northing: 6,031,484.21 usft Latitude: 70'29'51.231 N (usft) +E/ -W 0.00 usft Easting: 1,660,657.38 usft Longitude: 149° 50'4.099 W Position Uncertainty 39.00 0.00 usft Wellhead Elevation: D.00 usft Ground Level: 9.90usft Wellbore Plan: 3R-101 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 0 0 (nT) BGGM2016 3/1/2017 17.77 81.04 57,552 Design 3R-101wpl3 Gymdata gyro single shots Survey Tool Program Date 1118/2017 Audit Notes: To (usft) (usft) Survey (Wellborn) Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 2,350.35 (usft) (usft) (usft) (% 9,187.84 39.00 0.00 0.00 270.00 Tool Name Description GYD-GC-SS Gymdata gyro single shots Survey Tool Program Date 1118/2017 From To (usft) (usft) Survey (Wellborn) 39.00 950.00 3R-101wp13 (Plan: 3R-101) 950.00 1,950.00 3R-101wpl3(Plan: 3R-101) 950.00 2,350.35 3R-101wp13(Plan: 3R-101) 2,350.35 3,850.35 3R-101wp13(Plan: 3R-101) 2,350.35 9,187.84 3R-101wpl3(Plan: 3R-101) 9,187.84 10,687.84 3R-101wP13(Plan: 3R-101) 9,187.84 16,312.85 3R-101wp13 (Plan: 3R-101) Planned Survey 0.19 MD MD Error Inc (usft) (usft) (°) 39.00 0.00 0.00 100.00 1.15 0.00 117.90 1.15 0.00 20" x 42" 200.00 1.15 0.00 300.00 1.15 0.00 Tool Name Description GYD-GC-SS Gymdata gyro single shots MWD MWD -Standard MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD MWD -Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Ellipse Inc TVDSS Vert. Error Let Error Hoa. Error (°) (usft) (usft) (usft) (usft) 0.00 -9.90 0.00 0.00 0.00 0.00 51.10 1.15 0.04 0.04 0.00 69.00 1.15 0.19 0.19 0.00 151.10 1.15 0.19 0.19 0.00 251.10 1.15 0.33 0.33 1/182017 1:29:35PM Page 2 COMPASS 5000.1 Build 74 Errors Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 Survey Calculation Method: Design: 3R-101wp13 Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyonl42) True Minimum Curvature OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Let Error Horz. Error (us8) (usR) (I (I (usR) (usR) (usft) Waft) 400.00 1.15 0.00 0.00 351.10 1.15 0.48 0.48 KOP: Start 1.5°/100' DLS, 347.72° TF, for 200.09' 500.00 1.15 1.50 45.00 451.09 1.15 0.62 0.62 600.00 1.16 3.00 77.50 551.01 1.15 0.77 0.77 600.09 1.16 3.00 77.50 551.10 1.15 0.77 0.77 Start 2°1100' DLS, 0° TF, for 1142.21' 700.00 1.16 5.00 77.27 650.76 1.16 0.91 0.91 800.00 1.17 7.00 74.78 750.21 1.16 1.06 1.05 900.00 1.17 9.00 168.44 849.23 1.16 1.22 1.20 1,000.00 1.18 11.00 167.60 947.71 1.15 1.31 1.27 1,100.00 1.20 13.00 166.96 1,045.52 1.15 1.38 1.28 1,200+00 1.21 15.00 166.95 1,142.54 1.15 1.55 1.30 1,300.00 1.23 17.00 167.00 1,238.66 1.15 1.82 1.34 1,400.00 1.24 19.00 167.04 1,333.76 1.15 2.17 1.39 1,500.00 1.26 21.00 167.08 1,427.73 1.15 2.61 1.46 1,600.00 1.29 23.00 167.11 1,520.44 1.16 3.12 1.55 1,700.00 1.31 25.00 167.15 1,611.79 1.18 3.69 1.66 1,738.97 1.32 25.78 167.16 1,647.00 1.18 3.95 1.71 T3 1,742.31 1.32 25.85 167.16 1,650.00 1.18 3.95 1.71 Hold for 111.11' 1,794.08 1.33 25.85 167.17 1,696.60 1.20 4.32 1.79 Base Pfrost 1,800.00 1.33 25.85 167.17 1,701.92 1.20 4.32 1.79 1,853.42 1.33 25.85 167.18 1,750.00 1.22 4.66 1.86 Start 4.1100' DLS, 0° TF, for 496.93' 1,900.00 1.35 27.71 167.19 1,791.58 1.23 4.97 1.92 2,000.00 1.40 31.71 163.85 1,878.42 1.19 2.66 1.70 2,071.52 1.46 34.57 164.09 1,938.30 1.19 2.96 1.77 K15 2,100.00 1.46 35.71 164.09 1,961.59 1.19 2.96 1.77 2,200.00 1.52 39.71 164.34 2,040.69 1.21 3.29 1.83 2,300.00 1.60 43.71 164.58 2,115.33 1.23 3.66 1.90 2,350.35 1.64 45.72 164.70 2,151.10 1.24 3.86 1.93 Hold for 20'. 13-318" x 16" 2,370.35 1.66 45.72 164.76 2,165.07 1.19 3.95 1.94 Start 4°1100' DLS, 3.04° TF, for 821.15' 2,400.00 1.69 46.91 165.05 2,185.54 1.19 4.09 1.92 2,500.00 1.77 50.90 165.95 2,251.26 1.21 4.77 1.89 2,600.00 1.86 54.90 166.62 2,311.57 126 5.66 1.90 2,700.00 1.95 58.89 167.10 2,366.18 1.37 6.72 1.96 2,800.00 2.04 62.89 167.45 2,414.81 1.53 7.91 2.07 2,900.00 2.14 66.89 167.72 2,457.24 1.74 9.20 2.22 3,000.00 2.23 70.88 167.94 2,493.26 1.99 10.55 2.41 3,100.00 2.34 74.88 168.12 2,522.69 2.28 11.96 2.62 1/182017 1:29:35PM Page 3 COMPASS 5000.1 Build 74 Errors Report Company: ConowPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kupauk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 Survey Calculation Method; Design: 3R-101wp13 Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Let Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 3,191.50 2.44 78.54 168.27 2,543.72 2.56 13.28 2.83 Hold for 3656.42' 3,200.00 2.44 78.54 168.28 2,545.41 2.58 13.41 2.86 3,300.00 2.44 76.54 168.41 2,565.29 2.91 14.88 3.19 3,400.00 2.45 78.54 168.52 2,585.16 3.25 16.36 3.52 3,500.00 2.46 78.54 168.60 2,605.04 3.58 17.84 3.86 3,600.00 2.47 78.54 168.68 2,624.91 3.93 19.34 4.20 3,700.00 2.47 78.54 168.73 2,644.78 4.27 20.84 4.55 3,800.00 2.48 78.54 168.78 2,664.66 4.61 22.34 4.90 3,900.00 2.41 78.54 168.18 2,684.53 2.63 10.34 2.83 4,000.00 2.41 78.54 168.25 2,704.40 2.79 10.89 2.99 4,100.00 2.42 78.54 168.32 2,724.28 2.95 11.43 3.15 4,200.00 2.43 78.54 168.38 2,744.15 3.12 11.99 3.32 4,300.00 2.44 78.54 168.43 2,764.03 3.28 12.54 3.48 4,400.00 2.45 78.54 168.48 2,783.90 3.45 13.10 3.65 4,500.00 2.46 78.54 168.52 2,803.77 3.61 13.66 3.82 4,514.22 2.47 78.54 168.55 2,806.60 3.78 14.22 3.99 Top Ugnu C 4,600.00 2.47 78.54 168.55 2,823.65 3.78 14,22 3.99 4,700.00 2.48 78.54 168.59 2,843.52 3.95 14.78 4.15 4,800.00 2.49 78.54 168.62 2,863.40 4.12 15.35 4.32 4,900.00 2.50 78.54 168.65 2,883.27 4.29 15.91 4.50 5,000.00 2.51 78.54 168.67 2,903.14 4.46 16.48 4.67 5,100.00 2.52 78.54 168.70 2,923.02 4.63 17.05 4.84 5,200.00 2.53 78.54 168.72 2,942.89 4.80 17.62 5.01 5,300.00 2.54 78.54 168.74 2,962.76 4.97 18.19 5.18 5,400.00 2.55 78.54 168.76 2,982.64 5.14 18.76 5.35 5,500.00 2.56 78.54 168.78 3,002.51 5.31 19.33 5.53 5,600.00 2.57 78.54 168.79 3,022.39 5.48 19.91 5.70 5,681.08 2.59 78.54 168.81 3,038.50 5.65 20.48 5.87 Top Ugnu B 5,700.00 2.59 78.54 168.81 3,042.26 5.65 20.48 5.87 5,800.00 2.60 78.54 168.82 3,062.13 5.82 21.05 6.05 5,900.00 2.61 78.54 168.84 3,082.01 6.00 21.63 6.22 6,000.00 2.62 78.54 168.85 3,101.88 6.17 22.20 6.40 6,100.00 2.63 78.54 168.86 3,121.76 6.34 22.78 6.57 6,200.00 2.65 78.54 168.87 3,141.63 6.51 23.35 6.74 6,300.00 2.66 78.54 168.8B 3,161.50 6.68 23.93 6.92 6,400.00 2.67 78.54 168.89 3,181.38 6.86 24.50 7.09 6,500.00 2.68 78.54 168.90 3,201.25 7.03 25.08 7.27 6,600.00 2.70 78.54 168.91 3,221.12 7.20 25.86 7.44 6,700.00 2.71 78.54 168.92 3,241.00 7.37 26.23 7.62 6,800.00 2.72 78.54 168.93 3,260.87 7.55 26.81 7.79 6,826.30 2.73 78.54 168.93 3,266.10 7.63 27.09 7.88 Top Ugnu A 111812017 1:29:35PM Page 4 COMPASS 5000.1 Build 74 Errors Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Project Kuparuk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 Survey Calculation Method: Design: 3R-101wpl3 Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyonl42) Plan: 39+9,9 @ 48.90ush (Doyonl42) True Minimum Curvature OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Let Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 6,847.92 2.73 78.54 168.93 3,270.40 7.63 27.09 7.88 Start 4.5°/100' DLS, -91.34° TF, for 808' 6,900.00 2.90 78.49 168.93 3,280.77 7.72 27.31 7.96 7,000.00 4.15 78.46 168.87 3,300.76 7.89 27.48 8.13 7,100.00 5.94 78.50 168.76 3,320.74 8.06 27.49 8.32 7,200.00 7.91 78.61 168.58 3,340.59 8.23 27.36 8.53 7,300.00 9.94 78.80 168.34 3,360.19 8.41 27.06 8.75 7,379.46 11.97 78.99 168.04 3,375.50 8.58 26.61 8.97 Top N Sands 7,400.00 11.97 79.05 168.04 3,379.41 8.58 26.61 8.97 7,500.00 13.98 79.37 167.67 3,398.15 8.75 26.01 9.19 7,600.00 15.95 79.76 167.24 3,416.27 8.92 25.27 9.40 7,655.91 17.03 80.00 166.98 3,426.10 9.02 24.79 9.52 Hold for 200' 7,700.00 17.03 80.00 166.74 3,433.76 9.10 25.01 9.59 7,800.00 17.04 80.00 166.14 3,451.12 9.27 25.56 9.76 7,855.91 17.04 80.00 165.81 3,460.83 9.37 25.86 9.85 Start 4.5°/100' DLS, -72.2° TF, for 196.17' 7,900.00 17.89 80.61 165.57 3,468.25 9.44 25.52 9.90 8,000.00 19.77 82.04 165.03 3,483.34 9.62 24.60 10.00 8,052.08 20.72 82.80 164.73 3,490.22 9.71 24.08 10.05 Hold for 2.28' 8,054.36 20.72 82.80 164.72 3,490.50 9.71 24.09 10.05 Start 4.5°/100' DLS, .82.87° TF, for 756.68' 8,100.00 21.56 83.06 164.44 3,496.13 9.79 23.58 10.12 8,200.00 23.32 83.66 163.85 3,507.70 9.97 22.33 10.26 8,300.00 24.98 84.29 163.22 3,518.20 10.14 20.96 10.40 8,400.00 26.52 84.97 162.57 3,527.57 10.32 19.49 10.52 8,500.00 27.94 85.67 161.91 3,535.74 10.49 17.94 10.64 8,600.00 29.21 86.40 161.23 3,542.66 10.67 16.31 10.76 8,700.00 30.35 87.15 160.54 3,548.30 10.85 14.63 10.89 8,800.00 31.33 87.91 159.85 3,552.61 11.02 12.94 11.03 8,811.05 31.43 88.00 159.77 3,553.00 11.04 12.76 11.05 Hold for 376.8' 8,828.24 31.43 88.00 159.18 3,553.60 11.20 13.18 11.20 Top West Salk D 8,900.00 31.43 88.00 159.18 3,556.10 11.20 13.18 11.20 9,000.00 31.43 88.00 158.52 3,559.59 11.38 13.67 11.38 9,100.00 31.43 88.00 157.87 3,563.08 11.55 14.17 11.56 9,187.84 31.53 88.00 157.01 3,566.15 11.63 14.72 11.63 Adjust TF to 0°, for 20'- 9 618" x 12-1/4 9,200.00 31.53 88.00 156.86 3,566.57 11.63 14.82 11.64 9,207.84 31.53 88.00 155.76 3,566.85 11.63 14.88 11.64 Start 1.5°/100' DLS, 0° TF, for 189.98' 9,300.00 31.54 89.38 155.56 3,568.95 11.64 15.71 11.63 1/18/2017 1:29.35PM Page 5 COMPASS 5000.1 Build 74 Errors Report Company: ConomPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 Survey Calculation Method: Design: 3R-101wp13 Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyonl42) Plan: 39+9,9 @ 48.90usft (Doyonl42) True Minimum Curvature OAKEOMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Veit. Error Let Error Hors. Error (usft) (usft) (°) (°) (usft) (waft) (usft) (usft) 9,397.82 31.53 90.85 154.22 3,568.75 11.66 16.70 11.69 Hold for 483.84' 9,400.00 31.53 90.85 154.19 3,568.72 11.66 16.73 11.69 9,500.00 31.53 90.85 152.74 3,567.24 11.70 17.85 11.72 9,600.00 31.53 90.85 151.21 3,565.76 11.75 19.06 11.77 9,700.00 31.53 90.85 149.60 3,564.27 11.80 20.34 11.83 9,800.00 31.54 90.85 147.91 3,562.79 11.87 21.68 11.90 9,881.66 31.54 90.85 146.47 3,561.58 11.94 22.82 11.96 Start 1.1100' DLS, -180° TF, for 44.96' 9,900.00 31.54 90.67 146.15 3,561.34 11.95 23.07 11.97 9,926.62 31.54 90.40 145.67 3,561.09 11.97 23.44 11.98 Adjust TF to 180°, for 37.62' 9,964.24 31.55 90.02 145.00 3,560.95 12.01 23.96 12.01 Hold for 568.22' 10,000.00 31.55 90.02 144.34 3,560.94 12.04 24.47 12.04 10,100.00 31.55 90.02 142.45 3,560.89 12.14 25.93 12.14 10,200.00 31.55 90.02 140.52 3,560.85 12.25 27.42 12.25 10,300.00 31.55 90.02 138.54 3,560.81 12.37 28.93 12.37 10,400.00 31.56 90.02 136.56 3,560.77 12.50 30.47 12.51 10,500.00 31.56 90.02 134.57 3,560.73 12.64 32.02 12.64 10,532.46 31.56 90.02 133.93 3,560.71 12.69 32.53 12.69 Start 2.5°/100' DIS, 0° TF, for 179.05' 10,600.00 31.54 91.71 132.60 3,559.69 12.79 33.58 12.85 10,700.00 31.46 94.21 150.75 3,554.52 11.96 19.66 12.22 10,711.51 31.45 94.50 150.69 3,553.65 11.96 19.70 12.26 Adjust TF to 0°, for 1.07' 10,712.58 31.45 94.53 150.69 3,553.57 11.96 19.71 12.26 Hold for 310.18' 10,800.00 31.45 94.53 150.23 3,546.67 12.00 20.09 12.30 10,900.00 31.45 94.53 149.69 3,538.77 12.04 20.53 12.34 11,000.00 31.45 94.53 149.13 3,530.88 12.09 20.98 12.39 11,022.76 31.45 94.53 149.01 3,529.08 12.10 21.08 12.40 Start 2.6.1100' DLS, -180° TF, for 1.07' 11,023.83 31.45 94.50 149.00 3,529.00 12.10 21.09 12.40 Adjust TF to 160°, for 119.07' 11,100.00 31.52 92.60 148.59 3,524.29 12.14 21.41 12.26 11,142.90 31.55 91.52 148.36 3,522.75 12.16 21.60 12.22 Hold for 465.81' 11,200.00 31.55 91.52 148.04 3,521.23 12.19 21.85 12.25 11,300.00 31.55 91.52 147.45 3,518.57 12.25 22.32 12.30 11,400.00 31.56 91.52 146.86 3,515.91 12.31 22.79 12.36 11,500.00 31.56 91.52 146.25 3,513.26 12.37 23.27 12.42 11,600.00 31.56 91.52 145.63 3,510.60 12.43 23.75 12.48 11,608.72 31.56 91.52 145.58 3,510.37 12.44 23.80 12.49 Start 2.5°/100' OLS, 180° TF, for 60.93' 1/18/2017 1:29:35PM Page 6 COMPASS 5000.1 Build 74 Errors Report Company: ConowPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kupawk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 Survey Calculation Method: Design: 3R-101wpl3 Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyonl42) Plan: 39+9,9 @ 48.90usft (Doyonl42) True Minimum Curvature OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS VerL Error Lat. Error Hoa. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (waft) 11,669.65 31.58 90.00 145.21 3,509.56 12.47 24.08 12.47 Adjust TF to -180°, for 48.61' 11,700.00 31.59 89.24 145.02 3,509.76 12.49 24.22 12.49 11,718.15 31.59 88.79 144.92 3,510.07 12.51 24.30 12.50 Hold for 388.1' 11,800.00 31.59 88.79 144.41 3,511.81 12.56 24.69 12.55 11,900.00 31.59 88.79 143.76 3,513.92 12.63 25.19 12.62 12,000.00 31.59 88.79 143.11 3,516.04 12.70 25.69 12.69 12,100.00 31.59 88.79 142.45 3,518.15 12.77 26.19 12.77 12,106.26 31.59 88.79 142.41 3,518.29 12.78 26.22 12.77 Start 0.5°/100' DLS, 180° TF, for 13.46' 12,119.71 31.59 88.72 142.32 3,518.58 12.79 26.28 12.78 Adjust TF to -180°, for 11.94' 12,131.65 31.59 88.66 142.24 3,518.85 12.80 26.34 12.79 Hold for 448.81' 12,200.00 31.60 88.66 141.80 3,520.45 12.85 26.67 12.84 12,300.00 31.60 88.68 141.12 3,522.79 12.93 27.18 12.92 12,400.00 31.60 88.66 140.44 3,525.13 13.01 27.70 13.00 12,500.00 31.60 88.66 139.74 3,527.46 13.09 28.21 13.08 12,580.46 31.60 88.66 139.18 3,529.35 13.15 28.63 13.15 Start 1.51100' DLS, 0° TF, for 89.31' 12,600.00 31.61 88.95 139.05 3,529.75 13.17 28.73 13.16 12,669.77 31.60 90.00 138.56 3,530.39 13.23 29.09 13.23 Adjust TF to 0°, for 7.69' 12,677.36 31.60 90.11 138.51 3,530.38 13.24 29.13 13.24 Hold for 508.56' 12,700.00 31.60 90.11 138.35 3,530.34 13.26 29.25 13.26 12,800.00 31.61 90.11 137.64 3,530.14 13.34 29.77 13.34 12,900.00 31.61 90.11 136.93 3,529.94 13.43 30.30 13.43 13,000.00 31.61 90.11 136.22 3,529.74 13.52 30.83 13.52 13,100.00 31.61 90.11 135.50 3,529.54 13.61 31.36 13.62 13,185.91 31.62 90.11 134.89 3,529.37 13.70 31.81 13.70 Start 0.51100' DLS, 180° TF, for 22.76' 13,200.00 31.62 90.04 134.79 3,529.35 13.71 31.89 13.71 13,208.67 31.62 90.00 134.73 3,529.35 13.72 31.93 13.72 Adjust TF to 0°, for 0'. Hold for 410.81' 13,300.00 31.62 90.00 134.08 3,529.35 13.80 32.42 13.80 13,400.00 31.62 90.00 133.37 3,529.35 13.90 32.95 13.90 13,500.00 31.62 90.00 132.66 3,529.35 14.00 33.49 14.00 13,600.00 31.63 90.00 131.95 3,529.35 14.10 34.03 14.10 13,619.48 31.63 90.00 131.82 3,529.35 14.12 34.14 14.12 Adjust TF to 0°, for 63.89' - Start 1°/100' DLS, 0° TF, for 0' 13,683.37 31.62 90.64 131.37 3,528.99 14.19 34.48 14.20 Hold for 422.46' 13,700.00 31.62 90.64 131.25 3,528.81 14.20 34.57 14.22 13,800.00 31.63 90.64 130.55 3,527.69 14.31 35.12 14.32 1/18/2017 1:29: 35PM Page 7 COMPASS 5000.1 Build 74 Errors Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Cc -ordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kupamk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 Survey Calculation Method: Design: 3R-101wp13 Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyon142) Plan: 39+9.9 (off 48.90usft (Doyonl42) True Minimum Curvature OAKEDMP2 Planned Survey MD MD. Error Inc Ellipse Inc TVDSS Vert. Error Let Error Hoa. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 13,900.00 31.63 90.64 129.86 3,526.58 14.41 35.66 14.43 14,000.00 31.63 90.64 129.17 3,525.46 14.52 36.21 14.53 14,100.00 31.63 90.64 128.49 3,524.35 14.63 36.75 14.64 14,105.83 31.63 90.64 128.45 3,524.28 14.63 36.79 14.65 Start 0.6°/100' DLS, 0- TF, for 12.21' 14,118.05 31.63 90.70 128.37 3,524.14 14.65 36.85 14.66 Adjust TF to 0°, for 22.81' 14,140.85 31.63 90.81 128.21 3,523.84 14.67 36.98 14.69 Hold for 639.86' 14,200.00 31.63 90.81 127.81 3,523.00 14.74 37.30 14.76 14,300.00 31.64 90.81 127.15 3,521.58 14.85 37.85 14.87 14,400.00 31.64 90.81 126.49 3,520.16 14.96 38.40 14.98 14,500.00 31.64 90.81 125.85 3,518.74 15.07 38.96 15.09 14,600.00 31.64 90.81 125.21 3,517.32 15.19 39.51 15.21 14,700.00 31.65 90.81 124.58 3,515.89 15.30 40.06 15.32 14,780.70 31.65 90.81 124.08 3,514.75 15.40 40.51 15.42 Start 1°/100' DLS, 0° TF, for 38.6' 14,800.00 31.65 91.01 123.96 3,514.44 15.42 40.62 15.44 14,819.30 31.64 91.20 123.85 3,514.07 15.44 40.73 15.47 Adjust TF to 0°, for 4924' 14,868.54 31.64 91.69 123.55 3,512.83 15.50 41.00 15.55 Hold for 187.89' 14,900.00 31.64 91.69 123.36 3,511.90 15.54 41.17 15.59 15,000.00 31.64 91.69 122.76 3,508.94 15.66 41.73 15.71 15,056.43 31.64 91.69 122.43 3,507.27 15.73 42.05 15.77 Start 1°/100' DLS, 0° TF, for 45.76' 15,100.00 31.63 92.13 122.18 3,505.82 15.78 42.29 15.84 15,102.19 31.63 92.15 122.16 3,505.74 15.78 42.30 15.85 Adjust TF to 0°, for 36A6' 15,137.65 31.62 92.50 121.96 3,504.30 15.82 42.50 15.91 Hold for 650.23' 15,200.00 31.63 92.50 121.60 3,501.58 15.90 42.85 15.98 15,300.00 31.63 92.50 121.04 3,497.21 16.02 43.41 16.11 15,400.00 31.63 92.50 120.49 3,492.84 16.15 43.97 16.23 15,500.00 31.63 92.50 119.95 3,488.47 16.27 44.53 16.35 15,600.00 31.64 92.50 119.43 3,484.10 16.40 45.09 16.48 15,700.00 31.64 92.50 118.91 3,479.73 16.52 45.65 16.60 15,787.88 31.64 92.50 118.47 3,475.89 16.64 46.15 16.72 Start 0.6.1100' DLS, 160° TF, for 0.35' 15,788.23 31.64 92.50 118.47 3,475.87 16.64 46.15 16.72 Hold for 624.62' 15,800.00 31.64 92.50 118.41 3,475.36 16.65 46.21 16.73 15,900.00 31.65 92.50 117.92 3,470.99 16.78 46.78 16.86 16,000.00 31.65 92.50 117.44 3,466.62 16.91 47.34 16.99 16,100.00 31.65 92.50 116.97 3,462.26 17.04 47.91 17.12 16,200.00 31.66 92.50 116.51 3,457.89 17.17 48.47 17.25 Wa2017 1:29:35PM Page 8 COMPASS 5000.1 Build 74 Company: ConocoPhillips(Alaska) Inc.-Kup2 Project: Kuparuk River Unit Site: Kuparuk 3R Pad Well: Plan: 3R-101 Wellbore: Plan: 3R-101 Design: 3R-101wp13 Errors Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Hum. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 16,300.00 31.66 92.50 116.06 3,453.52 17.30 49.04 17.38 16,312.85 31.66 92.50 116 00 3,452.96 17.32 49.11 17.40 TO: 16312.85' MD, 3501.86' TVD - 41/2" x 63/4" 1/182017 1:29:35PM Page 9 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3R Pad Well: Plan: 3R-101 Wellbore: Plan: 3R-101 Design: 3R-101wp13 Errors Report Local Coordinate Reference: Well Plan: 3R-101 TVD Reference: Plan: 39+9.g @ 48.90usit (Doyon142) MD Reference: Plan: 39+9.9 @ 48.90usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Casing Points Vertical Depth Depth Measured Vertical (usft) Casing Hole Depth Depth 1,738.97 Diameter Diameter (usft) (usft) Name 5,681.08 3,087.40 117.90 117.90 20"x42" 20 42 2,350.35 2,200.00 13-3/8"x 16" 13-3/8 16 9,187.84 3,615.05 9 5/8"x 12-1/4 9-5/8 12-1/4 16,312.85 3,501.86 41/2"x6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Depth Depth (usft) (usft) Name 6,826.30 3,315.00 Top UgnuA 1,738.97 1,695.90 T3 7,379.46 3,424.40 Top N Sands 5,681.08 3,087.40 Top Ugnu B 8,828.24 3,602.50 Top West Sak D 1,794.08 1,745.50 Base Pfrost 2,071.52 1,987.20 K15 4,514.22 2,855.50 Top Ugnu C Dip Dip Direction Lithology (1) (1 0.00 0.00 0.00 1/18/2017 1:29:35PM Page 10 COMPASS 5000.1 Build 74 Company: ConomPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3R Pad Well: Plan: 3R-101 Wellbore: Plan: 3R-101 Design: 3R-101wp13 Casing Points Measured Vertical Diameter Depth Depth 42 (usft) (usft) 9-5/8 117.90 117.90 20"x42" 2,350.35 2,200.00 13-3/8"x 16" 9,187.84 3,615.05 9 5/8" x 12-1/4 16,312.85 3,501.86 41/2"x6-3/4" Formations Errors Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Name Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Casing Hale Diameter Diameter 20 42 13-3/8 16 9-5/8 12-1/4 4-1/2 6-3/4 Measured Depth (usft) 6,826.30 1,738.97 7,379.46 5,681.08 8,828.24 1,794.08 2,071.52 4,514.22 Vertical Depth (usft) 3,315.00 1,695.90 3,424.40 3,087.40 3,602.50 1,745.50 1,987.20 2,855.50 Name Top UgnuA T3 Top N Sands Top Ugnu B Top West Salk D Base Pfrost K15 Top Ugnu C Dip Dip Direction Lithology V) (°) 0.00 0.00 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +Nl-S +E/ -W (usft) (usft) (usft) (usft) Comment 400.00 400.00 0.00 0.00 KOP: Start 1.5'/100' DLS, 347.72° TF, for 200.09' 600.09 600.00 5.12 -1.11 Start 2°/100' DLS, 0° TF, for 1142.21' 1,742.31 1,698.90 281.29 -61.23 Hold for 111.11' 1,853.42 1,798.90 328.62 -71.53 Start 4°/100' DLS, 0° TF, for 496.93' 2,350.35 2,200.00 611.12 -133.02 Hold for 20' 2,370.35 2,213.97 625.11 -136.07 Start 4°/100' DLS, 3.04° TF, for 821.15' 3,191.50 2,592.62 1,327.20 -276.46 Hold for 3656.42' 6,847.92 3,319.30 4,849.55 -935.55 Start 4.5°/100' DLS, -91.34" TF, for 808' 7,655.91 3,475.00 5,530.00 -1,315.00 Hold for 200' 7,855.91 3,509.73 5,662.81 -1,48044 Start 4.5°/100' DLS, -72.2° TF, for 196.17' 8,052.08 3,539.12 5,782.50 -1,612.82 Hold for 2.28' 8,054.36 3,539.40 5,783.76 -1,614.69 Start 4.5°/100' DLS, -82.87° TF, for 756.68' 8,811.05 3,601.90 6,000.74 -2,325.28 Hold for 376.8' 9,187.84 3,615.05 6,001.76 -2,701.84 Adjust TF to O°, for 20' 9,207.84 3,615.75 6,001.82 -2,721.83 Start 1.5°/100' DLS, 0° TF, for 189.98' 9,397.82 3,617.65 6,002.33 -2,911.78 Hold for 483.84' 91881.66 3,610.48 6,003.65 -3,395.57 Start 1 °/100' DLS, -180° TF, for 44.96' 9,926.62 3,609.99 6,003.77 -3,440.52 Adjust TF to 180°, for 37.62' 9,964.24 3,609.85 6,003.88 -3,478.14 Hold for 568.22' 10,532.46 3,609.61 6,005.42 -4,046.36 Start 2.5"/100' DLS, 0" TF, for 179.05' 10,711.51 3,602.55 6,005.91 -4,225.23 Adjust TF to 0', for 1.07' 10,712.58 3,602.47 6,005.91 4,226.29 Hold for 310.18' 11,022.76 3,577.98 6,006.76 4,535.50 Start 2.5°/100'OLS, -180"TF, for 1.07' 11,023.83 3,577.90 6,006.76 -4,536.57 Adjust TF to 180% for 119.07' 11,142.90 3,571.65 6,007.08 4,655.46 Hold for 465.81' 11,608.72 3,559.27 6,008.35 -5,121.12 Start 2.5°/100' DLS, 180° TF, for 60.93' 11,669.65 3,558.46 6,008.52 -5,182.04 Adjust TF to -180°, for 48.51' 11,718.15 3,558.97 6,008.65 -5,230.53 Hold for 388.1' 12,106.26 3,567.19 6,009.71 -5,618.56 Start 0.5°/100' DLS, 180° TF, for 13.46' 12,119.71 3,567.48 6,009.74 -5,632.00 Adjust TF to -180", for 11.94' 12,131.65 3,567.75 6,009.77 -5,643.94 Hold for 448.81' 1/182017 1:29:35PM Page 11 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 3R Pad Well: Plan: 3R-101 Wellbore: Plan: 3R-101 Design: 3R-101wp13 Errors Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 3R-101 Plan: 39+9,9 @ 48.90usft (Doyon142) Plan: 39+9,9 @ 48,90usft (Doyon142) True Minimum Curvature OAKEDMP2 Casing Points Vertical 6,011.00 Dip Depth Measured Vertical Dip Direction Casing Hole Depth Depth 6,826.30 Diameter Diameter (usR) (usft) Name T3 0.00 117.90 117.90 20"x42" 20 42 2,350.35 2,200.00 13-3/8" x 16" 13-3/8 16 9,187.84 3,615.05 9 5/8" x 12-1/4 9-5/8 12-1/4 16,312.85 3,501.86 41/2"x6-3/4" 4-1/2 6-3/4 Formations Measured Vertical 6,011.00 Dip Depth Depth 3,579.29 Dip Direction (usft) (usR) Name Lithology (°) (°) 6,826.30 3,315.00 Top UgnuA 13,185.91 1,738.97 1,695.90 T3 0.00 7,379.46 3,424.40 Top N Sands -6,720.82 5,681.08 3,087.40 Top Ugnu B 6,012.71 8,828.24 3,602.50 Top West Bak D 3,578.25 1,794.08 1,745.50 Base Pfrost 0.00 2,071.52 1,987.20 K15 0.00 4,514.22 2,855.50 Top Ugnu C -7,195.52 12,580.46 3,578.25 6,011.00 -6,092.62 Start 1.5°/100' OLS, 0° TF, for 89.31' 12,669.77 3,579.29 6,011.24 -6,181.93 Adjust TF to 0', for 7.59' 12,677.36 3,579.28 6,011.26 -6,189.52 Hold for 508.55' 13,185.91 3,578.27 6,012.65 -6,698.06 Start 0.5°/100' DLS, 180° TF, for 22.76- 13,208.67 3,578.25 6,012.71 -6,720.82 Adjust TF to 0', for 0' 13,208.67 3,578.25 6,012.71 -6,720.82 Hold for 410.81' 13,619.48 3,578.25 6,013.83 -7,131.63 Adjust TF to 0°, for 63.89' 13,619.48 3,578.25 6,013.83 -7,131.63 Start 1°/100' DLS, 0° TF, for 0' 13,683.37 3,577.89 6,014.00 -7,195.52 Hold for 422.46' 14,105.83 3,573.18 6,015.15 -7,617.95 Start 0.5'/100' DLS, 0° TF, for 12.21- 14,11B.05 3,573.04 6,015.18 -7,630.17 Adjust TF to 0°, for 22.811 14,140.85 3,572.74 6,015.25 -7,652.97 Hold for 639.85' 14,780.70 3,563.65 6,016.99 -8,292.75 Start 1'/100' DLS, 0° TF, for 38.6' 14,819.30 3,562.97 6,017.09 -8,331.35 Adjust TF to 0°, for 49.24' 14,868.54 3,561.73 6,017.23 -8,380.57 Hold for 187.89' 15,056.43 3,556.17 6,017.74 -8,568.38 Start 1°/100' DLS, Oo TF, for 45.76- 15,102.19 3,554.64 6,017.86 -8,614.11 Adjust TF to 0', for 35.46' 15,137.65 3,553.20 6,017.96 -8,649.54 Hold for 650.23' 15,787.88 3,524.79 6,019.73 -9,299.15 Start 0.5°/100'DLS, 180' TF, for 0.35' 15,788.23 3,524.77 6,019.73 -9,299.50 Hold for 524.62' 16,312.85 3,501.86 6,021.16 -9,823.62 TD: 16312.85' MD, 3501.86' TVD Checked By: Approved By: Date: I IIIWO17 1.'29:35PM Page 12 COMPASS 5000.1 Build 74 Pool Report 3R-101 Surface Location I 13 CPA] Coordinate Converter From: Datum:NAD83 Region: alaska (" Latitude/Longitude IDegrees Minutes Seconds P UTM Zone: [— r South F State Plane Zone:14 J Units: us t f Legal Description (NAD27 only) Starting Coordinates: - X: 1660657.37965123 Y: 6031484.21427894 Datum: INAD27 Region: alaska r Latitude/Longtude IDecimalDegrees C' UTM Zone: True r South t: State Plane Zone: F-':-:1 Units: usft . C Legal Description (NAD27 only) Ending X' f 520625.980000003 Y: 6031732.15999999 Transform .Qud Help M CPA[ Coordinate Converter ..,_From: —....,.:_ _ To: _ Datum NAD83 Region: alaska Datum: NAD27 Region alaska C Latitude/Longitude Degrees Minutes Seconds . r Latitude/Longitude JDecimalDegiees r UTM Zone: r— r South r UTM Zone: True r South G State Plane Zone:rq Units: us -ft . r State Plane Zone: F4--:v]Units: us -ft C' LagalGescri; Mian (Np,D2; only C•' Legal I Description(NAD27 only) Starting Coordinates: -- X: 1660657.37965123 ]- Legal Description- ---------------� Township: p13 Range: pOg Y: 6031484.21427894 Meridian: JU "`- I Section:F9 — FNL 1630.4924 FEL . 2959.2486 Transform Quit Help 3R-101 Surface C M CPA! Coordinate Converter From:.._— Datum: NAD83 Region: alaska . r Latitude/Longitude Degrees Minutes Seconds . r UTM Zone: r— r- South r� State Plane Zone: I' J Units: us -ft r' Legal Description (NAD27 only) Starting Coordinates: , IOIF-L, -To:- Datum: NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees r UTM Zone: True r South r State Plane Zone:I" Units: u_,ft . r Legal Description (NAD27 only) -- Ending Coordinates: X: 1660522.71 X: 520491.312342821 Y: 6032094.90 Y: 6032342.84109003 M CPAI Coordinate Converter From: --- --- Datum: INAD83 Region: alaska . r Latitude/Longitude IDegrees Minutes Seconds . r UTM Zone: I — r South fState Plane Zone:ja �j Units: urft r Legal Da:c-riplicr,IN.LDL-a,j rl I_ Quit Help .Transform Datum:NAD27 Region: alaska r Latitude/Longitude IDecimalDegreers r UTM Zone: Tme I- South r State Plane Zone: f q _�-] Units: us -ft r Legal Description (NAD27 only) Starting Coordinates: ----___ — Legal Description - - -- X: 11660522.71 Township: 013 FN-',] Range: 009 Y: 6032094.90 Meridian: Section:9 _ FNL . 1019.3776 FEL 3090.6855 I TransformQuit Help 3R-101 Intermediate 1 Casing & Production Horizon 4 CPAI Coordinate From. _---- _--_ _. Datum: NAD83 . Region: alaska r Latitude/Longitude Decimal Degrees (' UTM Zone:I r South F State Plane Zone: Units: usf[ t` Legal Description (NAD27 only) G I:-- Y 4 -To:---- — ___ Datum: INAD27 Region: alaska C Latitude/Longitude IDecimalDegrees, i r UTM Zone: jTtue r South F Stale Plane Zone: I" J Units: us -ft {" Legal Description (NAD27 only) - Starting Coordinates: ------- Ending Coordinates: X: 1657944.45 X: 517913.10712622 Y. 6037478.00 Y: 6037725.95720974 ..... ..................... ... .... ............. ...... Transform i _qui! Help M CPAI Coordinate - From:. Datum: NAD83 . Region: Fal—ask—a.] C Latitude/Longitude jDecimalDegrees J (' UTM Zone: r"` r South 0' State Plane Zone:Units:urft . C" La,al 6ezriiFddnn fN.4D.7....YI Starting Coordinates:— -- X: 11657944.45 Y: 6037478.00 To---- Datum: IX —Datum: NAD27 Region: Flask. C Latitude/Longitude IDecimaiDegrees (' UTM Zone: True r South C State Plane Zone:I' J Units: usft P Legal Description (NAD27 only) Description— Township. 013 F-3 Range: 1009 Meridian: I" -1 Sectionp FNL -11908.64030 FEL 360.57065 Translorm L._...__ ........................__........_....., Quit Help 3R-101 TD rj CPAI Coordinate Converter From: -- To. Datum: NAD83 . Region: alaska . Datum: NADP? - Region: alaska r Latitude/Longitude IDecimalDegiees r" Latitude/Longitude DecimalDegrees r UTM Zone: r- South r UTM Zone: True 1— South R State Plane Zone: rq Units: us -ft . r� Stale Plane Zone: I'4 '] Units: us -ft . r" Legal Description (NAD27 only) C Legal Description (NAD27 only) Starting Coordinates: - -- --- X: 11650818.38 Ending Coordinates: — X: 510787.110649945 Y: IG037478.00 Y: 6037726.09768039 Transform ! Quit Help In, CPA[ From: Datum: NAD83 Region: alaska . C Latitude/Longitude 15ecimalDegrees r UTM Zone: f j— South G State Plane Zone:1' J Units: us t . r I mal De-scdption IN4D27 onlyl i To: Datum: NAD27 - Region: alaska r Latitude/Longitude DecimalDegrees r UTM Zone: True r South r State Plane Zone: F-----] Units: usft C Legal Description (NAD27 only) r Slaving Co«dnates:------- Legal Down Description- 013 I'"J Range: 009 I`J X: 1650818.38 Y: 6037478.00 Meridian: r` Section:r— --� _FNL . 1894.73497 FEL 12207,2072 i Transform Quit Help 1-2, Mk I 0111-01PE ro3-POS, C OP05-061 lq. 011ktok PoIn 1 3P -11O, 3& As -built AJR I NRB I IPER K090043ACS 12 112/18/ld JAH I JFC NOTES: 1. BASIS OF LOCATION AND ELEVATION IS DS3R MONUMENTATION PER LOUNSBURY & ASSOC. 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A,D. 27, AND GEODETIC COORDINATES ARE N.A.D. 27. 3. ELEVATIONS ARE B.P.M.S.L. 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACI SECTION 9, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN, ALASKA 5. DATES OF SURVEY: 12/18/16 FB# L16-40-5 6. ALL DISTANCES SHOWN ARE GROUND 9 ,5 01 6 S �g 10 o 11 DS3R SEE SHEET 2 FOR LOCATION INFORMATION '`.1.1 I AREA: 3R lips ca. Inc. 0 7 PER K160005ACS 4 5 PROJECT D VICINITY MAP 1" = 1 MILE 11 4 LEGEND • EXISTING CONDUCTOR LOCATION ®AS—BUILT CONDUCTOR LOCATION GRAPHIC SCALE 0 100 200 400 1 inch = 200 ft. LOUNSDURY & ASSOCIATES, INC. BzgvnoRs RN6Imn PI Nm DS3R WELL CONDUCTOR ASBUILT LOCATION i 1 Ei3 UNIT: D3 REV: 1 112/29/091 AJR I NRB I IPER K090043ACS 2 12/18/16 JAH JFC PER K160005ACS CONDUCTORS ARF I OCATFn W PPnTPAf'TCn CC/•TVAAI n T ,4 ., Well No. NAD 27 ASP Coordinates NAD 27 Geogra hic Coordinates Section Offset. Elev. Y X Lat. Long. F.N.L F.W.I. O.G. PAD 5 6031765.10' 520614.54' 70' 29' 52.596" 149' 49' 53.109" 1598' 2309' 4.7' 16.9' 6 6031741.56' 520622.68' 70' 29' 52.364" 149' 49' 52.871" 1622' 2317' 4.7' 10.9' 7 6031717.82' 520630.86' 70' 29' 52.131" 149' 49' 52.632" 1645' 2326' 4.8' 11.0' 8 6031694.24' 520639.12' 70' 29' 51.898" 149* 49' 52.391" 1669' 2334' 4.8' 10.8' 9 6031670.68' 520647.18' 70' 29' 51.666" 149. 49' 52.156" 1693' 2342' 4.8' 10.8' 10 6031646.96' 520655.38' 70' 29' 51.433" 149' 49' 51.916" 1716' 2350' 4.9' 10.8' 11 6031623.40' 520663.55' 70' 29' 51.201" 149' 49' 51.678" 1740' 2358' 5.0' 10.8' 12 6031599.81' 520671.67' -520709 70' 29' 50.969" 149' 49' 51.441" 1763' 2366' 5.1' 10.8' 14 6031491.19' 37' 70' 29' 49.699" 149' 49' 50.340" 1872' 2403' 5.5' 10.9' 15 6031467.51' 520717.59' 70' 29' 49.666" 149' 49' 50.100" 1896' 2411' 5.6' 10.9' 17 6031420.30' 520733.83' 70' 29' 49.201" 149' 49' 49.625" 1943' 2427' 5.7' 10.8' 18 6031396.65' 520741.97' 70' 29' 48.969" 149' 49' 49.388" 1967' 2435' 5.8' 10.6' 19 6031373.03' 520750.36' 70' 29' 48.736" 149' 49' 49.143" 1991' 2443' 5.9' 10.6' 20 6031349.41' 520758.32' 70' 29' 48.503" 149' 49' 48.910" 2014' 2451' 6.1' 10.9' 21 6031325.80' 520766.51' 70' 29' 48.271" 149' 49' 48.671" 2038 2459' 6.3' 11.7' 22 6031302.22' 520774.67' 70' 29' 46.039" 149' 49' 48.433" 2061' 2467' 6.5' 11.4' 25 6031443.85' 520725.61' 70' 29' 49.433" 149' 49' 49.865" 1920' 2419' 5.6' 10.9' 26 6031514.74' 520701.13' 70' 29' 50.131" 149' 49' 50.580" 1849' 2395' S.5' 11.0' *101 6031732.16' 520625.98' 70' 29' 52.272" 149' 49' 52,775" 1631' 2321' 4.8' 9.9' *102 6031703.85' 520635,69' 70' 29' 51.993" 149' 49' 52.491" 1659' 233(Y 4.8' 9.9' * CONDUCTOR ASBUILT THIS SURVEY OF ' •• p�•.•• .��",1� SURVEYOR'S CERTIFICATE `♦♦� ••'•9th 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 ..." ............ .......... °` ;' 'j -JEREMIAH F. CORNELLj�� DONE 8Y ME OR UNDER MY DIRECT SUPERVISION AND LS 12663 f► THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF DECEMBER 18, 2016. 's r fat9%..••'Pa • LOUNSBURY ��+�FfS510NA� .`• ��\ W ASs �� 3 INC. 31? ConocoPhillips Alaska, Inc. DS3R WELL CONDUCTOR 1-6316d18 12/29/09 1�.�,..� CEA-NRX-63181)18 1 PART.,2 OF 2 1 REV.2 1 Attachment 4 — 3R-101 Drilling Hazards Summary 16" Open Hole / 13-3/8" Casings Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin 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 12-1/4" Open Hole / 9-5/8" Casings 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 Anti -Collision Moderate Follow real time surveys very closely. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight 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 backreaming Fault Crossings and Concretions Moderate Use developed best practices for concretion drilling. Getting Liner to Bottom Moderate Maintain solids free water based mud properties and lubricity while running l ner lower com letion, monitor torque and drag. Attachment 5 — 3R-101 Cement Summary 13-3/8" Surface Casing run to 2351' MD 12200' TVD Cement from 2351' MD to 1851'(500' of fill) with 12.0 ppg DeepCRETE, and from 1851' to surface with ASL @ 11.0 ppg DeepCRETE. Assume 200% excess annular volume in permafrost and 50% excess below the permafrost (1799' MD). Lead slurry: (1851 - 1799') X 0.4202 ft'/ft X 1.5 (50% excess) = 33 ft' below permafrost 1799'X 0.4202 ft3/ft X 3.0 (200% excess) = 2268 ft' above permafrost Total volume = 33 + 2268 = 2301 ft' => 1193 Sx @ 1.93 ft3/sk Tail slurry: 500'X 0.4202 ft3/ft X 1.5 (50% excess) = 316 ft3 annular volume 80' X 0.8177 ft3/ft = 66 ft3 shoe joint volume Total volume = 316 + 66 = 382 ft3 => 235 Sx @ 1.63 ft'/sk System: 235 Sx 12.0 ppg DeepCRETE & 1193 Sx ASL 11.0 ppg DeepCRETE 9-5/8" Intermediate Casing run to 9188' MD / 3 615' TVD Cement from 9,188' MD to 5,100'(500' minimum above Ugnu B) with 15.8 ppg Class G w/GasBlok. Assume 40% excess annular volume. Tail slurry: (9,188'— 5,100') X 0.3219 ft3/ft X 1.4 (40% excess) = 1843 ft' annular volume 80'X 0.4172 ft3 /ft = 34 11:3 shoe joint volume Total volume = 1843 + 34 = 1877 ft3 => 1605 Sx @ 1.17 ft'/sk System: 1605 Sx 15.8 ppg Class G w/ adds (DECEIVE® Post Office Box 100360 JAN 2 5 2017 Anchorage, Alaska 99510-0360 Phone (907) 263-4249 q py/ pir Email: scoff.a.brunswicko_)conocophillips.com R"�GGC January 24, 2017 Alaska Oil and Gas Conservation Commission 333 West V1 Avenue, Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill, Well 3R-101 Saved: 23 -Jan -17 ConocoPhillips Re: Application for Permit to Drill Well 311-101 West Sak D Sand Multi -Lateral Producer. Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore producer well from the 3R pad. The expected spud date for this well is March 1, 2017. It is planned to use rig Doyon 142. 3R-101 is planned to be a dual lateral horizontal well in the West Sak D sand. When 3R-101 will drill a 16" surface hole & run 13-3/8" surface casing to +/-2,351'MD / 2,200' TVD cemented to surface. The intermediate hole section will drill a 12-1/4" hole to a depth of +/-9,188' MD / 3,615' TVD with 9-5/8" casing run & cemented in place. The 3R-101 lower lateral will be a 6-3/4" hole geo-steered to 16,313' MD / 3,502' TVD in the lower West Sak D sand package & completed with a 4-1/2" slotted liner. A separate PTD application will be submitted for the 3R-101 Ll lateral. Please rind 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 Scott Brunswick at 263-4249 (scott.a.brunswickna conocoohillins.com) or Chip Alvord at 265-6120. Sincerely, Scott Brt nsv, k k Drilling Engineer Application for Well Name Requirements of 20 AAC 25.005 (fl The well for which this application is submitted will be designated as 3R-101 Location Summary Requirements of 20 AAC 25.005(c)(2) ,Di application for a Pernit to Drill nmst be acemnpanied by each of the folloring items, except for an item already on file frith the commission and Identified in the application: (2) a plat idem f ing the property and the property's owners and showing (A)1he coordinates of the proposed location of the well at the surface, at the top of each objective forma/ion, and at total depth, referenced to govetvunentalsection lines. (B) the coordinates of the proposed location of the yell at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atn ospherie Administration; (C) the proposed depth of the well at the top of each objective jornmtion and at total dept!:; Location at Surface 1630.5' FNL, 2959.2' FEL, Sec 9, T 13N, R009E, UM NGSCoordinates Northings: 6,031,732.16' Eastings: 520,625.98' RKB Elevation 48.9'AMSL Pad Elevation 9.9'AMSL ' Location at Surface Casing 1019.38' FNL, 3090.7' FEL, Sec 9, T13N, R009E, UM NGSCoordinates Northings: 6,032,342.84' Eastings: 520,491.31' MeasuredDe th,RKB. 2,351' Total Vertical De tL, RKB. 2,200' Total Vertical Depth, SS. 1 2,151' Location at Intermediate Casing NGSCoordinates Northings: 6,037,726.09' Eastings: 510,787.11' 908.64' FNL, 360.57' FEL, Sec 5, TON, R009E, UM NGS Coordinates Northings: 6,037,725.95' Eastings: 517,913.11' Measured De th, RKB: 9,188' Total VertiealDe-th, RKB: 1 3,615' Total Vertical Depth, SS. 1 3,566' Location at Total Depth 894.73' FNL, 2207.21' FEL, Sec 6, TUN, R009E, UM NGSCoordinates Northings: 6,037,726.09' Eastings: 510,787.11' iMeasuredDe th, RKB: 16,313' Total Vertical De tL, RKB: 3,502' Total Vertical Depth, SS: 3,453' and (D) other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(6) !f a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-407) most (1) include a plat, draim to a satiable scale, shoring the path of the proposed wellbore, including all adjacent ivellbores within 200feet of wry porion of the proposed well: Please see Attachment: Directional Plan And (2) for all wells within 200 feel of the proposed wellbore (A) list the names of the operator of those wells to the extent that those names are known or discoverable in public records, and show that each named operator has been fivnished a copy of the application by certified mail; or ('B) state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill most be accompanied by each of 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 Hint out prevention equipment (BOPS) as required by 20 A,4C 25.035, 20 AAC 75.036, or 20 AAC 25.037. as applicable; Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the follmving items, except for an item already on file it ill, the commission and identified in the application: (4) information on drilling hacards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and mannaua potential sinface pressure based on a methane gradient The maximum potential surface pressure (MPSP) while drilling 3R-101 is calculated using an estimated maximum reservoir pressure of 1,660 psi (8.6 ppg, based Kigun 1 MDT pressure at a 3708' TVD reference datum), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A3 sand at 6,220' TVD: D Sand Estimated. BHP = 1,660 psi D Sand estimated depth = 3,708' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c) (4) (A) Hydrostatic of full gas column = 371 psi (3,708' TVD * 0.10 psi/ft) MPSP = BHP — gas column =1,289 psi (1,660 psi — 371 psi) (B) data or potential gas tunes: The wellbore 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 cones, and zones that have a propenshy for differential sticking; See attached 3R-101 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill nn st be accompanied by each of the following items. except for an item alienate on file with the commission and identified in the application: (5) a description of the procedure for conducting fornialion integrity, tests, as required under 20 AAC 15.030(l): 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 itenn already onfile with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any stoned liner, pre -perforated liner. or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg Hole 3¢e Weigh Grade Conn. Length Top MD/TVD Btm MDITVD Cement Program OD (in) t (Ibflt) (g) (ft) (h) 20 78.7 H-40 Welded 78 Surf 1171117 Existing Hydril Cement to Surface with 13-3/8 Y6 68 L-80 563 2,313 Surf 2,351 / 2,200 1,193 sx DeepCRETE Lead 11.0 ppg, 235 sx Dee CREfE Tail Slur 12.0 9-5/8 12-1/4 40 L-80 5631 9,150 Surf 9,188 / 3,615 1605 sx 15.8 ppg Class G 4-1/2 6-3/4 12.6 L-80 TxP 7,193 9,120 / 3,613 16,313 / 3,502 N/A 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 following items. excepi for an item already on file with the cannnission and identified in the application: (7) a diagram and description of the di✓etter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC25.035(h)(2); Please reference attachment for diverter schematic. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) ,An application fo a Permit to Drill must be accompanied by each of the following dents, excepi fo an item already ov file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033, 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. Surface 16" Hole Intermediate Production 13-3/8" Casing 9-7/8" Hole 6-3/4" Hole 7-5/8" Casing Mud System Spud Mud LSND (WBM) Flo-Thru (WBM) Density 8.5-9.5 9.0-10.0 9.0-9.5 PV ALAP 10-20 25-30 YP 30-80 20-30 15-20 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 160F 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 br each of the following items, except joi an item already on file with the commission and ident fled in the application. The proposed drilling program follows. Please refer to attachment for proposed well schematic. 1. Move in / rig up Doyon Rig 142. Install 21-1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 16" hole to casing point at +/- 2,351 MD / 2,200' TVD as per directional plan. Survey & log with MWD, gyro, Gamma, & Resistivity. / 3. Run and cement 13-3/8", 68#, L80, Hyd-563 casing to surface. Displace cement with mud & check floats upon bumping plug. Perform top job if required after notifying AOGCC. Evacuate top 2 feet of cement from annulus for sealant job (post rig.) 4. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP'S to 3500 psi (annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. 5. PU 12-1/4" PDC bit and directional drilling assembly, with MWD/LWD (Gamma, resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3000 psi for 30 minutes. 6. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 12.5 ppg, maximum of 16 ppg EMW LOT/FIT, record results. 7. Directionally drill to intermediate hole TD of 9,188' MD / 3,615' TVD landing in the West Sak D sand package. 8. Circulate & rotate at maximum rates until shakers are clean with minimum of 3 bottoms up. 9. POOH on elevators racking back 5" drill pipe. 10. Laydown intermediate BHA. 11. Run 9-5/8", 40# L80, Hydril 563 casing from surface to TD. 12. Pump cement job as per Schlumberger proposal. Top cement to be placed @ +/- 4,900' MD (500' minimum above Ugnu B formation). 13. Install 9-5/8" packoff & test to 5000 psi. 14. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel or isotherm to freeze protect. 15. Pick up 8-3/4" roller cone bit & RIH on 5" DP to top of float equipment. Clean out cement to top of float equipment & test casing to 3500 psi for 30 minute 16. Drill out shoe track & 20 ft formation. Perform LOT to a minimum of 12.0 ppg EMW maximum of 13.0 ppg, recording results. 17. POOH laying down 5" DP & clean out BHA. 18. PU 4" DP, 6-3/4" bit, and drilling assembly with MWD/LWD (Gamma, resistivity, Periscope) 19. Directionally drill 6-3/4" hole geo-steering through the West Sak D sand to TD --16,313' MD / 3,502' TVD as per directional plan. 20. Circulate 1 BU after TD and BROOH, at 9-5/8" shoe CBU to flush casing & POOH on elevators. 21. Lay down Production BHA. 22. PU and run 4-1/2", 12.6# slotted liner w/MLZXP liner hanger & packer. The top of liner will be placed at -9,000' MD, allowing for +/-120' of overlap in the 7-5/8" casing & proper spacing for the whipstock assembly. 23. Set liner hanger & packer using MWD to orient hanger. 24. PT liner top packer to 2,500 psi at surface for 10 minutes, chart results. 25. Flow check well for 30 minutes. 26. POOH with liner running tools and lay down. 27. Run & set Baker WindowMaster whipstock system, at window point of top of window +/8,975' MD / 3,609' TVD, just below the top of the D sand orienting with MWD. 28. Mill 8-3/4" window until top mill across face & clean up window. 29. Perform formation integrity test to minimum of 12.0 ppg, maximum of 13.0 ppg EMW, recording results. 30. POOH with milling BHA. 31. PU 6-3/4" bit, motor, MWD, & magnets to perform a clean out run & land the well. (GR, Res) 32. RIH, orient through window, & tag bottom. 33. End 3R-101 PTD & begin 3R-101 L1 PTD. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application fora Permit to Drill music be accompanied by each of the following dents, except for an dent ahead, onfile with the co nntission and identified to the application: (14) a general description of homy the operator plans to dispose of drilling mud and ciatings and a statement of whether the operator intends to request authori_ation under ]0 AAC 15.080 for an amndar disposal operation in the well: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the 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 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary Attachment 5 Cement Summaries Attachment 1— Proposed Well Schematic Well: KRU 3R-101 <== Data Input Name: CPAI <== Data Input Mud Weight (ppg) 10.00 <_= Data Input Weak point or LOT - Measured depth (ft) 2,351' <== Data Input Weak point or LOT True vertical depth (ft) 2,200' <== Data Input Weak point or LOT - Hole angle (deg) 45.7° <== Data Input Weak point or LOT - Hole size (in) 16.000" <== Data Input Weak point pressure or LOT - EMW (ppg) 12.50 <_=Data Input Zone of interest - Measured depth (ft) 8186' <== Data Input Zone of interest - True vertical depth (ft) 3,615' <== Data Input Zone of interest - Hole angle (deg) 88.0° <== Data Input Zone of interest - Hole size (in) 12.250" <== Data Input Zone of interest - Pore pressure EMW (ppg) 8.60 <== Data Input Gas gradient (psi/ft) 0.10 <== Data Input ML Bottom hole assembly OD (in) 8.0" <_= Data Input Bottom hole assembly length (ft) 151' <_= Data Input Drill pipe OD (in) 5.000" <== Data Input BHA annular vol. @ zone of interest (bbl/ft) 0.0836 DP annular vol. @ zone of interest (bbl/ft) 0.1215 DP annular vol. weak point(bbl/ft)0.2244 Additional safety margin (psi) 0.00 <== Data Input Weak point pressure (psi): Plo 1,430 psi Weak point pressure - Safety margin: Pmax 1,430 psi Pmax EMW 12.50 pp Max anticipated formation pressure (psi): Pf 1,617 psi Weak Pt to Zone of Interest distance (TVD ft): OH (TVD) 1,415' Weak Pt to Zone of Interest distance (MD ft): OH MD 6,837' Maximum influx height at the bit (TVD ft): H (ND) 1,308' Maximum influx height at the bit (MD ft): H (MD) 37,466' Calc. volume of (H) around BHA: Vl bha 12.6 bbl Calc. volume of (H) around drill pipe: V1 dp 4533.4 bbl Calc. volume that H equals @ initial shut in: V1 4546.0 bbl Calcvol. that H equals @ weak point (MD ft): VWp 420.1 bbl Calc. volume of Vwp @ initial shut in: V2 371.6 bbl Kick Tolerance: V2 371.6 bbl NOTE: V Loepp 3114117 1 Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Tuesday, March 14, 2017 3:12 PM To: Loepp, Victoria T (DOA) Subject: RE: 3R-101 & 3R-1011_1 PTD Intermediate Cement Victoria Being a non-frac'ed producer we didn't plan any cement evaluation of the casing in 311-101. Scott Brunswick Drilling Engineer ConocclPhillips Alaska (907) 263-4249 ( Office) (907) 227-8499 ( Cell ) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, March 14, 2017 3:00 PM To: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Subject: [EXTERNAL]RE: 313-101 & 3R-1011-1 PTD Intermediate Cement Scott, What are your plans for cement evaluation of the intermediate casing? 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. LoeI)p�:O alaska.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCCI, 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 a -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: Brunswick, Scott A [mailto:Scott.A.Brunswick(cDconocophillips com] Sent: Monday, March 13, 2017 1:50 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: 311-101 & 3R-1011.1 PTD Applications Status Hi Victoria Loepp, Victoria T (DOA) From: Sent: To: Subject: Attachments: Follow Up Flag: Flag Status: Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office ) (907) 227-8499 ( Cell ) Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Wednesday, March 01, 2017 3:08 PM Loepp, Victoria T (DOA) RE: 3R-101 & 3R -101L1 PTD Applications Status 311-101 Permit to Drill Hole Size Update.pdf; 3R-101 Ll Permit to Drill Hole Size Update.pdf Follow up Flagged From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, March 01, 2017 3:03 PM To: Brunswick, Scott A <Scott.A.Brunswick@conocophi Ili ps.com> Subject: [EXTERNAL]RE: 3R-101 & 3R -101L1 PTD Applications Status Please show changes in red or highlight - From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.comj Sent: Wednesday, March 01, 2017 3:00 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: 311-101 & 3R-1011.1 PTD Applications Status Thank you, appreciate this. Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office ) (907) 227-8499 ( Cell ) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.eov] Sent: Wednesday, March 01, 2017 2:53 PM To: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Subject: [EXTERNAL]RE: 311-101 & 3R-1011-1 PTD Applications Status Email me the first 9 pages of the package(don't include the 10-407 form- I will hand mark) with the changes shown in red. Same for the lateral if it changes also. From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.comj Sent: Wednesday, March 01, 2017 2:44 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Subject: RE: 311-101 & 3R-1011-1 PTD Applications Status I've handed the well to another engineer, the production hole will now change to 8.75" from 6.75", that's the only change. Should we submit updated paperwork for the hole size change? Everything else remains the same. Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 (Office) (907) 227-8499 ( Cell ) From: Brunswick, Scott A Sent: Wednesday, March 01, 2017 2:41 PM To: Toepp, Victoria T (DOA)' <victoria.loepp@alaska.gov> Subject: RE: 313-101 & 3R-1011-1 PTD Applications Status Roger that,thx. Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office ) (907) 227-8499 ( Cell ) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, March 01, 2017 2:38 PM To: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Subject: [EXTERNAL]RE: 311-101 & 3R-1011.1 PTD Applications Status Should see something early next week - From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Wednesday, March 01, 2017 2:33 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: 3R-101 & 3R-1011-1 PTD Applications Status Rig got delayed, so 3 weeks from now. Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office ) (907) 227-8499 ( Cell ) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, March 01, 2017 2:32 PM To: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Subject: [EXTERNAL]RE: 311-101 & 3R-1011.1 PTD Applications Status In process. Spud date? From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Wednesday, March 01, 2017 2:26 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Tolman, Ben V <Ben.V.Tolman@conocophillips.com>; Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann. HaggertV-Sherrod @contractor.conocophil lips.com> Subject: 313-101 & 3R-1011-1 PTD Applications Status Hi Victoria I was wondering about the status of the 314-101 & 3R-1011-1 PTD Application status? Thanks Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office ) (907) 227-8499 ( Cell ) TRANSMITTAL LETTER CHECKLIST WELL NAME: KLA U , 3R - /D l PTD: ,) 7 -1313 Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: 14l&44Al K �Z1y�_C POOL: �iVU- 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 onpermit). 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, t composite curves for well logs run must be submitted to the AOGCC within 90 da s after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 18 Well Name: KUPARUK RIV UNLT 3R_101 . Program DEV _ _ Well bore seg PTD#:2170130 Company CONOCOPHILLIPS ALASKA INC _ _ _...— Initial Class/Type DEV / PEND_ GeoArea 890 Unit 91160 On/Off Shore On Annular Disposal Administration 17 Nonconven. gas conforms to AS31.05,030Ij.1.A),Ij.2.A-D) NA 1 Permit fee attached _ _ _ NA 2 Lease number appropriate_ Yes ADL0355023, Surf Loc; ADL0355024, Top Prod Intent &. TO. _ 3 Unique well name and number _ Yes _ _ KRU 3R-101 4 Well located in.a defined pool Yes KUPARUK RIVER,. WEST SAK OIL - 490150, governed by Conservation. Order No. 406C. 5 Well located proper distance from drilling unit. boundary Yes CO 406C contains no spacing restrictions with. respect to drilling unit boundaries. 6 Well located proper distance from other wells. _ Yes _ CO 4060 has no interwell spacing restrictions, 7 Sufficient acreage available in. drilling unit Yes 8 If deviated, is wellbore plat included _ Yes Appr Date 9 Operator only affected party Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes PKB 1/26/2017 - - Yes - - - - - - 13 Can permit be approved before 15 -day wait. _ Yes 14 Well located within area and. strata authorized by Injection Order # (put 10# in comments). (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA Geology 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA Appr Date Geologic Engineering Public Date: Date Date Commissioner: Commissione : ' /6 / C issioner Its I% 78' conductor 2351'.MD 172%. excess Productive. interval will be completed with uncemented slotted production liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; no major risk failures Diverter meets regulations Max formation pressure is 1660 psig(8.6 ppg EMW ); will drill w/ 8.5-10.0 ppg EMW MPSP is 1289 psig; will test BOPs to 3500 psig. ,✓ 1-12S measures required / 1-12S measures required.... Max potential reservoir pressure is 8.6 ppg_EMW; will be drilled using 8.5 to 10.0 ppg. mud. 9 5/8" csg shoe to be set within top West Salk D; production hole will be. drilled. using 9.0-9,5. ppg mud. Development well to be drilled from onshore -3R -Pad. 18 Conductor string provided _ Yes Engineering 19 Surface casing protects all known USDWs Yes 20 CMT vol adequate to circulate. on conductor & surf csg _ Yes 21 CMT_vol adequate to tie-in long string to surf csg No 22 CMT will cover all known. productive horizons _ No 23 Casing designs adequate for C,. T, 8 & permafrost Yes 24 Adequate tankage or reserve pit Yes 25 If a re -drill., has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes 27 If diverter required, does it meet regulations Yes Appr Date 28 Drilling fluid program schematic & equip list adequate Yes VTL 3/14/2017 29 BOPEs,. do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes 31 Choke manifold complies w/API. RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable. Yes 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Geology 36 Data presented on potential overpressure zones. Yes Appr Date 37 Seismic analysis of shallow gas. zones NA PKB 1/26/2017 38 Seabed condition survey (if off -shore) _ _ _ _ NA 39 Contact name/phone for weekly. progress reports [exploratory only] _ NA. . Geologic Engineering Public Date: Date Date Commissioner: Commissione : ' /6 / C issioner Its I% 78' conductor 2351'.MD 172%. excess Productive. interval will be completed with uncemented slotted production liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; no major risk failures Diverter meets regulations Max formation pressure is 1660 psig(8.6 ppg EMW ); will drill w/ 8.5-10.0 ppg EMW MPSP is 1289 psig; will test BOPs to 3500 psig. ,✓ 1-12S measures required / 1-12S measures required.... Max potential reservoir pressure is 8.6 ppg_EMW; will be drilled using 8.5 to 10.0 ppg. mud. 9 5/8" csg shoe to be set within top West Salk D; production hole will be. drilled. using 9.0-9,5. ppg mud. Development well to be drilled from onshore -3R -Pad.