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214-138
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Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-11 50-029-20685-00 909447215 Kuparuk River Radial Bond Record Field & Processed 3-Jul-24 0 1 2 1B-04 50-029-20595-00 909359143 Kuparuk River Plug Setting Record Field- Final 5-Jun-24 0 1 3 1C-24 50-029-23063-00 n/a Kuparuk River Plug Setting Record Field- Final 6-May-24 0 1 4 1C-157 50-029-23754-00 909345851 Kuparuk River Water Flow Record Field & Processed 25-May-24 0 1 5 1D-135 50-029-22816-00 n/a Kuparuk River Plug Setting Record Field- Final 25-May-24 0 1 6 1D-145 50-029-23526-00 909335380 Kuparuk River Jewelry Record Field- Final 14-May-24 0 1 7 1E-08A 50-029-20496-01 909539034 Kuparuk River Plug Setting Record Field- Final 1-Jun-24 0 1 8 1F-03A 50-029-20853-01 909382731 Kuparuk River Leak Detect Log Field- Final 18-Jun-24 0 1 9 1F-03A 50-029-20853-01 909424095 Kuparuk River Multi Finger Caliper Field & Processed 2-Jul-24 0 1 10 1G-04 50-029-20835-00 909359162 Kuparuk River Patch Setting Record Field- Final 11-Jun-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39146 T39147 T39148 T39149 T39150 T38151 T39152 T39153 T39153 T39154 181-173 181-065 201-248 223-038 197-184 214-138 210-181 196-096 182-161 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:03:51 -08'00' 1D-145 50-029-23526-00 909335380 Kuparuk River Jewelry Record Field- Final 14-May-24 0 1 214-138 T38151 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 9463'feet N/A feet true vertical 3797'feet N/A feet Effective Depth measured 9463'feet 4581'feet true vertical 3797'feet 3739'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 4626' 3742' Packers and SSSV (type, measured and true vertical depth)4581' N/A 3739' N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 2564 2486' Burst Collapse Intermediate Liner 4734' Casing 37544772' 9425' 3797' 2523' 119'Conductor Surface 20" 13-3/8" 78' 4844' 4-1/2" measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-138 50-029-23526-00-00 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: ADL0025649, ADL0025650 Kuparuk River Field/ West Sak Oil Pool KRU 1D-145 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) 250 Gas-Mcf MD 0 Size 119' 1240 135050 0 00 155 323-160 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Baker HRD-EZXP W/HDs SSSV: None Adam Klem adam.klem@conocophillips.com (907) 2653-4529 RWO/CTD Engineer None Development Service GINJ SUSP SPLUG Gas 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 10:58 am, Jun 27, 2023 Page 1/6 1D-145 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/26/2023 13:00 5/26/2023 15:00 2.00 MIRU, MOVE MOB P Complete rig down Prep for move. 0.0 0.0 5/26/2023 15:00 5/26/2023 18:00 3.00 MIRU, MOVE MOB P Pull sub off well and stage on pad. Load out misc equipment. 0.0 0.0 5/26/2023 18:00 5/27/2023 00:00 6.00 MIRU, MOVE MOB P Move rig F/ 1E T/ 1D. 0.0 0.0 5/27/2023 00:00 5/27/2023 03:00 3.00 MIRU, MOVE MOB P Continue MOB 1E to 1D-145 0.0 0.0 5/27/2023 03:00 5/27/2023 07:00 4.00 MIRU, MOVE MOB P On 1D pad, R/U cellar containment. Rig up mats & herculite, Status tree 0.0 0.0 5/27/2023 07:00 5/27/2023 12:00 5.00 MIRU, MOVE MOB P Spot rig on well, Safe out rig. Stairs and landings. Berm up cellar, Berm rig. Set mud shack, set cutting box, set Tiger tank rig up hardline 0.0 0.0 5/27/2023 12:00 5/27/2023 13:00 1.00 MIRU, WELCTL MOB P Rig Accept 12:00, PJSM, Vault wellhead here. Lubricate out BPV. Initial tubing pressure 325 PSI 0.0 0.0 5/27/2023 13:00 5/27/2023 15:00 2.00 MIRU, WELCTL MOB P Take on fluid to pits, Rig up for kill, Load 3 1/2 tubing in shed 0.0 0.0 5/27/2023 15:00 5/27/2023 16:30 1.50 MIRU, WELCTL PRTS P PJSM, Air test surface lines with rig air, PT TT lines, cellar lines and manifold to 2000 PSI. Troubleshoot blooie line pressure gauge 0.0 0.0 5/27/2023 16:30 5/27/2023 17:00 0.50 MIRU, WELCTL CIRC P Initial tubing pressure 325 PSI. Bleed off gas to TT. Down to 245. Pressure back up to 280. 0.0 0.0 5/27/2023 17:00 5/27/2023 19:15 2.25 MIRU, WELCTL KLWL P Start well kill,with 29 BBl deep clean pill followed with seawater, total of 460 Bbls pumped. 8.5 PPG seawter returns to surface. 0.0 0.0 5/27/2023 19:15 5/27/2023 23:15 4.00 MIRU, WELCTL OWFF T OWFF- flow at surface. R/U gauges on TBG/IA. Perform draw down incrementally opening up well for 15 Min and closing and monitoring pressure for 15 Min. Initial shut in pressure 85 TBG/IA. After draw down 40 PSI TBG/IA. Still seeing crude at surface during bleed offs. Fill pits back up with seawater. Empty tiger tank and open top tank. Consult with town and decision made to make additional circulation with seawater. 0.0 0.0 5/27/2023 23:15 5/27/2023 23:30 0.25 MIRU, WELCTL SFTY T PJSM w/ rig crew on killing well. 0.0 0.0 5/27/2023 23:30 5/28/2023 00:00 0.50 MIRU, WELCTL KLWL T Kill well pumping down tubing @ 4 BPM, 215 PSI, w/ open choke. Monitoring volume pumped to volume returned. 0.0 0.0 5/28/2023 00:00 5/28/2023 01:45 1.75 MIRU, WELCTL KLWL T Kill well pumping down tubing @ 4 BPM, 215 PSI, w/ open choke. Total Bbls pumped = 472 Total Bbls returned = 350. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2023 Page 2/6 1D-145 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/28/2023 01:45 5/28/2023 08:45 7.00 MIRU, WELCTL OWFF T OWFF- flow at surface. Perform exhale test. Initial shut in pressure 90 TBG/IA. Open for 30 Min ~25 Bbls bleed back. Shut in for 10 Min 65 PSI TBG/IA. Open for 30 Min ~15 Bbls bleed back. Shut in for 10 Min 50 PSI TBG/IA. Open for 30 Min ~15 Bbls bleed back. Shut in for 10 Min 40 PSI TBG/IA. Open for 30 Min ~10 Bbls bleed back. Shut in for 10 Min 35 PSI TBG/IA. Open for 30 Min ~16 Bbls bleed back. Shut in for 10 Min 31 PSI TBG/IA. Open for 30 Min ~5 Bbls bleed back. Shut in for 10 Min 28 PSI TBG/IA Open for 30 Min ~10 Bbls bleed back. Shut in for 10 Min 26 PSI TBG/IA Open for 30 min ~9 bbls bleed back Shut in 10 min 25 PSIU TBG/IA 0.0 0.0 5/28/2023 08:45 5/28/2023 10:00 1.25 MIRU, WELCTL OWFF T Last bleed cycle getting crude in returns, Pressure stabilized T=35PSI, IA=37psi. 0.0 0.0 5/28/2023 10:00 5/28/2023 13:30 3.50 MIRU, WELCTL KLWL T Pits weighted up to 8.8 PPG. PJSM Pump down Tubing returns IA to TT. Pumped 494 BBls. Return 385 BBl. 8.78PPG, SITP=55, IA=55 Lost 136 BBls 0.0 0.0 5/28/2023 13:30 5/28/2023 16:00 2.50 MIRU, WELCTL OWFF T Initial SITP=55, IA=55 Bleed down. 85 BBls in open top. Start step wise bleed off Shut in 5 min bleed 10 min pressure recorded on shut in T=60 IA=57 85 BBls T=55 IA=55 87 BBl T+30 IA=33 90 BBl T=20 IA=20 95 BBl 14:35 T=18 IA=18 100 BBl 0.0 0.0 5/28/2023 16:00 5/28/2023 17:00 1.00 MIRU, WELCTL OWFF T Contine bleed Crane on location to lift second spooler T=12 IA=12 108 BBL, 23 BBl back 0.0 0.0 5/28/2023 17:00 5/28/2023 19:00 2.00 MIRU, WELCTL OWFF T Very light flow open for 2 Hrs, IA 12 T=12. Diminishing to no flow at tiger tank. 0.0 0.0 5/28/2023 19:00 5/29/2023 00:00 5.00 MIRU, WELCTL OWFF T 12 PSI remaining on TBG/IA. Open up bleed ports on TBG/IA in cellar to bucket. Allow well to exhale with diminishing returns starting at 1.5 BPH down T/ no flow. 30 Min no flow check - Good 0.0 0.0 5/29/2023 00:00 5/29/2023 00:30 0.50 MIRU, WELCTL MPSP P Set HP BPV. 0.0 0.0 5/29/2023 00:30 5/29/2023 01:00 0.50 MIRU, WELCTL PRTS P Rolling PT on BPV @ 2 BPM for 10 Min - Good test. 0.0 0.0 5/29/2023 01:00 5/29/2023 02:00 1.00 MIRU, WHDBOP RURD P B/D, R/D circ manifold. 0.0 0.0 5/29/2023 02:00 5/29/2023 04:00 2.00 MIRU, WHDBOP NUND P Nipple down tree and adaptor spool. Install tree test dart. Function LDS. Remove tree from cellar. Allowing charged formation pressure to relax after BPV test. Initial flow rate 3 BPH @ 03:30 Hrs 0.0 0.0 5/29/2023 04:00 5/29/2023 06:30 2.50 MIRU, WHDBOP NUND P N/U BOP Allowing charged formation pressure to relax after BPV test. 1.78 BPH @ 04:30 Hrs .8 BPH @ 06:00 Hrs 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2023 Page 3/6 1D-145 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/29/2023 06:30 5/29/2023 12:30 6.00 MIRU, WHDBOP NUND P Nipple up stack .59 BPH @ 06:30 .36 BPH @ 07:00 .19 BPH @ 07:30 No flow @ 08:00 0.0 0.0 5/29/2023 12:30 5/29/2023 13:30 1.00 MIRU, WHDBOP SFTY P PJSM, Perform full BOPE test 250 low, 3000 high, 2500 on annular preventer. Test witness waived by Austin McCloud, AOGCC 0.0 0.0 5/29/2023 13:30 5/29/2023 23:30 10.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested UVBR's, LVBRs w/ 3 1/2" test joint. Tested UVBRs and LVBRs w/ 4 ½ Test joint. 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 3 ½ & 4 1/2" EUE FOSVs. 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. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Austin McLeod. Annular failed on test #11. 0.0 0.0 5/29/2023 23:30 5/30/2023 00:00 0.50 MIRU, WHDBOP BOPE T Annular failed on test #11 w/ 3 1/2" test joint. L/D test joint. Suck out stack. 0.0 0.0 5/30/2023 00:00 5/30/2023 10:00 10.00 MIRU, WHDBOP BOPE T Change out annular element. 0.0 0.0 5/30/2023 10:00 5/30/2023 11:00 1.00 MIRU, WHDBOP BOPE T R/U 3.5" Test Joint and Test Equipment. 0.0 0.0 5/30/2023 11:00 5/30/2023 12:00 1.00 MIRU, WHDBOP BOPE T Test Annular and 3.5" IF FOSV to 250 / 3000 PSI. Conduct Accumulator Draw Down Test. Initial pressure=3000 PSI, after closure=1650 PSI, 200 PSI attained =22 sec, full recovery attained =131 sec. UVBR's= 5 sec, Annular= 13 sec. Simulated blinds= 5 sec. Simulated LPR's= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2070 PSI. 0.0 0.0 5/30/2023 12:00 5/30/2023 12:30 0.50 COMPZN, RPCOMP RURD P R/D Testing Equipment. 0.0 0.0 5/30/2023 12:30 5/30/2023 13:00 0.50 COMPZN, RPCOMP MPSP P Drain BOP Stack. Pull BPV after checking for pressure. 0.0 0.0 5/30/2023 13:00 5/30/2023 13:30 0.50 COMPZN, RPCOMP OWFF P Observe Well For Flow. 0.0 0.0 5/30/2023 13:30 5/30/2023 13:45 0.25 COMPZN, RPCOMP SFTY P PJSM for Rigging Up Elevators and Picking up Landing Joint. 0.0 0.0 5/30/2023 13:45 5/30/2023 17:00 3.25 COMPZN, RPCOMP RURD P Rig up Landing Joint and Surface Equipment. Hang ESP & Control Line Sheave. 0.0 0.0 5/30/2023 17:00 5/30/2023 18:00 1.00 COMPZN, RPCOMP THGR P MU Landing Joint to hanger and set 10K down. BOLDS. Unseated Hanger @ 185K / Free Weight 110K. Pull Hanger to RF.. 4,626.0 4,586.0 5/30/2023 18:00 5/30/2023 19:00 1.00 COMPZN, RPCOMP ALFT P Crew change out, PJSM with SLB, Summit, Vault and rig crew on laying down completion and spooling up wire. Terminate ESP Cable and Control Line. 4,586.0 4,586.0 5/30/2023 19:00 5/30/2023 20:00 1.00 COMPZN, RPCOMP RURD P L/D hanger and landing joint. Change elevators T/ 5 1/2". Resize tubing tongs to 5 1/2". 45,898.0 4,586.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2023 Page 4/6 1D-145 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/30/2023 20:00 5/30/2023 20:30 0.50 COMPZN, RPCOMP PULL P L/D 3 joint 5 1/2", 15.5# casing T/ 4505', PUW=100K. Connect SS control line ESP cable to spooling units. Loss rate= 8 BPH. 4,586.0 4,505.0 5/30/2023 20:30 5/30/2023 21:00 0.50 COMPZN, RPCOMP RURD P Change out handling equipment T/ 4 1/2". 4,505.0 4,505.0 5/30/2023 21:00 5/30/2023 22:15 1.25 COMPZN, RPCOMP PULL P L/D 4 1/2", 12.6#, IBT completion string T/ 38881'. PUW=96K. Spooling up SS control line & ESP cable. Loss rate = 10 BPH. Well out of balance fluid coming out top of tubing. 4,505.0 3,881.0 5/30/2023 22:15 5/31/2023 00:00 1.75 COMPZN, RPCOMP COND P Install FOSV. Lose rate in IA = 10 BPH. Take sample of MW coming out of tubing 8.78 PPG. MW in trip tank 8.87 PPG. Consult w/ town, decision made to build 35 Bbls 9.0 PPG dry job and pump into tubing slowly. 3,881.0 3,881.0 5/31/2023 00:00 5/31/2023 01:30 1.50 COMPZN, RPCOMP CIRC P Attempt to pump 9.0 PPG dry job w/ charge pump - not moving fluid. Pump 35 Bbls 9.0 PPG dry job @ 1/2 BPM, ICP=55 FCP=45. 17 Bbls returned to surface. 3,881.0 3,881.0 5/31/2023 01:30 5/31/2023 02:00 0.50 COMPZN, RPCOMP OWFF P Monitor IA w/ trip tank 6 BPH loss rate. Break off TD. Open up tubing - no flow for 30 Min. B/D TD. 3,881.0 3,881.0 5/31/2023 02:00 5/31/2023 08:30 6.50 COMPZN, RPCOMP PULL P Continue L/D 4 1/2" completion F/ 3881' T/ 1518' 3,881.0 1,518.0 5/31/2023 08:30 5/31/2023 10:30 2.00 COMPZN, RPCOMP RGRP T Mount on ESP Drive Motor Broke. Had Rig welder make repairs. 1,518.0 1,518.0 5/31/2023 10:30 5/31/2023 12:15 1.75 COMPZN, RPCOMP PULL P Continue L/D 4 1/2" completion F/ 1518' found hole in Joint #22. 1,518.0 710.0 5/31/2023 12:15 5/31/2023 14:45 2.50 COMPZN, RPCOMP PULD P L/D Gas Vent and Motor Shroud Assy. 710.0 542.0 5/31/2023 14:45 5/31/2023 15:45 1.00 COMPZN, RPCOMP PULL P Continue L/D 4 1/2" completion F/ 542' To Surface. Note: CMD had heavy scale and corrosion. Recovered 101 4.5" Clamps / 3 5-1/2" Clamps and 15 Bands. 542.0 0.0 5/31/2023 15:45 5/31/2023 16:00 0.25 COMPZN, RPCOMP SFTY P PJSM with Crane Operator and Crew Members. 0.0 0.0 5/31/2023 16:00 5/31/2023 18:00 2.00 COMPZN, RPCOMP RURD P Spot in crane. Remove ESP and Control Line Spools from Rig Floor. Load new Tec-Line Spooler. 0.0 0.0 5/31/2023 18:00 5/31/2023 22:00 4.00 COMPZN, RPCOMP RURD P Offload old clamp and bring new clamps to RF. Remove ESP sheave. Load hanger into pipe shed. Feed Tec wire over sheave. Verify jewelry running order and joint count. Dress tubing handling equipment for 4 1/2". ~8 BPH loss rate. 0.0 0.0 5/31/2023 22:00 5/31/2023 22:15 0.25 COMPZN, RPCOMP PRTS P Initial test on SLB gauge and Tec wire T/ 500 PSI for 5 Min & 7500 PSI for 15 Min. 0.0 0.0 5/31/2023 22:15 5/31/2023 22:45 0.50 COMPZN, RPCOMP SFTY P PJSM w/ SLB and rig crew on running 3 1/2" completion w/ SGM and Tec wire. 0.0 0.0 5/31/2023 22:45 6/1/2023 00:00 1.25 COMPZN, RPCOMP RCST P Run Baker 192-47 seal assembly, lower X nipple assembly. Make up gauge mandrel T/ 60', Install SGM gauge. 0.0 60.0 6/1/2023 00:00 6/1/2023 00:30 0.50 COMPZN, RPCOMP PRTS P PT SGM to Tec wire 500 PSI for 5 Min, 5000 PSI for 15 Min. Initial readings 56*, 19 PSI. 60.0 60.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2023 Page 5/6 1D-145 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/1/2023 00:30 6/1/2023 04:30 4.00 COMPZN, RPCOMP RCST P Continue RIH w/ 3 1/2" 9.3#, L-80, EUE- M completion. EUE-M torque T/ 2250 Ft/lbs w/ Run-N-Seal dope. Installing cannon clamp on each collar T/ 1820', SOW=55K. Loss rate ~8 BPH. 60.0 1,820.0 6/1/2023 04:30 6/1/2023 06:00 1.50 COMPZN, RPCOMP RCST T Troubleshoot Tec-Wire Communication Box. Down Hole Gauge showing good reading on Wire, No indication of bad wire. Ran jumper wire from Tec-Wire to Computer, good reading. 1,820.0 1,820.0 6/1/2023 06:00 6/1/2023 12:00 6.00 COMPZN, RPCOMP RCST P Continue RIH with 3.5" Completion f/1820' t/4,620'. UP WT 75K / ND WT 65K. Tag No Go 24' in on Joint 143. Filled hole and performed 15 min seal assembly integrity test, seals holding no losses to formation. Space out 5' from fully located. PUH and L/D Joint 143 & 142. MU Space Out pup and Hanger. Installed 146 Cross Collar Clamps and 3 half clamps on completion. 1,820.0 4,596.0 6/1/2023 12:00 6/1/2023 14:30 2.50 COMPZN, RPCOMP THGR P Install dummy penetrator in Hanger.Terminate Tec-Wire through Hanger. 4,596.0 4,596.0 6/1/2023 14:30 6/1/2023 18:15 3.75 COMPZN, RPCOMP CIRC P Circulate 290 Bbls of 8.85 PPG CI Brine down TBG followed by 40 Bbls 8.85 brine, while taking returns up the IA at 1 BPM, 45 psi. 4,596.0 4,596.0 6/1/2023 18:15 6/1/2023 19:45 1.50 COMPZN, RPCOMP OWFF P Allow charged formation to relax. 4,596.0 4,596.0 6/1/2023 19:45 6/1/2023 20:15 0.50 COMPZN, RPCOMP RURD P B/D surface lines. Empty trip tank. Suck out stack. 4,596.0 4,596.0 6/1/2023 20:15 6/1/2023 22:30 2.25 COMPZN, RPCOMP HOSO P RIH w/ hanger. Took weight with hanger in top annular. P/U inspect hanger. Center stack up. Run in hole and land hanger. Bottom of seals @ 4626'. PUW=73K, SOW =66K. RILDS. 4,596.0 4,626.0 6/1/2023 22:30 6/1/2023 23:00 0.50 COMPZN, RPCOMP PRTS P PT upper and lower hanger seals T/ 5000 PSI for 15 Min each. 4,626.0 4,626.0 6/1/2023 23:00 6/2/2023 00:00 1.00 COMPZN, RPCOMP RURD P R/U circ manifold to landing joint & IA. 4,626.0 4,626.0 6/2/2023 00:00 6/2/2023 01:00 1.00 COMPZN, RPCOMP RURD P R/U testing equipment 4,626.0 4,626.0 6/2/2023 01:00 6/2/2023 02:45 1.75 COMPZN, RPCOMP PRTS P PT TBG T/ 3500 PSI for 30 Min. Bleed tubing to 1500 PSI. PT IA T/ 2500 for 30 Min. Dump tubing pressure shear out SOV. Pump down IA @ 2 BPM, 170 PSI. Cleaning trip tank. 4,626.0 4,626.0 6/2/2023 02:45 6/2/2023 03:15 0.50 COMPZN, RPCOMP RURD P B/D, R/D TBG testing equipment. L/D landing joint. 4,626.0 4,626.0 6/2/2023 03:15 6/2/2023 03:30 0.25 COMPZN, RPCOMP MPSP P Set HP BPV. 4,626.0 4,626.0 6/2/2023 03:30 6/2/2023 04:00 0.50 COMPZN, RPCOMP PRTS P PT BPV from below T/ 1000 PSI for 10 Min. 4,626.0 4,626.0 6/2/2023 04:00 6/2/2023 04:30 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 0.0 0.0 6/2/2023 04:30 6/2/2023 07:30 3.00 COMPZN, RPCOMP NUND P Pull riser, N/D BOP and rack back on stump. 0.0 0.0 6/2/2023 07:30 6/2/2023 10:30 3.00 COMPZN, RPCOMP NUND P NU Production Tree. Perform Tec-Line feed through and secure Tec-Wire. SGM Final pressure = 1737.85 Temperature = 71.659* F 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2023 Page 6/6 1D-145 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/2/2023 10:30 6/2/2023 12:15 1.75 COMPZN, RPCOMP PRTS P PT Hanger Void to 5000 PSI for 15 Min. PT Tree to 250/5000 for 5 mins. 0.0 0.0 6/2/2023 12:15 6/2/2023 14:15 2.00 COMPZN, RPCOMP FRZP P Pulled Tupe "H" BPV. RU LRS and Circulate 140 bbls of Diesel down IA. RU Hose to TBG and Allow well to U- Tupe. 0.0 0.0 6/2/2023 14:15 6/2/2023 18:00 3.75 COMPZN, RPCOMP DMOB P Secure Rig for moving. Clean Cellar and area around Rig. Rig Released @ 1800 hrs. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2023 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:1D-145 smsmith Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Ball & Rod & RHC. Installed GLD 1D-145 6/11/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: smsmith 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 19.25 41.6 119.3 119.3 109.00 X52 Slip on SURFACE 13 3/8 12.42 41.3 2,564.0 2,485.6 68.00 L-80 HYD 563 INTERMEDIATE 9 5/8 8.84 37.8 4,771.6 3,754.1 40.00 L-80 Hyd 563 LINER - 7" x 5.5" x 4.5" 4 1/2 4.00 4,580.5 9,425.0 3,796.7 11.60 L-80 Hyd 563 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 33.9 Set Depth 4,626.0 Set Depth 3,742.4 String Ma 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 33.9 33.9 0.00 Hanger 13.313 Vetco Gray MB-222A 13 5/8" x 4 1/2" Tubing Hanger w/ 4.909 MCA Box Vault MB- 222A 3.900 2,729.9 2,646.0 16.92 Mandrel GAS LIFT 5.850 3.5" x 1.5" MMG, GLM SLB MMG 2.920 2,791.0 2,704.2 18.50 Nipple - X 4.496 3.5" x 2.813" X-Nipple Halliburt on X 2.813 4,504.8 3,734.5 86.16 Mandrel GAS LIFT 5.890 3.5" x 1.5" MMG, GLM SLB MMG 2.920 4,565.6 3,737.9 86.48 Sensor - Discharge Gauge 5.450 3.5" SGM, Gauge mandrel SLB SGM 2.940 4,586.9 3,739.3 85.91 Nipple - X 4.496 3.5" x 2.813" X-Nipple Halliburt on X 2.813 4,604.9 3,740.6 85.43 Locator 5.360 Baker 5.36" Locator Sub Baker Locator 4.880 4,606.7 3,740.8 85.39 Seal Assembly 4.730 Baker 192-47 Seal Assembly (4' From Fully Located) Baker 192-47 Seal Assembl y 3.880 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) 2,729.9 2,646.0 16.92 1 GAS LIFT GLV RK 1 1/2 1,397.0 6/11/2023 Schlumb erger MMG 0.125 4,504.8 3,734.5 86.16 2 GAS LIFT OV RK 1 1/2 0.0 6/10/2023 Schlumb erger MMG 0.188 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,580.5 3,738.8 86.08 PACKER 7.000 BAKER HRD-E ZXP W/ HDs Baker CPAI# 10787733 7.375 4,599.3 3,740.2 85.58 NIPPLE 7.000 BAKER RS NIPPLE Baker CPAI# 10787695 6.180 4,611.7 3,741.2 85.25 XO Reducing 7.000 XO 7" 26# Hydril 563 box X 5.5" 15.5# Hydril 563 pin CPAI# 11091227 4.870 4,632.7 3,743.0 84.91 XO Thread 7.000 XO 5-1/2" 15.5 ppf Hyd 563 box x 7" 26 ppf L-80 Hyd 563 pin CPAI#1367 7075 4.920 4,634.1 3,743.1 84.92 VALVE 7.000 BAKER FLUID LOSS CONTROL VALVE CPAI# 13527559 4.563 4,641.0 3,743.7 84.99 XO Reducing 7.000 XO 7" 29# Hyd 563 box x 5-1/2" 15.5# Hyd 563 pin CPAI#1367 7076 4.880 4,725.7 3,750.5 85.64 XO Reducing 5.500 XO 5.5" 15.5# Hyd 563 box x 4.5" 11.6# Hyd 563 pin CPAI#1367 9133 4.000 4,899.7 3,762.5 87.54 SWELL PACKER 4.500 TAM SWELL PACKER "F" (WATER ACTIVATED) CPAI#1367 2015 3.958 4,950.3 3,764.0 89.11 XO Thread 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80, Hyd 563 Box x pin ser # 18, Tracerco 920/Tracerc o 716 3.958 4,961.1 3,764.1 89.45 TRACER 4.500 TRACERCO TRACER CARTRIDGE SER#18 Tracerco #REF!3.958 4,980.8 3,764.2 90.07 XO Thread 4.500 XO 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L-80 Hyd 563 pin Tracerco 3.958 4,981.5 3,764.2 90.09 XO Thread 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563-m Box x pin CPAI # 13491224 3.958 5,645.8 3,759.6 89.38 SWELL PACKER 4.500 TAM SWELL PACKER "D" (WATER ACTIVATED) CPAI#1367 2015 3.958 5,697.5 3,760.3 89.33 XO Thread 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563 Box x pin 3.958 5,708.3 3,760.4 89.35 TRACER 4.500 TRACERCO TRACER CARTRIDGE SER#17 Tracerco ser # 17, Tracerco 911/Tracerc o 165A 3.958 5,727.9 3,760.6 89.41 XO Thread 4.500 XO 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L-80 Hyd 563 pin Tracerco 3.958 5,728.6 3,760.6 89.41 XO Thread 4.500 Pup Joint , 4-1/2", 11.6 ppf, L-80 Hyd 563-m Box x pin 3.958 1D-145, 6/27/2023 10:09:47 AM Vertical schematic (actual) LINER - 7" x 5.5" x 4.5"; 4,580.5 -9,425.0 INTERMEDIATE; 37.8-4,771.6 Nipple - X; 4,586.9 Mandrel GAS LIFT; 4,504.8 Nipple - X; 2,791.0 Mandrel GAS LIFT; 2,729.9 SURFACE; 41.3-2,564.0 CONDUCTOR; 41.6-119.3 Hanger; 33.9 KUP PROD KB-Grd (ft) 39.31 RR Date 8/21/2015 Other Elev 1D-145 ... TD Act Btm (ftKB) 9,463.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292352600 Wellbore Status PROD Max Angle & MD Incl (°) 91.44 MD (ftKB) 5,091.30 WELLNAME WELLBORE Annotation Last WO: End Date 6/3/2023 H2S (ppm) 0 Date 12/29/2015 Comment SSSV: NIPPLE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,305.4 3,768.1 88.60 SWELL PACKER 4.500 TAM SWELL PACKER "C" (WATER ACTIVATED) CPAI # 13672015 3.958 6,908.2 3,791.4 89.35 SWELL PACKER 4.500 TAM SWELL PACKER "B" (WATER ACTIVATED) CPAI # 13672015 3.958 6,960.0 3,791.9 89.48 XO Thread 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563 Box x pin 3.958 6,970.7 3,792.0 89.50 TRACER 4.500 TRACERCO TRACER CARTRIDGE SER#16 Tracerco ser # 16, Tracerco 926/Tracerc o 721 3.958 6,990.4 3,792.1 89.55 XO Thread 4.500 Crossover 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L- 80 Hyd 563 pin Tracerco 3.958 6,991.1 3,792.1 89.55 XO Thread 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563-m Box x pin 3.958 8,001.0 3,789.3 90.52 SWELL PACKER 4.500 TAM SWELL PACKER "A" FREECAP (WATER ACTIVATED) CPAI # 13672015 3.958 8,053.0 3,788.9 90.55 XO Thread 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563 Box x pin 3.958 8,083.4 3,788.6 90.64 XO Thread 4.500 XO 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L-80 Hyd 563 pin Tracerco 3.958 9,401.8 3,796.5 89.48 PACKOFF 5.000 BAKER PACK-OFF BUSHING CPAI # 13670383 2.380 1D-145, 6/27/2023 10:09:51 AM Vertical schematic (actual) LINER - 7" x 5.5" x 4.5"; 4,580.5 -9,425.0 INTERMEDIATE; 37.8-4,771.6 Nipple - X; 4,586.9 Mandrel GAS LIFT; 4,504.8 Nipple - X; 2,791.0 Mandrel GAS LIFT; 2,729.9 SURFACE; 41.3-2,564.0 CONDUCTOR; 41.6-119.3 Hanger; 33.9 KUP PROD 1D-145 ... WELLNAME WELLBORE JLC 4/10/2023 RBDMS JSB 041123 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-07-28_21087_KRU_1D-145_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21087 KRU 1D-145 50-029-23526-00 Caliper Survey w/ Log Data 28-Jul-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:214-138 T36878 Kayla Junke Digitally signed by Kayla Junke Date: 2022.08.12 15:38:39 -08'00' • • prD38 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, September 10, 2015 10:55 AM To: 'Hallford, Kelsey' Subject: RE: KRU 1D-145 completion report PTD#214-138 Include 315-454 Sundry for top job with the 10-407 for 214-138- Thanx, Victoria ScANNEL MAR 0 8 From: Hallford, Kelsey [mailto:Kelsey.Hallford@conocophillips.com] Sent: Thursday, September 10, 2015 10:10 AM To: Loepp, Victoria T(DOA) Cc: Allsup-Drake, Sharon K Subject: FW: KRU 1D-145 completion report PTD#214-138 Victoria — We have a question about sundry#315-454 for KRU well 1D-145. We are going to submit the completion report (10-407) soon and we wondered if we could include the sundry operations on the same form, thereby eliminating the need to submit a 10-404 for#315-454? We will include the sundry number on the completion report 10-407 instead. Please let us know the appropriate way to proceed. 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Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: '8/20/2015 214-138/315-454• 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360,Anchorage,AK 99501 •7/20/2015 50-029-23526-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 222'FNL,419'FEL, Sec.23,T11N, R10E, UM .8/3/2015 KRU 1D-145-; Top of Productive Interval: 9. KB(ft above MSL): 106' 17. Field/Pool(s): 901'FSL, 38'FEL, Sec. 14,T11N, R10E, UM GL(ft above MSL): 66.9' Kuparuk River Field/West Sak Oil Pool• Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 293'FSL,216'FEL, Sec. 11,T11N, R10E, UM 9425'MD/3797'TVD ADL 25650,25649 • 4b. Locbtion of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 560671 y- 5959444 Zone- 4 . 9463'MD/3797'TVD ALK 468,467 TPI: x- 561041 y- 5960570 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 560822 y- 5965$40 Zone- 4 nipple @ 493'MD/493'TVD 1676'MD/1650'TVD 5. Directional or Inclination Survey: Yes • E](a ached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) • not applicable 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, pore pressure log 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM • HOLE SIZE CEMENTING RECORD FT PULLED 20" 109# X-52 42' 119' 42' 119' 42" 53 sx AS I,295 sx AS I 13.375" 68# L-80 41.6' 2564' 41.6' 2486' 16" 1671 sx Class G 9.625" 40# L-80 37.8' 4772' 37.8' 3754' 12.25" 730 sx Class G 4.5" 11.6# L-80 4581' 9425' 3739' 3797' 6.75" screened 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): 4.5' 4626' 4580'MD/3739'TVD screened liner from 4581'-9425'MD 3739'-3797'TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. apiiiiivoN ; Was hydraulic fracturing used during completion? Yes❑ No ❑✓ 4 (f Per 20 AAC 25.283(i)(2)attach electronic and printed information • :' k5,1 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED r 1 t none 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting on facility hook-up r Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -0. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -► Form 10-407 Red ed5/2015 V/'J L /0/2 0/i 5-- CONTINUED ON PAGE 2 RBDMS��j, '�7EP 2 2 2015 Submit ORIGINIAL onlya ?' Y 10/10S- A r 04077,- G ,‘ 28.CORE DATA Conventional CO: Yes ❑ No ❑ Sidewall Cores:Os ❑ No Q 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. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1676' 1650' Attach separate pages to this form, if needed,and submit detailed test information, including reports, per 20 AAC 25.071. Ugnu A 3580' 3373' Top West Sak 4200' 3678' West Sak B 4721' 3750' West Sak B 6427' 3771' West Sak Base 9463' 3797' Formation at total depth: West Sak B ' 31. List of Attachments: Summary of Daily Operations,directional survey,schematic,cement reports Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kelsey Hallford @ 265-1577 Email: Kelsey.Hallford@cop.com fy, ,(,, ✓ . �j Printed Name: Graham L.Alvord Title: Alaska Drilling Manager L/ Signature: 4 OtJ Phone: 265-6120 Date: ci ' 11 j �� 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 la: 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 lb: 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 and Ground Level 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 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 5/2015 Submit ORIGINAL Only KUP PROD 1D-145 Conoc i hiJtipss Well Attributes 0 Max Angle&MD TD 1I.:-kd,IncaNVAWellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act atm(ftKB) a,rx„,),,,Blpa 500292352600 WEST SAK PROD 91.44 5,091.30 9,463.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1D-145,9/17/201512'56'53 PM SSSV:NIPPLE Last WO: 39.31 8/21/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER 339a ■ '"" Last Tag: Rev Reason:NEW WELL,GLV C/O smsmith 9/9/2015 Illl 1 Casing Strings OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.250 416 119.3 119.3 109.00 X52 Slip on ............................_.....................-..__..._" (.. ... -':...Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 133/8 12.415 41.3 2,564.0 2,485.6 68.00 L-80 HYD 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread INTERMEDIATE 95/8 8.835 37.8 4,771.6 3,754.1 40.00 L-80 Hyd 563 "A'Af CONDUCTOR;47.6-119.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread a a LINER 7'0 5 5"x 4.5" 4 1/2 4.000 4,580.5 9A25 0 3,796 7 11.60 L-80 Hyd 563 NIPPLE',494.3 „-,.m.. Liner Details Nominal ID Top(ftKB) Top(TOD)(ftKB) Top Incl(") Item Des Com (in) ( 4,580.51 3,738.8 86.08 PACKER BAKER HRD-E ZXP W/HDs 7.375 4,599.3 3,7402 85.58 NIPPLE BAKER RS NIPPLE 6.180 SURFACE;41.3-2,564.0- 4,602.1 3,740.4 85.51 HANGER BAKER FLEX LOCK HANGER 6.226 GAS LIFT;2,699.5 4,611.7 3,7412 85.25 XO Reducing -XO 7"26#Hydril 563 box X 5.5"15.58 Hydril 563 pin 4.870 GAS LIFT;3E62.1 4,613.1 3,741.3 85.22 SBE BAKER SEAL BORE EXTENSION 4.750 GAUGE;3,729.5 _ 4,634.1 3,743.1 84.92 VALVE BAKER FLUID LOSS CONTROL VALVE 4.563 XO Threads;3,nss 4,641.0 3,743.7 84.99 XO Reducing XO 7"29#Hyd 563 box x 5-1/2"15.5#Hyd 563 pin 4.880 GAS VENT,3,790.8 -ABATE 4,725.7 3,750.5 85.64 XO Reducing XO 5.5"15.58 Hyd 563 box x 4,5"11.6#Hyd 563 pin 4.000 lib GAS VENT;3,813.1 XO Enlarging,3,820.5 , 4,899.7 3,7625 87.54'SWELL TAM SWELL PACKER"F"(WATER ACTIVATED) 3.958 SHROUD;3,823.5 PACKER CENTRALIZR,3,828.3 0.0 SHROUD;3,829.8 W 4,961.1 3,764.1 89.45 TRACER TRACERCO TRACER CARTRIDGE SER#18 3.958 CENTRALIZR;3,834.6 lab SHROUD,3,836.14,991,2 3,764.1 90.39 SCREEN BAKER EXCLUDER 2000 SCREEN(64-77) 4.000 CENTRALIZR;3,840.9 s 5,645.8 3,759.6 89.38 SWELL TAM SWELL PACKER"D"(WATER ACTIVATED) 3.958 SHROUD;3,842.4 -� PACKER CENTRALIZR;3,847.1 SHROUD;3.848.6 5,708.3 3,760.4 89.35 TRACER TRACERCO TRACER CARTRIDGE SER#17 3.958 CENTRALIZR;3,853.4 SHROUD;3,854.9 5,738.4 3,760.7 89.43 SCREEN BAKER EXCLUDER 2000 SCREEN(52-63) 4.000 ACP;3,859.7 6,305.4 3,768.1 88.60 SWELL TAM SWELL PACKER"C"(WATER ACTIVATED) 3.958 PACKER B PROFILE;3,901.5 'ir;" 6,908.2 3,791.4 89.35 SWELL TAM SWELL PACKER"B"(WATER ACTIVATED) 3.958 NO-GO,3,943.2 K. PACKER ME Mili 6,970.7 3,792.0 89.50 TRACER TRACERCO TRACER CARTRIDGE SER#16 3.958 SLEEVE,3,995.0 f 7,000.8 3,792.2 89.55 SCREEN BAKER EXCLUDER 2000 SCREEN(30-51) 4.000 Mei 8,001.0 3,789.3 90.52 SWELL TAM SWELL PACKER"A"FREECAP(WATER 3.958 NIPPLE;4,059.7 PACKER ACTIVATED) 8,063.7 3,788.8 90.58 SCREEN TRACERCO TRACER CARTRIDGE SER#15 3.958 8,093.8 3,788.4 90.68 SCREEN BAKER EXCLUDER 2000 SCREEN(1-29) 4.000 LOCATOR;4,604.9 9,401.8 3,796.5 89.48 PACKOFF BAKER PACK-OFF BUSHING 2.380 Tubing Strings SEAL ASSY;4,606.7 Tubing Description Stung Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth IND)(...Wt(Iblft( Grade Top Connection TUBING-51/2"x4 41/2 3.958 33.9 4,626.0 3.7424 12.60 L-80 IBT-M . = 1/2 @161 65 J 1 :1 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (ml 33.9 33.9 0.00 HANGER VETCO GRAY MB22 TUBING HANGER 3.958 38.2 38.2 0.00 XO Enlarging XO 4.5",12.6 ppf,L-80 IBT-m box x 5.5",15.5 ppf 3.930 161.6 161.6 0.58 XO Reducing XO 5.5",15.5 ppf,L-80,IBT box x 4.5",12.6 ppf 3.930 INTERMEDIATE,37.8-4,771.6 494,3 494.2 2.62 NIPPLE CAMCO DB-6 NIPPLE 3.875 : 3,729.5 3,465.0 57.13 GAUGE BAKER GAUGE CARRIER,DUAL GUARDIAN 3.958 3,790.8 3,813.1 3,820.5 3,497.9 57.64 GAS VENT GAS VENT-POS-3 SSD(3.875"X SELECTIVE-CLOSED) 3.900 3,509.8 57.73 GAS VENT GAS VENT-POS-4 SSD(3.875"X SELECTIVE-OPEN) 3.900 3,513.8 57.75 XO Enlarging XO 4.5",12.6 ppf,L-80,Vam Top Box x 5.5"19ppF 3.910 3,823.5 3,515.4 57.77 SHROUD MOTOR SHROUD#6 4.670 3,828.3 3,517.9 57.78 CENTRALIZR MOTOR CENTRALIZER#5 4.670 3,829.8 3,518.7 57.79 SHROUD MOTOR SHROUD#5 4.670 3,834.6 3,521.3 57.81 CENTRALIZR MOTOR CENTRALIZER#4 4.670 ri 3,836.1 3,522.1 57.81 SHROUD MOTOR SHROUD#4 4.670 Q 3,840.9 3,524.6 57.83 CENTRALIZR MOTOR CENTRALIZER#3 4.670 3,842.4 3,525.4 57.84 SHROUD MOTOR SHROUD#3 4.670 liar 3,847.1 3,528.0 57.85 CENTRALIZR MOTOR CENTRALIZER#2 4.670 3,848.6 3,528.8 57.86 SHROUD MOTOR SHROUD#2 4.670 3,853.4 3,531.3 57.88 CENTRALIZR MOTOR CENTRALIZER#1 4.670 3,854.9 3,859.7 3,901.5 3,532.1 57.88 SHROUD MOTOR SHROUD#1 4.670 3,534.7 57.90 ACP ANNULAR CONNECTION PORT 3.960 3,556.8 58.47 B PROFILE B PROFILE ASSEMBLY 3.960 3,943.2 3,578.1 59.90 NO-GO NO-GO PROFILE 3.800 3,995.0 3,603.4 62.06 SLEEVE BAKER CMD SLIDING SLEEVE W/BX PROFILE-OPEN 3.812 4,059.8 3,631.7 65.99 NIPPLE CAMCO DB LANDING NIPPLE W/3.75"PROFILE 3.750 4,605.0 3,740.6 85.43 LOCATOR BAKER NO GO LOCATOR(ABOVE LOCATED) 3.870 4,606.7 3,740.8 85.39 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.880 III ' Y LINER-7"x 5.5"x 4,5";4,580.5 9,425.0 KUP PROD 1D-145 • Conoc©Phillips y Alaska,inc. c xxnet,.n. ••• 1D-145,9/17/201512.56.54 PM Vertical schematic(actual) .........HANGER 339.— � ' �f • ! I Mandrel Inserts ati I r. on Top(TVD) Valve Latch Port Slze TRO Run Top(ftKB) (ftt/B) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com { 2,699.5 2,616.8 CAMCO KBMG 1 GAS LIFT DMY BK-5 0000 0.0 8/172015 ,n,n,p w w w w w �`L,2 3,662.1 3,426.2 CAMCO KBMG 1 GAS LIFT SOV BK-5 0 000 3,000 0 8/17/2015 STS-1 .1 'IliCONDUCTOR 41.6-119.3 Notes:General&Safety End Date Annotation NIPPLE;494.3 — NOTE SURFACE,41.3-2,564.0— GAS LIFT;2,699.5 GAS LIFT;3,662.1 GAUGE;3,729.5 In XO Threads;3,775.6 GAS VENT;3,790.8 ? _ GAS VENT;3,813.1 t�•.s:: XO Enlarging;3,8205 „AK .,. SHROUD;3,823.5 CENTRALIZR;3,828.3 SHROUD;3,829.8 CENTRALIZR;3,834.6 SHROUD;3,836.1 CENTRALIZR;3,840.9 SHROUD;3,842.4 CENTRALIZR;3,847.1 SHROUD;3548.6 a CENTRALIZR;3,853.4 III SHROUD;3,854.9 ACP,3,859.7 , B PROFILE;3,901.5 ESL 1.1 NO-GO;3,943.2 iEr SLEEVE;9995.0 NIPPLE;4,059.7 IF LOCATOR;4,604.9 IFM SEAL ASSY;4,606.7 r INTERMEDIATE,37.81,771.6 • • Li 1 IE LINER-7"x5.5"x4.5";4,580.5 ■ L 5,425.01 • • Cement Detail Report 1D-145 ConocoPhillips String: Conductor Cement Job: DRILLING ORIGINAL, 7/17/2015 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 11/26/2014 12:00 11/28/2014 12:00 1D-145 Comment Stage 1,53 sx 15.7 ppg AS1 lead. Stage 2,295 sx 15.7 ppg AS1 lead. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Conductor Cement Prevent floatation 109.0 119.3 No No No Q Pump!nit(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) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment 53 sx 15.7 ppg AS1 Lead cement,est 1.16 ft3/sx Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Conductor Cement Cement conductor 62.0 109.0 No No No Q Pump Mit(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) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment 295 sx 15.7 ppg AS1 Lead cement,est 1.16 ft3/sx 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(Iblgal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 9/17/2015 • ! Conoco-PhillipsTime Log & Summary Wellview Web Reporting Report Well Name: 1D-145 Rig Name: DOYON 25 Job Type: DRILLING ORIGINAL Rig Accept: 7/18/2015 12:00:00 PM Rig Release: 8/20/2015 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/17/2015 24 hr Summary Release Doyon 25 from 1D-146 @ 12:00 hrs. Separate modules and back away from well. Lay mats around 1 D-145, begin stomping sub towards well. 12:00 14:00 2.00 0 0 MIRU MOVE RURD P Scope down derrick, pin top drive and prep to lower derrick. 14:00 16:30 2.50 0 0 MIRU MOVE RURD P Prep derrick, raise and pin C-section, dissconnect innerconnects. 16:30 17:30 1.00 0 0 MIRU MOVE RURD P PJSM, Prep and skid rig floor to move position. 17:30 18:30 1.00 0 0 MIRU MOVE RURD P Pin mast cylinders and lower derrick. 18:30 19:30 1.00 0 0 MIRU MOVE RURD P Prep cellar pinning lift cylinders, remove grating and cribbing. Unpin pipe shed. 19:30 22:30 3.00 0 0 MIRU MOVE MOB P Walk out pipe shed away from sub, walk power, pump and pit mods. Hook truck to power complex and stage forward. 22:30 00:00 1.50 0 0 MIRU MOVE MOB P Walk pipeshed away, move sub off 1D-146, moving towards 1D-145 via stompers. 07/18/2015 MIRU on 1D-145, R/U diverter components and ready for test,AOGCC waived witness. Complete acceptance •checklist, accept rig @ 12:00 hrs 7/18/15. Load casing shed with 5"HWDP, DP,4"DP drifted and tallied. SIMOP-C/O traction motor on top drive. Mud on location. 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Spot, center and shim sub over 1 D-145. Begin installing top DS sub/ pipeshed pin cylinder,walk pipeshed into sub with pits toward sub. 02:00 04:30 2.50 0 0 MIRU MOVE MOB P Spot pipe shed under sub, pin and shim in place. 04:30 05:30 1.00 0 0 MIRU MOVE RURD P PJSM-Prep Derrick and raise. 05:30 06:30 1.00 0 0 MIRU MOVE RURD P PJSM-Skid floor over well center. 06:30 10:00 3.50 0 0 MIRU MOVE MOB P Walk pits, pump, motors and casing shed into position. Lower C section, raise cattle chute. Lower cellar house and shim. Install cellar grating, hook up innerconnects. 10:00 10:30 0.50 0 0 MIRU MOVE RURD P Swap power from cold starts to 3516 power. Test E-Stops, start up Amphion system. 10:30 12:00 1.50 0 0 MIRU MOVE RURD P Unpin to bridle up,scope up derrick. SIMOPS-Complete rig move and rig accept checklist. Hang permits and well sign. Rig accepted @ 12:00 hrs 7/18/15 Page 1 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 0 0 MIRU MOVE RURD P R/D bridle lines and yokes from topdrive. Pull RKB's, attach safety slings at innerconnects. 13:30 14:30 1.00 0 0 MIRU MOVE RURD P Pull PS-21 slips, P/U 14'surface riser via beaverslide, lower same to cellar to N/U diverter. 14:30 16:30 2.00 0 0 MIRU MOVE RURD P Set surface annular on riser, service and inspect crown, perform derrick inspection. Remove un-needed mats around rig, SIMOPS-M/U pup jt to top drive and set in slips. un-pin and remove blocks from top drive. SIMOPS-Load pipe shed with 5" HWDP, 5"DP and 4"DP 16:30 18:00 1.50 0 0 MIRU MOVE RURD P Attach 7'section of 16"diverter line to end of diverter for 102'total length. Clean/secure 1 D-146 cellar. Continue N/U surface annular, diverter tee and riser. SIMOPS-Continue removing blocks from top drive, begin discoonnect electrical connections and top drive traction motor. Continue proccessing drill pipe in casing shed, strap and drift. 18:00 21:30 3.50 0 0 MIRU MOVE RURD P Continue to torque all flange connections on diverter tee, riser and bag. N/U flow box,flow line and jet all lines. SIMOPS-Load strap and tally 21 jts, 5" HWDP, 33 jts 5" DP, 159 jts 4"DP in casing shed. Remove topdrive traction motor. 21:30 00:00 2.50 0 0 MIRU MOVE RURD P Continue rigging up diverter, accumulator hoses to surface annular and diverter knife valve. SIMOPS-Pick and install new topdrive traction motor. 07/19/2015 Complete traction motor install, C/O saver sub and upper IBOP. Complete rigging up,take on Drilplex mud into pits. Pick up 7 stands 5"HWDP, 35 stands 5"DP,53 stands 4" DP. 00:00 03:30 3.50 0 0 MIRU MOVE RURD P Continue working on traction motor, clean and organize rig after rig move. Hook up Koomey lines to surface annular, continue to load and strap drill pipe in the casing shed. Complete derrick inspection,grease top drive and blocks. 03:30 05:00 1.50 0 0 MIRU MOVE RURD P Change out saver sub, remove upper /lower IBOP. Send out upper IBOP for re-build. 05:00 08:30 3.50 0 0 MIRU MOVE RURD P Install backer rod on Joes box, install pitcher nipple, air up flow line air boots. Remove kelly hose& re-adjust. Re-route man rider line. Install 4"slip inserts, elevators. Calibrate block height on Amphion and Totco. SIMOPS-Begin bringing on Drilplex mud into pits. Page 2 of 40 Time Logs ! • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 12:00 3.50 0 0 MIRU MOVE PULD P !P/U 4" DP and stand back 23 stands. SIMOPS-Pre-Spud meeting with day crew. 12:00 16:45 4.75 0 0 MIRU MOVE PULD P Continue making up stands 4"DP 1x1 (53 total)with 2 stands HWDP and jars. 16:45 19:00 2.25 0 0 MIRU MOVE RURD P PJSM, Install new upper IBOP, install lower IBOP and 41/2" IF saver sub. 19:00 19:30 0.50 0 0 MIRU MOVE SVRG P Service and inspect topdrive and blocks. 19:30 00:00 4.50 0 0 MIRU MOVE PULD P C/O elevators and P/U 7 stands 5" DP, 33 stands 5"DP. Start picking up 5"doubles from tubs. SIMOPS- P/U BHA via beaver slide, install 4' long 4" riser nipples on conductor outlets. Load, strap and tally 12 jts HWDP for BHA. C/O expansion boots in pits. SIMOPS-Pre-Spud meeting with night crew. 07/20/2015 P/U remaining 5" DP, surface monels,jars, BHA#1. Perform diverter function test,waived by AOGCC Bob Noble. Cleanout conductor and spud 16"surface hole, running gyro single shots. Drill from conductor 119' MD to 850' MD. 00:00 03:30 3.50 0 0 MIRU MOVE PULD P Continue P/U 4"total 54 doubles from pipe shed, make up into stands. 03:30 04:00 0.50 0 0 MIRU MOVE PULD P P/U 12 joints 5"HWDP for BHA and rack back. C/O slip inserts. P/U ,NMDC and rack back. 04:00 04:45 0.75 0 0 MIRU MOVE BOPE P Perform diverter function test and Accumulator drawdown. System pressure=3050 psi, Pressure after functioning=2100 psi, 200 psi attained=l3 sec, full system recovery=51 sec. 6 bottle N2 average=2000 psi. Knife valve fully opened=14 sec,Annular fully closed=40 sec.AOGCC Bob Noble waived witness of test. 04:45 09:00 4.25 0 88 MIRU MOVE BHAH P PJSM and P/U BHA as per SLB reps. RIH with BHA to 88', orient UBHO and carry scribe up. Continue P/U BHA. SIMOPS-Rig up surface Gyro and hoisting unit. 09:00 09:30 0.50 88 106 MIRU MOVE SEQP P Fill lines and pressure test surface lines to 3500 psi. Pumped 15 bbl water to fill lines and swap to Drilplex mud. Shallow hole test @ 425 gpm, 285 psi, 35%flow out,tag up on bottom @ 106' MD. 09:30 09:45 0.25 106 119 MIRU MOVE DRLG P Clean out conductor from 106' MD to 119'MD,450 gpm,409 psi,44%flow out,40 rpm. Page 3 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 11:30 1.75 119 280 SURFA( DRILL DDRL P Drill 16"Surface hole from 119' MD to 280' MD, 280'TVD.450 gpm, 409 psi,44%flow out, 40 rpm,TQ on/off=4k/2k, 22k WOB. P/U=60k, 5/0=58k, ROT=58k,ART=1.93, ADT=1.93.Total bit hrs=1.93, Total Jar hrs=1.93. 11:30 12:00 0.50 280 187 SURFA( DRILL BHAH P POOH from 280'MD to 95' MD, rack back 5"HWDP. P/U NMDC stands for BHA#2, RIH to 187' MD. 12:00 13:00 1.00 187 193 SURFA( DRILL BHAH P Continue M/U BHA#2 per DD/MWD from 187' MD. 13:00 14:15 1.25 193 281 SURFA( DRILL WASH T Unable to work past fill/obstruction @ 193'MD, Kelly up to jars and wash down to 226'MD @ 410 gpm, 450 psi,22%flow out, P/U=64k, S/O=66k. Obtain gyro check shot, continue wash down to 281'MD. Noted low Drilplex mud viscosity. 14:15 18:00 3.75 281 503 SURFA( DRILL DDRL P Directional drill 16"surface hole from 281'MD to 503'MD, 502'TVD, 500 gpm, 900 psi, 38%flow out,40 rpm, TQ on/off=4k/2k,WOB=26k, P/U=75k, S/0=80k, ROT=77k, Obtain gyro survey each stand. 18:00 00:00 6.00 503 850 SURFA( DRILL DDRL P Continue directional drill 16"surface hole from 503'MD to 850'MD, 848' TVD, 550 gpm, 1100 psi, 42%flow out,60 rpm, TQ on/off=5k/1.5k, WOB=28k, P/U=86k, S/0=87k, ROT=87k, Obtain gyro survey each stand.AST=4.63,ART=1.60, ADT=6.23. Total bit hrs=6.23, Total Jar hrs=6.23. Mud loss recorded for tour=25.4 bbl 37/21/2015 Drill from 850'to 2490'in 16"surface hole. 00:00 06:00 6.00 850 1,174 SURFA( DRILL DDRL P Drill 16"surface hole from 850' MD to 1174' MD, 1167'TVD, 650 gpm, 1408 psi,44%flow out, 70 rpm,Torque on/off=6-7K/1.5k,WOB=32K, PU= 98K, SO=93K, ROT=95K, Obtain gyro survey each stand. 06:00 12:00 6.00 1,174 1,566 SURFA( DRILL DDRL P Drill 16"surface hole from 1174' MD to 1566'MD, 1545'TVD, 600 gpm, 1340 psi,46%flow out, 70 rpm, Torque on/off=6-7K/1.5k,WOB= 32K, PU= 100K, S0=94K, ROT= 97K, Obtain gyro survey each stand to 1256'with MWD surveys clear of interference.AST=5.67,ART= 1.01, ADT=6.68. Total bit hrs= 14.84, Total Jar hrs=14.84. Crew change. Page 4 of 40 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 ' 6.00 1,566 2,016 SURFA( DRILL DDRL P Drill 16"surface hole from 1156' MD to 2016' MD, 1964'TVD, 600 gpm, 1480 psi,42%flow out, 70 rpm, Torque on/off=7K/1.5K,WOB=32K, PU= 119K, SO= 104K, ROT= 104K. 18:00 00:00 6.00 2,016 2,490 SURFA( DRILL DDRL P Drill 16"surface hole from 2016' MD to 2490' MD, 2413'TVD,600 gpm, 1450 psi,41%flow out, 70 rpm, Torque on/off=65K/4K,WOB=32K, PU= 131K, S0= 107K, ROT= 107K. AST=6.72,ART= 1.31,ADT=8.03. Total bit hrs=22.87, Total Jar hrs=22.87. Crew change. No losses for day. 37/22/2015 Continue drilling to TD at 2574', CBU 1.5X, BROOH at full drilling rate. LD BHA and RU and Run 13 3/8" casing per running order to 784'. 00:00 02:00 2.00 2,490 2,574 SURFA( DRILL DDRL P Drill 16"surface hole from 2490' MD to 2574'MD, 2413'TVD,600 gpm, 1450 psi, 44%flow out, 70 rpm, Torque on/off=5K/4K,WOB=32K, PU= 133K, SO= 117K, ROT= 119K. AST=0.96,ART=0.14,ADT= 1.1, TTL bit hours=23.97, TTL bit hours= 23.97. 02:00 03:00 1.00 2,574 2,484 SURFA( CASING CIRC P Circulate 1.5 BU at 750 GPM with 1750 psi, FO=45%, 70 RPM with 5K torque with recipe on stand. 03:00 07:30 4.50 2,484 1,347 SURFA( CASING BKRM P BROOH at 750 GPM with 1720 psi, F=45%, 5K torque. 07:30 08:00 0.50 1,347 1,347 SURFA( CASING CIRC P Reduce pulling speed and continue to BROOH at 700 GPM with 1496 psi, F0=44%, 80 RPM with 4K torque. 08:00 09:00 1.00 1,347 1,252 SURFA( CASING BKRM P BROOH with 700 GPM with 1450 psi, F0=44%, 80 RPM with 3-4K torque. Pumped 453 BBL while BROOH from 1347'to 1252'. 09:00 10:00 1.00 1,252 1,055 SURFA( CASING CIRC P Circulate to clean up hole with reduced pulling rate with cuttings unloading at shaker,slowly BROOH to avoid washout. Pumped 1314 BBL to clean up cuttings as hole unloaded at the shakers. 10:00 11:00 1.00 1,055 975 SURFA( CASING BKRM P BROOH from 1055'to 975'with 700 GPM with 1450 psi, FO=44%, 80 RPM with 3-4K torque. 11:00 12:00 1.00 975 690 SURFA( CASING BKRM P BROOH with 500 GPM with 750 psi, FO=39%, 80 RPM with 3K torque. Pumped 654 BBL while BROOH from 975'to 690'. Crew change. 12:00 13:00 1.00 690 503 SURFA( CASING BKRM P BROOH with 620 GPM with 1050 psi, F0=36%, 75 RPM with 2K torque. PU=74K. S0=78K. 13:00 13:15 0.25 503 503 SURFA( CASING OWFF P Observe well for flow at the HWDP; Static. Page 5 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:15 16:15 3.00 503 0 SURFA( CASING BHAH P POOH racking back HW, NMDC, and LD BHA#2 per SLB DD and MWD. Proper fill observed on the trip. 16:15 17:00 0.75 0 0 SURFA( CASING BHAH P Clean and clear floor of BHA components, bring casing equipment to the rig floor and stage to RU. 17:00 18:45 1.75 0 0 SURFA( CASING RURD P RU casing equipment, slide door elevators,Volant tool, pull PS-21 slip system, install Master bushing, and RU 250 ton casing slips. 18:45 19:00 0.25 0 0 SURFA( CASING SFTY P Hold PJSM for running casing with Tenaris rep, GBR saing, rig crew and rig team. 19:00 20:00 1.00 0 78 SURFA( CASING PUTB P MU 13 3/8"68#L-80 Hyd563 surface casing shoe track with bakerLok to pin of#4 joint. Install bow spring centralizers per detail. 20:00 00:00 4.00 78 784 SURFA( CASING PUTB P MU 13 3/8"68#L-80 Hyd563 surface casing, installing bow spring centralizers per detail; one per joint. Filling on-the-fly and topping off every 10 joints. Torque 27K,for first 8 joints,then 30K torque on#9 on per Tenaris thread specialist. 07/23/2015 Continue to run 13 3/8"68#L-80 casing per plan, land, C&C, Pump cement. No cement to surface, ND diverter and Prepare for cement top job. 00:00 05:30 5.50 784 1,816 SURFA( CASING PUTB P PU 13 3/8"68#L-80 Hyd563 surface casing, installing bow spring centralizers per detail; one per joint. Filling on-the-fly and topping off every 10 joints. Torque 30K torque per Tenaris rep. Run casing to 1820'and hit bridge. 05:30 06:00 0.50 1,816 1,855 SURFA( CASING WASH T Attempt to work through bridge without pumps. Stage pumps to 8 BPM with 280 psi,wash down through bridge. 06:00 06:30 0.50 1,855 1,855 SURFA( CASING CIRC P Circulate BU at the base of permafrost as planned with 8 BPM with 275 psi, 31% FO, 06:30 09:30 3.00 1,855 2,522 SURFA( CASING PUTB P PU 13 3/8"68#L-80 Hyd563 surface casing, installing bow spring centralizers per detail; one per joint. Filling on-the-fly and topping off every 10 joints. Torque 30K torque per Tenaris rep. 09:30 10:30 1.00 2,522 2,564 SURFA( CASING HOSO P PU 13 3/8"XO and MU hanger. PU and MU landing joint. 10:30 11:00 0.50 2,564 2,564 SURFA( CEMEN-CIRC P Circulate at 8 BPM with 275 psi, 31% FO. Landing hanger every third stroke. PU=200K, SO= 156K. 11:00 11:30 0.50 2,564 2,564 SURFA( CEMEN.RURD P Blow down top drive and RU cement lines/circ equipment. Page 6 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 2,564 2,564 SURFA( CEMEN-CIRC P Circulate at 8 BPM with 375 psi, 26%FO. Landing hanger every third stroke. Condition mud while reciprocating. Crew change. 12:00 13:30 1.50 2,564 2,564 SURFA( CEMEN-CIRC P Circulate at 8 BPM with 380 psi, 26%FO. Landing hanger every third stroke. Condition mud while reciprocating. PU=210K, S0= 160K. 13:30 13:45 0.25 2,564 2,564 SURFA( CEMEN-SFTY P PJSM for cementing with SLB, rig crew, and CPAI rep. 13:45 16:15 2.50 2,564 2,564 SURFA( CEMEN-CMNTP Swap pumping to SLB and pump cement per schedule. Pump 5 BBL water and PT surface lines to 4000 psi. Pump 75.3 BBLs of CW100 at 5.5 BPM with 170 psi, Pump 73.2 BBL MudPushll 10.5 ppg at 6.8 BPM with 240 psi,While batching,drop bottom plug at 14:33 hours. Pump 432.1 BBL of Lead cement11.0 ppg at 7 BPM with 290 psi; FCP=259 psi at 7 BPM. Batch and pump 68.9 BBL of 12.0 ppg Tail cement at 4.6 BPM with150 psi. PU=235K, S0= 146K. Drop top plug and kick out with 10 BBL of water. Reciprocate pipe throughout job with full returns. 16:15 17:15 1.00 2,564 2,564 SURFA( CEMEN CMNT P Swap to rig pumps and chase cement with mud. Bump plug on calculated strokes, held 500 psi over FCP and floats held with no cement returns to surface. From displacement calculated TOC at 120'. 17:15 19:30 2.25 2,564 0 SURFA( CEMEN RURD P RD and blow down all lines, disengage CRT and LD landing joint. RD, clean and LD casing handling equipment. Jet flow line with black product pill, drain and flush stack. Clean and flush all lines and valves. Clean pits. 19:30 00:00 4.50 0 0 SURFA( CEMEN;NUND P ND diverter line, ND flow line, flow nipple, flow box, ND surface bag, riser and diverter Tee. Pull and send down Master Bushings. Crew change at 22:00 hours X7/24/2015 Perform cement Top Job, Inspected by AOGCC rep Mat Herrera. NU BOPE and test BOPE. Witness waived by AOGCC Representative John Crisp. 00:00 01:00 1.00 0 0 SURFA( CEMEN NUND P Continue to ND diverter line, remove _starting head. 01:00 02:00 1.00 0 0 SURFA( CEMEN CMNT T Run 3/4"top job string into conductor to 130'. No more depth could be obtained. Page 7 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 05:15 3.25 0 0 SURFA( CEMEN-CMNT T Flushed conductor with 40 BBL water until 8.6 returns were weighed and good flow out on returns. Pumped 40 BBL Lead 11.1 ppg cement before returns were seen at surface. At 55 BBL 11.1 ppg cement was seen at the surface. 57.1 BBL pumped total to clear hopper of cements. Cement measured at 34" from top of conductor. 05:15 06:00 0.75 0 0 SURFA( CEMEN-CMNT T RD and blow down all lines and flush cementing equipment. 06:00 10:00 4.00 0 0 SURFA( WHDBO NUND P Install hold down flange, install sub seal per Vetco Grey rep, MU well head and test to 2000 psi for 10 minutes witness by CPAI rep, continue to NU high riser, BOPE, Joe's box,flow lines, Kill and chokes lines. Crew change. 10:00 12:00 2.00 0 0 SURFA( WHDBO NUND P Continue to NU, BOPE, Joe's box, flow lines, Kill and chokes lines. Torque all bolts and flange connections. ND diverter line. 12:00 16:00 4.00 0 0 SURFA( WHDBO NUND P Continue to install and torque all bolts, chink and secure Joe's box, install Strip-O-matic. SIMOPS; Weld top job slot on conductor. Load BHA components into casing shed. 16:00 16:30 0.50 0 0 SURFA(WHDBO RURD P PU 9.625"test joint, install test plug , RU test equipment, flush lines with water. �. .......... Page 8 of 40 Time Logs . • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 22:00 5.50 0 0 SURFA( WHDBO BOPE P Pressure test BOPE to 250/3,500psi for 5 minutes to chart recorder, testing annular, upper 9-5/8"casing rams, blind shear rams, lower 2-1/2"x5-1/2"VBRs, choke valves 1-15, manual&auto choke, choke& kill manuals, HCR valves,4"valve on kill line, 5"TIW, 5"dart valve, and Upper&lower IBOP. 5"and 9-5/8" test joints were used. Manual operated and super choke tested to 250/2,000psi for 5 minutes to chart recorder.Witness waived by AOGCC Representative John Crisp. Perform Koomey drawdown test. Accumulator PSI=3,050 psi, Manifold=1,500 psi, System pressure1,550 psi after all functions on bottles.200 psi attained=21 sec with 2 electric pumps, full system pressure attained=204 sec with 2 electric and 2 air pumps. 6 bottle N2 average=2,016 psi. Closing times for annular=22 sec, UPR= 16 sec, BSR= 16 sec, LPR= 16 sec, Choke HCR=2 sec, Kill HCR=2 sec. 22:00 23:00 1.00 0 0 SURFA( WHDBO RURD P RD test equipment, blow down choke and kill lines, pull test plug, drain stack and set 12 5/16"wear ring. 23:00 00:00 1.00 0 0 SURFA( CEMEN-BHAH P Mobilize BHA components to the rig floor and stage in the pipe shed for PU. 07/25/2015 PU BHA#3, RIH, slip and Cut drill line, perform good casing test. Drill out shoe track and perform FIT test to 14.4 ppg EMW. Drill ahead in the 12-1/4" intermediate. 00:00 00:15 0.25 0 0 SURFA( CEMEN-SFTYP PJSM with SLB DD and MWD, crew to discuss BHA PU and MU. 00:15 03:00 2.75 0 184 SURFA( CEMEN-BHAH P PU/MU BHA; MU bit, MWD, scribe motor to assembly. 03:00 03:30 0.50 184 420 SURFA( CEMEN-TRIP P Trip in hole with HWDP stands from 184 to 420'. 03:30 04:00 0.50 420 746 SURFA( CEMEN-PULD P Single in with jars and HWDP for BHA#3 from 420'to 614'. 04:00 05:00 1.00 746 2,386 SURFA( CEMEN TRIP P Trip in the hole with 5"DP from 614' to 2,350' MD. 05:00 05:45 0.75 2,386 2,386 SURFA( CEMEN DHEQ P Shallow pulse test MWD; Good with 500 GPM with 1179 psi,28% FO. 05:45 06:00 0.25 2,386 2,386 SURFA( CEMEN SFTY P PJSM for slip and cut. 06:00 08:00 2.00 2,386 2,386 SURFA( CEMEN SLPC P Slip and Cut drill line, cut 11 wraps for 86', Calibrate TOTCO,Amphion system, SLB MWD block height and hookload sendors. 08:00 08:30 0.50 2,386 2,386 SURFA( CEMEN-SVRG P Service rig and topdrive and PS-21 slip system. 08:30 08:45 0.25 2,386 2,386 SURFA( CEMEN SFTY P PJSM for casing test. 08:45 09:00 0.25 2,386 2,386 SURFA( CEMEN-RURD P RU test equipment for PT of casing. Page 9 of 40 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:45 1.75 2,386 2,386 SURFA( CEMEN-PRTS P Test casing to 3000 psi to chart for 30 minutes; Good. 10:45 11:00 0.25 2,386 2,386 SURFA( CEMEN-RURD P RD from testing, blow down Kill, cement and test lines. 11:00 12:00 1.00 2,386 2,475 SURFA( CEMEN WASH P Wash down and tag TOC at 2475' with 20K. PU= 133K, S0= 104K. Wash with 500 GPM with 330 psi, 27%FO. Crew change. 12:00 14:15 2.25 2,475 2,574 SURFA( CEMEN-DRLG P Drill out shoe track 2475', float at 2480', cement from 2481 to 2561' , and shoe 2561'to 2563'. Drill at 400 GPM with 850 psi,23% FO,40 RPM with 8K torque and 7K WOB. 14:15 14:30 0.25 2,574 2,594 SURFA( DRILL DDRL P Drill 12 1/4"Intermediate hole from 2574'to 2594', and stop for FIT. 14:30 15:15 0.75 2,594 2,594 SURFA( DRILL CIRC P Circulate BU to condition mud for FIT at 450 GPM with 880 psi,26% FO,40 RPM with 6K torque for 379 BBLs. 15:15 16:15 1.00 2,594 2,594 SURFA( DRILL FIT P RU test equipment, blow down top drive,and Perform FIT to 14.4 ppg EMW with 600 psi with 9.8 ppg mud. Pumped 1.8 BBL and 0.6 BBL bled back. RD test equipment and blow down lines. 16:15 18:00 1.75 2,594 2,594 INTRM1 DRILL DISP P Displace; pump 45 BBL spacer, displace well with 9.4 ppg LSND with rotation and reciprocation. Pump 578 GPM with 950 psi, 32% FO,40 RPM with 6K torque. When new mud got to surface cleaned pits and took off the remaining surface mud. PU= 146K, SO= 112K. 18:00 00:00 6.00 2,594 3,098 INTRM1 DRILL DDRL P Drill ahead per plan at 550 GPM with 1020 psi, 30% FO, 70 RPM with 9K torque, 25K WOB. ECD= 10.0. PU= 156K, SO= 117K, Rot= 131K. AST=2.72,ART=0.80,ADT=3.52, TTL bit hours=3.52, Jar hours= 27.49. Crew change. SPR @ 2594' MD 2507'TVD. MW= 9.4 ppg Time= 1735 #1 MP-20/30 SPM with 130/150 psi #2 MP-20/30 SPM with 130/150 psi 07/26/2015 Drill ahead in 12 1/4"hole section from 3098'to 4424'. 00:00 04:00 4.00 3,098 3,394 INTRM1 DRILL DDRL P Drill 12 1/4" hole section from 3098' to 3394'at 750 GPM with 1510 psi, 36%FO, 70 RPM with 9K torque, 30K WOB. ECD=9.9. PU= 158K, S0= 120K, Rot= 135K. Page 10 of 40 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:30 0.50 3,394 3,394 INTRM1 DRILL CIRC P Rotate and Recip while circulating out 55 BBL High Vis sweep. PU= 173K, SO= 117K, Rot= 131K. With good return increase with the sweep pumping continued for another 55 BBL. 04:30 10:00 5.50 3,394 3,488 INTRMI DRILL DDRL P Drill 12 1/4"hole section from 3394' to 3488'at 750 GPM with 1510 psi, 36%FO, 70 RPM with 9K torque, 30K WOB. ECD=9.80. PU= 154K, S0= 124K, Rot= 139K. 10:00 10:30 0.50 3,488 3,488 INTRM1 DRILL CIRC P Rotate and Recip while circulating out 55 BBL High Vis sweep. PU= 154K, SO= 121K, Rot= 139K. Pump at 750 GPM with 1520 psi, 37% FO, 70 RPM with 7K Torque. Pump 54 BBL High Vis sweep. 10:30 12:00 1.50 3,488 3,598 INTRMI DRILL DDRL P Drill 12 1/4" hole section from 3488' to 3598'at 750 GPM with 1530 psi, 36%FO, 70 RPM with 7K torque, 30K WOB. ECD=9.78. PU= 154K, S0= 121K, Rot= 139K. AST= 3.92, ART= 1.06,ADT=4.98, TTL bit hours=8.50, Jar hours=73.50. Crew change. SPR @ 4332'MD 3766'TVD. MW= 9.9 ppg Time=2248 #1 MP-20/30 SPM with 200/230 psi #2 MP-20/30 SPM with 220/250 psi 12:00 18:00 6.00 3,598 4,056 INTRM1 DRILL DDRL P Drill 12 1/4" hole section from 3598' to 4056'at 750 GPM with 1700 psi, 37%FO, 70 RPM with 10K torque, 10-25K WOB. ECD= 10.21. PU= 161K, SO= 122K, Rot= 131K. Pump 56 BBL High Vis sweep with no increase in returns. Weight up to 9.9 ppg on-the-fly. SPR @ 4050' MD 3635'TVD. MW= 9.4 ppg Time= 1831 #1 MP-20/30 SPM with 210/230 psi #2 MP-20/30 SPM with 190/210 psi 18:00 00:00 6.00 4,056 4,424 INTRM1 DRILL DDRL P Drill 12 1/4" hole section from 4056' to 4424'at 750 GPM with 2120 psi, 36%FO, 70 RPM with 7K torque, 30K WOB. ECD= 10.65. PU= 155K, SO= 123K, Rot= 133K. AST= 3.92,ART= 1.06,ADT=5.18, TTL bit hours= 14.15, Jar hours=79.15. Crew change. SPR @ 4332' MD 3766'TVD. MW= 9.9 ppg Time=2248 #1 MP-20/30 SPM with 200/230 psi #2 MP-20/30 SPM with 220/250 psi Page.i I of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/27/2015 24 hr Summary Drill ahead in 12 1/4"hole section 4424'to 4782'. TD called at 4782'. CBU, back-ream to shoe, circulate casing clean and POOH on elevators. LD BHA#3. 00:00 04:00 4.00 4,424 4,700 INTRM1 DRILL DDRL P Drill 12 1/4" hole section from 4424' to 4700'at 750 GPM with 2200 psi, 38%FO, 70 RPM with 9K torque, 30K WOB. ECD=9.80. PU= 154K, SO= 124K, Rot= 139K. 04:00 04:45 0.75 4,700 4,700 INTRMI DRILL CIRC P Rotate and Recip while circulating out 55 BBL High Vis sweep. PU= 173K, SO= 117K, Rot= 131K. SIMOPs; Put DP in shed to drill further. 04:45 05:00 0.25 4,700 4,700 INTRM1 DRILL OTHR P Geologist and SLB DD confer on Geo-steering into zone. 05:00 06:15 1.25 4,700 4,782 INTRM1 DRILL DDRL P Drill 12 1/4" hole section from 4700' to 4782' at 750 GPM with 2190 psi, 38%FO, 70 RPM with 8K torque, 5-10K WOB. ECD= 10.68. PU= 160K, SO= 124K, Rot= 140K. AST= 1.49,ART= 1.55,ADT=3.04,TTL bit hours= 16.72, Jar hours=81.72. 06:15 08:00 1.75 4,782 4,782 INTRM1 CASING CIRC P Rotate and Recip at 750 GPM with 2190 psi, 38%FO, 70 RPM with 8K torque, PU= 160K, SO= 125K, Rot= 140K. Pumped 1240 BBL, Monitor well; static. PJSM for BROOH. SPR @ 4871' MD 3755'TVD. MW= 9.9 ppg Time=0630 #1 MP-20/30 SPM with 240/260 psi #2 MP-20/30 SPM with 220/260 psi 08:00 12:00 4.00 4,782 3,397 INTRM1 CASING BKRM P BROOH from 4782'to 3397'at 750 GPM with 2005 psi, 70 RPM with 7K torque. PU= 155K, SO= 121K, Rot= 130K. 12:00 16:00 4.00 3,397 2,542 INTRM1 CASING BKRM P BROOH from 3397'to 2542'at 750 GPM with 2005 psi, 70 RPM with 7K torque. PU= 155K, SO= 121K, Rot= 130K. 16:00 18:45 2.75 2,542 2,542 INTRM1 CASING CIRC P Rotate and Recip at 750 GPM with 2190 psi, 38% FO, 70 RPM with 5K torque, PU= 160K, SO= 125K, Rot= 140K. Pumped 1240 BBL. 18:45 19:00 0.25 2,542 2,542 INTRMI CASING OWFF P Observe well for flow; Static. 19:00 22:00 3.00 2,542 185 INTRM1 CASING TRIP P POOH on elevators from 2542'to 2162', continue from 2162' to POOH racking back HW, LD jars and replace with HW,stand back. 22:00 00:00 2.00 185 32 INTRM1 CASING:BHAH P LD BHA#3, LD collars, MWD and stabs. Crew change. Losses for trip 21.2 BBL during trip out of hole. 07/28/2015 LD BHA#3, RU for casing run. Run 9 5/8"40#L-80 Hyd563 casing. Pump cement. Page 12 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 32 0 INTRM1'CASING BHAH P Continue to LD BHA; drain motor, clean and clear floor of BHA components and handling equipment. 00:30 04:00 3.50 0 0 INTRM1 CASING RURD P Clean and clear floor, Flush stack, service bales and drain stack. Pull wear bushing, pull and clean Strip-o-matic. Wash out BOP stack. , RU Volant tools and casing handling equipment. 04:00 08:30 4.50 0 1,874 INTRM1 CASING PUTB P MU shoe track and run 9 5/8"40# L-80 Hyd563 casing per running order to 1874'. Filling on-the-fly and topping off every 10th joint with Fill-up hose. Make up joints with power tongs and running on elevators with 15,000 ft-lb torque MU. 08:30 09:00 0.50 1,874 1,874 INTRMI CASING CIRC P Establish circulation at 2 BPM with 145 psi, 12%FO. Stage pumps to 5 BPM with 185 psi, 17% FO. Rotate at 10 RPM with 3K torque to improve return FO to 20%. 09:00 11:00 2.00 1,874 2,542 INTRMI CASING PUTB P Run 9 5/8"casing from 1874'to 2542' placing Volant hydroforms every joint #1-50. 11:00 12:00 1.00 2,542 2,542 INTRM1 CASING CIRC P Circulate BU at shoe with 5 BPM with 185 psi, 20% FO. Rotate at 10 RPM with 3K torque. Pump 228 BBL, PU= 137K, SO= 118K. 12:00 12:30 0.50 2,542 2,995 INTRMI CASING PUTB P Run 9 5/8"casing from 2542'to 2995',filling on the fly and topping off every 10th joint. PU= 151K, SO= 121K. Crew change. 12:30 13:00 0.50 2,995 2,995 INTRM1 CASING CIRC P Circulate with 5 BPM with 200 psi, 20% FO. 13:00 16:00 3.00 2,995 4,724 INTRMI CASING PUTB P RIH with 9 5/8"casing from 2995'to 4724'. 16:00 16:30 0.50 4,724 4,772 INTRM1 CASING HOSO P PU and MU hanger and landing joint, RIH and land at 4772'at 16:30. 16:30 18:30 2.00 4,772 4,772 INTRM1 CEMEN-CIRCP Circulate and condition mud with Volant, staging pumps from 1 BPM to 5 BPM with 310 psi, 20%FO. PU=205K, S0= 118K. 18:30 20:00 1.50 4,772 4,772 INTRM1 CEMEN-CIRCP Land on hanger and RU cement lines, blow down top drive and 20:00 20:15 0.25 4,772 4,772 INTRM1 CEMEN-SFTY P Hold PJSM with crew, SLB cementers and CPAI rep. Page 13 of 40 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 22:45 2.50 4,772 4,772 INTRM1 CEMEN-CMNT P Pump cement per program with SLB pumps; Pump 5.5 BBL of Mudpush and test lines to 4000 psi. Open and pump 44.6 BBL of 10.5 ppg MPII at 6.6 BPM with 350 psi, 19%FO to total 50.1 BBL of MPII pumped. Drop bottom plug,etch and pump 45.8 BBL of 15.8 ppg Lead cement at 5.5 BPm with 85 psi, 19% FO. Batch and pump 105.9 BBL of 15.8 ppg Tail cement with GasBlok at 6.5 BPM with195 psi,23% FO. Drop top plug and kick out with 10 BBL of MP. SLB chases with 9.9 ppg OBM at 5.9 BPM with FCP of 900 psi, 18% FO. Slow pump rate to 3 BPM at 335 BBL of OBM away. Pump total of 348.9 BBL of OBM chase without bumping plug. Check floats; Good. CIP at 2225 hours. 22:45 00:00 1.25 4,772 4,772 INTRM1 CEMEN-RURD P RD and Blow down all lines, dis-engage CRT and RD Volant, drain stack with Landing joint in place. Clean trip tank and blow down cellar pump to keep OBM separted from LSND. Crew change. 07/29/2015 RD from cementing, Install 9 5/8"Pack-off, Test BOPE and MU BHA#4 for Clean-out of shoe track and FIT test. 00:00 01:00 1.00 4,772 0 INTRM1 CEMEN-RURD P Continue to clean BOP stack, break out and LD landing joint, RD csaing elevators and install 5"DP elevators. 01:00 02:30 1.50 0 0 INTRM1 CEMEN-PRTS P RU and test 9 5/8"pack-off to 5000 psi for 10 minutes,witnessed by CPAI rep Paul Smith. 02:30 04:45 2.25 0 0 INTRM1 CEMEN-FRZP P Perform freeze protect; flush with 169 BBL of water and 123 BBL of diesel for freeze protect. 04:45 09:00 4.25 0 0 INTRM1 WHDBO BOPE P Witness waived by AOGCC Representative Matt Herrera. Pressure test BOPE to 250/3500psi for 5 minutes to chart recorder, testing annular, upper 9-5/8"casing rams, blind shear rams, lower 2-1/2"x5-1/2"VBRs, choke valves 1-15, manual&auto choke, choke& kill manuals, HCR valves, 4"valve on kill line, 5"TIW, 5"dart valve, and Upper&lower IBOP. 5"and 9-5/8" test joints were used. Manual operated and super choke tested to 250/2,000 psi for 5 minutes to chart recorder. 09:00 12:00 3.00 0 0 INTRM1 WHDBO BOPE P With 4"test joint test LPRs, 5"TIW, 5"dart valve 250/3500 psi. Crew change. Page 14 of 40 Time Logs • Date From To Dur S. Depth E. Death Phase Code Subcode T 'Comment 12:00 13:00 1.00 0 0 INTRM1 WHDBO BOPE P Continue to test BOPE. 13:00 16:00 3.00 0 0 INTRM1 WHDBO BOPE T Pull to unseat test plug and it became lodged Crooked in the stack, and could not be pulled with test joint. Rigged up lifting eye and engaged test plug,was able to pull successfullly. 16:00 22:00 6.00 0 0 INTRM1 WHDBO BOPE P Perform Koomey drawdown test. Accumulator PSI=3,050 psi, Manifold=1,500 psi, System pressure1,650 psi after all functions on bottles. 200 psi attained=25 sec with 2 electric pumps, full system pressure attained =204 sec with 2 electric and 2 air pumps. 6 bottle N2 average=2,016 psi. Closing times for annular=22 sec, UPR= 16 sec, BSR= 16 sec, LPR= 16 sec, Choke HCR=2 sec, Kill HCR=2 sec. 22:00 23:00 1.00 0 0 INTRM1 WHDBO RURD P Pull test plug and LD test joint, blow down choke lines and kill lines Set wear bushing and RILDS 23:00 00:00 1.00 0 224 INTRM1 CEMEN-BHAH P PU and MU BHA#4 for Clean-out run. NU bit and bit sub with ported float t 1st HWDP. RIH with HW to 224. 37/30/2015 RIH with 8 3/4"clean-out assembly and perform casing test to 3500 psi; Good. Drill out shoe track and 20'of new hole. Perform FIT to 13.0 ppg EMW. POOH 00:00 04:30 4.50 224 4,582 INTRM1 CEMEN-TRIPP RIH with 8 3/4"BHA#4 from 224 to 4582'. Filled pipe at 2689'. PU= 146K, S0= 112K 04:30 05:00 0.50 4,582 4,582 INTRM1 CEMEN RURD P RU for 9 5/8"casing test. 05:00 06:45 1.75 4,582 4,582 INTRM1 CEMEN PRTS P Perform casing pressure test on chart to 3500 psi; Good. Pumped 52 strokes and bled back 5.2 BBL. 06:45 07:00 0.25 4,582 4,582 INTRM1 CEMEN RURD P RD and blow down from casing test. SPR @ 4482'MD 3739'TVD. MW= 9.9 ppg Time=0700 #1 MP-20/30 SPM with 220/300 psi #2 MP-20/30 SPM with 220/300 psi 07:00 07:30 0.50 4,582 4,649 INTRM1 CEMEN-WASH P Wash down and tag 4739'realize a depth discrepency, pull up and circulate with 2 BPM with 230 psi, 14%FO. PU= 147K, S0= 1133K. 07:30 10:00 2.50 4,649 4,649 INTRM1 CEMEN-CIRCT Research tallies and location, and inventory all DP and HW. Discover DP tally error and BHA error. Correct DP tally and continue. Reset depth and proceed to RIH. Page 15 of 40 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 4,649 4,718 INTRM1 CEMEN-DRLG P Wash down at 2 BPM with 210 psi and tag with 20K down at 4679'. Increase flow to 400 GPM with 1255 psi, 27% FO, 0 RPM with 7K torque, 4-10K WOB. Drill float collar at 4687' with 8-10 WOB, Drilling cement from 4688'to 4718', 450 GPM with 1592 psi, 30% FO, 11K WOB with 80 RPM with 7K torque. Crew change. OAP=250 psi. No losses this tour. 12:00 14:30 2.50 4,718 4,782 INTRM1 CEMEN-DRLG P Continue to drill cementin shoe track at 460 GPM with 1572 psi, 28% FO, 80 RPM with 7K torque, 11K WOB. Tag shoe at 4771'and drill to 4782' cleaning out rat hole. 14:30 14:45 0.25 4,782 4,804 INTRM1 CEMEN-DDRL P Drill 20 foot of new hole at 475 GPM with 1680 psi, 28% FO, 80 RPM with 7.5K torque and 5K WOB. ADT= 0.23, Jars=0.23 hours. 14:45 16:15 1.50 4,804 4,740 INTRM1 CEMEN-CIRC P Circulate and condition mud at 475 GPM with 1680 psi, 29% FO, 80 RPM with 7K torque. Pumped 856 BBLs to achieve 9.9 ppg mud in and out. Obtain SPR and monitor well for 10 minutes; Static. SPR @ 4764' MD 3752'TVD. MW= 9.9 ppg Time= 1605 #1 MP-20/30 SPM with 220/280 psi #2 MP-20/30 SPM with 210/270 psi 16:15 17:30 1.25 4,740 4,740 INTRM1 CEMEN-FIT P Perform FIT to 13.0 ppg EMW. Blow down top drive purge lines and perform FIT pumping 1.3 BBL for 605 psi with 1.3 BBL bled back. RD and blow down test equipment. 17:30 19:45 2.25 4,740 1,240 PROD1 DRILL TRIP P Trip out of the hole with 4" DP from 4740 to 1240', monitor for 10 minutes; Static. Strap out of the hole. 19:45 20:30 0.75 1,240 1,240 PROD1 DRILL TRIP T Trouble time broken out for extra time to strap out of the hole. 20:30 22:15 1.75 1,240 0 PROD1 DRILL TRIP P Continue to trip from 1240'to surface with HWDP. Strap out of the hole. 22:15 23:00 0.75 0 0 PROD1 DRILL BHAH P LD BHA break bit and bit sub and LD. Clean and clear floor. 23:00 00:00 1.00 0 0 PROD1 DRILL RURD P Install Strip-o-matic, change out saver sub. 37/31/2015 MU and RIH with 6 3/4"drilling assembly. Displace to FazePro OBM and drill ahead to 5315'. 00:00 01:30 1.50 0 0 PROD1 DRILL RURD P Continue to change out saver sub to complete assembly of the XT-39 sub. 01:30 02:00 0.50 0 47 PROD1 DRILL BHAH P MU BHA; Bit and Xceed Rotary steerable. Change out PS-21 slip inserts to 4" DP. 02:00 04:30 2.50 47 409 PROD1 DRILL BHAH P MU BHA to 409'with MWD and HW. Page 16 of 40 Time Logs • , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 07:00 2.50 409 1,762 PROD1 DRILL PULD P PU 27 joints of 4" DP singles. and 54 Doubles from the pipe shed bins. 07:00 07:15 0.25 1,762 1,762 PROD1 DRILL DHEQ P Shallow pulse test MWD tools; Good. 07:15 09:00 1.75 1,762 4,680 PROD1 DRILL TRIP P Trip in the hole from 1762'to 4680'. PU=99K, SO=84K, Proper fill observed via pit#3. 09:00 10:15 1.25 4,680 4,805 PROD1 DRILL WASH P Wash down from 4680'to 4805', 225 GPM with 1940 psi. PU=99K, SO= 85K. 10:15 10:30 0.25 4,805 4,805 PROD1 DRILL SFTY P PJSM for displacement to clean OBM. 10:30 12:00 1.50 4,805 4,805 PROD1 DRILL DISP P Pump 62 BBL spacer High Vis, chase with 379 BBLs Faze Pro 9.9 ppg OBM. Rotate and reciprocate at 220 GPM with 1827 psi, 19% FO, 60 RPM with 3K off bottom torque. PU= 99K, SO=84K, Rot=91K, Pumped 377 BBL. OAP=350 psi SPR @ 4771' MD 3754'TVD. MW= 9.9 ppg Time= 1015 #1 MP-20/30 SPM with 520/820 psi #2 MP-20/30 SPM with 460/720 psi 12:00 12:12 0.20 4,805 4,805 PROD1 DRILL OWFF P Observe well for flow; Static 12:12 13:45 1.55 4,805 4,805 PROD1 DRILL COND P Obtain SPR's, clean shaker and trough and pit#3 13:45 18:00 4.25 4,805 4,962 PROD1 DRILL DDRL P Drill 6 3/4"hole from 4805'to 4962'at 225 GPM with 2080 psi, 18% FO, 140 RPM with 3K torque and 2K WOB. ECD= 10.25. PU= 102K, S0=84K. ADT=3.41, Jars=3.41 hours. 18:00 00:00 6.00 4,962 5,315 PROD1 DRILL DDRL P Drill 6 3/4"hole from 4962'to 5315'at 255 GPM with 2170 psi, 28% FO, 140 RPM with 4K torque and 2K WOB. ECD= 10.49. ADT=3.70 Jars=3.70 hours. OAP=550 psi. 20 BBL loss this tour, 20 for the day. SPR @ 4771' MD 3754'TVD. MW= 9.9 ppg Time= 1215 #1 MP-20/30 SPM with 325/550 psi #2 MP-20/30 SPM with 300/550 psi 08/01/2015 Drilling ahead in production 6 3/4"section from 5315'to 7030'with dilutions per mud engineers to control solids content. 00:00 01:00 1.00 5,315 5,315 PROD1 DRILL DLOG P Performa Stethoscope drawdown reading at 5204 on the 1st sample and 5207 on the 2nd sample; successful with a 9.89 ppg EMW reading. Page 17 of 40 •Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 06:00 5.00 5,315 5,816 PROD1 DRILL DDRL P Drill 6 3/4"hole from 5315'to 5816'at 255 GPM with 2185 psi, 18% FO, 140 RPM with 4K torque and 3K WOB. ECD= 10.5. PU= 107K, SO= 80K, Rot=91K. SPR @ 5436' MD 3761'TVD. MW= 9.85 ppg Time=0217 #1 MP-20/30 SPM with 380/600 psi #2 MP-20/30 SPM with 380/620 psi 06:00 12:00 6.00 5,816 6,196 PROD1 DRILL DDRL P Drill 6 3/4"hole from 5816'to 6196'at 255 GPM with 2227 psi, 17% FO, 140 RPM with 4K torque and 3K WOB. ECD= 10.47. PU= 107K, SO=77K, Rot=93K. ADT=6.62, TTL bit hours= 13.73, Jars= 13.73 hours. Drill concretions at;6033', 6190', 6196'per drilling procedure. OAP=400 psi. 0 BBL loss this tour. SPR @ 5998' MD 3761'TVD. MW= 9.85 ppg Time=0745 #1 MP-20/30 SPM with 400/760 psi #2 MP-20/30 SPM with 380/620 psi 12:00 18:00 6.00 6,196 6,575 PROD1 DRILL DDRL P Drill 6 3/4"hole from 6196'to 6575'at 265 GPM with 2490 psi, 17% FO, 140 RPM with 5K torque and 6K WOB. ECD= 10.74. PU= 115K, SO= 71K, Rot=90K. ADT=4.33,TTL bit hours= 18.06, Jars= 18.06 hours. 18:00 23:00 5.00 6,575 6,954 PROD1 DRILL DDRL P Drill 6 3/4"hole from 6575'to 6954'at 265 GPM with 2730 psi, 18%FO, 140 RPM with 4K torque and 2K WOB. ECD= 10.92. PU= 115K, SO= 71K, Rot=90K. 23:00 23:18 0.30 6,954 6,954 PROD1 DRILL DDRL T Trouble-shoot Power drive; cycle pumps to reset. Successful reset on second cycle when down on pumps for>5 minutes. 23:18 00:00 0.70 6,954 7,030 PROD1 DRILL DDRL P Drill 6 3/4"hole from 6954'to 7030'at 265 GPM with 2660 psi, 18%FO, 140 RPM with 4K torque and 4K WOB. ECD= 10.97. PU= 113K, S0=73K, Rot=93K. ADT=2.76, TTL bit hours=20.82, Jars=20.82 hours. OAP=500 psi. 0 BBL loss this tour, 0 for the day. SPR @ 6386' MD 3766'TVD. MW= 9.9 ppg Time= 1520 #1 MP-20/30 SPM with 380/640 psi #2 MP-20/30 SPM with 400/640 psi Page 18 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 38/02/2015 24 hr Summary Drilling ahead in production 6 3/4"section from 7030'to 9041', drilling concretions and diluting per mud engineers to control solids content. 00:00 06:00 6.00 7,030 7,429 PROD1 DRILL DDRL P Drill 6 3/4"hole from 7030'to 7429'at 265 GPM with 2650 psi, 18%FO, 140 RPM with 4K torque and 3K WOB. ECD= 10.77. PU= 116K, S0=75K, Rot=90K. Drilling concretions at 7330', 7340', 7366', and 7424'per concretion procedure. 06:00 12:00 6.00 7,429 7,713 PROD1 DRILL DDRL P Drill 6 3/4"hole from 7429'to 7713'at 270 GPM with 2807 psi, 19% FO, 150 RPM with 4K torque and 3-12K WOB. ECD= 10.74. PU= 113K, SO= 71K, Rot=95K.ADT=8.12, TTL bit hours=28.94, Jar hours=28.94. Drilling concretions at 7428', 7455', and 7474'per concretion procedure. Crew change. OAP=400 psi. 0 BBL loss this tour. SPR @ 7517' MD 3794'TVD. MW= 9.9 ppg Time=0930 #1 MP-20/30 SPM with 420/660 psi #2 MP-20/30 SPM with 440/760 psi 12:00 18:00 6.00 7,713 8,525 PROD1 DRILL DDRL P Drill 6 3/4"hole from 7713'to 8525'at 270 GPM with 2940 psi, 18% FO, 150 RPM with 5K torque and 4K WOB. ECD= 11.25. PU= 117K, SO= 72K, Rot=94K.ADT=4.40, TTL bit hours=33.34, Jar hours=33.34. SPR @ 8188' MD 3787'TVD. MW= 9.85 ppg Time= 1555 #1 MP-20/30 SPM with 500/740 psi #2 MP-20/30 SPM with 470/740 psi 18:00 00:00 6.00 8,525 9,041 PROD1 DRILL DDRL P Drill 6 3/4"hole from 8525'to 9041'at 270 GPM with 2990 psi, 18% FO, 150 RPM with 5K torque and 1K WOB. ECD= 11.12. PU= 119K, SO= 72K, Rot=90K.ADT=4.14, TTL bit hours=37.48, Jar hours=37.48. Crew change. OAP=500 psi. 0 BBL loss this tour. SPR @ 8757' MD 3793'TVD. MW= 9.8 ppg Time=2015 #1 MP-20/30 SPM with 510/800 psi #2 MP-20/30 SPM with 520/780 psi 08/03/2015 Drill ahead to TD at 9463, 05:15. Circulate BU 7X. BROOH to 5435'. Page 19 of 40 Time Logs i • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:15 5.25 9,041 9,463 PROD1 DRILL DDRL P Drill 6 3/4"hole from 7713'to 9463'at 270 GPM with 2940 psi, 18% FO, 150 RPM with 5K torque and 4K WOB. ECD= 11.15. PU= 121K, S0= 72K, Rot=96K. ADT=3.65, TTL bit hours=41.13.Jar hours=41.13. 05:15 12:00 6.75 9,463 9,000 PROD1 CASING CIRC P Rotate and reciprocate from 9463'to 9000'at 270 GPM with 3030 psi, 19%FO, 150 RPM with 5K torque. PU= 117K, SO=72K, Rot=94K. Pumped 2246 BBL. Crew change. OAP=400 psi. No losses for tour. SPR @ 9463' MD 3796'TVD. MW= 9.85 ppg Time=0530 #1 MP-20/30 SPM with 460/740 psi #2 MP-20/30 SPM with 500/840 psi 12:00 15:15 3.25 9,000 8,760 PROD1 CASING CIRC P Rotate and reciprocate from 9000'to 8760'at 270 GPM with 2780 psi, 17%FO, 150 RPM with 5K torque. PU= 117K, SO=72K, Rot=94K. ECD= 10.91. Pumped 3384 BBL. Perform 580 BBL dump and dilute. 15:15 00:00 8.75 8,760 5,390 PROD1 CASING BKRM P BROOH from 8760'to 5390'at 270 GPM with 2415 psi, 18% FO, 150 RPM with 4K Torque, ECD= 10.44. Pulling at 840 FPH, PU= 106K, S0= 74K. Crew change. OAP=250 psi. No lossess for the day. 38/04/2015 Continue to BROOH to shoe at 4772. Circulate 1/2 BU and open Well Commander circ sub and continue to circulate well clean. POOH and L/D BHA, R/U and lay down excess drill pipe and prep for scraper run. 00:00 02:00 2.00 5,390 4,771 PROD1 CASING BKRM P BROOH from 5390'to 4771'at 270 GPM with 2338 psi, 18% FO, 150 RPM with 4K torque, ECD= 10.36. 840 FPH pulling speed. PU= 103K, SO=78K. OA @ 00:30 hrs=350 psi 02:00 02:15 0.25 4,771 4,771 PROD1 CASING OWFF P Observe well for flow for 15 minutes; Static. 02:15 02:30 0.25 4,771 4,771 PROD1 CASING CIRC P Drop WC 1.75"activation ball and pump down at 2 BPM with 403 psi. Ball on seat at 172 strokes. Increasae pressure to 1000 psi and hold. Increase pressure to 1300 psi and hold. Increase pressure to 1500 psi and well commander opened. Checked with 2 BPM at 155 psi. 02:30 07:45 5.25 4,771 4,771 PROD1 CASING CIRC P Rotate and reciprocate from 4771'to 4680' , 380 gpm, 1253 psi,23%flow out. Increase pump rate to 460 gpm, 1654 psi 26% flow out. Decrease rate to 270 gpm,645 psi, 18%flow out, 100 rpm, 2k Torgue, P/U=99k, S/O=86k, ROT=90k Page 20 of 40 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 11:45 4.00 4,771 4,771 PROD1 CASING CIRC T Continue to circulate while waiting on orders. Rotate and reciprocate from 4771'to 4680' , 380 gpm, 1253 psi, 23%flow out. Increase pump rate to 460 gpm, 1654 psi 26% flow out. Decrease rate to 270 gpm, 645 psi, 18%flow out, 100 rpm, 2k Torgue, P/U=99k, 5/0=86k, ROT=90k, Total strokes pumped 55,900, 5630 bbl. 11:45 12:00 0.25 4,771 4,771 PROD1 CASING CIRC P Drop 1.75"OD Well commander activation ball, chase at 84 gpm 130 psi. Pressure up to 1000 psi for 30 sec, 1300 psi 30 sec, 1697 psi well commander closed, bleed pressure to O. Total 2-1.75"OD activation balls in catcher. OA pressure @ 12:00=200 psi 12:00 13:15 1.25 4,771 4,680 PROD1 CASING CIRC P Circulate while R&R from 4771'MD to 4680' MD©270 gpm, 2250 psi, 17%flow out, 150 rpm, 2.5k Tq, 10.35 ECD, 2560 strokes pumped. P/U-97k, 5/0=87k. 13:15 15:30 2.25 4,680 226 PROD1 CASING TRIP T POOH from 4680' MD to 226'MD on elevators, monitor well on trip tank. "Note-Divert from plan due to waiting on solids free MOBM to be mixed and delivered to rig for displacement. Plan was to P/U casing scraper assy and RBIH,then displace to SFMOBM. Due to mud delay, decision was made to POOH and make separate cleanout run. 15:30 15:45 0.25 226 226 PROD1 CASING OWFF T Monitor well static, SIMOPS-CIO PS-21 slip inserts. 15:45 17:15 1.50 226 0 PROD1 CASING BHAH T L/D BHA#5 as per DD/MWD. Calc fill=30.7 bbl,Actual fill=36.2 bbl. 17:15 17:45 0.50 0 0 PROD1 CASING BHAH T Clean and clear rig floor of BHA components SIMOPS-DTH set up 225 bbl open top tank in containment for acid pickle job. 17:45 18:30 0.75 0 0 PROD1 CASING RURD T P/U and install mousehole, P/U thread protectors,finish download MWD data and prep shed for laying down singles and doubles. 18:30 00:00 5.50 0 0 PROD1 CASING PULD P Lay down 4"drill pipe via mousehole, lay down 52 stands total, storing 19 doubles in pipe shed mags. 38/05/2015 P/U cleanout assy, RIH on 4"DP to 4700'and P/U well commander, scraper, magnets and brushes.XO to 5" and wait on mud. Decision to POOH and test BOPE, POOH and L/D BHA. Notice given to AOGCC,witness waived by Bob Noble to test after midnite. Page 21 of 40 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 0 0 PROD1 CASING RURD T LID mousehole, CIO PS-21 slip inserts for 9-5/8"to hand slip bowls. Clean and clear rig floor, monitor well via trip tank. 02:00 02:30 0.50 0 285 PROD1 CASING BHAH T PJSM, M/U 6-3/4"clean out BHA to 285'MD, monitor displacement via trip tank. 02:30 05:30 3.00 285 4,682 PROD1 CASING TRIP T RIH from 285' MD to 2183' MD fill pipe at 2183', 3 bpm 140 psi, 14% flow out. Blow down top drive, continue RIH from 2183'MD to 4081' MD, fill drill pipe, blow down top drive. Continue RIH from 4081'MD to 4682'MD. 05:30 07:30 2.00 4,682 4,682 PROD1 CASING SLPC P PJSM, cut and slip drilling line, cut 9 wraps for 71'. Calibrate Amphion and Totco block height sensors. 07:30 08:00 0.50 4,682 4,682 PROD1 CASING SVRG P Service top drive and complete PM on draworks. 08:00 08:30 0.50 4,682 4,682 PROD1 CASING BHAH T PJSM, M/U 9-5/8"scraper assembly, C/O PS-21 slip inserts to hand slip bowls. L/D 7"Well commander and XO to pipeshed. 08:30 11:30 3.00 4,682 4,682 PROD1 CASING SFTY T Hold man down drill with AAR,then table top well kill drill. SIMOPS-wait on 1.75"OD drift for Well Commander. Continue monitoring well via trip tank. 11:30 11:45 0.25 4,682 4,682 PROD1 CASING BHAH P Drift 7"well commander with 1.75" OD ball to verify it will pass through ball catcher. Continue M/U 9-5/8" scraper assembly. M/U10'5"pup joint. 11:45 12:00 0.25 4,682 4,682 PROD1 CASING RURD T PJSM, C/O 4"XT39 saver sub to 4'%" IF, continue monitor well via trip tank. P/U 10', 5"DP pup to C/O sver sub- not in string. OA pressure=200 psi 12:00 14:00 2.00 4,682 4,682 PROD1 CASING SVRG T Continue changing out to 4'/2' IF saver sub and perform PM on top drive. 14:00 19:30 5.50 4,682 4,682 PROD1 CASING RURD T Drift and strap 175 joints 2-7/8" tubing. SIMOPS-Perform PM's, housekeeping, bring on 9.9 ppg Faze Pro mud to pits. Stage 120 super sliders,240 clamps and 45 6'/z" Hydraform centralizers to rig floor. *Decision made to POOH and test BOPE while waiting for Solids free MOBM to be mixed and delivered to rig. 19:30 20:45 1.25 4,682 4,650 PROD1 CASING BHAH T Lay down scraper assembly and CBU @ 260 gpm, 825 psi, 18%flow out. MW in/out=9.9 ppg. Total strokes pumped=3148 Page 22 of 40 Time Logs S • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 23:00 2.25 4,650 0 PROD1 CASING TRIP T POOH on elevators from 4650' MD, rack back HWDP and L/D bit, stab and XO. Calc fill=28.2 bbl,Actual fill=35.1 bbl. 23:00 00:00 1.00 0 0 PROD1 WHDBO RURD T Clean rig floor, drain stack, pull wear bushing and P/U joint 5" DP to hang below test plug for BOP testing. OA pressure=250 psi Fluid lost for tour=6 bbl 08/06/2015 Test BOPE with 5 test joints, set wear ring, P/U cleanout assy and RIH to 4682'. M/U Well comander, magnet, scraper and brush, park at shoe 4752'MD and monitor well.Wait on EMS-6800 mixing and testing. 00:00 01:30 1.50 0 0 PROD1 WHDBO MPSP T Make up 1 joint of 5"drill pipe below Vetco test plug, torque to 22k. Drain BOP stack, set upper test plug, witnessed by Vetco rep. 01:30 10:30 9.00 0 0 PROD1 WHDBO BOPE T Test BOPE to 250/3500 psi 5 min ea charted, chokes to 250/2000 psi. AOGCC Bob Noble waived witness of test.With 5"test joint test annular, 4"kill, Choke valves 1,13,14,15. Upper IBOP, valves 2,10,12, HCR Kill, lower IBOP, 2-7/8"x5-'/z'LPR, 5" Dart valve.With 4-1/2"test joint tested annular, manual kill,valves 2,9,10,11. 5"TIW,2-7/8"x5-'/z" LPR, 4" Dart valve.With 4"test joint tested annular, valves 2,7,8,10,4" TIW. Tested manual choke'B'and super choke to 250/2000 psi 5 min each,2-7/8"x5-%" LPR, 3'/z' Dart valve.With 5'/z'test joint tested annular,valves 3,6, 3'h"TIW, 2-7/8"x5-'/z'LPR, 2-7/8"TIW. Pull test joint tested Blind/shear rams with valves 4,5.With 2-7/8"test joint tested annular, HCR choke, HCR kill, 2-7/8"TIW, manual choke valve, 2-7/8"x5-'/z'LPR. 10:30 11:00 0.50 0 0 PROD1 WHDBO BOPE T Perform accumulator drawdown test, system pressure=3050 psi, manifold pressure=1500 psi, pressure after functioning=1550 psi,200 psi attained=25 seconds with 2 electric pumps,full system pressure recovery=138 seconds with 2 electric and 2 air pumps. Closing times, Annular=23 sec, UP=18 sec, Blind/shear=16 sec, Choke HCR=2 sec, Kill HCR=2 sec, 6 bottle N2 average=2054 psi.AOGCC Bob Noble waived witness of test @ 19:11 hrs 8/5/15. Page 23 of 40 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 0 0 PROD1 WHDBO RURD T Rig down test equipment, pull upper test plug, install Vetco 12%"ID wear bushing. Blow down test pump, kill and choke. _OA pressure=200 psi 12:00 12:15 0.25 0 0 PROD1 WHDBO RURD T Continue install of wear bushing per Vetco, RILDS. Blow down mud line. 12:15 14:00 1.75 0 0 PROD1 CASING RURD P Load liner hanger, liner top packer and seal bore components in pipe shed. P/U casing tools to rig floor, R/U to make up hanger. 14:00 15:30 1.50 0 0 PROD1 CASING PULD P Make up ZXP, liner hanger, SBE, FLCV assembly with running tool and rack back in derrick per BOT rep. 15:30 16:00 0.50 0 0 PROD1 CASING RURD P R/D power tongs, change out PS-21 inserts. 16:00 16:45 0.75 0 285 PROD1 CASING BHAH T M/U bit, near bit stab, bit sub. C/O float in stab. RIH with 3 stands _HWDP to 285'MD. 16:45 19:15 2.50 285 4,682 PROD1 CASING TRIP T RIH on elevators,4"DP from 285' MD to 4682'MD, filling pipe every 20 stands, minitor displacement via pit #2. 19:15 19:45 0.50 4,682 4,752 PROD1 CASING BHAH T M/U XO, 7"Well Commander, magnet, scraper and brush. Run in 30'with 5"drill pipe to 4752' MD. L/D double to facilitate top drive PM's. 19:45 00:00 4.25 4,752 4,752 PROD1 CASING WAIT T Monitor well @ 4752' MD via trip tank, perform PM's, housekeeping, install new cabinet in BOP deck, prime and paint. Review lower completion running order. 08/07/2015 Run in hole to TD with cleanout assy and casing scraper, CBU. Displace to new 9.9 ppg FazePro, obtain test results. Clean pits and onload EMS-6800 into pits. Perform PST testing, failed repeated tests. Run EMS-6800 over 325 mesh screens and tested, failed. Rig up MI Filtration system. Troubleshoot top drive electrical issues. 00:00 03:00 3.00 4,752 4,752 PROD1 CASING WAIT T Continue to monitor well @ 4752' MD via TT, Perform PM's, housekeeping, service and inspect top drive and blocks. Continue to prime cabinet in Girder storage. P/U=97k, 5/0=89k. 03:00 07:30 4.50 4,752 9,431 PROD1 CASING TRIP P TIH with cleanout and casing scraper assy from 4752'MD to 9431'MD. Monitor displacement via pit#2, P/U=173k, S/O=128k. SPR's @ 9432'MD, 3796'TVD, 9.95 ppg, 07:30 hrs #1-20 spm=360 psi,30 spm=500 psi #2-20 spm=380 psi,30 spm=540 psi Page 24 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:00 0.50 9,431 9,463 PROD1 CASING SFTY P PJSM with vac truck drivers, Mud Engineer, pit watchers on dislace well to clean Faze Pro OBM.Wash down from 9431'MD to 9463',tag with 5k WOB. 2 bpm 360 psi, 12% flow out. 08:00 09:30 1.50 9,463 9,450 PROD1 CASING DISP P Rotate and reciprocate from 9450' MD displace well to 9.9 ppg FazePro OBM, 5 bpm 900 psi,21%flow out, 6 bpm 1245 psi 21%flow out, 7 bpm 1634 psi 22%flow out, 8 bpm 2064 psi 22%flow out. 30 rpm, 6k Tq, P/U=173k, S/O=128k, ROT=140k. Pumped 5200 stks total. 09:30 10:00 0.50 9,450 9,427 PROD1 CASING OTHR P At 9427' MD, drop 2.115"OD Well Commander activation ball, chase with 3 bpm 530 psi 15%flow out. Ball on seat @ 360 stks, pressure up to 1000 psi 30 sec, increase to 1250 psi open well commander. Pump 3 bpm© 185 psi 17%flow out. 10:00 12:00 2.00 9,427 9,427 PROD1 CASING CIRC P Continue circulating through well commander @ 14 bpm 1790 psi, 32%flow out, 100 rpm, 7k Tq. Reduce rate to 5 bpm @ 7200 stks, 310 psi, 17%flow out, 100 rpm, 7k Tq.Total strokes pumped 8923. Mud weight in/out=9.9 ppg. OA pressure=200 psi 12:00 12:15 0.25 9,427 9,421 PROD1 CASING OTHR P Drop 2.115"activation ball and pump down @ 3 bpm, 145 psi, 14%flow out. Ball on seat @ 363 stks, pressure up to 1400 psi and observe closure. Confirm activation @ 3 bpm 500 psi. 12:15 21:15 9.00 9,421 9,450 PROD1 CASING CIRC T Circulate while R&R from 9450'MD to 9421' MD @ 5 bpm, 960 psi, 17% flow out, 50 rpm, 6k Tq.At 11,600 stks, reduce rate to 3 bpm, 510 psi, 30 rpm, 6k Tq.At 18,700 stks reduce rate to 2 bpm, 390 psi, 15% flow out. SIMOPS-Clean pits and onload EMS-6800 SFMOBM. P/U=170k, S/O=125k. 21:15 21:45 0.50 9,450 9,450 PROD1 CASING SEQP T Shut down pumps to perform test over 325 mesh shaker screens with EMS-6800, grab samples under shakers and run PST-failed. SIMOPS-Rig up MI Filtration van and equipment in containment behind rig. Page 25 of 40 Time Logs • . Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 22:00 0.25 9,450 9,450 PROD1 CASING CIRC P Re-esablish circulation @ 2 bpm 450 psi, rotate 10 rpm 6k Tq. Observe sharp increase in torque to 12k, stalling out top drive to 8 rpm. Increase pump rate to 5 bpm to clean off scrapers while troubleshooting issue. Decide to rack back 1 stand to move scraper to new location. 22:00 22:15 0.25 9,450 9,400 PROD1 CASING RGRP T Rack back 1 stand-observe high torque readings(3k)on top drive spinning freely. Blow down top drive and rig up cement line and headpin to circulate while troubleshooting topdrive. 22:15 22:45 0.50 9,400 9,400 PROD1 CASING RGRP T Rig blacked out,two 3516's shut down,stemming from topdrive overload, tripping out systems, including 3516 radiators. Restart genetators, electrician troubleshooting while reciprocating string and pumping 2 bpm via cement line. 22:45 00:00 1.25 9,400 9,400 PROD1 CASING CIRC T Circulate through cement line while reciprocating from 9428'MD to 9400' MD @ 2 bpm,497 psi, 13%flow out, P/U=170k, 5/0=120k. Shut down for 10 minutes to test EMS-6800 over 325 mesh screens and catch samples for PST testing-failed. 38/08/2015 POOH to casing shoe to troubleshoot and repair top drive. SIMOPS-determine plan forward with completion fluid program, process EMS-6800 SFMOBM on rig over 325 mesh screens to obtain passing PST test successfully. 00:00 00:30 0.50 9,400 9,400 PROD1 CASING OWFF T Rig down cement line and head pin, monitor well 30 minutes static and prepare to POOH to shoe for topdrive repair while troubleshooting SFMOBM contaminate issue. 00:30 08:00 7.50 9,400 4,680 PROD1 CASING TRIP T POOH on elevators from 9429' MD to 4680' MD, monitoring displacement via TT1 &2. P/U=108k, 5/0-92k. 08:00 08:30 0.50 4,680 4,680 PROD1 CASING RURD T C/O slip inserts, elevators, lay down scraper assembly to pipe shed in one piece. Take pictures of scrapers and magnets. R/U headpin and cement hose, 08:30 12:00 3.50 4,680 4,680 PROD1 CASING OWFF T Stage pumps up tpo 3 bpm, 340 psi, 20%flow out. S/D mud pump and circulate across top while monitorng well via TT-2. Perform PST mud testing, clean shakers and troughs under shakers and to pits. SIMOPS- Troubleshoot top drive. Loss for tour=5 bbl Page 26 of 40 Time Logs i • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 4,680 4,680 PROD1 CASING OTHR T Clean under shakers and mud trough, R/U&circ EMS-6800 SFMOBM across shakers dressed with 325 mesh screens. Obtain samples for PST testing. Monitor well via trip tank. Repair topdrive 20 pin connector and test. Continue troubleshooting topdrive ground fault. Perform housekeeping and PM's throughout rig. OA pressure=200 psi Losses for tour=0 bbl OA pressure=200 psi 38/09/2015 Continue processing EMS-6800 over 325 mesh screens until all fluid passes PST. Replace top drive traction motor and test OK. Begin running in hole to displace well to 10.1 ppg EMS-6800. 00:00 12:00 12.00 4,680 4,680 PROD1 CASING OTHR T Bringing on EMS-6800 SFMOBM and circulate across 325 mesh shaker screens for passing PST. Monitor well via trip tank. Pick up and break out scraper, brushes and magnets. Leave Well commander on rig floor. Break Well commander and remove 2 activation balls from catcher. Perform housekeeping and PM's throughout rig, continue troubleshooting top drive. Rig up and pull drillers side traction motor from top drive. Total loss to hole for tour 1.5 bbl. OA pressure=190 psi 12:00 21:45 9.75 4,680 4,680 PROD1 CASING RGRP T Continue circulating EMS-6800 over 325 mesh screens for passing PST. Change out traction drive motor and test-good no faults. SIMOPS-Hydro Blast 2-7/8"box and pin protectors at central shop due to grit and excess dope. 21:45 00:00 2.25 4,680 8,464 PROD1 CASING TRIP P Trip in hole on elevators from 4680' MD to 8464'MD, monitor well via TT. Fill pipe every 20 stands. SIMOPS-Continue to hydro Blast 2-7/8"box and pin protectors at central shop due to grit and excess dope. OA=200 psi, losses for tour=0 X8/10/2015 Run in hole to bottom, displace well to EMS-6800, pump out of lateral to 4650'inside shoe. Clean surface equipment and lines. Circulate well and surface volume over 325 mesh screens to achieve passing PST. Page 27 of 40 Time Logs • i Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 8,464 9,463 PROD1 CASING TRIP P Continue RIH from 8464'MD to 9463' MD, monitoring displacement via trip tank. SIMOPS-Complete cleaning of Hydril 511 2.875 thread protectors. 01:00 03:30 2.50 9,463 9,463 PROD1 CASING CIRC P CBU x 2 while R&R stage up to 5 bpm, 1299 psi,22%flow out, 30 rpm, 7k Tq. Total strokes pumped= 7200. Substantial amount of sand/cuttings returns at 1 BU. 03:30 06:45 3.25 9,463 9,463 PROD1 CASING DISP P PJSM, displace well from 9.9 ppg FazePro OBM to 10.1 ppg EMS-6800 solids free OBM while rotaing 30 rpm, 7k Tq, reciprocating pipe from 9463'MD to 9382'MD. Pumped 70 bbl 10.5 ppg Hi Vis spacer @ 4 bpm 900 psi, followed by 280 bbl 10.1 ppg 120 FV spacer at 4 bpm, followed by 280 bbl filtered 10.1 ppg 96 FV 4 bpm, FCP=787 psi. Spotting clean fluid in the lateral,first spacer out of the hole. Shut down. 06:45 12:00 5.25 9,463 6,163 PROD1 CASING PMPO P Begin pumping out of the hole from 9463' MD to 6163' MD, pumping 1.6 bpm, pulling 30 fpm pumping total 5 bbl per stand. SIMOPS-Cleaning box and pin ends on 2.875" H511 wash pipe Fluid lost for tour= 18 bbl OA @ 11:30=350 psi 12:00 14:15 2.25 6,163 4,650 PROD1 CASING PMPO P Continue pumping out of hole from 6163'MD to 4650' MD @ 1.6 bpm 140 psi, 30 fpm for 5 bbl/stand. P/U=104k, S/0=94k. SIMOPS-Set up new(400 bbl)acid returns open top and recieve de-contamination trailer from SRT. 14:15 21:00 6.75 4,650 4,650 PROD1 CASING OTHR P Clean pits, rig floor,joes box, flowline, beneath shakers, mud trough, pump suction lines and suction manifolds on both mud pumps. Flush all equipment and lines. Take on additional EMS-6800 Solids free MOBM and circulate over 325 mesh screens for passing PST. Page 28 of 40 Time Logs 1 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 4,650 4,650 PROD1 CASING CIRC P Establish circulation while R&R 30 rpm, stage pumps up to 7 bpm 1010 psi,20%flow out, mud weight in/out= 10.1 ppg. Circulate over 325 mesh screens to achieve passing PST. Pumped total 10000 strokes (1007 bbl)@ midnight(full circulation with pits=580 bbl) PST packed off within 10 sec after first full circulation. 38/11/2015 Circulate until clean EMS in casing. POOH and L/D BHA. L/D 4"drill pipe. RIH with liner work string and R/U to perform acid pickle. 00:00 11:15 11.25 4,650 4,650 PROD1 CASING CIRC P Continue circulation while R&R 30 rpm 2k Tq, 7 bpm 1010 psi, 20%flow out, mud weight in/out= 10.1 ppg. Circulate over 325 mesh screens to achieve passing PST. Pumped total 53090 strokes(5346 bbl) 9+full circulations, hole and pits=580 bbl) PST passed final tests for 3 qts, sec per qt= 10.88 sec, 9.3 sec, 14.68 sec. 11:15 11:45 0.50 4,650 4,650 PROD1 CASING OWFF P Blow down top drive. Monitor well for flow 30 minutes-static. Prep for POOH. 11:45 12:00 0.25 4,650 4,360 PROD1 CASING TRIP P Begin POOH on elevators from 4650' MD to 4360' MD, pull 2 stands watching fluid fall then put on trip tank. Good displacement. Total lost for tour=30 bbl OA pressure@ 11:30 525 psi 12:00 14:00 2.00 4,360 286 PROD1 CASING TRIP P Continue POOH on elevators from 4360' MD to 286'MD, monitoring displacement via trip tank. 14:00 14:30 0.50 286 0 PROD1 CASING BHAH P Rack back 3 stands HWDP and L/D BHA. Monitor displacement via trip tank. Calculated displacement=27.3 bbl,Actual Displacement=33.4 bbl. 14:30 15:00 0.50 0 0 PROD1 CASING RURD P Clean and clear rig floor, change out PS-21 slip inserts, P/U mousehole. 15:00 20:15 5.25 0 0 COMPZ CASING PULD P Lay down 46 stands 4"drill pipe via mousehole. Monitor well via trip tank. 20:15 20:45 0.50 0 0 COMPZ CASING RURD P Lay down mousehole, change out PS-21 slip inserts. 20:45 23:00 2.25 0 4,703 COMPZ CASING TRIP P P/U mule shoe and RIH with 5"DP and 5" HWDP liner running work string 50 stands to 4703'MD. Monitor displacement via trip tank. SIMOPS-Begin laying out lower completion components for final inspection and running order in casing/pipe shed. Page 29 of 40 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 4,703 4,703 COMPZ CASING RURD P Rig up for 5"Acid Pickle job, spot and rig up SLB, build spacers. Rig up hardline to DP on rig floor with 5" TIW valve, chik-san and Halliburton valve. Total lost for tour=2.7 bbl OA pressure=400 psi 08/12/2015 Perform acid pickle on 5"liner work string, POOH installing supersliders on 5"DP and HWDP. P/U and RIH with OHSAS lower completion to 5'/2'H563 XO. 00:00 01:30 1.50 4,703 4,703 COMPZ CASING RURD P R/U to perform acid pickle job on liner running work string. Build Hi Vis pill, Deepclean spacer.Walk all hardlines, double check de-contamination staion. PJSM with CPAI, SLB, MI ASRC. 01:30 02:00 0.50 4,703 4,703 COMPZ CASING SFTY P PJSM on acid job with CPAI, Doyon crew, SLB, MI and ASRC. 02:00 07:00 5.00 4,703 4,703 COMPZ CASING CIRC P Perform Acid pickle. Flush lines with water to tank, pump 10 bbl water to SLB, Pump Hi Vis spacer to tank, pump 15 bbl spacer to SLB. Pressure test lines to 250/3500 psi-good. Down drill pipe SLB pumped 5 bbl 10.3 ppg Hi Vis spacer, Swap to rig to pump 10 bbl DeepClean spacer, followed by 6 bbl Hi Vis spacer to displace to DP 1 bpm 250 psi. Swap to SLB to pump 11.9 bbl 8.9 ppg 15%HCI followed by 5 bbl Hi Vis brine spacer, 1 bpm 200 psi,4-5%flow out. Swap to rig to displace acid to the mule shoe with 54 bbl of 10.1 ppg brine, 1 bpm, 206 psi. Shut down, line up to reverse circulate. Reverse out acid treatment to open top tank @ 1 bpm 100-200 psi. Pumped total 104 bbl to clean up. 07:00 09:00 2.00 4,703 4,703 COMPZ CASING CIRC P Rig up to circulate down pipe, circulate 3 bottoms ip, staged up to 9 bpm, 1500 psi, 24%flow out. 09:00 09:30 0.50 4,703 4,703 COMPZ CASING OWFF P Rig down circulating equipment, monitor well static. 09:30 12:00 2.50 4,703 2,050 COMPZ CASING TRIP P POOH from 4703' MD to 2050'MD monitoring displacement via trip tank. Installing super sliders on every joint starting on stand 43 per WWT rep. Losses for tour=12 bbl OA pressure @ 12:00 hrs=500 psi 12:00 14:00 2.00 2,050 0 COMPZ CASING TRIP P Continue POOH from 2050' MD installing super sliders every joint, total of 117 sliders ran on 5"string. Monitor displacement via trip tank. Page 30 of 40 Time Logs • • ,Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 15:00 1.00 0 0 COMPZ CASING RURD P Rig up to run 4'/2'liner, load pipeshed with liner equipment, and verify count. 15:00 15:30 0.50 0 0 COMPZ CASING SFTY P PJSM on running liner, DDI, CPAI, Baker, and Doyon casing. _ 15:30 00:00 8.50 0 4,698 COMPZ CASING PUTB P RIH with 11.6#L-80 Hydril 563,4'/z" Excluder 2000 screens,tracer cartridges and swell packers per detail. Monitor displacement via pit 8. Swell#1 in the hole @ 19:10,#2 @21:00,#3 @ 21:50,#4 @ 22:35, #5 @ 23:00 hrs. Ran total 26 4'/2' blanks, 2 5'/2'blanks, 5 swell packers,4 tracers, 77 Excluder screens. P/U XO to 5%H 563. Losses for tour=5 bbl OA pressure=400 08/13/2015 Cross over to 5%"563, run two joints 5%. R/U false rotary table, PJSM, R/U and run Slick stinger and 163 jts Hydrill 511 inner string. M/U liner hanger and ZXP, FLCV,XO to DP and run liner on DP. Set liner hanger and begin displacement to brine. 00:00 01:00 1.00 4,698 4,780 COMPZ CASING PUTB P Continue RIH with 4%"OHSAS liner assy,XO to 5%"Hydril 563, run 2 joints 5%"to 4780'MD. 01:00 01:45 0.75 4,780 4,780 COMPZ CASING RURD P Rig down 5%"running equipment, R/U to run 2-7/8" Hydril 511. Rig up false rotary table, bowl and slips, elevators and tongs. 01:45 03:00 1.25 4,780 4,780 COMPZ CASING PULD P M/U Baker slick stinger, RIH followed by 2-7/8"Hydril 511 inner string, torquing all connections to 800 ft/lbs. Run dog collar on 2-7/8"for first 50 joints. 03:00 03:30 0.50 4,780 4,780 COMPZ CASING PULD T Change out joints#4 and#5 due to galled threads. Joint#29 had dented box end. 03:30 09:30 6.00 4,863 4,863 COMPZ CASING PULD P Continue RIH with 2-7/8" Hydril 511, run total 163 joints and no-go out on depth, P/U=62k, S/0=57k. 09:30 10:30 1.00 4,780 4,863 COMPZ CASING HOSO P Space out inner string, laying down joint#163, pick up 7.68'pup, Baker XO to EUE and Baker fluid loss control valve shifting tool. 10:30 11:15 0.75 4,863 4,863 COMPZ CASING OTHR P C/O elevators, M/U ZXP liner top packer/liner hanger assembly. R/D 2-7/8"handling equipment, 11:15 11:45 0.50 4,863 4,863 COMPZ CASING RUNL P M/U 7"Well Commander, RIH with 5"DP to 4863'MD. P/U=122k, S/0=109k. 11:45 12:00 0.25 4,863 4,863 COMPZ CASING CIRC P Break circulation, stage pumps up to 3 bpm, 700 psi, 16%flow out. Circulate inner string volume-30 bbl. Losses for tour=0 bbl OA pressure= 175 psi. Page 31 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 16:00 4.00 4,863 9,423 COMPZ CASING RUNL P Run 4'/2'liner on 5"drill pipe and 5" HWDP with super sliders from 4863' MD to 9423' MD. Fill pipe every 10 stands, monitor displacement via pit 8. 16:00 18:30 2.50 9,423 9,425 COMPZ CASING PACK P Drop 1"phenolic ball&pump down @ 2.5 bpm, 920 psi, 16%flow out. Reduce flow to 1 bpm @ 70 bbl,445 psi 7%flow out. Ball on seat @ 833 stks. Pressure up to 3300 psi and slack off to 80k hookload. P/U 3'to breakover @ 177k.Attempt to slack off to 80k without success. Pressure up to 700 psi and slack off to 90k hookload. Increase pressure to 3600 psi, set down to 84k. Bleed pressure to 700 psi. P/U to breakover @ 181k. Bleed off pressure to 0 and set down to 81k to confirm liner hanger is set. Top of liner 4580.49'MD, Liner shoe @ 9425' MD. Pressure up to 4350 and shear out ball seat. P/U 3'to breakover @ 161k to release from hanger. P/U=177k, S/O=122k with liner. P/U=161 k W/O liner. 18:30 20:15 1.75 9,425 9,425 COMPZ WELLPF CIRC P Establish circulation© 1.5 bpm, 560 psi,9%flow out. SIMOPS-Prep pits,trucks and filtration/tank farm for brine displacement. 20:15 00:00 3.75 9,425 9,425 COMPZ WELLPF DISP P PJSM,displace well from SFMOBM to NaCI/NaBr brine. Start displacement with 20 bbl LVT-200, 70 bbl transition spacer, 100 bbl Citric Acid spacer, 50 bbl transition spacer, chase with 580 bbl Safe Break CBF filtered brine from tank farm,250 bbl Safe-Break CBF pumped at midnite. 2.5 bpm, ICP=850 psi, FCP=380 psi. 08/14/2015 Complete brine displacement through entire hole until brine returns at surface. Shut down and clean surface equipment. Open Well commander, isolate open hole and circulate brine to 37 NTU. R/U, PJSM and Perform 9%Formic acid soak. Monitor losses. 00:00 05:15 5.25 9,425 9,425 COMPZ WELLPF DISP P Continue to displace well to NaCI/NaBr 10.1 ppg brine @ 2.5 bpm, 380 psi, 15%flow out.Total strokes pumped 11974. 05:15 10:30 5.25 9,425 9,425 COMPZ WELLPF OTHR P Monitor well, clean pits, under shakers, flowline, rotary table.Wait on Engineers flan forward. Page 32 of 40 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:15 1.75 9,425 9,425 COMPZ WELLPF CIRC P Establish baseline parameters pumping 3 bpm,440 psi, 9%flow out. Drop 2.115"WC openiong ball @ 3 bpm, 440 psi, 9%flow out. Ball on seat @ 200 stks, open ports @ 1315 psi. New parameters open 3 bpm, 60 psi, 8%flow. Drop 2.063" isolation ball at same parameters. No sign of isolation once on seat. Stage pumps up to 5 bpm 166 psi, 14%flow out and CBU. Total losses for tour= 15 bbl OA pressure=650 psi. 12:15 15:15 3.00 9,425 9,425 COMPZ WELLPF CIRC P Circulate 66.5 bbl DeepClean/Citric pill @ 5 bpm 142 psi, 13%flow out. Followed by 92.5 bbl HEC-10 Hi Vis pill @ 5 bpm. ICP=237 psi, FCP=480 psi 13%flow out. Followed by 444 bbl filtered brine until clean 37 NTU reading. FCP @ 5 bpm on brine= 175 psi. 15:15 16:00 0.75 9,425 9,425 COMPZ WELLPF CIRC P Drop 2.115"Well commander ball down @ 3 bpm, 64 psi, 8%flow out. Ball on seat @ 230 strokes, pressure up to 1114 psi and hold, increase to 1500 psi and hold 30 sec, increase to 1600 psi and WC shifted without closing completely. Circ rate remained 3 bpm, 64 psi. Drop second 2.115"ball, on seat @ 230 strokes, pressure up to 2150 and observe WC close. 16:00 16:30 0.50 9,425 9,425 COMPZ WELLPF CIRC T WC shifted without closing completely. Circ rate remained 3 bpm,64 psi. Drop second 2.115" ball, on seat @ 230 strokes, pressure up to 2150 and observe WC close. 16:30 17:30 1.00 9,425 9,425 COMPZ WELLPF SFTY P PJSM with CPAI WSL, Doyon crew, SLB pumpers, MI and CPAI engineering group on pumping 9% formic acid soak. 17:30 18:45 1.25 9,425 9,425 COMPZ WELLPF RURD P Line up and transfer 20 bbl water to SLB and 15 bbl 10.1 ppg filtered brine to SLB unit via injection line. Page 33 of 40 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 21:30 2.75 9,425 9,425 COMPZ WELLPF CIRC P Line up and pump 10 bbl 10.1 ppg brine from SLB unit down string, PT surface lines from SLB unit to 4" standpipe Demco valve, and down to mud pump to 4000 psi-good. Pump 220 bbl 10.3 ppg 9%Formic acid down string, 3.5 bpm for first 97 bbl then slowed to 2 bpm 160 psi for remainder, chase with 5 bbl 10.1 ppg brine. Swap to rig to displace acid© 2 bpm, 180 psi, 5%flow out for 95 bbl from MI tank farm filtered 10.1 ppg brine. Total pumped 317 bbl, total returns=273 bbl for total of 44 bbl dynamic loss. (17.6 bph). 21:30 00:00 2.50 9,425 9,425 COMPZ WELLPF OWFF P Monitor well via trip tank establishing consistant loss rate of 24 bph. Total loss for tour=89.4 bbl. 08/15/2015 Complete first 9% Formic acid soak, monitor losses. Pump 2nd 220 bbl 9%Formic acid soak for 6 hrs. ,Circulate well clean, set ZXP liner top packer and test to 1500 psi 30 min good. 00:00 03:00 3.00 9,425 9,425 COMPZ WELLPF OWFF P Continue to monitor well while soaking 9%formic acid.Well losses reduced from 28 bph to 18 bph after 6 hours. 03:00 03:15 0.25 9,425 9,425 COMPZ WELLPF SFTY P PJSM with CPAI WSL, Doyon Drilling crew, SLB pumping crew, MI Mud Engineers, MI Filtration,ASRC on pumping Formic acid job#2. 03:15 03:45 0.50 9,425 9,425 COMPZ WELLPF RURD P Line up and pump from rig to SLB 15 bbl fresh water, followed by 15 bbl filtered brine from MI tank farm. 03:45 06:30 2.75 9,425 9,425 COMPZ WELLPF CIRC P Line up and SLB pumped 215 bbl of 10.3 ppg 9%Formic Acid/Brine down string, foillowed by 5 bbl filtered brine. Starting 3 bpm, 786 psi, 8% flow out. Monitoring bbl in/out and losses recording every 5 minutes, Decreasing to 2 bpm 270 psi, 3-4% flow out. Swap over to rig pumps and pump 92 bbl filtered brine @ 2 bpm 230 psi, increasing to 3 bpm 486 psi 4-5%flow out.Total bbl pumped=312, total returned 218. 06:30 12:00 5.50 9,425 9,425 COMPZ WELLPF OWFF P Monitor well via trip tank while acid soaking, static losses 15-20 bph. Rig down, blow down injection line. Remove master bushings, install PS-21's. R/U on IA for packer test. Total fluid lost for tour=231.5 OA pressure= 190 psi Page 34 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 9,425 9,425 COMPZ WELLPF OWFF P Continue monmitoring well establishing final loss rate of 17 bph. SIMOPS-P/U hanger,tree componenets, cannon clamps and other upper completion equipment to rig floor. 13:30 14:30 1.00 9,425 9,425 COMPZ WELLPF RURD P PJSM on circulating out spent acid, Spot vac trucks to open top tank. 14:30 20:00 5.50 9,425 9,425 COMPZ WELLPF DISP P Displace well to 10.1 ppg NaCI/NaBr brine taking returns to pits and monitoring loss rate until ph reached 5, pumping 5 bpm, 1127 psi, 11% flow out. (153 bbl pumped, 111 bbl returned). Closed annular and divert to open top tank, continue pumping 5 bpm, 1220 psi for 1085 bbl until ph of 4 and brine cleaned up. Open annular and tanke returns to rig pits for treatment, circulate additional 52 bbl.Total pumped 1290 bbl. 20:00 23:15 3.25 9,425 9,425 COMPZ WELLPF OWFF P Monitor well flowing back. Slack off 3' to 9420'MD with 80k set down to confirm liner hanger set. P/U to breakover @ 9423' 180k. P/U additional 5'to 9418'to expose dog sub. Continue monitoring well flowing back, reducing rate from 2 bpm to .06 bpm. 23:15 23:30 0.25 9,425 9,418 COMPZ WELLPF PACK P Slack off with 50k set down and observe ZXP shear out, P/U to break over @ 165k, rotate© 15 rpm and set down 65k to set packer, observe set. 23:30 00:00 0.50 9,418 9,418 COMPZ WELLPF PRTS P Pressure test ZXP packer and IA to 1500 psi for 30 minutes charted, good test. Fluid lost for tour=209 bbl OA @ 24:00=290 psi 08/16/2015 P/U and shift FLCV, POOH Spotting 40 bbl Citric pills inside screens x 3. POOH laying down Hydril 511, pulling through FLCV @ 4634'. Circulate and treat brine ph, pumping clean<10 RIH with 5"drill pipe, removing supersliders. Give AOGCC 24 notice of BOPE test prior to running completion 8/17. 00:00 01:30 1.50 9,418 9,393 COMPZ WELLPF CIRC P P/U 25'to 9393'MD, pump in 40 bbl Citric acid pill, chase with 70 bbl filtered 10.1 ppg brine from tank farm @ 2 bpm, 119 psi,4%flow out. Shut down and observe well go static after 5 min. 01:30 04:00 2.50 9,393 6,775 COMPZ WELLPF TRIP P P/U 17'to 9376'MD pull into FLCV shifting tool, pull 10k over to 177k, and wait 2 minutes. Pull additional 1.2k and observed shifting of FLCV. Blow down top drive, continue to POOH from 9376'MD to 6775'MD while monitoring displacement via trip tank, losses 18 bph. Page 35 of 40 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:30 0.50 6,775 6,775 COMPZ WELLPF CIRC P Pump 40 bbl citric acid pill chased with 40 bbl filtered brine from tank farm @ 2 bpm, 94 psi,4%flow out. Monitor well static 5 minutes. 04:30 05:45 1.25 6,775 4,856 COMPZ WELLPF TRIP P Continue POOH from 6775' MD to 4856'MD, monitoring displacement via trip tank, losses 18 bph. 05:45 07:00 1.25 4,856 4,735 COMPZ WELLPF BHAH P Lay down Well commander, Lay down Baker liner running tools, space out pups, ITTS assembly, 1 joint of 2-7/8"EUE, FLCV shifting tool to 4735. 07:00 07:30 0.50 4,735 4,668 COMPZ WELLPF PULD P Rig up and lay down 2-7/8" Hydril 511 to 4668' MD. 07:30 08:45 1.25 4,668 4,668 COMPZ WELLPF CIRC P Rig up circulating equipment, load string with 27 bbl citric acid pill @ 2 bpm, 150 psi, 6%flow out. Close anular and bullhead away total 40 bbl of citric pill, chased with 27 bbl filtered brine @ 2 bpm, ICP=198 psi, FCP=240 psi. Open annular and rig down circulating equipment. 08:45 09:15 0.50 4,668 4,668 COMPZ WELLPF OWFF P Monitor well flow back, diminishing flow, static after 20 minutes. 09:15 09:30 0.25 4,668 4,611 COMPZ WELLPF TRIP P Continue POOH from 4668' MD to 4611'MD, pulling 2-3/8"mule shoe through the FLCV, no sign of overpull. 09:30 10:00 0.50 4,611 4,611 COMPZ WELLPF OWFF P Monitor well for 30 minutes-Static, no gain, no loss. 10:00 13:30 3.50 4,611 4,611 COMPZ WELLPF CIRC P R/U head pin circulating equipment, circulate 10.1 ppg filtered brine @ 3.9 bpm,490 psi, 11%flow out, conditoning and raising ph from 3-4 to 7. 13:30 14:00 0.50 4,611 4,611 COMPZ WELLPF RURD P Rig down head pin, blow down top drive, C/O elevators. Monitor well for 5 min-static. 14:00 21:00 7.00 4,611 0 COMPZ WELLPF PULD P Continue POOH from 4611' MD to surface, laying down 2-7/8" Hydril 511 and mule shoe, monitoring hole fill via trip tank#2. 21:00 22:00 1.00 0 0 COMPZ WELLPF RURD P Clean and clear rig floor, P/U and break down Baker Liner running tools, L/D. 22:00 23:00 1.00 0 0 COMPZ WELLPF SVRG P Pull PS-21 slips, pull strip-o-matic to C/O 3 air boots. Re-install PS-21's and C/O slip inserts to 5". 23:00 00:00 1.00 0 550 COMPZ WELLPF TRIP P R/U, P/U mule shoe and RIH to 550' with 5" DP and 5"HWDP removing drill pipe supersliders. 38/17/2015 Complete RIH removing supersliders. Slip and cut, spot inhibited brine, POOH laying down 5" DP and HWDP. R/U and test BOPE with 4'/2'test joint,witnessed by AOGCC Jeff Jones. R/U to run upper completion. Page 36 of 40 9 Time Logs • i Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:30 4.50 550 4,576 COMPZ WELLPF TRIP P Continue RIH with 5"DP and 5" HWDP, removing drillpipe supersliders. Lay down top single on stand 48 to space out for spotting inhibited brine and cut/slip drilling line. 04:30 06:30 2.00 4,576 4,576 COMPZ WELLPF SLPC P Cut and slip drilling line, service top drive and blocks, calibrate Ampion and Totco block height. SIMOPS-Spot 60 bbl 10.1 ppg corrosion inhibited brine#3 bpm, chase with 30 bbl 10.1 ppg filtered brine. 06:30 12:00 5.50 4,576 567 COMPZ WELLPF PULD P POOH from 4576'MD to 4418'MD racking back stand 49, P/U top single on 48. Continue POOH from 4418' MD to 567 laying down 13 doubles, followed by 79 singles of 5" DP. 72 singles set aside to be sent to Tuboscope. Lay down 21 joints 5" HWDP for return to Doyon 141. OA pressure @ 12:00= 170 psi Losses for tour=0 12:00 13:00 1.00 567 0 COMPZ WELLPF PULD P Continue POOH laying down 5" HWDP from 567'MD. 13:00 13:30 0.50 0 0 COMPZ WELLPF PULD P RIH with 3 stands 5" DP and lay down 1 x 1. Monitor well via trip tank 13:30 15:30 2.00 0 0 COMPZ WHDBO RURD P P/U 41/2"test joint, pull wear bushing, set test plug. R/U test equipment, flush and fill lines with water. Change out chart recorder. 15:30 19:15 3.75 0 0 COMPZ WHDBO BOPE P Test BOPE with 4'/2'test joint, 250/3500 psi.AOGCC Jeff Jones witnessed test. Chokes tested to 250-2000 psi. Tested annular preventer, 2-7/8"x5'/2'LPR's, choke valves 1-15, Manual operated and super choke, choke and kill manuals and HCR's, 4"Valve on kill line,4" TIW,4"Dart valve, Upper and lower IBOP. 19:15 19:45 0.50 0 0 COMPZ WHDBO BOPE P Perform Accumulator drawdown. System pressure=3050 psi, Manifold pressure= 1500 psi, Pressure after functioning all rams and annular= 1800 psi.200 psi attained=22 seconds with 2 electric pumps, full system recovery= 112 seconds with 2 electric and 2 air pumps. Closing times,Annular=23 sec, UPR= 18 sec, Blind/shear= 16 sec, LPR= 16 sec, Choke HCR=2 sec, Kill HCR= 2 sec.6 bottle N2 average=2016 psi.Witnessed by AOGCC Jeff Jones. #2 Pit Volume sensor failed, was cleaned and re-tested gopod. 19:45 20:15 0.50 0 0 COMPZ WHDBO RURD P Pull test plug, L/D test joint, blow down and rig down test equipment. Page 37 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T -Comment 20:15 22:00 1.75 0 0 COMPZ RPCOM RURD P R/U 4%"handling equipment, hang sheaves, verify pipe count and jewelry order in pipe shed. SIMOPS-Remove 145 cannon clamps from rig floor due wrong type. 22:00 22:45 0.75 0 0 COMPZ RPCOM SFTY P PJSM with CPAI WSL, CPAI engineers,Access reps, Baker tool rep, Baker Centrilift. Discuss motor pick plan and rigging. 22:45 23:30 0.75 0 0 COMPZ RPCOM RURD P Drain stack, P/U jt 4'%"tubing with ESP motor from shed, RIH and remove ESP motor from protective joint. Send ESP motor down to pipe shed to suspend on bridge crane, send out 414'joint. 23:30 00:00 0.50 0 0 COMPZ RPCOM RURD P Continue rigging up sheaves, handling equipment and mobilizing new Cannnon Clamps to rig floor. 08/18/2015 RIH with 4.5" 12.6#L-80 TBG to 850'. Splice the ESP cable. RIH to 896'and install gauges and TEC wire on gauge carrier. RIH with 3.83"drift on slick line to NO-GO.Test motor guide and RIH to latch. P/U CENTERLIFT and tools. 00:00 01:30 1.50 0 0 COMPZ;RPCOM RURD P Continue with 4.5" 12.6#L-80 IBTM upper completion R/U. 01:30 06:45 5.25 0 850 COMPZ RPCOM PUTB P Run 4.5"tubing to 766'and plug in PLE to ACP connector. RIH to 850' installing band clamps and shroud cable clamps as per ACCESS Rep. Monitor displacement via trip tank. 06:45 07:30 0.75 850 850 COMPZ RPCOM RURD P Remove CAVIN slips, R/D tongs, remove PS21 slips and install master bushings. 07:30 12:00 4.50 850 850 COMPZ RPCOM ALFT P R/U to splice ESP cable, P/U ESP wire spooling unit, and R/U sheaves. Build cover on rig floor to cover splicing table, R/U air heater trunks to rig floor. Splice wire, circulate across the top via trip tank, monitor well, (Static). 12:00 13:00 1.00 850 850 COMPZ RPCOM ALFT P Complete ESP cable splice, monitor well via trip tank. 13:00 15:00 2.00 850 896 COMPZ RPCOM PUTB P RIH with 4.5"tubing from 850'to 896'. 15:00 17:30 2.50 896 896 COMPZ RPCOM ALFT P Install guages on top of gauge carrier, splice TEC wire to guages and test. 17:30 19:45 2.25 896 1,678 COMPZ RPCOM PUTB P RIH with 4.5"tubing from 896'to 1,678'. 19:45 20:30 0.75 1,678 1,678 COMPZ RPCOM ALFT P R/U HES slick line sheaves and tools. 20:30 21:00 0.50 1,678 1,678 COMPZ RPCOM ALFT P RIH with 3.83'drift on slick line to NO-GO and POOH. 21:00 22:00 1.00 1,678 1,678 COMPZ RPCOM ALFT P P/U ESP motor guide and test fire. Check electrical integrity(good). 22:00 23:00 1.00 1,678 1,678 COMPZ RPCOM ALFT P Run ESP motor guide on slick line to latch(latch first try). 23:00 00:00 1.00 1,678 1,678 COMPZ RPCOM ALFT P R/U BAKER CENTERLIFT pump components to slickline. Page 38 of 40 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/19/2015 24 hr Summary RIH with 4.5" 12.6#L-80 TBG from 1678'to 4632.58'drifting TBG every 1000'. Space out(5'from being fully located 4627.12'). Terminate TEC wire to hanger and set hanger. Unable to run lock down screws in on TBG hanger due to damaged threads on screws and upper completion well head. VETCO GRAY expediting 3 new screws with gland nuts to rig ASAP. 00:00 02:30 2.50 1,678 1,678 COMPZ RPCOM ALFT P RIH with slick Iline and set Centalift pumps and pack-off. POOH with running assemebly. Monitor well via trip tank. 02:30 03:15 0.75 1,678 1,678 COMPZ RPCOM PRTS P Test pack-off to 2000 psi for 30 minutes 03:15 04:00 0.75 1,678 1,678 COMPZ RPCOM ALFT P RIH with slick line and set slip stop in place. POOH with running tool assemebly. 04:00 06:00 2.00 1,678 2,713 COMPZ RPCOM PUTB P RIH with 4.5"Tubing from 1678'to 2713',topping off every joint. 06:00 07:15 1.25 2,713 2,713 COMPZ RPCOM ALFT P Run slick line with a 3.833"drift to the top of the slip stop. POOH with drift assemebly. 07:15 09:00 1.75 2,713 3,715 COMPZ RPCOM PUTB P RIH with 4.5"Tubing from 2713'to 3715',topping off every joint. 09:00 10:00 1.00 3,715 3,715 COMPZ RPCOM ALFT P Run slick line with a 3.833"drift to the top of the slip stop. POOH with drift assembly. 10:00 12:00 2.00 3,715 4,632 COMPZ RPCOM PUTB P RIH with 4.5"Tubing from 3715'to 4632',tag No GO 7'down on joint 117. 12:00 14:15 2.25 4,632 4,632 COMPZ RPCOM HOSO P Set down 10K X 2 to confirm No Go. Lay down 5 joints of 4.5"tubing joints#117-#113. P/U 3 joints of 5.5" 15.50#L-80 IBTM. Mule shoe at 4632.58. Space Out, 5'from being fully located 4627.12, M/U hanger, 14:15 16:15 2.00 4,632 4,632 COMPZ RPCOM ALFT P Run slick line with a 3.833"drift to 3747'WLM, POOH with slick line and R/D. 16:15 20:15 4.00 4,632 4,632 COMPZ RPCOM ALFT P Terminate TEC wire to hanger, cut and splice ESP cable, 20:15 21:30 1.25 4,632 4,632 COMPZ RPCOM RURD P R/D TEC wire sheave and tugger snatch block. R/D ESP spool, TEC wire spool and Baker Centralift tools. Total clamps count: 4.5"Cannon Clamps= 101 5.5"Cannon Clamps =3 stainless steel bands= 16. 21:30 00:00 2.50 4,632 4,632 COMPZ RPCOM THGR T Unable to run 3 lock down screws on tubing hanger due to damaged threads. Notifications were made to CPAI Completion Engineer Supervisor and CPAI Drilling Superintendent.VETCO GREY Rep is expediting lock down screws and gland nuts ASAP. Page 39 of 40 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/20/2015 24 hr Summary Repair upper wellhead lock down screw threads. Shear out the SOV and circulate. Set the BPV and test to 1500 psi. Conduct a integrity test on the TEC wire and ESP. Install TWC and test the Tree. Pull the TWC and freeze protect the well. Install BPV and remove fluids from the pits. Rig Released 24:00 hrs 8/20/15 00:00 02:00 2.00 4,626 4,626 COMPZ RPCOM THGR T Chase out lock down screw thread grooves on tubing hanger. Replace 3 lock down screws and gland packing nuts. 02:00 03:30 1.50 4,626 4,626 COMPZ RPCOM PRTS P Test wellhead upper and lower seals to 5000 psi for 15 minutes. 03:30 04:00 0.50 4,626 4,626 COMPZ RPCOM CIRC P Shear out SOV at 3563 psi. Circulate 4 bbls at 1 bpm, 140 psi, 3%flow. Reverse circulate 4 bbls at 1 bpm,77 psi,4%flow. 04:00 05:00 1.00 4,626 4,626 COMPZ WHDBO MPSP T Attempted to set BPV,would not set. The starting thread on the valve had been damaged. 05:00 07:45 2.75 4,626 0 COMPZ WHDBO MPSP P Set BPV and test to 1500 psi for 30 minutes. Bleed pressure off 50 psi/min to 750 psi. hold 750 psi for 30 minutes and bleed pressure off 25 psi/min to 0 psi. 07:45 10:00 2.25 0 0 COMPZ WHDBO NUND P Nipple down BOPE, flowline, Joes box, remove kill/choke lines. Break apart interconnect and prep cattle shute and derrick for move. 10:00 11:30 1.50 0 0 COMPZ WHDBO THGR P Remove tubing hanger installation plate. Install hydraulic remote valve and conduct integrity test on TEC wire and ESP. Install 4"actuated valve with bleed ring and 2"actuated valves as per VETCO Rep. 11:30 15:00 3.50 0 0 COMPZ WHDBO NUND P N/U Tree,terminate TEC wire and test Tree void seals to 5000 psi for 15 minutes. 15:00 16:30 1.50 0 0 COMPZ WHDBO MPSP P Dry rod out BPV, install TWC and Test Tree. Fill stack with diesel and test Lubricator 250 psi/3500 psi for 5 minutes. 16:30 18:45 2.25 0 0 COMPZ WHDBO FRZP P Flush surface lines with diesel and test to 1500 psi. Pump 122 bbls of diesel down the IA taking returns through the tubing. Pump at 58 gpm, ICP 200 psi, FCP 480 psi. 18:45 20:00 1.25 0 0 COMPZ WHDBO FRZP P Line up and allow diesel to U-tube down the tubing for 1 hour. 20:00 22:00 2,00 0 0 COMPZ WHDBO MPSP P R/U lubricator and test to 250 psi/3500 psi. Install BPV, R/D lubricator, injection lines and hoses. 22:00 00:00 2.00 0 0 DEMOB MOVE RURD P Pump brine out the pits and ready pits for move. Rig release 2400 hrs 8/20/15 Page 40 of 40 • • NADConversion Kuparuk River Unit Kuprauk 1D Pad 1D-145 Definitive Survey Report 13 August, 2015 NAD I27 0 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 10-145 Project: Kuparuk River Unit TVD Reference: Actual:66.9+39.31 @ 106.21 usft(Doyon25) Site: Kuprauk 1D Pad MD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Well: 1 D-145 North Reference: True Wellbore: 1D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1D-145 Well Position +N/-S 0.00 usft Northing: 5,959,444.08 usft Latitude: 70° 17'59.132 N +E/-W 0.00 usft Easting: 560,670.82 usft Longitude: 149°30'31.092 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 66.90 usft Wellbore 1D-145 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 7/31/2015 19.03 80.97 57,507 Design 111145 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.31 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.31 0.00 0.00 350.00 Survey Program Date From To ' (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 100.00 1,256.00 1D-145 Srvy#1 GYD-GC-SS(1D-145) GYD-GC-SS Gyrodata gyro single shots 7/22/2015 8:4i 1,281.11 2,502.11 1D-145 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/22/2015 8:4: 2,596.79 4,709.56 1D-145 Srvy#3 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/26/2015 6:4' 4,806.99 9,398.65 1D-145 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/3/2015 9:34 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.31 0.00 0.00 39.31 -66.90 0.00 0.00 5,959,444.08 560,670.82 0.00 0.00 UNDEFINED 100.00 0.01 95.38 100.00 -6.21 0.00 0.01 5,959,444.08 560,670.83 0.02 0.00 GYD-GC-SS(1) 119.30 0.35 173.33 119.30 13.09 -0.06 0.01 5,959,444.02 560,670.83 1.80 -0.06 GYD-GC-SS(1) 20"x 34" NOT an Actual Survey 126.00 0.47 173.74 126.00 19.79 -0.11 0.02 5,959,443.97 560,670.84 1.80 -0.11 GYD-GC-SS(1) 220.00 0.76 159.61 219.99 113.78 -1.07 0.28 5,959,443.01 560,671.11 0.35 -1.11 GYD-GC-SS(1) 313.00 1.01 146.06 312.98 206.77 -2.33 0.95 5,959,441.76 560,671.79 0.35 -2.46 GYD-GC-SS(1) 406.00 1.78 127.14 405.96 299.75 -3.88 2.56 5,959,440.22 560,673.41 0.95 -4.27 GYD-GC-SS(1) 500.00 2.67 114.90 499.88 393.67 -5.69 5.71 5,959,438.44 560,676.57 1.07 -6.59 GYD-GC-SS(1) 594.00 4.19 98.13 593.72 487.51 -7.10 11.10 5,959,437.07 560,681.97 1.92 -8.91 GYD-GC-SS(1) 688.00 5.98 82.61 687.35 581.14 -6.95 19.35 5,959,437.29 560,690.23 2.39 -10.21 GYD-GC-SS(1) 8/13/2015 10:31:37AM Page 2 COMPASS 5000.1 Build 74 0 Schlumberger 411, Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-145 Project: Kuparuk River Unit TVD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Site: Kuprauk 1D Pad MD Reference: Actual:66.9+39.31 @ 106.21 usft(Doyon25) Well: 1D-145 North Reference: True Wellbore: 1D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 783.00 6.51 89.35 781.78 675.57 -6.25 29.64 5,959,438.07 560,700.51 0.95 -11.31 GYD-GC-SS(1) 878.00 8.07 105.17 876.02 769.81 -7.94 41.47 5,959,436.48 560,712.35 2.66 -15.02 GYD-GC-SS(1) 973.00 10.73 116.45 969.75 863.54 -13.62 55.83 5,959,430.91 560,726.75 3.39 -23.11 GYD-GC-SS(1) 1,067.00 10.26 122.18 1,062.18 955.97 -21.98 70.75 5,959,422.67 560,741.73 1.22 -33.93 GYD-GC-SS(1) 1,161.00 10.55 118.64 1,154.63 1,048.42 -30.56 85.38 5,959,414.21 560,756.44 0.75 -44.93 GYD-GC-SS(1) 1,256.00 13.53 119.40 1,247.53 1,141.32 -40.19 102.70 5,959,404.73 560,773.83 3.14 -57.41 GYD-GC-SS(1) 1,281.11 14.74 122.52 1,271.88 1,165.67 -43.35 107.95 5,959,401.61 560,779.11 5.69 -61.44 MWD+IFR-AK-CAZ-SC(2) 1,375.96 15.06 124.41 1,363.54 1,257.33 -56.80 128.30 5,959,388.32 560,799.56 0.61 -78.21 MWD+IFR-AK-CAZ-SC(2) 1,469.99 16.15 126.62 1,454.10 1,347.89 -71.50 148.87 5,959,373.79 560,820.25 1.32 -96.27 MWD+IFR-AK-CAZ-SC(2) 1,564.64 18.00 129.88 1,544.58 1,438.37 -88.73 170.66 5,959,356.73 560,842.18 2.20 -117.02 MWD+IFR-AK-CAZ-SC(2) 1,659.70 18.38 132.06 1,634.89 1,528.68 -108.19 193.06 5,959,337.46 560,864.73 0.82 -140.07 MWD+IFR-AK-CAZ-SC(2) 1,754.17 19.55 136.27 1,724.24 1,618.03 -129.59 215.05 5,959,316.24 560,886.88 1.90 -164.97 MWD+IFR-AK-CAZ-SC(2) 1,849.18 25.23 142.64 1,812.06 1,705.85 -157.20 238.34 5,959,288.82 560,910.40 6.49 -196.20 MWD+IFR-AK-CAZ-SC(2) 1,943.54 24.04 145.16 1,897.83 1,791.62 -188.96 261.53 5,959,257.25 560,933.84 1.68 -231.51 MWD+IFR-AK-CAZ-SC(2) 2,037.74 22.96 146.40 1,984.22 1,878.01 -220.02 282.66 5,959,226.37 560,955.22 1.26 -265.76 MWD+IFR-AK-CAZ-SC(2) 2,131.71 19.54 139.38 2,071.80 1,965.59 -247.22 303.04 5,959,199.34 560,975.82 4.53 -296.09 MWD+IFR-AK-CAZ-SC(2) 2,227.67 18.00 138.32 2,162.65 2,056.44 -270.48 323.35 5,959,176.25 560,996.31 1.64 -322.52 MWD+IFR-AK-CAZ-SC(2) 2,322.91 17.23 125.92 2,253.46 2,147.25 -289.75 344.57 5,959,157.15 561,017.68 4.01 -345.18 MWD+IFR-AK-CAZ-SC(2) 2,418.21 16.62 117.19 2,344.65 2,238.44 -304.26 368.12 5,959,142.83 561,041.35 2.74 -363.56 MWD+IFR-AK-CAZ-SC(2) 2,502.11 14.16 105.12 2,425.55 2,319.34 -312.42 388.71 5,959,134.83 561,062.00 4.80 -375.18 MWD+IFR-AK-CAZ-SC(2) 2,564.00 13.65 98.16 2,485.63 2,379.42 -315.44 403.25 5,959,131.94 561,076.57 2.82 -380.67 MWD+IFR-AK-CAZ-SC(3) NOT an Actual Survey 13-3/8"x 16" 2,596.79 13.47 94.30 2,517.51 2,411.30 -316.27 410.89 5,959,131.17 561,084.21 2.82 -382.82 MWD+IFR-AK-CAZ-SC(3) 2,656.93 15.33 85.48 2,575.76 2,469.55 -316.17 425.81 5,959,131.39 561,099.12 4.77 -385.31 MWD+IFR-AK-CAZ-SC(3) 2,752.83 17.42 56.40 2,667.92 2,561.71 -307.21 450.44 5,959,140.54 561,123.69 8.72 -380.76 MWD+IFR-AK-CAZ-SC(3) 2,846.94 20.09 40.18 2,757.09 2,650.88 -287.05 472.62 5,959,160.88 561,145.70 6.20 -364.76 MWD+IFR-AK-CAZ-SC(3) 2,941.95 20.21 29.55 2,846.31 2,740.10 -260.30 491.25 5,959,187.78 561,164.11 3.85 -341.65 MWD+IFR-AK-CAZ-SC(3) 3,036.87 22.06 15.12 2,934.91 2,828.70 -228.80 504.00 5,959,219.38 561,176.60 5.80 -312.84 MWD+IFR-AK-CAZ-SC(3) 3,131.39 28.38 8.34 3,020.39 2,914.18 -189.39 511.90 5,959,258.84 561,184.18 7.34 -275.41 MWD+IFR-AK-CAZ-SC(3) 3,224.82 32.94 6.61 3,100.74 2,994.53 -142.16 518.04 5,959,306.12 561,189.94 4.97 -229.96 MWD+IFR-AK-CAZ-SC(3) 3,320.60 35.88 2.74 3,179.76 3,073.55 -88.24 522.38 5,959,360.07 561,193.85 3.82 -177.61 MWD+IFR-AK-CAZ-SC(3) 3,415.83 39.45 359.71 3,255.14 3,148.93 -30.09 523.57 5,959,418.22 561,194.56 4.22 -120.55 MWD+IFR-AK-CAZ-SC(3) 3,510.04 45.72 357.64 3,324.47 3,218.26 33.60 522.02 5,959,481.89 561,192.51 6.82 -57.56 MWD+IFR-AK-CAZ-SC(3) 3,603.86 47.75 357.64 3,388.77 3,282.56 101.86 519.21 5,959,550.12 561,189.14 2.16 10.15 MWD+IFR-AK-CAZ-SC(3) 3,698.68 55.20 353.54 3,447.80 3,341.59 175.73 513.38 5,959,623.93 561,182.71 8.55 83.91 MWD+IFR-AK-CAZ-SC(3) 3,733.44 57.38 352.36 3,467.09 3,360.88 204.42 509.82 5,959,652.59 561,178.93 6.88 112.79 MWD+IFR-AK-CAZ-SC(3) 3,793.18 57.65 352.16 3,499.18 3,392.97 254.36 503.04 5,959,702.47 561,171.74 0.53 163.14 MWD+IFR-AK-CAZ-SC(3) 3,887.98 58.01 351.21 3,549.66 3,443.45 333.76 491.43 5,959,781.76 561,159.49 0.93 243.35 MWD+IFR-AK-CAZ-SC(3) 3,980.52 61.18 349.64 3,596.49 3,490.28 412.44 478.14 5,959,860.33 561,145.57 3.72 323.15 MWD+IFR-AK-CAZ-SC(3) 4,072.68 66.78 351.78 3,636.90 3,530.69 494.14 464.81 5,959,941.91 561,131.58 6.42 405.92 MWD+IFR-AK-CAZ-SC(3) 4,165.06 73.20 352.05 3,668.50 3,562.29 580.04 452.61 5,960,027.70 561,118.69 6.95 492.63 MWD+IFR-AK-CAZ-SC(3) 8/13/2015 10:31:37AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-145 Project: Kuparuk River Unit TVD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Site: Kuprauk 1D Pad MD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Well: 1D-145 North Reference: True Wellbore: 1D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 4,257.17 75.27 352.65 3,693.52 3,587.31 667.89 440.82 5,960,115.44 561,106.19 2.33 581.20 MWD+IFR-AK-CAZ-SC(3) 4,348.56 78.31 353.65 3,714.41 3,608.20 756.22 430.21 5,960,203.67 561,094.87 3.49 670.02 MWD+IFR-AK-CAZ-SC(3) 4,442.95 83.81 352.67 3,729.07 3,622.86 848.76 419.11 5,960,296.11 561,083.02 5.92 763.09 MWD+IFR-AK-CAZ-SC(3) 4,534.65 87.30 351.76 3,736.17 3,629.96 939.32 406.72 5,960,386.57 561,069.91 3.93 854.43 MWD+IFR-AK-CAZ-SC(3) 4,626.86 84.85 351.35 3,742.49 3,636.28 1,030.31 393.21 5,960,477.44 561,055.66 2.69 946.38 MWD+IFR-AK-CAZ-SC(3) 4,709.56 85.67 351.52 3,749.32 3,643.11 1,111.81 380.94 5,960,558.82 561,042.73 1.01 1,028.77 MWD+IFR-AK-CAZ-SC(3) 4,771.60 85.55 352.71 3,754.07 3,647.86 1,173.08 372.45 5,960,620.02 561 033.75 1.92 1,090.58 MWD+IFR-AK-CAZ-SC(4) 9 5/8"X 12-1/4 NOT an Mint Survey 4,806.99 85.48 353.39 3,756.84 3,650.63 1,208.10 368.18 5,960,655.00 561,029.20 1.92 1,125.82 MWD+IFR-AK-CAZ-SC(4) 4,901.86 87.59 353.18 3,762.57 3,656.36 1,302.15 357.11 5,960,748.94 561,017.37 2.24 1,220.35 MWD+IFR-AK-CAZ-SC(4) 4,993.32 90.46 351.79 3,764.13 3,657.92 1,392.80 345.15 5,960,839.48 561,004.68 3.49 1,311.70 MWD+IFR-AK-CAZ-SC(4) 5,091.30 91.44 350.99 3,762.50 3,656.29 1,489.66 330.49 5,960,936.21 560,989.24 1.29 1,409.64 MWD+IFR-AK-CAZ-SC(4) 5,185.96 91.42 350.62 3,760.14 3,653.93 1,583.07 315.37 5,961,029.49 560,973.36 0.39 1,504.26 MWD+IFR-AK-CAZ-SC(4) 5,282.01 89.32 350.36 3,759.52 3,653.31 1,677.79 299.50 5,961,124.08 560,956.73 2.20 1,600.30 MWD+IFR-AK-CAZ-SC(4) 5,376.54 90.00 349.85 3,760.08 3,653.87 1,770.91 283.25 5,961,217.05 560,939.74 0.90 1,694.82 MWD+IFR-AK-CAZ-SC(4) 5,472.31 90.41 349.96 3,759.74 3,653.53 1,865.20 266.47 5,961,311.19 560,922.19 0.44 1,790.59 MWD+IFR-AK-CAZ-SC(4) 5,566.51 90.13 348.63 3,759.29 3,653.08 1,957.76 248.97 5,961,403.60 560,903.95 1.44 1,884.78 MWD+IFR-AK-CAZ-SC(4) 5,661.44 89.23 347.02 3,759.82 3,653.61 2,050.55 228.95 5,961,496.21 560,883.19 1.94 1,979.64 MWD+IFR-AK-CAZ-SC(4) 5,756.32 89.48 344.12 3,760.89 3,654.68 2,142.42 205.31 5,961,587.88 560,858.81 3.07 2,074.22 MWD+IFR-AK-CAZ-SC(4) 5,852.00 90.03 341.05 3,761.30 3,655.09 2,233.70 176.68 5,961,678.92 560,829.44 3.26 2,169.09 MWD+IFR-AK-CAZ-SC(4) 5,945.89 89.89 340.06 3,761.37 3,655.16 2,322.23 145.42 5,961,767.19 560,797.48 1.06 2,261.70 MWD+IFR-AK-CAZ-SC(4) 6,041.27 90.46 342.62 3,761.08 3,654.87 2,412.59 114.91 5,961,857.29 560,766.24 2.75 2,355.99 MWD+IFR-AK-CAZ-SC(4) 6,136.35 87.85 344.51 3,762.48 3,656.27 2,503.77 88.01 5,961,948.23 560,738.61 3.39 2,450.44 MWD+IFR-AK-CAZ-SC(4) 6,231.57 88.04 346.87 3,765.89 3,659.68 2,595.97 64.49 5,962,040.23 560,714.35 2.48 2,545.33 MWD+IFR-AK-CAZ-SC(4) 6,327.18 88.76 351.26 3,768.56 3,662.35 2,689.78 46.37 5,962,133.89 560,695.47 4.65 2,640.86 MWD+IFR-AK-CAZ-SC(4) 6,421.41 88.08 353.29 3,771.16 3,664.95 2,783.11 33.71 5,962,227.11 560,682.06 2.27 2,734.98 MWD+IFR-AK-CAZ-SC(4) 6,515.65 85.87 354.42 3,776.14 3,669.93 2,876.67 23.64 5,962,320.57 560,671.23 2.63 2,828.87 MWD+IFR-AK-CAZ-SC(4) 6,610.36 87.88 353.25 3,781.30 3,675.09 2,970.69 13.48 5,962,414.50 560,660.31 2.45 2,923.22 MWD+IFR-AK-CAZ-SC(4) 6,704.80 88.01 353.88 3,784.69 3,678.48 3,064.47 2.90 5,962,508.18 560,648.98 0.68 3,017.41 MWD+IFR-AK-CAZ-SC(4) 6,800.15 87.40 356.97 3,788.50 3,682.29 3,159.43 -4.70 5,962,603.07 560,640.62 3.30 3,112.25 MWD+IFR-AK-CAZ-SC(4) 6,894.31 89.32 358.36 3,791.20 3,684.99 3,253.47 -8.53 5,962,697.06 560,636.02 2.52 3,205.52 MWD+IFR-AK-CAZ-SC(4) 6,989.57 89.55 358.56 3,792.14 3,685.93 3,348.69 -11.09 5,962,792.25 560,632.70 0.32 3,299.74 MWD+IFR-AK-CAZ-SC(4) 7,085.32 89.52 358.52 3,792.92 3,686.71 3,444.40 -13.53 5,962,887.93 560,629.48 0.05 3,394.43 MWD+IFR-AK-CAZ-SC(4) 7,179.48 89.93 0.00 3,793.37 3,687.16 3,538.55 -14.75 5,962,982.06 560,627.51 1.63 3,487.35 MWD+IFR-AK-CAZ-SC(4) 7,273.67 89.23 1.88 3,794.06 3,687.85 3,632.72 -13.20 5,963,076.23 560,628.29 2.13 3,579.83 MWD+IFR-AK-CAZ-SC(4) 7,368.58 89.89 5.05 3,794.79 3,688.58 3,727.44 -7.47 5,963,170.98 560,633.26 3.41 3,672.11 MWD+IFR-AK-CAZ-SC(4) 7,463.65 90.68 6.48 3,794.31 3,688.10 3,822.03 2.08 5,963,265.63 560,642.05 1.72 3,763.60 MWD+IFR-AK-CAZ-SC(4) 7,559.16 90.31 6.87 3,793.49 3,687.28 3,916.89 13.18 5,963,360.57 560,652.38 0.56 3,855.09 MWD+IFR-AK-CAZ-SC(4) 7,653.94 90.31 4.33 3,792.98 3,686.77 4,011.21 22.43 5,963,454.95 560,660.87 2.68 3,946.37 MWD+IFR-AK-CAZ-SC(4) 7,748.49 90.58 0.01 3,792.24 3,686.03 4,105.66 26.01 5,963,549.43 560,663.68 4.58 4,038.77 MWD+IFR-AK-CAZ-SC(4) 8/13/2015 10:31:37AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-145 Project: Kuparuk River Unit TVD Reference: Actual:66.9+39.31 @ 106.21 usft(Doyon25) Site: Kuprauk 1D Pad MD Reference: Actual:66.9+39.31 @ 106.21 usft(Doyon25) Well: 1D-145 North Reference: True Wellbore: 1 D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,843.17 90.79 355.97 3,791.11 3,684.90 4,200.26 22.69 5,963,643.98 560,659.60 4.27 4,132.51 MWD+IFR-AK-CAZ-SC(4) 7,937.82 90.61 356.11 3,789.95 3,683.74 4,294.67 16.16 5,963,738.33 560,652.30 0.24 4,226.62 MWD+IFR-AK-CAZ-SC(4) 8,032.53 90.48 355.77 3,789.05 3,682.84 4,389.14 9.45 5,963,832.74 560,644.83 0.38 4,320.82 MWD+IFR-AK-CAZ-SC(4) 8,128.16 90.79 356.68 3,787.99 3,681.78 4,484.56 3.15 5,963,928.09 560,637.77 1.01 4,415.88 MWD+IFR-AK-CAZ-SC(4) 8,222.67 89.54 359.01 3,787.72 3,681.51 4,578.99 -0.40 5,964,022.48 560,633.45 2.80 4,509.50 MWD+IFR-AK-CAZ-SC(4) 8,317.49 90.17 358.74 3,787.96 3,681.75 4,673.79 -2.26 5,964,117.25 560,630.83 0.72 4,603.18 MWD+IFR-AK-CAZ-SC(4) 8,411.81 90.03 0.53 3,787.79 3,681.58 4,768.11 -2.86 5,964,211.55 560,629.46 1.90 4,696.17 MWD+IFR-AK-CAZ-SC(4) 8,507.11 89.38 3.07 3,788.29 3,682.08 4,863.35 0.13 5,964,306.81 560,631.69 2.75 4,789.44 MWD+IFR-AK-CAZ-SC(4) 8,601.65 88.72 3.42 3,789.85 3,683.64 4,957.73 5.48 5,964,401.21 560,636.28 0.79 4,881.45 MWD+IFR-AK-CAZ-SC(4) 8,696.67 89.17 6.51 3,791.60 3,685.39 5,052.36 13.70 5,964,495.90 560,643.73 3.29 4,973.22 MWD+IFR-AK-CAZ-SC(4) 8,791.33 89.72 9.64 3,792.52 3,686.31 5,146.07 27.00 5,964,589.70 560,656.27 3.36 5,063.20 MWD+IFR-AK-CAZ-SC(4) 8,886.34 89.62 12.42 3,793.07 3,686.86 5,239.31 45.17 5,964,683.08 560,673.69 2.93 5,151.87 MWD+IFR-AK-CAZ-SC(4) 8,981.58 89.79 14.40 3,793.56 3,687.35 5,331.95 67.26 5,964,775.89 560,695.03 2.09 5,239.26 MWD+IFR-AK-CAZ-SC(4) 9,075.64 89.72 15.86 3,793.96 3,687.75 5,422.74 91.81 5,964,866.87 560,718.84 1.55 5,324.42 MWD+IFR-AK-CAZ-SC(4) 9,172.02 89.52 15.48 3,794.60 3,688.39 5,515.54 117.84 5,964,959.86 560,744.12 0.45 5,411.28 MWD+IFR-AK-CAZ-SC(4) 9,266.50 89.52 15.02 3,795.39 3,689.18 5,606.69 142.69 5,965,051.20 560,768.23 0.49 5,496.73 MWD+IFR-AK-CAZ-SC(4) 9,361.98 89.52 16.53 3,796.19 3,689.98 5,698.57 168.65 5,965,143.28 560,793.44 1.58 5,582.71 MWD+IFR-AK-CAZ-SC(4) 9,398.65 89.48 17.10 3,796.51 3,690.30 5,733.67 179.25 5,965,178.46 560,803.76 1.56 5,615.43 MWD+IFR-AK-CAZ-SC(4) 9,463.00 89.48 17.10 3,797.09 3,690.88 5,795.17 198.18 5,965,240.11 560,822.18 0.00 5,672.72 PROJECTED to TD 8/13/2015 10:31:37AM Page 5 COMPASS 5000.1 Build 74 tr as • i Cement Detail Report 1D-145 Corxxc Phillips String: Surface casing cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface casing cement 7/23/2015 16:55 7/24/2015 05:00 1D-145 Comment Stage 1; 1228 sx 11.0 ppg Lead. 233 sx 12 ppg Tail Stage 2; 163 sx 11.1 ppg Lead. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface casing cement Cement surface casing 442.0 2,574.0 No 0.0 Yes Yes 0 Pump!nit(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) 5 3 5 148.0 288.0 Yes 30.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pumped cement job per plan and got no returns to surface. Swap pumping to SLB and pump cement per schedule. Pump 5 BBL water and PT surface lines to 4000 psi. Pump 75.3 BBLs of CW100 at 5.5 BPM with 170 psi, Pump 73.2 BBL MudPushll 10.5 ppg at 6.8 BPM with 240 psi,While batching,drop bottom plug at 14:33 hours. Pump 432.1 BBL of Lead cement11.0 ppg at 7 BPM with 290 psi; FCP=259 psi at 7 BPM. Batch and pump 68.9 BBL of 12.0 ppg Tail cement at 4.6 BPM with150 psi. PU=235K, SO=146K. Drop top plug and kick out with 10 BBL of water. Reciprocate pipe throughout job with full returns. Swap to rig pumps and chase cement with mud. Bump plug on calculated strokes, held 500 psi over FCP and floats held with no cement returns to surface. From displacement calculated TOC at 120'. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 442.0 2,072.0 1,270 G 432.2 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.83 11.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.07 gal/sx Additive Type Concentration Conc Unit label Retarder D177 0.02 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,072.0 2,574.0 234 G 68.2 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.63 5.48 12.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D185 0.06 gal/sx Additive Type Concentration Conc Unit label Acelerator D186 0.03 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Top Job cement Bring cement to surface 44.3 442.0 No 17.1 No No Q Pump!nit(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) 1 1 1 250.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Run 3/4"top job string into conductor to 130'. No more depth could be obtained. Flushed conductor with 40 BBL water until 8.6 returns were weighed and good flow out on returns. Pumped 40 BBL Lead 11.1 ppg cement before returns were seen at surface. At 55 BBL 11.1 ppg cement was seen at the surface. 57.1 BBL pumped total to clear hopper of cements. Cement measured at 34"from top of conductor. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 43.5 442.0 167 G 57.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.83 11.00 7.25 Page 1/2 Report Printed: 9/17/2015 • • Cement Detail Report 41, 1D-145 ConocoPhillips String: Surface casing cement Job: Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.07 gal/sx Additive Type Concentration Conc Unit label Retarder D177 0.02 gal/sx Page 2/2 Report Printed: 9/17/2015 i • Cement Detail Report itio 11,79: gra I 1D-145 ConocoPhiii ps String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 7/28/2015 20:15 7/28/2015 22.45 1D-145 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 2,914.0 4,782.0 Yes 151.7 Yes Yes Cement Q Pump!nit(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) 6 3 5 670.0 460.0 Yes 18.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 4,676.9 Drill Bit 4,804.0 8 3/4 Comment Pump cement per program with SLB pumps; Pump 5.5 BBL of Mudpush and test lines to 4000 psi. Open and pump 44.6 BBL of 10.5 ppg MPII at 6.6 BPM with 350 psi, 19%FO to total 50.1 BBL of MPII pumped. Drop bottom plug,atch and pump 45.8 BBL of 15.8 ppg Lead cement at 5.5 BPm with 85 psi, 19%FO. Batch and pump 105.9 BBL of 15.8 ppg Tail cement with GasBlok at 6.5 BPM with195 psi,23%FO. Drop top plug and kick out with 10 BBL of MP. SLB chases with 9.9 ppg OBM at 5.9 BPM with FCP of 900 psi, 18%FO. Slow pump rate to 3 BPM at 335 BBL of OBM away. Pump total of 348.9 BBL of OBM chase without bumping plug. Check floats;Good. CIP at 2225 hours. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 2,914.0 3,500.0 222 G 45.8 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.10 15.80 12.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.04 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 3,500.0 4,782.0 508 G 105.9 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.22 15.80 5.00 Additives Additive Type Concentration Conc Unit label Gas Block 600G 1.0 gal/sx Additive Type Concentration Conc Unit label Antifoam D046 0.1 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.35 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.1 gal/sx Page 1/1 Report Printed: 9/17/2015 0 • 21 41 38 - 26139 GEI ` - SchlumbergerG 2 o Zui Drilling & Measurements Transmittal#: 20AUG15-SP03 DATA LOGGED MWD/LWD LogProduct Delivery %/2u2o,g M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1D-145 Date Dispatched: 20-Aug-15 Job#: 15AKA0096 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2"TVD x x VISION*Service 5" MD x x VISION*Service 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:DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a�conocophillips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 6..„,„g2t,Received By: V REC I r '214138 • Au 020E5 26139 AOGCC FINAL NADConversion Kuparuk River Unit Kuprauk 1D Pad 1D-145 Definitive Survey Report 13 August, 2015 NAD 27 1 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-145 Project: Kuparuk River Unit TVD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Site: Kuprauk 1D Pad MD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Well: 1 D-145 North Reference: True Wellbore: 1D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1D-145 Well Position +N/-S 0.00 usft Northing: 5,959,444.08 usft Latitude: 70°17'59.132 N +E/-W 0.00 usft Easting: 560,670.82 usft Longitude: 149°30'31.092 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usfl Ground Level: 66.90usft Wellbore 1D-145 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 7/31/2015 19.03 80.97 57,507 Design 1D-145 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.31 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 39.31 0.00 0.00 350.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 100.00 1,256.00 1D-145 Srvy#1 GYD-GC-SS(1 D-145) GYD-GC-SS Gyrodata gyro single shots 7/22/2015 8:41 1,281.11 2,502.11 1D-145 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/22/2015 8:4: 2,596.79 4,709.56 1D-145 Srvy#3 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/26/2015 6:4 4,806.99 9,398.65 1 D-145 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/3/2015 9:34 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 39.31 0.00 0.00 39.31 -66.90 0.00 0.00 5,959,444.08 560,670.82 0.00 0.00 UNDEFINED 100.00 0.01 95.38 100.00 -6.21 0.00 0.01 5,959,444.08 560,670.83 0.02 0.00 GYD-GC-SS(1) 119.30 0.35 173.33 119.30 13.09 -0.06 0.01 5,959,444.02 560,670.83 1.80 -0.06 GYD-GC-SS(1) NOT m Actual Suety 20"x 34" 126.00 0.47 173.74 126.00 19.79 -0.11 0.02 5,959,443.97 560,670.84 1.80 -0.11 GYD-GC-SS(1) 220.00 0.76 159.61 219.99 113.78 -1.07 0.28 5,959,443.01 560,671.11 0.35 -1.11 GYD-GC-SS(1) 313.00 1.01 146.06 312.98 206.77 -2.33 0.95 5,959,441.76 560,671.79 0.35 -2.46 GYD-GC-SS(1) 406.00 1.78 127.14 405.96 299.75 -3.88 2.56 5,959,440.22 560,673.41 0.95 -4.27 GYD-GC-SS(1) 500.00 2.67 114.90 499.88 393.67 -5.69 5.71 5,959,438.44 560,676.57 1.07 -6.59 GYD-GC-SS(1) 594.00 4.19 98.13 593.72 487.51 -7.10 11.10 5,959,437.07 560,681.97 1.92 -8.91 GYD-GC-SS(1) 688.00 5.98 82.61 687.35 581.14 -6.95 19.35 5,959,437.29 560,690.23 2.39 -10.21 GYD-GC-SS(1) 8/13/2015 10:31:37AM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-145 Project: Kuparuk River Unit TVD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Site: Kuprauk 1D Pad MD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Well: 1D-145 North Reference: True Wellbore: 1 D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 783.00 6.51 89.35 781.78 675.57 -6.25 29.64 5,959,438.07 560,700.51 0.95 -11.31 GYD-GC-SS(1) 878.00 8.07 105.17 876.02 769.81 -7.94 41.47 5,959,436.48 560,712.35 2.66 -15.02 GYD-GC-SS(1) 973.00 10.73 116.45 969.75 863.54 -13.62 55.83 5,959,430.91 560,726.75 3.39 -23.11 GYD-GC-SS(1) 1,067.00 10.26 122.18 1,062.18 955.97 -21.98 70.75 5,959,422.67 560,741.73 1.22 -33.93 GYD-GC-SS(1) 1,161.00 10.55 118.64 1,154.63 1,048.42 -30.56 85.38 5,959,414.21 560,756.44 0.75 -44.93 GYD-GC-SS(1) 1,256.00 13.53 119.40 1,247.53 1,141.32 -40.19 102.70 5,959,404.73 560,773.83 3.14 -57.41 GYD-GC-SS(1) 1,281.11 14.74 122.52 1,271.88 1,165.67 -43.35 107.95 5,959,401.61 560,779.11 5.69 -61.44 MWD+IFR-AK-CAZ-SC(2) 1,375.96 15.06 124.41 1,363.54 1,257.33 -56.80 128.30 5,959,388.32 560,799.56 0.61 -78.21 MWD+IFR-AK-CAZ-SC(2) 1,469.99 16.15 126.62 1,454.10 1,347.89 -71.50 148.87 5,959,373.79 560,820.25 1.32 -96.27 MWD+IFR-AK-CAZ-SC(2) 1,564.64 18.00 129.88 1,544.58 1,438.37 -88.73 170.66 5,959,356.73 560,842.18 2.20 -117.02 MWD+IFR-AK-CAZ-SC(2) 1,659.70 18.38 132.06 1,634.89 1,528.68 -108.19 193.06 5,959,337.46 560,864.73 0.82 -140.07 MWD+IFR-AK-CAZ-SC(2) 1,754.17 19.55 136.27 1,724.24 1,618.03 -129.59 215.05 5,959,316.24 560,886.88 1.90 -164.97 MWD+IFR-AK-CAZ-SC(2) 1,849.18 25.23 142.64 1,812.06 1,705.85 -157.20 238.34 5,959,288.82 560,910.40 6.49 -196.20 MWD+IFR-AK-CAZ-SC(2) 1,943.54 24.04 145.16 1,897.83 1,791.62 -188.96 261.53 5,959,257.25 560,933.84 1.68 -231.51 MWD+IFR-AK-CAZ-SC(2) 2,037.74 22.96 146.40 1,984.22 1,878.01 -220.02 282.66 5,959,226.37 560,955.22 1.26 -265.76 MWD+IFR-AK-CAZ-SC(2) 2,131.71 19.54 139.38 2,071.80 1,965.59 -247.22 303.04 5,959,199.34 560,975.82 4.53 -296.09 MWD+IFR-AK-CAZ-SC(2) 2,227.67 18.00 138.32 2,162.65 2,056.44 -270.48 323.35 5,959,176.25 560,996.31 1.64 -322.52 MWD+IFR-AK-CAZ-SC(2) 2,322.91 17.23 125.92 2,253.46 2,147.25 -289.75 344.57 5,959,157.15 561,017.68 4.01 -345.18 MWD+IFR-AK-CAZ-SC(2) 2,418.21 16.62 117.19 2,344.65 2,238.44 -304.26 368.12 5,959,142.83 561,041.35 2.74 -363.56 MWD+IFR-AK-CAZ-SC(2) 2,502.11 14.16 105.12 2,425.55 2,319.34 -312.42 388.71 5,959,134.83 561,062.00 4.80 -375.18 MWD+IFR-AK-CAZ-SC(2) 2,564.00 13.65 98.16 2,485.63 2,379.42 -315.44 403.25 5,959,131.94 561,076.57 2.82 -380.67 MWD+IFR-AK-CAZ-SC(3) NOT.nA 13-3/8"x 16" W Survey 2,596.79 13.47 94.30 2,517.51 2,411.30 -316.27 410.89 5,959,131.17 561,084.21 2.82 -382.82 MWD+IFR-AK-CAZ-SC(3) 2,656.93 15.33 85.48 2,575.76 2,469.55 -316.17 425.81 5,959,131.39 561,099.12 4.77 -385.31 MWD+IFR-AK-CAZ-SC(3) 2,752.83 17.42 56.40 2,667.92 2,561.71 -307.21 450.44 5,959,140.54 561,123.69 8.72 -380.76 MWD+IFR-AK-CAZ-SC(3) 2,846.94 20.09 40.18 2,757.09 2,650.88 -287.05 472.62 5,959,160.88 561,145.70 6.20 -364.76 MWD+IFR-AK-CAZ-SC(3) 2,941.95 20.21 29.55 2,846.31 2,740.10 -260.30 491.25 5,959,187.78 561,164.11 3.85 -341.65 MWD+IFR-AK-CAZ-SC(3) 3,036.87 22.06 15.12 2,934.91 2,828.70 -228.80 504.00 5,959,219.38 561,176.60 5.80 -312.84 MWD+IFR-AK-CAZ-SC(3) 3,131.39 28.38 8.34 3,020.39 2,914.18 -189.39 511.90 5,959,258.84 561,184.18 7.34 -275.41 MWD+IFR-AK-CAZ-SC(3) 3,224.82 32.94 6.61 3,100.74 2,994.53 -142.16 518.04 5,959,306.12 561,189.94 4.97 -229.96 MWD+IFR-AK-CAZ-SC(3) 3,320.60 35.88 2.74 3,179.76 3,073.55 -88.24 522.38 5,959,360.07 561,193.85 3.82 -177.61 MWD+IFR-AK-CAZ-SC(3) 3,415.83 39.45 359.71 3,255.14 3,148.93 -30.09 523.57 5,959,418.22 561,194.56 4.22 -120.55 MWD+IFR-AK-CAZ-SC(3) 3,510.04 45.72 357.64 3,324.47 3,218.26 33.60 522.02 5,959,481.89 561,192.51 6.82 -57.56 MWD+IFR-AK-CAZ-SC(3) 3,603.86 47.75 357.64 3,388.77 3,282.56 101.86 519.21 5,959,550.12 561,189.14 2.16 10.15 MWD+IFR-AK-CAZ-SC(3) 3,698.68 55.20 353.54 3,447.80 3,341.59 175.73 513.38 5,959,623.93 561,182.71 8.55 83.91 MWD+IFR-AK-CAZ-SC(3) 3,733.44 57.38 352.36 3,467.09 3,360.88 204.42 509.82 5,959,652.59 561,178.93 6.88 112.79 MWD+IFR-AK-CAZ-SC(3) 3,793.18 57.65 352.16 3,499.18 3,392.97 254.36 503.04 5,959,702.47 561,171.74 0.53 163.14 MWD+IFR-AK-CAZ-SC(3) 3,887.98 58.01 351.21 3,549.66 3,443.45 333.76 491.43 5,959,781.76 561,159.49 0.93 243.35 MWD+IFR-AK-CAZ-SC(3) 3,980.52 61.18 349.64 3,596.49 3,490.28 412.44 478.14 5,959,860.33 561,145.57 3.72 323.15 MWD+IFR-AK-CAZ-SC(3) 4,072.68 66.78 351.78 3,636.90 3,530.69 494.14 464.81 5,959,941.91 561,131.58 6.42 405.92 MWD+IFR-AK-CAZ-SC(3) 4,165.06 73.20 352.05 3,668.50 3,562.29 580.04 452.61 5,960,027.70 561,118.69 6.95 492.63 MWD+IFR-AK-CAZ-SC(3) 8/13/2015 10:31:37AM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-145 Project: Kuparuk River Unit TVD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Site: Kuprauk 1D Pad MD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Well: 1D-145 North Reference: True Wellbore: 1 D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,257.17 75.27 352.65 3,693.52 3,587.31 667.89 440.82 5,960,115.44 561,106.19 2.33 581.20 MWD+IFR-AK-CAZ-SC(3) 4,348.56 78.31 353.65 3,714.41 3,608.20 756.22 430.21 5,960,203.67 561,094.87 3.49 670.02 MWD+IFR-AK-CAZ-SC(3) 4,442.95 83.81 352.67 3,729.07 3,622.86 848.76 419.11 5,960,296.11 561,083.02 5.92 763.09 MWD+IFR-AK-CAZ-SC(3) 4,534.65 87.30 351.76 3,736.17 3,629.96 939.32 406.72 5,960,386.57 561,069.91 3.93 854.43 MWD+IFR-AK-CAZ-SC(3) 4,626.86 84.85 351.35 3,742.49 3,636.28 1,030.31 393.21 5,960,477.44 561,055.66 2.69 946.38 MWD+IFR-AK-CAZ-SC(3) 4,709.56 85.67 351.52 3,749.32 3,643.11 1,111.81 380.94 5,960,558.82 561,042.73 1.01 1,028.77 MWD+IFR-AK-CAZ-SC(3) 4,771.60 85.55 352.71 3,754.07 3,647.86 1,173.08 372.45 5,960,620.02 561,033.75 1.92 1,090.58 MW D+I FR-AK-CAZ-SC(4) NOT an Acta survey 9 518"x 12-1/4 4,806.99 85.48 353.39 3,756.84 3,650.63 1,208.10 368.18 5,960,655.00 561,029.20 1.92 1,125.82 MWD+IFR-AK-CAZ-SC(4) 4,901.86 87.59 353.18 3,762.57 3,656.36 1,302.15 357.11 5,960,748.94 561,017.37 2.24 1,220.35 MWD+IFR-AK-CAZ-SC(4) 4,993.32 90.46 351.79 3,764.13 3,657.92 1,392.80 345.15 5,960,839.48 561,004.68 3.49 1,311.70 MWD+IFR-AK-CAZ-SC(4) 5,091.30 91.44 350.99 3,762.50 3,656.29 1,489.66 330.49 5,960,936.21 560,989.24 1.29 1,409.64 MWD+IFR-AK-CAZ-SC(4) 5,185.96 91.42 350.62 3,760.14 3,653.93 1,583.07 315.37 5,961,029.49 560,973.36 0.39 1,504.26 MWD+IFR-AK-CAZ-SC(4) 5,282.01 89.32 350.36 3,759.52 3,653.31 1,677.79 299.50 5,961,124.08 560,956.73 2.20 1,600.30 MWD+IFR-AK-CAZ-SC(4) 5,376.54 90.00 349.85 3,760.08 3,653.87 1,770.91 283.25 5,961,217.05 560,939.74 0.90 1,694.82 MWD+IFR-AK-CAZ-SC(4) 5,472.31 90.41 349.96 3,759.74 3,653.53 1,865.20 266.47 5,961,311.19 560,922.19 0.44 1,790.59 MWD+IFR-AK-CAZ-SC(4) 5,566.51 90.13 348.63 3,759.29 3,653.08 1,957.76 248.97 5,961,403.60 560,903.95 1.44 1,884.78 MWD+IFR-AK-CAZ-SC(4) 5,661.44 89.23 347.02 3,759.82 3,653.61 2,050.55 228.95 5,961,496.21 560,883.19 1.94 1,979.64 MWD+IFR-AK-CAZ-SC(4) 5,756.32 89.48 344.12 3,760.89 3,654.68 2,142.42 205.31 5,961,587.88 560,858.81 3.07 2,074.22 MWD+IFR-AK-CAZ-SC(4) 5,852.00 90.03 341.05 3,761.30 3,655.09 2,233.70 176.68 5,961,678.92 560,829.44 3.26 2,169.09 MWD+IFR-AK-CAZ-SC(4) 5,945.89 89.89 340.06 3,761.37 3,655.16 2,322.23 145.42 5,961,767.19 560,797.48 1.06 2,261.70 MWD+IFR-AK-CAZ-SC(4) 6,041.27 90.46 342.62 3,761.08 3,654.87 2,412.59 114.91 5,961,857.29 560,766.24 2.75 2,355.99 MWD+IFR-AK-CAZ-SC(4) 6,136.35 87.85 344.51 3,762.48 3,656.27 2,503.77 88.01 5,961,948.23 560,738.61 3.39 2,450.44 MWD+IFR-AK-CAZ-SC(4) 6,231.57 88.04 346.87 3,765.89 3,659.68 2,595.97 64.49 5,962,040.23 560,714.35 2.48 2,545.33 MWD+IFR-AK-CAZ-SC(4) 6,327.18 88.76 351.26 3,768.56 3,662.35 2,689.78 46.37 5,962,133.89 560,695.47 4.65 2,640.86 MWD+IFR-AK-CAZ-SC(4) 6,421.41 88.08 353.29 3,771.16 3,664.95 2,783.11 33.71 5,962,227.11 560,682.06 2.27 2,734.98 MWD+IFR-AK-CAZ-SC(4) 6,515.65 85.87 354.42 3,776.14 3,669.93 2,876.67 23.64 5,962,320.57 560,671.23 2.63 2,828.87 MWD+IFR-AK-CAZ-SC(4) 6,610.36 87.88 353.25 3,781.30 3,675.09 2,970.69 13.48 5,962,414.50 560,660.31 2.45 2,923.22 MWD+IFR-AK-CAZ-SC(4) 6,704.80 88.01 353.88 3,784.69 3,678.48 3,064.47 2.90 5,962,508.18 560,648.98 0.68 3,017.41 MWD+IFR-AK-CAZ-SC(4) 6,800.15 87.40 356.97 3,788.50 3,682.29 3,159.43 -4.70 5,962,603.07 560,640.62 3.30 3,112.25 MWD+IFR-AK-CAZ-SC(4) 6,894.31 89.32 358.36 3,791.20 3,684.99 3,253.47 -8.53 5,962,697.06 560,636.02 2.52 3,205.52 MWD+IFR-AK-CAZ-SC(4) 6,989.57 89.55 358.56 3,792.14 3,685.93 3,348.69 -11.09 5,962,792.25 560,632.70 0.32 3,299.74 MWD+IFR-AK-CAZ-SC(4) 7,085.32 89.52 358.52 3,792.92 3,686.71 3,444.40 -13.53 5,962,887.93 560,629.48 0.05 3,394.43 MWD+IFR-AK-CAZ-SC(4) 7,179.48 89.93 0.00 3,793.37 3,687.16 3,538.55 -14.75 5,962,982.06 560,627.51 1.63 3,487.35 MWD+IFR-AK-CAZ-SC(4) 7,273.67 89.23 1.88 3,794.06 3,687.85 3,632.72 -13.20 5,963,076.23 560,628.29 2.13 3,579.83 MWD+IFR-AK-CAZ-SC(4) 7,368.58 89.89 5.05 3,794.79 3,688.58 3,727.44 -7.47 5,963,170.98 560,633.26 3.41 3,672.11 MWD+IFR-AK-CAZ-SC(4) 7,463.65 90.68 6.48 3,794.31 3,688.10 3,822.03 2.08 5,963,265.63 560,642.05 1.72 3,763.60 MWD+IFR-AK-CAZ-SC(4) 7,559.16 90.31 6.87 3,793.49 3,687.28 3,916.89 13.18 5,963,360.57 560,652.38 0.56 3,855.09 MWD+IFR-AK-CAZ-SC(4) 7,653.94 90.31 4.33 3,792.98 3,686.77 4,011.21 22.43 5,963,454.95 560,660.87 2.68 3,946.37 MWD+IFR-AK-CAZ-SC(4) 7,748.49 90.58 0.01 3,792.24 3,686.03 4,105.66 26.01 5,963,549.43 560,663.68 4.58 4,038.77 MWD+IFR-AK-CAZ-SC(4) 8/13/2015 10:31:37AM Page 4 COMPASS 5000.1 Build 74 411, • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-145 Project: Kuparuk River Unit TVD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Site: Kuprauk 10 Pad MD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Well: 1D-145 North Reference: True Wellbore: 1 D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,843.17 90.79 355.97 3,791.11 3,684.90 4,200.26 22.69 5,963,643.98 560,659.60 4.27 4,132.51 MWD+IFR-AK-CAZ-SC(4) 7,937.82 90.61 356.11 3,789.95 3,683.74 4,294.67 16.16 5,963,738.33 560,652.30 0.24 4,226.62 MWD+IFR-AK-CAZ-SC(4) 8,032.53 90.48 355.77 3,789.05 3,682.84 4,389.14 9.45 5,963,832.74 560,644.83 0.38 4,320.82 MWD+IFR-AK-CAZ-SC(4) 8,128.16 90.79 356.68 3,787.99 3,681.78 4,484.56 3.15 5,963,928.09 560,637.77 1.01 4,415.88 MWD+IFR-AK-CAZ-SC(4) 8,222.67 89.54 359.01 3,787.72 3,681.51 4,578.99 -0.40 5,964,022.48 560,633.45 2.80 4,509.50 MWD+IFR-AK-CAZ-SC(4) 8,317.49 90.17 358.74 3,787.96 3,681.75 4,673.79 -2.26 5,964,117.25 560,630.83 0.72 4,603.18 MWD+IFR-AK-CAZ-SC(4) 8,411.81 90.03 0.53 3,787.79 3,681.58 4,768.11 -2.86 5,964,211.55 560,629.46 1.90 4,696.17 MWD+IFR-AK-CAZ-SC(4) 8,507.11 89.38 3.07 3,788.29 3,682.08 4,863.35 0.13 5,964,306.81 560,631.69 2.75 4,789.44 MWD+IFR-AK-CAZ-SC(4) 8,601.65 88.72 3.42 3,789.85 3,683.64 4,957.73 5.48 5,964,401.21 560,636.28 0.79 4,881.45 MWD+IFR-AK-CAZ-SC(4) 8,696.67 89.17 6.51 3,791.60 3,685.39 5,052.36 13.70 5,964,495.90 560,643.73 3.29 4,973.22 MWD+IFR-AK-CAZ-SC(4) 8,791.33 89.72 9.64 3,792.52 3,686.31 5,146.07 27.00 5,964,589.70 560,656.27 3.36 5,063.20 MWD+IFR-AK-CAZ-SC(4) 8,886.34 89.62 12.42 3,793.07 3,686.86 5,239.31 45.17 5,964,683.08 560,673.69 2.93 5,151.87 MWD+IFR-AK-CAZ-SC(4) 8,981.58 89.79 14.40 3,793.56 3,687.35 5,331.95 67.26 5,964,775.89 560,695.03 2.09 5,239.26 MWD+IFR-AK-CAZ-SC(4) 9,075.64 89.72 15.86 3,793.96 3,687.75 5,422.74 91.81 5,964,866.87 560,718.84 1.55 5,324.42 MWD+IFR-AK-CAZ-SC(4) 9,172.02 89.52 15.48 3,794.60 3,688.39 5,515.54 117.84 5,964,959.86 560,744.12 0.45 5,411.28 MWD+IFR-AK-CAZ-SC(4) 9,266.50 89.52 15.02 3,795.39 3,689.18 5,606.69 142.69 5,965,051.20 560,768.23 0.49 5,496.73 MWD+IFR-AK-CAZ-SC(4) 9,361.98 89.52 16.53 3,796.19 3,689.98 5,698.57 168.65 5,965,143.28 560,793.44 1.58 5,582.71 MWD+IFR-AK-CAZ-SC(4) 9,398.65 89.48 17.10 3,796.51 3,690.30 5,733.67 179.25 5,965,178.46 560,803.76 1.56 5,615.43 MWD+IFR-AK-CAZ-SC(4) 9,463.00 89.48 17.10 3,797.09 3,690.88 5,795.17 198.18 5,965,240.11 560,822.18 0.00 5,672.72 PROJECTED to TD 8/13/2015 10:31:37AM Page 5 COMPASS 5000.1 Build 74 • • 2 1 113398 25 RECEIVED AUG 20201;1 AOGCC FINAL ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad 1D-145 Definitive Survey Report 13 August, 2015 NAD 83 • . Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-145 Project: Kuparuk River Unit TVD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Site: Kuparuk 1D Pad MD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Well: 1D-145 North Reference: True Wellbore: 1D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145 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 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 1D-145 Well Position +N/-S 0.00 usft Northing: 5,959,195.59 usfl Latitude: 70° 17 58.080 N +E/-W 0.00 usft Easting: 1,700,702.78 usfl Longitude: 149°30'42.256 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usfl Ground Level: 66.90 usft Wellbore 1D-145 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 7/31/2015 19.03 80.97 57,507 Design 1D-145 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.31 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.31 0.00 0.00 350.00 Survey Program Date 8/13/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 100.00 1,256.00 1D-145 Srvy#1 GYD-GC-SS(1D-145) GYD-GC-SS Gyrodata gyro single shots 7/22/2015 8:41 1,281.11 2,502.11 1D-145 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/22/2015 8:4: 2,596.79 4,709.56 1D-145 Srvy#3 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/26/2015 6:4 4,806.99 9,398.65 1 D-145 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/3/2015 9:34 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 39.31 0.00 0.00 39.31 -66.90 0.00 0.00 5,959,195.59 1,700,702.78 0.00 0.00 UNDEFINED 100.00 0.01 95.38 100.00 -6.21 0.00 0.01 5,959,195.59 1,700,702.79 0.02 0.00 GYD-GC-SS(1) 119.30 0.35 173.33 119.30 13.09 -0.06 0.01 5,959,195.53 1,700,702.80 1.80 -0.06 GYD-GC-S (1) NOT an Actual Survey 20"x 34" 126.00 0.47 173.74 126.00 19.79 -0.11 0.02 5,959,195.48 1,700,702.80 1.80 -0.11 GYD-GC-SS(1) 220.00 0.76 159.61 219.99 113.78 -1.07 0.28 5,959,194.51 1,700,703.07 0.35 -1.11 GYD-GC-SS(1) 313.00 1.01 146.06 312.98 206.77 -2.33 0.95 5,959,193.26 1,700,703.75 0.35 -2.46 GYD-GC-SS(1) 406.00 1.78 127.14 405.96 299.75 -3.88 2.56 5,959,191.72 1,700,705.38 0.95 -4.27 GYD-GC-SS(1) 500.00 2.67 114.90 499.88 393.67 -5.69 5.71 5,959,189.95 1,700,708.54 1.07 -6.59 GYD-GC-SS(1) 594.00 4.19 98.13 593.72 487.51 -7.10 11.10 5,959,188.58 1,700,713.94 1.92 -8.91 GYD-GC-SS(1) 688.00 5.98 82.61 687.35 581.14 -6.95 19.35 5,959,188.79 1,700,722.19 2.39 -10.21 GYD-GC-SS(1) 8/13/2015 8:21:49AM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-145 Project: Kuparuk River Unit TVD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Site: Kuparuk 1D Pad MD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Well: 1D-145 North Reference: True Wellbore: 1D-145 Survey Calculation Method: Minimum Curvature Design: 1 D-145 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 783.00 6.51 89.35 781.78 675.57 -6.25 29.64 5,959,189.57 1,700,732.48 0.95 -11.31 GYD-GC-SS(1) 878.00 8.07 105.17 876.02 769.81 -7.94 41.47 5,959,187.98 1,700,744.31 2.66 -15.02 GYD-GC-SS(1) 973.00 10.73 116.45 969.75 863.54 -13.62 55.83 5,959,182.41 1,700,758.71 3.39 -23.11 GYD-GC-SS(1) 1,067.00 10.26 122.18 1,062.18 955.97 -21.98 70.75 5,959,174.18 1,700,773.70 1.22 -33.93 GYD-GC-SS(1) 1,161.00 10.55 118.64 1,154.63 1,048.42 -30.56 85.38 5,959,165.71 1,700,788.40 0.75 -44.93 GYD-GC-SS(1) 1,256.00 13.53 119.40 1,247.53 1,141.32 -40.19 102.70 5,959,156.23 1,700,805.80 3.14 -57.41 GYD-GC-SS(1) 1,281.11 14.74 122.52 1,271.88 1,165.67 -43.35 107.95 5,959,153.11 1,700,811.07 5.69 -61.44 MWD+IFR-AK-CAZ-SC(2) 1,375.96 15.06 124.41 1,363.54 1,257.33 -56.80 128.30 5,959,139.82 1,700,831.52 0.61 -78.21 MWD+IFR-AK-CAZ-SC(2) 1,469.99 16.15 126.62 1,454.10 1,347.89 -71.50 148.87 5,959,125.29 1,700,852.21 1.32 -96.27 MWD+IFR-AK-CAZ-SC(2) 1,564.64 18.00 129.88 1,544.58 1,438.37 -88.73 170.66 5,959,108.23 1,700,874.14 2.20 -117.02 MWD+IFR-AK-CAZ-SC(2) 1,659.70 18.38 132.06 1,634.89 1,528.68 -108.19 193.06 5,959,088.96 1,700,896.69 0.82 -140.07 MWD+IFR-AK-CAZ-SC(2) 1,754.17 19.55 136.27 1,724.24 1,618.03 -129.59 215.05 5,959,067.74 1,700,918.84 1.90 -164.97 MWD+IFR-AK-CAZ-SC(2) 1,849.18 25.23 142.64 1,812.06 1,705.85 -157.20 238.34 5,959,040.32 1,700,942.36 6.49 -196.20 MWD+IFR-AK-CAZ-SC(2) 1,943.54 24.04 145.16 1,897.83 1,791.62 -188.96 261.53 5,959,008.75 1,700,965.80 1.68 -231.51 MWD+IFR-AK-CAZ-SC(2) 2,037.74 22.96 146.40 1,984.22 1,878.01 -220.02 282.66 5,958,977.87 1,700,987.17 1.26 -265.76 MWD+IFR-AK-CAZ-SC(2) 2,131.71 19.54 139.38 2,071.80 1,965.59 -247.22 303.04 5,958,950.83 1,701,007.77 4.53 -296.09 MWD+IFR-AK-CAZ-SC(2) 2,227.67 18.00 138.32 2,162.65 2,056.44 -270.48 323.35 5,958,927.74 1,701,028.26 1.64 -322.52 MWD+IFR-AK-CAZ-SC(2) 2,322.91 17.23 125.92 2,253.46 2,147.25 -289.75 344.57 5,958,908.64 1,701,049.63 4.01 -345.18 MWD+IFR-AK-CAZ-SC(2) 2,418.21 16.62 117.19 2,344.65 2,238.44 -304.26 368.12 5,958,894.32 1,701,073.30 2.74 -363.56 MWD+IFR-AK-CAZ-SC(2) 2,502.11 14.16 105.12 2,425.55 2,319.34 -312.42 388.71 5,958,886.32 1,701,093.95 4.80 -375.18 MWD+IFR-AK-CAZ-SC(2) 2,564.00 13.65 98.16 2,485.63 2,379.42 -315.44 403.25 5,958,883.43 1,701,108.52 2.82 -380.67 MWD+IFR-AK-CAZ-SC(3) 13-318"x 16" NOT an Actual Survey 2,596.79 13.47 94.30 2,517.51 2,411.30 -316.27 410.89 5,958,882.65 1,701,116.16 2.82 -382.82 MWD+IFR-AK-CAZ-SC(3) 2,656.93 15.33 85.48 2,575.76 2,469.55 -316.17 425.81 5,958,882.87 1,701,131.07 4.77 -385.31 MWD+IFR-AK-CAZ-SC(3) 2,752.83 17.42 56.40 2,667.92 2,561.71 -307.21 450.44 5,958,892.03 1,701,155.63 8.72 -380.76 MWD+IFR-AK-CAZ-SC(3) 2,846.94 20.09 40.18 2,757.09 2,650.88 -287.05 472.62 5,958,912.37 1,701,177.65 6.20 -364.76 MWD+IFR-AK-CAZ-SC(3) 2,941.95 20.21 29.55 2,846.31 2,740.10 -260.30 491.25 5,958,939.26 1,701,196.06 3.85 -341.65 MWD+IFR-AK-CAZ-SC(3) 3,036.87 22.06 15.12 2,934.91 2,828.70 -228.80 504.00 5,958,970.86 1,701,208.55 5.80 -312.84 MWD+IFR-AK-CAZ-SC(3) 3,131.39 28.38 8.34 3,020.39 2,914.18 -189.39 511.90 5,959,010.32 1,701,216.13 7.34 -275.41 MWD+IFR-AK-CAZ-SC(3) 3,224.82 32.94 6.61 3,100.74 2,994.53 -142.16 518.04 5,959,057.60 1,701,221.90 4.97 -229.96 MWD+IFR-AK-CAZ-SC(3) 3,320.60 35.88 2.74 3,179.76 3,073.55 -88.24 522.38 5,959,111.55 1,701,225.81 3.82 -177.61 MWD+IFR-AK-CAZ-SC(3) 3,415.83 39.45 359.71 3,255.14 3,148.93 -30.09 523.57 5,959,169.70 1,701,226.52 4.22 -120.55 MWD+IFR-AK-CAZ-SC(3) 3,510.04 45.72 357.64 3,324.47 3,218.26 33.60 522.02 5,959,233.37 1,701,224.47 6.82 -57.56 MWD+IFR-AK-CAZ-SC(3) 3,603.86 47.75 357.64 3,388.77 3,282.56 101.86 519.21 5,959,301.60 1,701,221.11 2.16 10.15 MWD+IFR-AK-CAZ-SC(3) 3,698.68 55.20 353.54 3,447.80 3,341.59 175.73 513.38 5,959,375.41 1,701,214.68 8.55 83.91 MWD+IFR-AK-CAZ-SC(3) 3,733.44 57.38 352.36 3,467.09 3,360.88 204.42 509.82 5,959,404.08 1,701,210.90 6.88 112.79 MWD+IFR-AK-CAZ-SC(3) 3,793.18 57.65 352.16 3,499.18 3,392.97 254.36 503.04 5,959,453.95 1,701,203.72 0.53 163.14 MWD+IFR-AK-CAZ-SC(3) 3,887.98 58.01 351.21 3,549.66 3,443.45 333.76 491.43 5,959,533.25 1,701,191.47 0.93 243.35 MWD+IFR-AK-CAZ-SC(3) 3,980.52 61.18 349.64 3,596.49 3,490.28 412.44 478.14 5,959,611.81 1,701,177.55 3.72 323.15 MWD+IFR-AK-CAZ-SC(3) 4,072.68 66.78 351.78 3,636.90 3,530.69 494.14 464.81 5,959,693.39 1,701,163.57 6.42 405.92 MWD+IFR-AK-CAZ-SC(3) 4,165.06 73.20 352.05 3,668.50 3,562.29 580.04 452.61 5,959,779.18 1,701,150.69 6.95 492.63 MWD+IFR-AK-CAZ-SC(3) 8/13/2015 8:21:49AM Page 3 COMPASS 5000.1 Build 74 • • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-145 Project: Kuparuk River Unit TVD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Site: Kuparuk 1D Pad MD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Well: 1D-145 North Reference: True Wellbore: 1D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,257.17 75.27 352.65 3,693.52 3,587.31 667.89 440.82 5,959,866.93 1,701,138.19 2.33 581.20 MWD+IFR-AK-CAZ-SC(3) 4,348.56 78.31 353.65 3,714.41 3,608.20 756.22 430.21 5,959,955.16 1,701,126.87 3.49 670.02 MWD+IFR-AK-CAZ-SC(3) 4,442.95 83.81 352.67 3,729.07 3,622.86 848.76 419.11 5,960,047.60 1,701,115.03 5.92 763.09 MWD+IFR-AK-CAZ-SC(3) 4,534.65 87.30 351.76 3,736.17 3,629.96 939.32 406.72 5,960,138.05 1,701,101.92 3.93 854.43 MWD+IFR-AK-CAZ-SC(3) 4,626.86 84.85 351.35 3,742.49 3,636.28 1,030.31 393.21 5,960,228.92 1,701,087.68 2.69 946.38 MWD+IFR-AK-CAZ-SC(3) 4,709.56 85.67 351.52 3,749.32 3,643.11 1,111.81 380.94 5,960,310.31 1,701,074.75 1.01 1,028.77 MWD+IFR-AK-CAZ-SC(3) 4,771.60 85.55 352.71 3,754.07 3,647.86 1,173.08 372.45 5,960,371.51 1,701,065.78 1.92 1,090.58 MWD+IFR-AK-CAZ-SC(4) 9 5/8"x 12-1/4 NOT an Actual Survey 4,806.99 85.48 353.39 3,756.84 3,650.63 1,208.10 368.18 5,960,406.49 1,701,061.23 1.92 1,125.82 MWD+IFR-AK-CAZ-SC(4) 4,901.86 87.59 353.18 3,762.57 3,656.36 1,302.15 357.11 5,960,500.43 1,701,049.40 2.24 1,220.35 MWD+IFR-AK-CAZ-SC(4) 4,993.32 90.46 351.79 3,764.13 3,657.92 1,392.80 345.15 5,960,590.97 1,701,036.72 3.49 1,311.70 MWD+IFR-AK-CAZ-SC(4) 5,091.30 91.44 350.99 3,762.50 3,656.29 1,489.66 330.49 5,960,687.70 1,701,021.28 1.29 1,409.64 MWD+IFR-AK-CAZ-SC(4) 5,185.96 91.42 350.62 3,760.14 3,653.93 1,583.07 315.37 5,960,780.98 1,701,005.41 0.39 1,504.26 MWD+IFR-AK-CAZ-SC(4) 5,282.01 89.32 350.36 3,759.52 3,653.31 1,677.79 299.50 5,960,875.57 1,700,988.78 2.20 1,600.30 MWD+IFR-AK-CAZ-SC(4) 5,376.54 90.00 349.85 3,760.08 3,653.87 1,770.91 283.25 5,960,968.55 1,700,971.79 0.90 1,694.82 MWD+IFR-AK-CAZ-SC(4) 5,472.31 90.41 349.96 3,759.74 3,653.53 1,865.20 266.47 5,961,062.69 1,700,954.25 0.44 1,790.59 MWD+IFR-AK-CAZ-SC(4) 5,566.51 90.13 348.63 3,759.29 3,653.08 1,957.76 248.97 5,961,155.09 1,700,936.02 1.44 1,884.78 MWD+IFR-AK-CAZ-SC(4) 5,661.44 89.23 347.02 3,759.82 3,653.61 2,050.55 228.95 5,961,247.71 1,700,915.26 1.94 1,979.64 MWD+IFR-AK-CAZ-SC(4) 5,756.32 89.48 344.12 3,760.89 3,654.68 2,142.42 205.31 5,961,339.38 1,700,890.88 3.07 2,074.22 MWD+IFR-AK-CAZ-SC(4) 5,852.00 90.03 341.05 3,761.30 3,655.09 2,233.70 176.68 5,961,430.42 1,700,861.52 3.26 2,169.09 MWD+IFR-AK-CAZ-SC(4) 5,945.89 89.89 340.06 3,761.37 3,655.16 2,322.23 145.42 5,961,518.69 1,700,829.56 1.06 2,261.70 MWD+IFR-AK-CAZ-SC(4) 6,041.27 90.46 342.62 3,761.08 3,654.87 2,412.59 114.91 5,961,608.79 1,700,798.32 2.75 2,355.99 MWD+IFR-AK-CAZ-SC(4) 6,136.35 87.85 344.51 3,762.48 3,656.27 2,503.77 88.01 5,961,699.74 1,700,770.70 3.39 2,450.44 MWD+IFR-AK-CAZ-SC(4) 6,231.57 88.04 346.87 3,765.89 3,659.68 2,595.97 64.49 5,961,791.74 1,700,746.45 2.48 2,545.33 MWD+IFR-AK-CAZ-SC(4) 6,327.18 88.76 351.26 3,768.56 3,662.35 2,689.78 46.37 5,961,885.39 1,700,727.57 4.65 2,640.86 MWD+IFR-AK-CAZ-SC(4) 6,421.41 88.08 353.29 3,771.16 3,664.95 2,783.11 33.71 5,961,978.61 1,700,714.16 2.27 2,734.98 MWD+IFR-AK-CAZ-SC(4) 6,515.65 85.87 354.42 3,776.14 3,669.93 2,876.67 23.64 5,962,072.08 1,700,703.34 2.63 2,828.87 MWD+IFR-AK-CAZ-SC(4) 6,610.36 87.88 353.25 3,781.30 3,675.09 2,970.69 13.48 5,962,166.00 1,700,692.43 2.45 2,923.22 MWD+IFR-AK-CAZ-SC(4) 6,704.80 88.01 353.88 3,784.69 3,678.48 3,064.47 2.90 5,962,259.69 1,700,681.10 0.68 3,017.41 MWD+IFR-AK-CAZ-SC(4) 6,800.15 87.40 356.97 3,788.50 3,682.29 3,159.43 -4.70 5,962,354.58 1,700,672.74 3.30 3,112.25 MWD+IFR-AK-CAZ-SC(4) 6,894.31 89.32 358.36 3,791.20 3,684.99 3,253.47 -8.53 5,962,448.57 1,700,668.15 2.52 3,205.52 MWD+IFR-AK-CAZ-SC(4) 6,989.57 89.55 358.56 3,792.14 3,685.93 3,348.69 -11.09 5,962,543.76 1,700,664.83 0.32 3,299.74 MWD+IFR-AK-CAZ-SC(4) 7,085.32 89.52 358.52 3,792.92 3,686.71 3,444.40 -13.53 5,962,639.44 1,700,661.62 0.05 3,394.43 MWD+IFR-AK-CAZ-SC(4) 7,179.48 89.93 0.00 3,793.37 3,687.16 3,538.55 -14.75 5,962,733.57 1,700,659.65 1.63 3,487.35 MWD+IFR-AK-CAZ-SC(4) 7,273.67 89.23 1.88 3,794.06 3,687.85 3,632.72 -13.20 5,962,827.74 1,700,660.44 2.13 3,579.83 MWD+IFR-AK-CAZ-SC(4) 7,368.58 89.89 5.05 3,794.79 3,688.58 3,727.44 -7.47 5,962,922.49 1,700,665.42 3.41 3,672.11 MWD+IFR-AK-CAZ-SC(4) 7,463.65 90.68 6.48 3,794.31 3,688.10 3,822.03 2.08 5,963,017.14 1,700,674.21 1.72 3,763.60 MWD+IFR-AK-CAZ-SC(4) 7,559.16 90.31 6.87 3,793.49 3,687.28 3,916.89 13.18 5,963,112.08 1,700,684.54 0.56 3,855.09 MWD+IFR-AK-CAZ-SC(4) 7,653.94 90.31 4.33 3,792.98 3,686.77 4,011.21 22.43 5,963,206.46 1,700,693.03 2.68 3,946.37 MWD+IFR-AK-CAZ-SC(4) 7,748.49 90.58 0.01 3,792.24 3,686.03 4,105.66 26.01 5,963,300.93 1,700,695.86 4.58 4,038.77 MWD+IFR-AK-CAZ-SC(4) 8/13/2015 8:21:49AM Page 4 COMPASS 5000.1 Build 74 I • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-145 Project: Kuparuk River Unit TVD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Site: Kuparuk 1D Pad MD Reference: Actual:66.9+39.31 @ 106.21usft(Doyon25) Well: 1D-145 North Reference: True Wellbore: 1D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,843.17 90.79 355.97 3,791.11 3,684.90 4,200.26 22.69 5,963,395.49 1,700,691.78 4.27 4,132.51 MWD+IFR-AK-CAZ-SC(4) 7,937.82 90.61 356.11 3,789.95 3,683.74 4,294.67 16.16 5,963,489.84 1,700,684.48 0.24 4,226.62 MWD+IFR-AK-CAZ-SC(4) 8,032.53 90.48 355.77 3,789.05 3,682.84 4,389.14 9.45 5,963,584.24 1,700,677.02 0.38 4,320.82 MWD+IFR-AK-CAZ-SC(4) 8,128.16 90.79 356.68 3,787.99 3,681.78 4,484.56 3.15 5,963,679.60 1,700,669.96 1.01 4,415.88 MWD+IFR-AK-CAZ-SC(4) 8,222.67 89.54 359.01 3,787.72 3,681.51 4,578.99 -0.40 5,963,773.99 1,700,665.65 2.80 4,509.50 MWD+IFR-AK-CAZ-SC(4) 8,317.49 90.17 358.74 3,787.96 3,681.75 4,673.79 -2.26 5,963,868.76 1,700,663.03 0.72 4,603.18 MWD+IFR-AK-CAZ-SC(4) 8,411.81 90.03 0.53 3,787.79 3,681.58 4,768.11 -2.86 5,963,963.06 1,700,661.67 1.90 4,696.17 MWD+IFR-AK-CAZ-SC(4) 8,507.11 89.38 3.07 3,788.29 3,682.08 4,863.35 0.13 5,964,058.32 1,700,663.90 2.75 4,789.44 MWD+IFR-AK-CAZ-SC(4) 8,601.65 88.72 3.42 3,789.85 3,683.64 4,957.73 5.48 5,964,152.72 1,700,668.49 0.79 4,881.45 MWD+IFR-AK-CAZ-SC(4) 8,696.67 89.17 6.51 3,791.60 3,685.39 5,052.36 13.70 5,964,247.41 1,700,675.95 3.29 4,973.22 MWD+IFR-AK-CAZ-SC(4) 8,791.33 89.72 9.64 3,792.52 3,686.31 5,146.07 27.00 5,964,341.21 1,700,688.50 3.36 5,063.20 MWD+IFR-AK-CAZ-SC(4) 8,886.34 89.62 12.42 3,793.07 3,686.86 5,239.31 45.17 5,964,434.59 1,700,705.92 2.93 5,151.87 MWD+IFR-AK-CAZ-SC(4) 8,981.58 89.79 14.40 3,793.56 3,687.35 5,331.95 67.26 5,964,527.39 1,700,727.26 2.09 5,239.26 MWD+IFR-AK-CAZ-SC(4) 9,075.64 89.72 15.86 3,793.96 3,687.75 5,422.74 91.81 5,964,618.37 1,700,751.08 1.55 5,324.42 MWD+IFR-AK-CAZ-SC(4) 9,172.02 89.52 15.48 3,794.60 3,688.39 5,515.54 117.84 5,964,711.37 1,700,776.36 0.45 5,411.28 MWD+IFR-AK-CAZ-SC(4) 9,266.50 89.52 15.02 3,795.39 3,689.18 5,606.69 142.69 5,964,802.70 1,700,800.48 0.49 5,496.73 MWD+IFR-AK-CAZ-SC(4) 9,361.98 89.52 16.53 3,796.19 3,689.98 5,698.57 168.65 5,964,894.78 1,700,825.69 1.58 5,582.71 MWD+IFR-AK-CAZ-SC(4) 9,398.65 89.48 17.10 3,796.51 3,690.30 5,733.67 179.25 5,964,929.96 1,700,836.02 1.56 5,615.43 MWD+IFR-AK-CAZ-SC(4) 9,463.00 89.48 17.10 3,797.09 3,690.88 5,795.17 198.18 5,964,991.61 1,700,854.44 0.00 5,672.72 PROJECTED to TD 8/13/2015 8:21:49AM Page 5 COMPASS 5000.1 Build 74 41111 Off. 7,Ed A THE STATE Alaska Oil and Gas „ALASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O '4LA5 Fax: 907.276.7542 www.aogcc.alaska.gov Kelsey Hallford 133Drilling Engineer ( ... ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-145 Sundry Number: 315-454 Dear Ms. Hallford: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, f-7/7511— Cat y P. oerster Chair DATED this day of July, 2015 Encl. • • NEL. JUL 2 7 2.015 STATE OF ALASKA I t-S 7/ 24 ALASKA OIL AND GAS CONSERVATION COMMISSION �J J ` APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 s_`1 tit i"`Top Job ❑✓ 2.Operator Name: 4.Current Wet Class: 5.Permit to Drill Number: ConocoPhillips Exploratory ❑ Development Q r 214-138 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. PO Box 100360 Anchorage,AK 99510 50-029-23526-00-00 , 7.If perforating: //ii ✓ 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 0 KRU 1 D-145 9.Property Designation(Lease Number): 10.Field/Pod(s): ADL 25650, 25649 . Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): ?. '-(y l LiC1( Z1519 ' zyeliR' , 'i1 c..,.rt) Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2564' 13-3/8" 2564' 2496' '120psi Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): n/a n/a n/a n/a n/a Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): n/a n/a 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program © BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: July 24,2015 OIL ❑' . WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Yes Date: July 23,2015 GAS ❑ WAG LI GSTOR 0 SPLUG ❑ Commission Representative: Victoria Loepp GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kelsey Hanford Email kelsey.hallford( cop.com Printed Name Kelsey Hallford Title Drilling Engineer Signature tPhone 907-440-0004 Date July 24,2015 (/ / � COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315— S l Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No i Subsequent Form Required: 1 v APPROVED BY p / Approved by: COMMISSIONER THE COMMISSION Date: 1— Zd Ls V7L Z$// il�►� 2?-��S RBDMS--)kA AUG - 2 2015 ORIGINAL 07�74,- Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • ' From: Hallford, Kelsey [mailto:Kelsey.Hallford©conocophillips.comj Sent: Friday, July 24, 2015 5:38 AM To: Loepp, Victoria T(DOA); Doyon 25 Company Man Cc: Voss, Jake; Vosen, BrookeLynn; Woodard, Madeline E; Lehman, Nick R; Doyon 25 Rig Engineer; Bearden, J Daniel; Ardrey, Blake M; Brunswick, Scott A; Lee, David L; Shultz, Steve (Orbis Engineering, Inc.); Guo, Haibin; Callahan, Mike S; Hyden, Duncan P; Herbert, Frederick 0 Subject: RE: Permit# 214-138: 1D-145 Surface Cement-Top Job Victoria, We have completed our top job for the surface hole on 1D-145. Prior to cementing,we flushed the annulus of MudPush II and tagged at 130' MD with our 3/"tubing. We saw cement back at surface after pumping 55bbls,continued pumping for a total of 57.1bbls of 11ppg Lead cement. Please call or email with any questions or concerns, Kelsey From: Hallford, Kelsey Sent: 23 July 2015 19:01 To: 'victoria.loepp@alaska.gov'; Doyon 25 Company Man Cc: 'Voss, Jake (Jake.Voss@conocophillips.com)'; Vosen, BrookeLynn; Woodard, Madeline E; Lehman, Nick R; Doyon 25 Rig Engineer; Bearden, J Daniel; Ardrey, Blake M (Blake.M.Ardrey@conocophillips.com); Brunswick, Scott A; Lee, David L; Shultz, Steve (Orbis Engineering, Inc.); Guo, Haibin; Callahan, Mike S; Hyden, Duncan P; Herbert, Frederick 0 Subject: Permit# 214-138: 1D-145 Surface Cement-Top Job Victoria, As mentioned on the phone,we will require a top job on our surface cement job for 1D-145. Our cement volumes were based on 200%excess in the permafrost and 50%excess from the permafrost to the shoe. We had full returns over the course of the cement job, but did not get cement to surface.We received 59bbls of the MudPushll to surface, leading us to calculate an additional 16bbls of cement needed to reach surface.Our estimated TOC is currently at 120' MD,we will use%"tubing to flush the annulus and perform our top job to achieve cement to surface. The cement job went as follows: 75bbls CW100 75bbls MudPush II 432.2bbls 11ppg Lead 68.9bbls 12ppg Tail Plugs bumped on calculated strokes Floats held Please call or email with any questions or concerns, Kelsey Hallford Drilling Engineer I ConocoPhillips Office: +1-907-265-1577 Cell: +1-907-440-0004 Email: kelsey.hailford(p,cop.com 2 411 Cementing ]o� Report CemCATv1.6 $cblumberger Well 1D-145 Client ConocoPhillips Field Kuparuk SIR No. DDKA-00020/7689 Engineer John Morrison Job Type Surface Country United States Job Date 07-23-2015 Time 07/23/201510:43,9 — Pressure Rate top out densit— Rig floor press -Surface densi Messages 10:43:39 • I L r� • [ • g head rate heck • h head rate check • I Reset Total,Vol=11.78 bb 11:34:00 I I ? • • • • • 12:24:00 r • . •• • • • i • i • • • • pjsm • • on location @ 0900 • • 13:14:00 s • mix water temp 80 degrees • • i - rig pump down,lined up to c I • E start 5 bbls water ahead [ 1 • Reset Total,Vol=5.0 bbl �` • low pressure stall 14:04:00 , • ,.,� r !! High PT to 4000 II! I i bleed off,good test • i - start 75 bbls CW-100 • • flow out 18% 7 • • • down on pump,CW-100 pur Reset Total,Vol=75.3 bbl 14:54:00 • • • • j start batching MPII I start pumping MPH • return flow 20I%going down • i Down on pump,start batchir • • I lead cement wet l • i i Reset Total,Vol=72.9 bbl 15:44:00 _ 4• I • I i startpumping lead cement 3 i • 20°/6 return flow,going dowi i • j • j r-' silo swap cement scaled©11#durinc ,e • ' CW-100 @shce 16:34:00 - • E• MP II @shce • • • • bottom plug landed • • • cement @shce , down on pump 3 I Reset Total,Vol=432.2 bb • - ( , tail mudscaled @ 12# 17:24:00 E Reset Total,Vol=68.9 bbl s • i start 10 bbls water behind • I 1 still redprocating • [• down on pump,rig is lining 1 • • • I 1090 strokes away 18:03:31 • . 8 bpm return flow 23% bumped plug @ 3584 stroke • II 01:18:53 [ I • ; i 11 re-spotted for top job • i• ; 7 mixing top out with small tul 1 • • ' I Reset Total,Vol=9.5 bbl 02:14:00 • start pumping water ahead ' ,• • - 3 have returns in the cellar € II • 03:09:00 i Reset Total,Vol=45.0 bbl - start batching cement • • Reset Total,Vol=0.05 bbl • • • scale 11.3 • • III Ig•••04:04:00 j • E cement to surface • 04:59:00 I 11#cement to surface •• • • • 05:34:43 • ; [ • • • 57.1 total bbls pumped for tr • • • • hh:mm:ss 0.00 1000 2000 3000 4000 5000 0.00 2.0 4.0 6.0 8.0 10.0 5.0 10.0 15.0 20.0 25.0 0.00 1250 2500 3750 5000 0.00 6.3 12.5 18.8 25.0 WM/1M05:34:a PSI B/M LB/G PSI LB/G 07/24/2015 06:15:03 • Schlumberger Cementing Service Report Customer lob Number ConocoPhillips DDKA-00020/7689 Well Location(legal) 1 Schlumberger Location Job Start 1D-145 1D-145 Drill Site 10 Prudhoe Other Jul/23/2015 Field Formation Name/Type Deviation Bit Size Well MD Well TVD Kuparuk Clean-Sandstone 24 deg 16.0 in 2574.0 ft 2489.0 ft County Beechey Point State/Province Alaska BHP BHST BHCT Pore Press.Gradient Well Master 0631602467 API/UWI 5002923526000 psi 60 degF 77 degF lb/gal Rig Name Drilled For Service Via Casing/Liner Doyon 25 Oil&Gas Land Depth,ft Size,in Weight,lb/ft Grade Thread Offshore Zone Well Class Well Type 2564.0 13.4 68.0 L-80 HYD 563 Old Development 0.0 0.0 0.0 Drilling Fluid Type Max.Density Plastic Viscosity Tubing/Drill Pipe lb/gal CP T/D Depth,ft Size,in Weight,lb/ft Grade Thread Service Line Job Type Cementing Surface Max.Allowed Tub.Press Max.Allowed Ann.Press WH Connection Perforations/Open Hole psi psi 2"FMC Top,ft Bottom,ft shot/ft No.of Shots Total Interval Service Instructions ft ft ft ft Diameter ft ft n Treat Down Displacement Packer Type Packer Depth Casing 371.4 bbl ft Tubing Vol. Casing Vol. Annular Vol. Openhole Vol. bbl 383.5 bbl bbl bbl Casing/Tubing Secured El 1 Hole Vol.Circulated prior to Cement i Casing Tools Squeeze Job Lift Pressure 300 psi Shoe Type Float Squeeze Type Pipe Rotated 0 Pipe Reciprocated El Shoe Depth 2564.0 ft Tool Type No.Centralizers 60 Top Plugs 1 Bottom Plugs 1 Stage Tool Type Tool Depth ft Cement Head Type Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Arrived on Location Leave Location Collar Type Float Tall Pipe Depth ft Jul/23/2015 Jul/23/2015 Jul/23/2015 Collar Depth 2481.0 ft Sqz.Total Vol. bbl Date Time Treating Flow Density WHP Stage Message 24-hr Pressure Rate LB/G PSI Volume clock PSI B/M BBL 07/23/2015 10:43:39 67 0.0 0.05 -25 0.0 Started Acquisition 07/23/2015 10:44:49 67 0.0 0.05 -23 0.0 07/23/2015 10:45:59 67 0.0 0.05 -24 0.0 07/23/2015 10:47:09 67 0.0 0.05 -24 0.0 07/23/2015 10:48:19 66 0.0 0.05 -25 0.0 07/23/2015 10:49:29 67 0.0 0.05 -25 0.0 07/23/2015 10:50:39 70 0.0 0.05 -18 0.0 07/23/2015 10:51:49 67 0.0 0.05 -22 0.0 07/23/2015 10:52:59 67 0.0 0.05 -11 0.0 07/23/2015 10:54:09 66 0.0 0.04 -19 0.0 07/23/2015 10:55:19 85 0.0 8.33 -19 0.0 07/23/2015 10:56:29 136 0.0 8.33 -16 0.0 07/23/2015 10:57:39 93 0.0 8.34 -18 0.0 07/23/2015 10:58:49 69 0.0 8.35 -17 0.0 07/23/2015 10:59:59 206 0.0 8.36 -19 0.0 07/23/2015 11:01:09 76 0.0 8.35 -20 0.0 07/23/2015 11:02:19 69 0.0 8.35 -16 0.0 07/23/2015 11:03:29 69 0.0 8.36 -21 0.0 07/23/2015 11:04:39 72 0.0 8.36 -20 0.0 07/23/2015 11:05:49 69 0.0 8.35 -20 0.0 07/23/2015 11:08:09 106 0.0 8.36 -23 0.0 Page 1 of 13 • Well Field Job Start Customer Job Number 10-145 1D-145 Kuparuk Jul/23/2015 ConocoPhillips DDKA-00020/7689 Date Time Treating Flow Density WHP Stage Message 24-hr Pressure Rate LB/G PSI Volume clock PSI B/M BBL 07/23/2015 11:09:19 104 3.0 8.36 -23 2.8 07/23/2015 11:10:15 109 0.0 8.36 -22 3.2 h head rate check 07/23/2015 11:10:29 108 3.0 8.36 -23 3.6 07/23/2015 11:11:39 69 0.0 8.36 -24 6.2 07/23/2015 11:11:43 69 0.0 8.36 -23 6.2 Reset Total,Vol=11.78 bbl 07/23/2015 11:12:49 135 0.0 8.35 -23 0.0 07/23/2015 11:13:59 71 0.0 4.71 -23 0.0 07/23/2015 11:15:09 71 0.0 8.34 -22 0.0 07/23/2015 11:16:19 102 0.0 8.34 -23 0.0 07/23/2015 11:17:29 69 0.0 8.35 -24 0.0 07/23/2015 11:18:39 70. 0.0 8.35 -22 0.0 07/23/2015 11:19:49 69 0.0 8.35 24 0.0 07/23/2015 11:20:59 68 0.0 8.35 81 0.0 07/23/2015 11:22:09 83 0.0 8.35 182 0.0 07/23/2015 11:23:19 69 0.0 8.35 164 0.0 07/23/2015 11:24:29 69 0.0 8.36 174 0.0 07/23/2015 11:25:39 69 0.0 8.35 187 0.0 07/23/2015 11:26:49 70 0.0 8.35 225 0.0 07/23/2015 11:27:59 69 0.0 8.35 196 0.0 07/23/2015 11:29:09 70 0.0 8.36 239 0.0 07/23/2015 11:30:19 70 0.0 8.36 257 0.0 07/23/2015 11:31:29 69 0.0 8.36 293 0.0 07/23/2015 11:32:39 70 0.0 8.36 299 0.0 07/23/2015 11:33:49 70 0.0 8.36 309 0.0 07/23/2015 11:34:59 69 0.0 8.36 300 0.0 07/23/2015 11:36:09 70 0.0 8.36 306 0.0 07/23/2015 11:37:19 71 0.0 8.36 303 0.0 07/23/2015 11:38:29 70 0.0 8.36 360 0.0 07/23/2015 11:39:39 71 0.0 8.36 346 0.0 07/23/2015 11:40:49 69 0.0 8.36 343 0.0 07/23/2015 11:43:09 70 0.0 8.36 339 0.0 07/23/2015 11:44:19 71 0.0 8.36 341 0.0 07/23/2015 11:45:29 71 0.0 8.36 350 0.0 07/23/2015 11:46:39 71 0.0 8.36 352 0.0 07/23/2015 11:47:49 70 0.0 8.36 297 0.0 07/23/2015 11:48:59 70 0.0 8.36 329 0.0 07/23/2015 11:50:09 70 0.0 8.36 329 0.0 07/23/2015 11:51:19 70 0.0 8.36 359 0.0 07/23/2015 11:52:29 70 0.0 8.36 302 0.0 07/23/2015 11:53:39 70 0.0 8.36 316 0.0 07/23/2015 11:54:49 70 0.0 8.36 332 0.0 07/23/2015 11:55:59 70 0.0 8.36 325 0.0 07/23/2015 11:57:09 71 0.0 8.36 323 0.0 07/23/2015 11:58:19 71 0.0 8.36 326 0.0 07/23/2015 11:59:29 70 0.0 8.36 330 0.0 07/23/2015 12:00:39 69 0.0 8.36 314 0.0 07/23/2015 12:01:49 70 0.0 8.36 319 0.0 07/23/2015 12:02:59 69 0.0 8.36 357 0.0 07/23/2015 12:04:09 70 0.0 8.36 295 0.0 07/23/2015 12:05:19 70 0.0 8.36 293 0.0 07/23/2015 12:06:29 70 0.0 8.36 329 0.0 07/23/2015 12:07:39 70 0.0 8.36 369 0.0 07/23/2015 12:08:49 69 0.0 8.36 367 0.0 07/23/2015 12:09:59 69 0.0 8.36 306 0.0 Page 2 of 13 • • . Well Field Job Start 3 Customer Job Number 1D-145 10-145 Kuparuk Jul/23/2015 ConocoPhillips DDKA-00020/7689 Date Time Treating Flow Density' WHP I Stage Message 24-hr Pressure Rate LB/G PSI Volume dock PSI B/M BBL 07/23/2015 12:12:19 71 0.0 8.36 340 0.0 07/23/2015 12:13:29 69 0.0 8.36 302 0.0 07/23/2015 12:14:39 70 0.0 8.36 374 0.0 07/23/2015 12:15:49 69 0.0 8.36 342 0.0 07/23/2015 12:18:09 70 0.0 8.36 391 0.0 07/23/2015 12:19:19 69 0.0 8.36 331 0.0 07/23/2015 12:20:29 69 0.0 8.36 355 0.0 07/23/2015 12:21:39 69 0.0 8.36 366 0.0 07/23/2015 12:22:49 69 0.0 8.36 309 0.0 07/23/2015 12:23:59 68 0.0 8.37 343 0.0 07/23/2015 12:25:09 70 0.0 8.36 343 0.0 07/23/2015 12:26:19 69 0.0 8.36 327 0.0 07/23/2015 12:27:29 69 0.0 8.36 308 0.0 07/23/2015 12:28:39 69 0.0 8.36 354 0.0 07/23/2015 12:29:49 69 0.0 8.36 348 0.0 07/23/2015 12:30:59 69 0.0 8.36 319 0.0 07/23/2015 12:32:09 69 0.0 9.36 337 0.0 07/23/2015 12:33:19 70 0.0 8.36 347 0.0 07/23/2015 12:34:29 69 0.0 8.36 374 0.0 07/23/2015 12:35:39 69 0.0 8.36 347 0.0 07/23/2015 12:36:49 69 0.0 8.36 371 0.0 07/23/2015 12:37:59 69 0.0 8.36 362 0.0 07/23/2015 12:39:09 69 0.0 8.36 367 0.0 07/23/2015 12:40:19 69 0.0 8.36 402 0.0 07/23/2015 12:41:29 68 0.0 8.36 365 0.0 07/23/2015 12:42:39 68 0.0 8.36 361 0.0 07/23/2015 12:43:49 69 0.0 8.36 386 0.0 07/23/2015 12:44:59 68 0.0 8.36 334 0.0 07/23/2015 12:46:09 69 0.0 8.36 378 0.0 07/23/2015 12:47:19 68 0.0 8.36 400 0.0 07/23/2015 12:48:29 68 0.0 8.36 314 0.0 07/23/2015 12:49:39 69 0.0 8.36 340 0.0 07/23/2015 12:50:49 69 0.0 8.36 374 0.0 07/23/2015 12:53:09 69 0.0 8.36 345 0.0 07/23/2015 12:54:19 69 0.0 8.36 379 0.0 07/23/2015 12:55:29 68 0.0 8.35 308 0.0 07/23/2015 12:56:39 69 0.0 8.36 344 0.0 07/23/2015 12:57:49 68 0.0 8.36 375 0.0 07/23/2015 12:58:53 69 0.0 8.36 365 0.0 pjsm 07/23/2015 12:58:59 69 0.0 8.36 322 0.0 07/23/2015 12:59:19 68 0.0 8.36 322 0.0 on location @ 0900 07/23/2015 12:59:38 68 0.0 8.36 342 0.0 mix water temp 80 degrees 07/23/2015 13:00:09 68 0.0 8.36 336 0.0 07/23/2015 13:01:19 69 0.0 8.36 350 0.0 07/23/2015 13:02:29 67 0.0 8.36 315 0.0 07/23/2015 13:03:39 69 0.0 8.36 343 0.0 07/23/2015 13:04:49 69 0.0 8.36 341 0.0 07/23/2015 13:05:59 69 0.0 8.36 310 0.0 07/23/2015 13:07:09 68 0.0 8.36 329 0.0 07/23/2015 13:08:19 67 0.0 8.36 361 0.0 07/23/2015 13:09:29 69 0.0 8.36 326 0.0 07/23/2015 13:10:39 68 0.0 8.36 337 0.0 07/23/2015 13:11:49 68 0.0 8.36 361 0.0 07/23/2015 13:12:59 69 0.0 8.36 315 0.0 Page 3 of 13 • i • , Well Field Job Start Customer lob Number 1D-145 1D-145 Kuparuk Jul/23/2015 ConocoPhillips DDKA-00020/7689 Date Time Treating Flow Density WHP Stage Message 24-hr Pressure Rate LB/6 PSI Volume clock PSI B/M BBL 07/23/2015 13:15:19 68 0.0 8.36 375 0.0 07/23/2015 13:16:29 69 0.0 8.36 322 0.0 07/23/2015 13:17:39 68 0.0 8.36 325 0.0 07/23/2015 13:18:49 68 0.0 8.36 335 0.0 07/23/2015 13:19:59 68 0.0 8.36 -10 0.0 07/23/2015 13:21:09 68 0.0 8.36 -16 0.0 07/23/2015 13:22:14 69 0.0 8.36 -16 0.0 rig pump down,lined up to cementers 07/23/2015 13:22:19 69 0.0 8.36 -16 0.0 07/23/2015 13:22:29 84 0.3 8.36 -2 0.0 start 5 bbls water ahead 07/23/2015 13:23:29 99 0.0 8.35 4 0.0 07/23/2015 13:24:39 123 0.2 8.35 25 0.1 07/23/2015 13:25:49 130 0.0 8.36 36 0.2 07/23/2015 13:28:09 185 2.5 8.35 50 3.1 07/23/2015 13:29:19 102 0.0 8.36 6 3.4 07/23/2015 13:29:22 102 0.0 8.36 6 3.4 Reset Total,Vol=5.0 bbl 07/23/2015 13:30:29 225 0.0 8.36 131 0.0 07/23/2015 13:30:30 260 0.0 8.36 166 0.0 low pressure stall 07/23/2015 13:31:27 480 0.0 8.36 385 0.0 High PT to 4000 07/23/2015 13:31:39 546 0.0 8.37 448 0.0 07/23/2015 13:32:49 3977 0.0 8.36 3891 0.0 07/23/2015 13:33:36 4203 0.0 8.36 4122 0.0 bleed off,good test 07/23/2015 13:33:59 1938 0.0 8.36 1853 0.0 07/23/2015 13:35:09 105 0.0 8.36 8 0.0 07/23/2015 13:36:05 114 0.0 8.36 23 0.0 start 75 bbls CW-100 07/23/2015 13:36:19 124 1.7 8.37 21 0.2 07/23/2015 13:37:29 376 5.2 8.36 126 4.6 07/23/2015 13:38:39 371 5.1 8.36 125 10.3 07/23/2015 13:39:49 430 5.7 8.36 160 16.4 07/23/2015 13:40:27 433 5.7 8.36 160 19.9 flow out 18% 07/23/2015 13:40:59 439 5.7 8.36 163 22.8 07/23/2015 13:42:09 445 5.7 8.36 164 29.1 07/23/2015 13:43:19 438 5.7 8.36 162 35.5 07/23/2015 13:44:29 440 5.7 8.36 166 41.8 07/23/2015 13:45:39 453 5.7 8.36 164 48.2 07/23/2015 13:46:49 454 5.7 8.36 176 54.5 07/23/2015 13:47:59 468 5.8 8.36 180 60.9 07/23/2015 13:49:09 384 4.4 8.36 155 67.1 07/23/2015 13:50:19 336 4.3 8.37 129 71.8 07/23/2015 13:51:29 110 0.0 8.36 22 75.3 07/23/2015 13:52:05 118 0.0 8.35 23 75.3 down on pump,CW-100 pumped 07/23/2015 13:52:10 117 0.0 8.35 25 75.3 Reset Total,Vol=75.3 bbl 07/23/2015 13:52:39 118 0.0 8.36 18 0.0 07/23/2015 13:53:49 123 0.0 8.34 15 0.0 07/23/2015 13:54:59 125 0.0 8.26 20 0.0 07/23/2015 13:56:09 125 0.0 8.25 12 0.0 07/23/2015 13:56:14 125 0.0 8.45 12 0.0 start batching MPII 07/23/2015 13:57:19 125 0.0 11.10 12 0.0 07/23/2015 13:58:29 126 0.0 11.19 12 0.0 07/23/2015 13:59:39 125 0.0 11.17 11 0.0 07/23/2015 14:00:49 126 0.0 11.12 6 0.0 07/23/2015 14:01:59 110 4.1 10.82 13 0.0 07/23/2015 14:02:02 112 4.1 10.81 12 0.0 start pumping MPII 07/23/2015 14:03:09 310 3.8 11.43 126 3.4 07/23/2015 14:04:19 319 3.7 10.71 141 7.7 Page 4 of 13 • • Well Field Job Start Customer Job Number 1D-145 10-145 Kuparuk Jul/23/2015 ConocoPhillips DDKA-00020/7689 Date Time Treating - Flow Density WHP Stage I Message 24-hr Pressure Rate LB/9 PSI Volume clock PSI B/M BBL 07/23/2015 14:06:39 463 5.5 9.07 192 16.2 07/23/2015 14:07:49 582 6.9 11.74 232 22.9 07/23/2015 14:08:59 596 6.9 10.99 235 30.7 07/23/2015 14:10:09 580 6.9 10.50 246 38.5 07/23/2015 14:11:19 569 6.9 10.42 239 46.3 07/23/2015 14:12:24 559 6.5 10.68 226 53.6 return flow 20%going down with pipe 07/23/2015 14:12:29 538 6.4 10.69 224 54.1 07/23/2015 14:13:39 514 6.4 10.69 212 61.4 07/23/2015 14:14:49 528 6.4 10.63 226 68.8 07/23/2015 14:15:59 189 0.0 10.59 66 72.9 07/23/2015 14:16:24 130 0.0 10.54 29 72.9 Down on pump,start batching lead 07/23/2015 14:17:09 137 0.0 0.42 27 73.0 07/23/2015 14:18:19 92 0.0 10.43 -8 73.0 07/23/2015 14:19:29 91 0.0 9.01 -8 73.0 07/23/2015 14:20:39 114 0.0 9.84 -5 73.0 07/23/2015 14:20:59 115 0.0 10.74 -2 73.0 lead cement wet 07/23/2015 14:21:49 115 0.0 11.03 -5 73.0 07/23/2015 14:22:59 115 0.0 10.93 -5 73.0 07/23/2015 14:24:09 115 0.0 10.95 -3 73.0 07/23/2015 14:24:37 115 0.0 10.94 -4 73.0 Reset Total,Vol=72.9 bbl 07/23/2015 14:25:06. 108 0.0 10.96 -2 0.0 start pumping lead cement 07/23/2015 14:25:19 144 4.1 10.95 16 0.3 07/23/2015 14:26:29 495 4.7 10.89 199 5.6 07/23/2015 14:27:39 770 6.7 10.90 294 11.8 07/23/2015 14:28:49 821 7.1 10.91 306 19.9 07/23/2015 14:29:59 825 7.1 10.97 312 27.9 07/23/2015 14:31:09 851 7.1 10.90 318 35.9 07/23/2015 14:32:19 834 7.1 10.81 297 44.0 07/23/2015 14:33:29 815 7.1 10.88 313 52.1 07/23/2015 14:34:39 819 7.1 10.96 305 60.2 07/23/2015 14:35:49 841 7.1 11.08 306 68.2 07/23/2015 14:36:59 841 7.1 11.05 303 76.3 07/23/2015 14:38:09 857 7.1 11.06 307 84.3 07/23/2015 14:39:19 853 7.1 11.04 306 92.4 07/23/2015 14:39:28 852 7.1 11.04 295 93.4 20%return flow,going down 07/23/2015 14:40:29 854 7.1 11.03 295 100.4 07/23/2015 14:41:39 833 7.1 11.04 296 108.5 07/23/2015 14:42:49 864 7.3 11.02 284 116.7 07/23/2015 14:43:59 854 7.3 11.05 307 124.9 07/23/2015 14:45:09 895 7.2 11.08 322 133.1 07/23/2015 14:46:19 878 7.3 11.08 321 141.4 07/23/2015 14:47:29 876 7.2 11.07 306 149.6 07/23/2015 14:48:39 865 7.2 11.09 305 157.7 07/23/2015 14:49:49 853 7.3 11.04 283 165.9 07/23/2015 14:50:57 858 7.3 10.96 282 173.9 silo swap 07/23/2015 14:50:59 864 7.3 10.96 295 174.1 07/23/2015 14:52:09 807 7.3 10.79 259 182.4 07/23/2015 14:53:19 782 7.3 11.09 244 190.7 07/23/2015 14:54:29 827 7.3 11.09 247 198.9 07/23/2015 14:55:39 816 7.3 10.99 245 207.1 07/23/2015 14:55:56 803 7.3 10.99 233 209.1 cement scaled @ 11#during batch up 07/23/2015 14:56:49 740 7.1 11.00 210 215.3 07/23/2015 14:57:59 758 7.1 11.01 209 223.3 07/23/2015 14:59:07 752 7.2 11.02 207 231.1 CW-100 @ shoe Page 5 of 13 • • • Well Field Job Start Customer Job Number 1D-145 1D-145 Kuparuk Jul/23/2015 ConocoPhillips DDKA-00020/7689 Date Time Treating Flow Density WHP Stage Message 24-hr Pressure Rate LB/G PSI Volume clock PSI B/M BBL 07/23/2015 15:00:19 753 7.1 11.00 205 239.4 07/23/2015 15:01:29 750 7.111.03 218 247.5 07/23/2015 15:02:39 778 7.1 11.05 212 255.6 07/23/2015 15:03:49 783 7.1 11.03 220 263.6 07/23/2015 15:04:59 769 7.1 11.05 219 271.6 07/23/2015 15:06:09 763 7.1 10.98 203 279.7 07/23/2015 15:07:19 781 7.1 11.04 212 287.7 07/23/2015 15:08:29 811 7.1 11.09 223 295.7 07/23/2015 15:09:39 798 7.1 11.10 226 303.6 07/23/2015 15:10:30 792 7.1 11.07 225 309.4 MP II @ shoe 07/23/2015 15:10:49 777 7.1 11.05 204 311.6 07/23/2015 15:11:59 842 7.3 11.01 227 319.7 07/23/2015 15:13:09 848 7.3 11.02 236 327.9 07/23/2015 15:14:19 837 7.4 11.09 238 336.1 07/23/2015 15:15:29 839 7.4 11.12 231 344.3 07/23/2015 15:16:39 844 7.3 11.08 238 352.4 07/23/2015 15:17:49 805 7.4 11.17 215 360.6 07/23/2015 15:18:59 857 7.4 11.03 262 368.7 07/23/2015 15:19:57 850 7.4 11.02 270 375.4 bottom plug landed 07/23/2015 15:20:09 862 7.4 11.01 266 376.8 07/23/2015 15:21:19 826 7.4 11.11 247 385.0 07/23/2015 15:22:01 814 7.4 11.14 241 389.8 cement @ shoe 07/23/2015 15:22:29 840 7.4 11.15 240 393.1 07/23/2015 15:23:39 803 7.4 11.12 236 401.2 07/23/2015 15:24:49 863 7.3 11.15 228 409.3 07/23/2015 15:25:59 861 7.4 11.07 238 417.4 07/23/2015 15:27:09 886 7.4 11.24 257 425.5 07/23/2015 15:28:19 323 3.4 11.07 77 429.9 07/23/2015 15:29:29 98 0.0 11.04 6 432.2 07/23/2015 15:29:39 99 0.0 11.05 6 432.2 down on pump 07/23/2015 15:29:44 100 0.0 11.05 6 432.2 Reset Total,Vol=432.2 bbl 07/23/2015 15:30:39 100 0.0 11.07 3 0.0 07/23/2015 15:31:49 100 0.0 10.12 2 0.0 07/23/2015 15:32:59 100 0.0 10.07 6 0.0 07/23/2015 15:34:09 100 0.0 9.93 5 0.0 07/23/2015 15:35:19 100 0.0 9.93 3 0.0 07/23/2015 15:36:29 99 0.0 8.40 2 0.0 07/23/2015 15:37:39 98 0.0 10.52 7 0.0 07/23/2015 15:38:49 98 0.0 12.00 7 0.0 07/23/2015 15:39:59 97 0.0 11.30 0 0.0 07/23/2015 15:41:09 97 0.0 11.91 4 0.0 07/23/2015 15:42:19 139 4.6 12.05 7 0.1 07/23/2015 15:43:29 456 4.7 12.18 93 5.5 07/23/2015 15:44:39 514 4.7 12.15 125 10.9 07/23/2015 15:45:49 524 4.7 12.10 139 16.2 07/23/2015 15:45:58 509 4.7 12.09 142 16.9 tail mudscaled @ 12# 07/23/2015 15:46:59 550 4.7 12.09 144 21.5 07/23/2015 15:48:09 538 4.7 12.06 149 26.8 07/23/2015 15:49:19 525 4.7 12.16 147 32.2 07/23/2015 15:50:29 551 4.7 12.15 157 37.5 07/23/2015 15:51:39 563 4.7 12.11 155 42.8 07/23/2015 15:52:49 525 4.7 12.06 147 48.1 07/23/2015 15:53:59 535 4.7 12.06 148 53.4 07/23/2015 15:55:09 490 4.7 12.01 120 58.8 Page 6 of 13 • • • Well Field Job Start Customer Job Number 1D-1451D-145 Kuparuk Jul/23/2015 ConocoPhillips DDKA-00020/7689 Date Time Treating Flow Density WHP Stage Message 24-hr Pressure Rate LB/G PSI Volume clock PSI B/M BBL 07/23/2015 15:57:29 280 1.8 12.07 60 66.4 07/23/2015 15:58:39 172 1 1.5 12.12 23 68.1 07/23/2015 15:59:17 106 0.0 12.03 2 68.9 Reset Total,Vol=68.9 bbl 07/23/2015 15:59:49 107 0.0 12.01 4 0.0 07/23/2015 16:00:59 106 0.0 12.00 3 0.0 07/23/2015 16:02:09 105 0.0 11.99 6 0.0 07/23/2015 16:03:19 106 0.0 11.97 4 0.0 07/23/2015 16:03:46 106 0.0 11.97 4 0.0 start 10 bbis water behind 07/23/2015 16:04:29 550 7.2 11.98 185 3.0 07/23/2015 16:04:49 459 7.2 11.99 114 5.2 still reciprocating 07/23/2015 16:05:39 136 0.0 12.00 8 9.4 07/23/2015 16:05:57 66 0.0 12.00 -13 9.4 down on pump,rig is lining up 07/23/2015 16:06:49 73 0.0 12.02 -10 9.4 07/23/2015 16:07:59 79 0.0 11.98 364 9.4 07/23/2015 16:09:09 199 0.0 11.99 323 9.4 07/23/2015 16:10:19 160 0.0 11.99 328 9.4 07/23/2015 16:11:29 73 0.0 11.99 343 9.4 07/23/2015 16:12:39 72 0.0 8.66 354 9.4 07/23/2015 16:13:49 74 0.0 9.19 340 9.4 07/23/2015 16:14:59 75 0.0 9.20 375 9.4 07/23/2015 16:16:09 72 0.0 9.53 372 9.4 07/23/2015 16:17:19 73 0.0 10.35 365 9.4 07/23/2015 16:18:29 73 0.0 11.12 394 9.4 07/23/2015 16:19:39 73 0.0 11.18 400 9.4 07/23/2015 16:20:44 73 0.0 11.15 395 9.4 1090 strokes away 07/23/2015 16:20:49 73 0.0 11.12 390 9.4 07/23/2015 16:20:55 73 0.0 11.11 398 9.4 8 bpm 07/23/2015 16:21:59 73 0.0 11.18 410 9.4 07/23/2015 16:22:00 73 0.0 11.18 408 9.4 return flow 23% 07/23/2015 16:23:09 73 0.0 11.31 401 9.4 07/23/2015 16:24:19 73 0.0 11.30 410 9.4 07/23/2015 16:25:29 72 0.0 8.70 418 9.4 07/23/2015 16:26:39 72 0.0 8.59 422 9.4 07/23/2015 16:27:49 195 0.0 -3.11 414 9.4 07/23/2015 16:28:59 208 0.0 7.84 429 9.4 07/23/2015 16:30:09 78 0.0 7.99 455 9.4 07/23/2015 16:31:19 104 0.0 5.76 455 9.4 07/23/2015 16:32:29 77 0.0 8.26 448 9.4 07/23/2015 16:33:39 86 0.0 8.31 463 9.4 07/23/2015 16:34:49 86 0.0 8.33 459 9.4 07/23/2015 16:35:59 73 0.0 8.42 450 9.4 07/23/2015 16:37:09 73 0.0 8.42 482 9.4 07/23/2015 16:38:19 92 0.0 8.39 506 9.4 07/23/2015 16:39:29 295 0.0 8.39 500 9.4 07/23/2015 16:40:39 73 0.0 8.40 518 9.4 07/23/2015 16:41:49 72 0.0 8.42 549 9.4 07/23/2015 16:42:59 72 0.0 8.44 540 9.4 07/23/2015 16:44:09 300 0.0 8.43 548 9.4 07/23/2015 16:45:19 75 0.0 8.41 583 9.4 07/23/2015 16:46:29 72 0.0 8.40 586 9.4 07/23/2015 16:47:39 72 0.0 8.35 566 9.4 07/23/2015 16:48:49 72 0.0 8.34 587 9.4 07/23/2015 16:49:59 256 0.0 8.38 602 9.4 07/23/2015 16:51:09 76 0.0 8.39 277 9.4 Page 7 of 13 • + • Well+ Field ]ob Start Customer lob Number i 1D-145 1D-145 Kuparuk Jul/23/2015 ConocoPhillips DDKA-00020/7689 Date Time Treating Flow Density WHP Stage ! Message 24-hr Pressure Rate LB/G PSI Volume. dock PSI B/M BBL 07/23/2015 16:53:29 178 0.0 8.40 279 9.4 07/23/2015 16:54:39 115 0.0 8.38 858 9.4 07/23/2015 16:55:49 88 0.0 8.41 852 9.4 07/23/2015 16:56:28 98 0.0 8.41 851 9.4 bumped plug @ 3584 strokes away 07/23/2015 16:56:59 74 0.0 8.41 851 9.4 07/23/2015 16:58:09 72 0.0 8.39 851 9.4 07/23/2015 16:59:19 72 0.0 8.02 851 9.4 07/23/2015 17:00:29 246 0.0 8.35 814 9.4 07/23/2015 17:01:39 173 0.0 8.35 -19 9.4 07/23/2015 17:02:49 194 0.0 8.36 -19 9.4 07/23/2015 17:03:59 118 0.0 8.36 -18 9.4 07/23/2015 17:05:09 81 0.0 8.36 -11 9.4 07/23/2015 17:07:29 84 0.0 -3.11 -17 9.4 07/23/2015 17:08:39 72 0.0 0.10 -17 9.4 07/23/2015 17:09:49 70 0.0 0.11 -17 9.4 07/23/2015 17:10:59 70 0.0 0.11 -18 9.4 07/23/2015 17:12:09 70 0.0 0.06 -18 9.4 07/23/2015 17:13:19 71 0.0 0.09 -17 9.4 07/23/2015 17:14:29 70 0.0 0.06 -17 9.4 07/23/2015 17:15:39 72 0.0 0.06 -14 9.4 07/23/2015 17:16:49 70 0.0 0.06 -1 9.4 07/23/2015 17:17:59 70 0.0 0.06 -16 9.4 07/23/2015 17:19:09 70 0.0 0.06 -16 9.4 07/23/2015 17:20:19 70 0.0 0.06 -16 9.4 07/23/2015 17:21:29 70 0.0 0.06 -16 9.4 07/23/2015 17:22:39 70 0.0 0.06 -16 9.4 07/23/2015 17:23:49 70 0.0 0.06 -16 9.4 07/23/2015 17:24:59 69 0.0 0.06 -16 9.4 07/23/2015 17:26:09 69 0.0 0.06 -16 9.4 07/23/2015 17:27:19 70 0.0 0.06 -16 9.4 07/23/2015 17:28:29 69 0.0 0.06 -16 9.4 07/23/2015 17:29:39 69 0.0 0.06 -10 9.4 07/23/2015 17:30:49 69 0.0 0.06 -11 9.4 07/23/2015 17:31:59 70 0.0 0.06 -11 9.4 07/23/2015 17:33:09 69 0.0 0.06 -12 9.4 07/23/2015 17:34:19 69 0.0 0.06 -11 9.4 07/23/2015 17:35:29 69 0.0 0.06 -11 9.4 07/23/2015 17:36:39 69 0.0 0.05 -11 9.4 07/23/2015 17:37:49 69 0.0 0.06 -11 9.4 07/23/2015 17:38:59 69 0.0 0.06 -11 9.4 07/23/2015 17:40:09 69 0.0 0.06 -8 9.4 07/23/2015 17:42:29 69 0.0 0.06 -11 9.4 07/23/2015 17:43:39 69 0.0 0.06 -16 9.4 07/23/2015 17:44:49 69 0.0 0.06 -15 9.4 07/23/2015 17:45:59 69 0.0 0.06 -16 9.4 07/23/2015 17:47:09 69 0.0 0.06 -15 9.4 07/23/2015 17:48:19 69 0.0 0.06 -11 9.4 07/23/2015 17:49:29 69 0.0 0.06 -11 9.4 07/23/2015 17:50:39 69 0.0 0.06 -9 9.4 07/23/2015 17:51:49 69 0.0 0.06 -4 9.4 07/23/2015 17:52:59 69 0.0 0.06 -10 9.4 07/23/2015 17:54:09 69 0.0 0.06 -11 9.4 07/23/2015 17:55:19 69 0.0 0.05 -7 9.4 07/23/2015 17:56:29 69 0.0 0.05 -15 9.4 Page8 of 13 • • . Well Field lob Start Customer lob Number 1D-145 1D-145 Kuparuk Jul/23/2015 ConocoPhillips DDKA-00020/7689 Date Time Treating Flow Density WHP Stage Message 24-hr Pressure Rate LB/G PSI Volume dock PSI B/M BBL 07/24/2015 01:37:19 68 0.0 0.04 -3746 9.4 07/24/2015 01:37:26 69 0.0 0.05 -3746 9.4 re-spotted for top job 07/24/2015 01:38:29 68 0.0 0.05 -3746 9.4 07/24/2015 01:39:39 68 0.0 0.05 -3746 9.4 07/24/2015 01:40:49 68 0.0 0.04 -3746 9.4 07/24/2015 01:41:59 68 0.0 0.05 -3746 9.4 07/24/2015 01:42:18 68 0.0 0.05 -3746 9.4 mixing top out with small tub only 07/24/2015 01:43:09 68 0.0 0.05 -3746 9.4 07/24/2015 01:45:29 68 0.0 0.05 -3746 9.4 07/24/2015 01:46:39 68 0.0 0.04 -3746 9.4 07/24/2015 01:47:49 94 0.0 0.05 -3746 9.4 07/24/2015 01:48:59 76 0.0 0.05 -3746 9.4 07/24/2015 01:50:09 165 0.0 8.34 -3745 9.4 07/24/2015 01:51:19 70 0.0 8.35 -3745 9.4 07/24/2015 01:52:29 69 0.0 8.35 -3745 9.4 07/24/2015 01:53:39 69 0.0 8.33 -3745 9.4 07/24/2015 01:54:49 133 0.0 8.35 -3745 9.4 07/24/2015 01:55:59 161 0.0 8.35 -3745 9.4 07/24/2015 01:57:09 71 0.0 8.34 -3745 9.4 07/24/2015 01:58:19 71 0.0 8.36 -3745 9.4 07/24/2015 01:59:29 85 0.0 8.35 -3744 9.4 07/24/2015 02:00:39 70 0.0 8.35 -3745 9.4 07/24/2015 02:01:49 70 0.0 8.36 -3745 9.4 07/24/2015 02:02:59 70 0.0 8.36 -3745 9.4 07/24/2015 02:03:15 69 0.0 8.36 -3745 9.4 Reset Total,Vol=9.5 bbl 07/24/2015 02:04:09 69 0.0 8.36 -3744 0.0 07/24/2015 02:05:19 69 0.0 8.36 -3745 0.0 07/24/2015 02:06:29 70 0.0 8.36 -3744 0.0 07/24/2015 02:07:39 69 0.0 8.36 -3744 0.0 07/24/2015 02:08:49 69 0.0 8.36 -3745 0.0 07/24/2015 02:09:59 69 0.0 8.36 -3745 0.0 07/24/2015 02:11:09 69 0.0 8.36 -3745 0.0 07/24/2015 02:12:19 69 0.0 8.36 -3745 0.0 07/24/2015 02:13:29 69 0.0 8.36 -3745 0.0 07/24/2015 02:14:39 69 0.0 8.36 -3745 0.0 07/24/2015 02:15:49 69 0.0 8.36 -3745 0.0 07/24/2015 02:16:59 69 0.0 8.36 -3745 0.0 07/24/2015 02:18:09 146 0.3 8.35 -3745 0.0 07/24/2015 02:18:17 149 0.4 8.35 -3744 0.0 start pumping water ahead 07/24/2015 02:19:37 109 0.4 8.34 -3744 0.0 have returns in the cellar 07/24/2015 02:20:29 107 0.4 8.34 -3745 0.0 07/24/2015 02:21:39 106 0.3 8.35 -3745 0.0 07/24/2015 02:22:49 105 0.3 8.35 -3745 0.0 07/24/2015 02:23:59 145 0.6 8.35 -3745 0.0 07/24/2015 02:25:09 136 0.6 8.34 -3745 0.0 07/24/2015 02:26:19 133 0.5 8.35 -3745 0.0 07/24/2015 02:27:29 201 0.8 8.35 -3745 0.0 07/24/2015 02:28:39 189 0.8 8.34 -3745 0.0 07/24/2015 02:29:49 189 0.8 8.35 -3745 0.0 07/24/2015 02:30:59 188 0.8 8.39 -3745 0.0 07/24/2015 02:32:09 188 0.8 8.35 -3744 0.0 07/24/2015 02:33:19 188 0.8 8.35 -3744 0.0 07/24/2015 02:34:29 186 0.8 8.35 -3745 0.0 07/24/2015 02:35:39 186 0.8 8.35 -3744 0.0 Page 9 of 13 • • Well Field lob Start Customer Job Number 1D-145 1D-145 Kuparuk Jul/23/2015 ConocoPhillips DDKA-00020/7689 ~ Date Time Treating 1 Flow Density WHP Stage Message 24-hr Pressure '. Rate LB/G PSI Volume dock PSI B/M BBL i 07/24/2015 02:37:59 186 0.8 8.35 -3745 ' 0.0 07/24/2015 02:39:09 187 0.8 8.34 -3745 0.0 07/24/2015 02:40:19 186 0.8 8.34 -3744 0.0 07/24/2015 02:41:29 188 0.8 8.35 -3745 0.0 07/24/2015 02:42:39 186 0.8 8.34 -3744 0.0 07/24/2015 02:43:49 239 0.9 8.34 -3744 0.0 07/24/2015 02:44:59 236 0.9 8.34 -3745 0.0 07/24/2015 02:46:09 236 0.9 8.34 -3745 0.0 07/24/2015 02:47:19 235 0.9 8.34 -3745 0.0 07/24/2015 02:48:29 237 0.9 8.35 -3744 0.0 07/24/2015 02:49:39 238 0.9 8.35 -3744 0.0 07/24/2015 02:50:49 238 0.9 8.34 -3745 0.0 07/24/2015 02:51:59 239 0.9 8.35 -3745 0.0 07/24/2015 02:53:09 238 0.9 8.34 -3745 0.0 07/24/2015 02:55:29 236 0.9 8.35 -3744 0.0 07/24/2015 02:56:39 237 0.9 8.35 -3744 0.0 07/24/2015 02:57:49 238 0.9 8.34 -3745 0.0 07/24/2015 02:58:59 236 0.9 8.34 -3744 0.0 07/24/2015 03:00:09 236 0.9 8.35 -3744 0.0 07/24/2015 03:01:19 236 0.9 8.34 -3745 0.0 07/24/2015 03:02:29 237 0.9 8.34 -3745 0.0 07/24/2015 03:03:39 236 0.9 8.34 -3744 0.0 07/24/2015 03:04:49 235 0.9 8.34 -3745 0.0 07/24/2015 03:05:59 238 0.9 8.34 -3745 0.0 07/24/2015 03:07:09 238 0.9 8.35 -3745 0.0 07/24/2015 03:08:19 238 0.9 8.34 -3744 0.0 07/24/2015 03:09:29 238 0.9 8.34 -3745 0.0 07/24/2015 03:10:39 242 0.9 8.35 -3745 0.0 07/24/2015 03:11:49 241 0.9 8.35 -3744 0.0 07/24/2015 03:12:59 186 0.0 8.35 -3744 0.0 07/24/2015 03:13:44 67 0.0 8.35 -3744 0.0 Reset Total,Vol=45.0 bbl 07/24/2015 03:14:09 66 0.0 8.35 -3745 0.0 07/24/2015 03:15:19 66 0.0 -3.11 -3745 0.0 07/24/2015 03:16:10 65 0.0 -3.11 -3746 0.0 start batching cement 07/24/2015 03:16:29 65 0.0 -3.09 -3745 0.0 07/24/2015 03:17:39 -390 0.0 -3.12 -3748 0.0 07/24/2015 03:18:49 88 0.0 -3.11 -3747 0.0 07/24/2015 03:19:59 -560 0.0 -3.11 -3748 0.0 07/24/2015 03:21:09 100 0.0 -3.08 -3748 0.0 07/24/2015 03:22:19 67 0.0 -3.10 -3747 0.0 07/24/2015 03:23:29 67 0.0 -3.12 -3748 0.0 07/24/2015 03:23:56 67 0.0 -3.11 -3747 0.0 Reset Total,Vol=0.05 bbl 07/24/2015 03:24:39 67 0.0 -3.11 -3747 0.0 07/24/2015 03:25:49 66 0.0 -3.11 -3747 0.0 07/24/2015 03:26:59 66 0.0 -3.09 -3748 0.0 07/24/2015 03:28:09 143 0.0 -3.10 -3747 0.0 07/24/2015 03:30:29 130 0.6 -3.10 -3747 0.0 07/24/2015 03:31:39 133 0.6 -3.09 -3747 0.0 07/24/2015 03:32:49 134 0.6 -3.11 -3747 0.0 07/24/2015 03:33:27 134 0.6 -3.12 -3747 0.0 scale 11.3 07/24/2015 03:33:59 133 0.6 -3.11 -3747 0.0 07/24/2015 03:35:09 133 0.6 -3.11 -3747 0.0 07/24/2015 03:36:19 134 0.5 -3.11 -3747 0.0 07/24/2015 03:37:29 136 0.6 -3.12 -3748 0.0 Page 10 of 13 • • • •- . Well Field Job Start Customer Job Number 10-145 1D-145 Kuparuk Jul/23/2015 ConocoPhillips DDKA-00020/7689 Date Time Treating Flow Density WHP Stage Message 24-hr Pressure Rate LB/G PSI Volume clock PSI B/M BBL 07/24/2015 03:39:49 133 0.6 -3.11 -3748 0.0 07/24/2015 03:40:59 134 0.5 -3.11 -3747 0.0 07/24/2015 03:42:09 133 0.5 -3.11 -3747 0.0 07/24/2015 03:43:19 132 0.6 -3.10 -3747 0.0 07/24/2015 03:44:29 136 0.6 -3.11 -3747 0.0 07/24/2015 03:45:39 193 0.5 -3.11 -3748 0.0 07/24/2015 03:46:49 133 0.6 -3.11 -3748 0.0 07/24/2015 03:47:59 134 0.5 -3.11 -3747 0.0 07/24/2015 03:49:09 132 0.6 -3.11 -3747 0.0 07/24/2015 03:50:19 152 0.5 -3.11 -3747 0.0 07/24/2015 03:51:29 214 0.5 -3.11 -3747 0.0 07/24/2015 03:52:39 212 0.5 11.27 -3746 0.0 07/24/2015 03:53:49 209 0.5 11.13 -3746 0.0 07/24/2015 03:54:59 167 0.5 10.91 -3746 0.0 07/24/2015 03:56:09 166 0.5 10.95 -3746 0.0 07/24/2015 03:57:19 170 0.5 10.96 -3746 0.0 07/24/2015 03:58:29 165 0.5 10.98 -3746 0.0 07/24/2015 03:59:39 165 0.5 11.01 -3746 0.0 07/24/2015 04:00:49 164 0.5 11.09 -3746 0.0 07/24/2015 04:01:59 168 0.5 11.12 -3746 0.0 07/24/2015 04:03:09 171 0.5 11.11 -3746 0.0 07/24/2015 04:04:19 171 0.5 11.11 -3746 0.0 07/24/2015 04:05:29 171 0.5 11.01 -3746 0.0 07/24/2015 04:06:39 165 0.5 11.00 -3746 0.0 07/24/2015 04:07:49 164 0.6 11.04 -3746 0.0 07/24/2015 04:08:59 163 0.5 11.06 -3746 0.0 07/24/2015 04:10:09 163 0.6 11.07 -3746 0.0 07/24/2015 04:11:19 162 0.5 11.14 -3746 0.0 07/24/2015 04:12:29 169 0.5 11.06 -3746 0.0 07/24/2015 04:13:39 165 0.5 11.02 -3746 0.0 07/24/2015 04:14:49 162 0.5 10.99 -3746 0.0 07/24/2015 04:15:59 200 0.6 10.95 -3746 0.0 07/24/2015 04:17:09 241 0.7 10.98 -3746 0.0 07/24/2015 04:18:19 244 0.8 10.87 -3746 0.0 07/24/2015 04:19:29 257 0.8 10.83 -3746 0.0 07/24/2015 04:20:39 277 0.8 11.10 -3746 0.0 07/24/2015 04:21:49 327 0.8 11.03 -3746 0.0 07/24/2015 04:22:59 329 0.8 11.03 -3746 0.0 07/24/2015 04:24:09 322 0.8 8.07 -3746 0.0 07/24/2015 04:25:19 288 0.8 -3.11 -3747 0.0 07/24/2015 04:26:29 314 0.8 -3.11 -3748 0.0 07/24/2015 04:27:39 287 0.8 -3.10 -3748 0.0 07/24/2015 04:28:49 273 0.8 -3.12 -3748 0.0 07/24/2015 04:29:59 310 0.8 -3.11 -3747 0.0 07/24/2015 04:31:09 263 0.8 -3.12 -3747 0.0 07/24/2015 04:32:19 241 0.8 -3.10 -3747 0.0 07/24/2015 04:33:29 239 0.8 -3.11 -3747 0.0 07/24/2015 04:34:39 337 0.8 -3.10 -3747 0.0 07/24/2015 04:35:49 332 0.8 -3.11 -3747 0.0 07/24/2015 04:36:59 317 0.5 -3.11 -3747 0.0 cement to surface 07/24/2015 04:38:09 247 0.5 -3.11 -3747 0.0 07/24/2015 04:39:19 226 0.5 -3.11 -3747 0.0 07/24/2015 04:40:29 259 0.5 -3.11 -3747 0.0 07/24/2015 04:41:39 193 0.5 -3.12 -3747 0.0 Page 11 of 13 • • • Well Field Job Start Customer Job Number 1D-145 1D-145 Kuparuk Jul/23/2015 ConocoPhillips DDKA-00020/7689 Date Time Treating Flow Density WHP Stage Message 24-hr Pressure Rate LB/G PSI Volume clock PSI B/M BBL 07/24/2015 04:43:59 182 0.5 -3.11 -3747 0.0 07/24/2015 04:45:09 168 0.5 -3.11 -3747 0.0 07/24/2015 04:46:19 233 0.5 -3.11 -3747 0.0 07/24/2015 04:47:29 238 0.5 -3.11 -3747 0.0 07/24/2015 04:48:39 234 0.5 -3.11 -3748 0.0 07/24/2015 04:49:49 227 0.5 -3.11 -3747 0.0 07/24/2015 04:50:59 287 0.5 -3.11 -3748 0.0 07/24/2015 04:52:09 241 0.5 -3.11 -3747 0.0 07/24/2015 04:53:19 221 0.5 -3.11 -3747 0.0 07/24/2015 04:54:29 216 0.5 -3.11 -3747 0.0 07/24/2015 04:55:39 208 0.5 -3.11 -3747 0.0 07/24/2015 04:56:49 254 0.5 -3.10 -3747 0.0 07/24/2015 04:57:59 271 0.5 -3.10 -3747 0.0 07/24/2015 04:59:09 264 0.5 -3.10 -3747 0.0 07/24/2015 05:00:19 259 0.5 -3.09 -3747 0.0 07/24/2015 05:01:29 279 0.5 -3.10 -3748 0.0 07/24/2015 05:02:39 259 0.5 -3.11 -3747 0.0 07/24/2015 05:03:49 256 0.5 -3.10 -3747 0.0 07/24/2015 05:04:59 251 0.5 -3.11 -3747 0.0 07/24/2015 05:06:09 240 0.5 -3.10 -3747 0.0 07/24/2015 05:07:19 238 0.5 -3.08 -3747 0.0 07/24/2015 05:07:29 236 0.5 -3.10 -3747 0.0 114 cement to surface 07/24/2015 05:08:29 81 0.0 -3.11 -3747 0.0 07/24/2015 05:09:39 67 0.0 -3.11 -3747 0.0 07/24/2015 05:10:49 67 0.0 -3.11 -3747 0.0 07/24/2015 05:11:59 66 0.0 -3.11 -3747 0.0 07/24/2015 05:13:09 70 0.0 -3.11 -3747 0.0 07/24/2015 05:14:19 76 0.0 -3.11 -3747 0.0 07/24/2015 05:15:29 78 0.0 -3.11 -3747 0.0 07/24/2015 05:16:39 62 0.0 -3.11 -3747 0.0 07/24/2015 05:17:49 62 0.0 -3.13 -3747 0.0 07/24/2015 05:18:59 62 0.0 -3.08 -3747 0.0 07/24/2015 05:20:09 62 0.0 -3.11 -3747 0.0 07/24/2015 05:21:19 66 0.0 -3.11 -3747 0.0 07/24/2015 05:22:29 60 0.0 -3.11 -3747 0.0 07/24/2015 05:23:39 64 0.0 -3.11 -3747 0.0 07/24/2015 05:24:49 59 0.0 -3.11 -3747 0.0 07/24/2015 05:25:59 66 0.0 -3.11 -3747 0.0 07/24/2015 05:27:09 65 0.0 -3.11 -3747 0.0 07/24/2015 05:28:19 65 0.0 -3.12 -3747 0.0 07/24/2015 05:29:29 66 0.0 -3.07 -3747 0.0 07/24/2015 05:30:39 65 0.0 -3.12 -3747 0.0 07/24/2015 05:31:49 142 0.0 -3.11 -3747 0.0 07/24/2015 05:32:59 187 0.0 -3.09 -3747 0.0 07/24/2015 05:34:09 67 0.0 -3.11 -3747 0.0 Page 12 of 13 . _• • • Well Field Job Start Customer Job Number 1D-145 1D-145 Kuparuk Jul/23/2015 ConocoPhillips DDKA-00020/7689 Post Job Summary Average Pump Rates,bbl/min Volume of Fluid Injected,bbl Slurry N2 Mud Maximum Rate Total Slurry Mud Spacer N2 2.9 7.7 558.1 0.0 150.0 Treating Pressure Summa l''...,:,:' ,0''' : ! Breakdown Fluid Maximum Final Average Bump Plug to Breakdown Type Volume Density 4267 81 156 800 bbl Ib/gal Avg.N2 Percent Designed Slurry Volume Displacement Mix Water Temp Cement Circulated to Surface? Volume bbl % 0.0 bbl 10.0 bbl 80 degF Washed Thru Perfs ❑ To ft Customer or Authorized Representative Schlumberger Supervisor Circulation Lost ❑ Job Completed XD Lee Martin John Morrison - _ Page 13 of 13 • Pro 0)4-- 13� Loepp, Victoria T (DOA) From: Herrera, Matthew F (DOA) Sent: Tuesday,July 28, 2015 4:50 PM To: Regg,James B (DOA) Cc: Loepp,Victoria T (DOA) Subject: KRU-1D-145 Attachments: P and A Report 1D-145.xlsx Follow Up Flag: Follow up Flag Status: Flagged Here is the memo for the TOC verification on KRU-1D-145. Matt Herrera Petroleum Inspector Alaska Oil &Gas Conservation Commission 907-659-7966 Office 907-448-1227 Work Cell Ph 907-953-7966 Personal Cell Ph 1 111 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: July 24, 2015 P.I. Supervisor SUBJECT: P&A THRU: Well Name/Number KRU-1D-145 Operator CPAI Pad or Platform KRU-1 D-Pad FROM: Matt Herrera Field/Unit KRU-Oil Pool Petroleum Inspector PTD#214138 Section: Township: Range: Meridian: Lease No.: Drilling Rig: Doyon 25 Rig Elevation: Total Depth: Operator Rep.: Lee Hinckel Casina/Tubinq Data: Casing Removal: Conductor: 20 O.D. Shoe@ Casing Cut@ Feet Surface: 9 5/8 O.D. Shoe@ Casing Cut@ Feet Intermediate: 7 O.D. Shoe@ Casing Cut@ Feet Production: O.D. Shoe@ Casing Cut@ Feet Liner: O.D. Shoe@ Casing Cut@ Feet Tubing: 41/2 O.D. Tail@ Casing Cut@ Feet Pluming Data: Type Pluq Bottom of T.O.C. Mud Weight Pressure (bottom up) Founded on Cement(M.D.) T.O.C. Depth Verified? above plug Test Surface Bottom 130' 1 32" Visual 11.0 No I � Type Pluq Founded on: Verified? Open Hole Bottom Drilipipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T.Tag Casing Stub Retainer No Surface Approval of well plan from Victoria Loepp AOGCC per Email and phone conversation. Cement top was verified at surface by visual through an opening in casing at 32"from top of conductor cc: Attachments: Distribution: -Well File(original) -Read File -DNR/DOG Rev.:5/28/00 by L.R.G. P and A Report 1D-145.xlsx 8/12/2015 • • Pro Z14 - / 38 Loepp, Victoria T (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Monday,July 27, 2015 10:17 AM To: Loepp, Victoria T (DOA) Subject: RE: Permit#214-138: 1D-145 Surface Cement -Top Job Attachments: 1D-145surfacecementreport.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, please see the attached cement pumping report. I am filing the hard copies today. Kelsey Hallford From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaskagov] Sent: 26 July 2015 15:58 To: Hallford, Kelsey Subject: [EXTERNAL]Re: Permit# 214-138: 1D-145 Surface Cement-Top Job Yes, attach the cement pumping report. Also,please submit paper copies in duplicate to the AOGCC as you would any 10-403, Monday morning. Thanx, Victoria On Jul 24, 2015, at 4:29 PM, Hallford, Kelsey<Kelsey.Hallford@conocophillips.com>wrote: Victoria, Please find the 10-403 form for the 1D-145 surface cement top job. Would you like the cement pumping report as an attachment? Thanks, Kelsey Hallford From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@ alaska.gov] Sent: 24 July 2015 08:46 To: Hallford, Kelsey Cc: Regg, James B (DOA) Subject: [EXTERNAL]RE: Permit# 214-138: 1D-145 Surface Cement -Top Job Kelsey, Please submit a 10-403 for the top job as soon as possible. Include verbal approval by AOGCC on form. 1 • • Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepot 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: Hallford, Kelsey [mailto:Kelsey.Hallford@conocophillips.com] Sent: Friday, July 24, 2015 5:38 AM To: Loepp, Victoria T(DOA); Doyon 25 Company Man Cc: Voss, Jake; Vosen, BrookeLynn; Woodard, Madeline E; Lehman, Nick R; Doyon 25 Rig Engineer; Bearden, J Daniel; Ardrey, Blake M; Brunswick, Scott A; Lee, David L; Shultz, Steve (Orbis Engineering, Inc.); Guo, Haibin; Callahan, Mike S; Hyden, Duncan P; Herbert, Frederick 0 Subject: RE: Permit# 214-138: 1D-145 Surface Cement-Top Job Victoria, We have completed our top job for the surface hole on 1D-145. Prior to cementing, we flushed the annulus of MudPush II and tagged at 130' MD with our%" tubing. We saw cement back at surface after pumping 55bbls, continued pumping for a total of 57.1bbls of 11ppg Lead cement. Please call or email with any questions or concerns, Kelsey From: Hallford, Kelsey Sent: 23 July 2015 19:01 To: 'victoria.loepp@alaska.gov; Doyon 25 Company Man Cc: 'Voss, Jake (Jake.Voss@conocophillips.com)'; Vosen, BrookeLynn; Woodard, Madeline E; Lehman, Nick R; Doyon 25 Rig Engineer; Bearden,J Daniel; Ardrey, Blake M (Blake.M.Ardrey©conocophillips.com); Brunswick, Scott A; Lee, David L; Shultz, Steve (Orbis Engineering, Inc.); Guo, Haibin; Callahan, Mike S; Hyden, Duncan P; Herbert, Frederick 0 Subject: Permit# 214-138: 1D-145 Surface Cement-Top Job Victoria, As mentioned on the phone,we will require a top job on our surface cement job for 1D-145.Our cement volumes were based on 200%excess in the permafrost and 50%excess from the permafrost to the shoe. We had full returns over the course of the cement job, but did not get cement to surface.We received 59bbls of the MudPushll to surface, leading us to calculate an additional 16bbls of cement needed to reach surface. Our estimated 2 TOC is currently at 120' MD,we wile%"tubing to flush the annulus and perform our top job to achieve cement to surface. The cement job went as follows: 75bbls CW100 75bbls MudPush II 432.2bbls 11ppg Lead 68.9bbls 12ppg Tail Plugs bumped on calculated strokes Floats held Please call or email with any questions or concerns, Kelsey Hallford Drilling Engineer I ConocoPhillips Office: +1-907-265-1577 Cell: +1-907-440-0004 Email: kelsey.hallford(ccop.com <10-403.jpg> 3 Schiumberger • Cementing Sere Report Customer lob Number ConocoPhillips DDKA-00020/7689 Well Location(legal) Schlumberger Location Job Start 1D-145 10-145 Drill Site 1D Prudhoe Other Jul/23/2015 Field Formation Name/Type Deviation MR Size Well MD Weil TVD Kuparuk Clean-Sandstone 24 deg 16.0 in 2574.0 ft 2488.0 ft County Beechey Point Stab/Province Alaska IMP MIST MGT Pore Press.Gradient Weil Nester 0631602467 API/ONO 5002923526000 psi 60 degF 77 degF lb/gal Rig Name Drilled For Service Via Casing/Liner Doyon 25 Oil&Gas Land Dego,ft Woe,M Weight,lb/ft Grade Thread Offshore Zone Well Claes Well Type 2564.0 13.4 68.0 L-80 HYD 563 Old Development 0.0 0.0 0.0 Drilling Fluid Type flax.Density Plastic Viscosity Tubing/or ll Pipe lb/gal cP T/D Depth,ft Size,in Weight,lb/ft Grade Thread Service Line lob Type Cementing Surface Nax.Allowed Tub.Press Max.Allowed Ann.Press WM Connection PpMratla s/Open Mole psi psi 2"FMC Tap,ft __. Bottom,ft shot/ft No.of Shots Total Interval Servica Instructions ft ft ft ft ft Diameter ft ft in Treat Down Displacement Packer Type Packer Depth Casing 371.4 bbl ft Tubing Vol. Casing Vol. Annular Vol. _.. Openhele Vol bbl 383.5 bbl bbl bbl Casing/Tubing Secured El 1 Mole Vol.Circulated prior to Cement ❑X Casing Tools Squeeze lob LIC Pressure 300 psi Shoe Type Float Squeeze Type Pipe Rotated El Pipe Redprocatod QX Shoe Depth -_.-_-. 2564.0 ft T001Tiffie No.Centralizers 60 I Top Plugs 1 Batton Mugs 1 Stage Tool Type Tool Depth ft Cement Mead Type Stage Tool Depth ft Tall Pipe Size In 3ab Scheduled For Arrived on Location Leave Location Collar Type Float Tall Pipe Depth ft Jul/23/2015 Jul/23/2015 JuV23/2015 Collar Depth 2481.0 ft sox.Total Vol. bbl Date Time Treating Row Density WMP Stale - Message 24 hr Pressure Rab ora PSI VeWme dodo PSI B/M NIL 07/23/2015 10:43:39 67 0.0 0.05 -25 0.0 Started Acquisition 07/23/2015 10:44:49 67 0.0 0.05 -23 0.0 07/23/2015 10:45:59 67 0.0 0.05 -24 0.0 07/23/2015 10:47:09 67 0.0 0.05 -24 0.0 07/23/2015 10:48:19 66 0.0 0.05 -25 0.0 07/23/2015 10:49:29 67 0.0 0.05 -25 0.0 07/23/2015 10:50:39 70 0.0 0.05 -18 0.0 07/23/2015 10:51:49 67 0.0 0.05 -22 0.0 07/23/2015 10:52:59 67 0.0 0.05 -11 0.0 07/23/2015 10:54:09 66 0.0 0.04 -19 0.0 07/23/2015 10:55:19 85 0.0 8.33 -19 0.0 07/23/2015 10:56:29 136 0.0 8.33 -16 0.0 07/23/2015 10:57:39 93 0.0 8.34 -18 0.0 07/23/2015 10:58:49 69 0.0 8.35 -17 0.0 07/23/2015 10:59:59 206 0.0 8.36 -19 0.0 07/23/2015 11:01:09 76 0.0 8.35 -20 0.0 07/23/2015 11:02:19 69 0.0 8.35 -16 0.0 07/23/2015 11:03:29 69 0.0 8.36 -21 0.0 07/23/2015 11:04:39 72 0.0 8.36 -20 0.0 07/23/2015 11:05:49 69 0.0 8.35 -20 0.0 07/23/2015 11:08:09 106 0.0 8.36 -23 0.0 Pegs 1 of 13 WAR lob Start Costume lob Humber 10-145 10-145 Kuparuk Jul/23/2015 coPhillips DDKA-00020/7689 Data Time Treating Flow Density WHP 1 Stage Message 24-hr Pressure Rah LB/6 PSI Volume Clock PSI BM BBL 07/23/2015 11:09:19 104 3.0 8.36 -23 2.8 07/23/2015 11:10:15 109 0.0 8.36 -22 3.2 h head rate check 07/23/2015 11:10:29 108 3.0 8.36 -23 3.6 07/23/2015 11:11:39 69 0.0 8.36 -24 6.2 07/23/2015 11:11:43 69 0.0 8.36 -23 6.2 Reset Total,Vole 11.78 bbl 07/23/2015 11:12:49 135 0.0 8.35 -23 0.0 07/23/2015 11:13:59 71 0.0 4.71 -23 0.0 07/23/2015 11:15:09 71 0.0 8.34 -22 0.0 07/23/2015 11:16:19 102 0.0 8.34 -23 0.0 07/23/2015 11:17:29 69 0.0 8.35 -24 0.0 07/23/2015 11:18:39 70 0.0 8.35 -22 0.0 07/23/2015 11:19:49 69 0.0 8.35 24 0.0 07/23/2015 11:20:59 68 0.0 8.35 81 0.0 07/23/2015 11:22:09 83 0.0 8.35 182 0.0 07/23/2015 11:23:19 69 0.0 8.35 164 0.0 07/23/2015 11:24:29 69 0.0 8.36 174 0.0 07/23/2015 11:25:39 69 0.0 8.35 187 0.0 07/23/2015 11:26:49 70 0.0 8.35 225 0.0 07/23/2015 11:27:59 69 0.0 8.35 196 0.0 07/23/2015 11:29:09 70 0.0 8.36 239 0.0 07/23/2015 11:30:19 70 0.0 8.36 257 0.0 07/23/2015 11:31:29 69 0.0 8.36 293 0.0 07/23/2015 11:32:39 70 0.0 8.36 299 0.0 07/23/2015 11:33:49 70 0.0 8.36 309 0.0 07/23/2015 11:34:59 69 0.0 8.36 300 0.0 07/23/2015 11:36:09 70 0.0 8.36 306 0.0 07/23/2015 11:37:19 71 0.0 8.36 303 0.0 07/23/2015 11:38:29 70 0.0 8.36 360 0.0 07/23/2015 11:39:39 71 0.0 8.36 346 0.0 07/23/2015 11:40:49 69 0.0 8.36 343 0.0 07/23/2015 11:43:09 70 0.0 8.36 339 0.0 07/23/2015 11:44:19 71 0.0 8.36 341 0.0 07/23/2015 11:45:29 71 0.0 8.36 350 0.0 07/23/2015 11:46:39 71 0.0 8.36 352 0.0 07/23/2015 11:47:49 70 0.0 $.36 297 0.0 07/23/2015 11:48:59 10 0.0 8.36 329 0.0 07/23/2015 11:50:09 70 0.0 8.36 329 0.0 07/23/2015 11:51:19 70 0.0 8.36 359 0.0 07/23/2015 11:52:29 70 0.0 8.36 302 0.0 07/23/2015 11:53:39 70 0.0 8.36 316 0.0 07/23/2015 11:54:49 70 0.0 8.36 332 0.0 07/23/2015 11:55:59 70 0.0 8.36 325 0.0 07/23/2015 11:57:09 71 0.0 8.36 323 0.0 07/23/2015 11:58:19 71 0.0 8.36 326 0.0 07/23/2015 11:59:29 70 0.0 8.36 330 0.0 07/23/2015 12:00:39 69 0.0 8.36 314 0.0 07/23/2015 12:01:49 70 0.0 8.36 319 0.0 07/23/2015 12:02:59 69 0.0 8.36 357 0.0 07/23/2015 12:04:09 70 0.0 8.36 295 0.0 07/23/2015 12:05:19 70 0.0 8.36 293 0.0 07/23/2015 12:06:29 70 0.0 8.36 329 0.0 07/23/2015 12:07:39 70 0.0 8.36 369 0.0 07/23/2015 12:08:49 69 0.0 8.36 367 0.0 07/23/2015 12:09:59 69 0.0 8.36 306 0.0 Pegs 2 of 13 Welt Fiel " Jab Start Job Number 1D-145 10-145 Kuparuk lul/23/2015 coPhillips DDKA-00020/7689 Date Time Treating Flow Density WNP ---- Stage Message 24-hr Pressure Rate LB/6 PSI Volume dock PSI B/M BBL 07/23/2015 12:12:19 71 0.0 8.36 340 0.0 07/23/2015 12:13:29 69 0.0 8.36 302 0.0 07/23/2015 12:14:39 70 0.0 8.36 374 0.0 07/23/2015 12:15:49 69 0.0 8.36 342 0.0 07/23/2015 12:18:09 70 0.0 8.36 391 0.0 07/23/2015 12:19:19 69 0.0 8.36 331 0.0 07/23/2015 12:20:29 69 0.0 8.36 355 0.0 07/23/2015 12:21:39 69 0.0 8.36 366 0.0 07/23/2015 12:22:49 69 0.0 8.36 309 0.0 07/23/2015 12:23:59 68 0.0 8.37 343 0.0 07/23/2015 12:25:09 70 0.0 8.36 343 0.0 07/23/2015 12:26:19 69 0.0 8.36 327 0.0 07/23/2015 12:27:29 69 0.0 8.36 308 0.0 07/23/2015 12:28:39 69 0.0 8.36 354 0.0 07/23/2015 12:29:49 69 0.0 8.36 348 0.0 07/23/2015 12:30:59 69 0.0 8.36 319 0.0 07/23/2015 12:32:09 69 0.0 8.36 337 0.0 07/23/2015 12:33:19 70 0.0 8.36 347 0.0 07/23/2015 12:34:29 69 0.0 8.36 374 0.0 07/23/2015 12:35:39 69 0.0 8.36 347 0.0 07/23/2015 12:36:49 69 0.0 8.36 371 0.0 07/23/2015 12:37:59 69 0.0 8.36 362 0.0 07/23/2015 12:39:09 69 0.0 8.36 367 0.0 07/23/2015 12:40:19 69 0.0 8.36 402 0.0 07/23/2015 12:41:29 68 0.0 8.36 365 0.0 07/23/2015 12:42:39 68 0.0 8.36 361 0.0 07/23/2015 12:43:49 69 0.0 8.36 386 0.0 07/23/2015 12:44:59 68 0.0 8.36 334 0.0 07/23/2015 12:46:09 69 0.0 8.36 378 0.0 07/23/2015 12:47:19 68 0.0 8.36 400 0.0 07/23/2015 12:48:29 68 0.0 8.36 314 0.0 07/23/2015 12:49:39 69 0.0 8.36 340 0.0 07/23/2015 12:50:49 69 0.0 8.36 374 0.0 07/23/2015 12:53:09 69 0.0 8.36 345 0.0 07/23/2015 12:54:19 69 0.0 8.36 379 0.0 07/23/2015 12:55:29 68 0.0 8.35 308 0.0 07/23/2015 12:56:39 69 0.0 8.36 344 0.0 07/23/2015 12:57:49 68 0.0 8.36 375 0.0 07/23/2015 12:58:53 69 0.0 8.36 365 0.0 Wm 07/23/2015 12:58:59 69 0.0 8.36 322 0.0 07/23/2015 12:59:19 68 0.0 8.36 322 0.0 on location 0 0900 07/23/2015 12:59:38 68 0.0 8.36 342 0.0 nix water temp 80 degrees 07/23/2015 13:00:09 68 0.0 8.36 336 0.0 07/23/2015 13:01:19 69 0.0 8.36 350 0.0 07/23/2015 13:02:29 67 0.0 8.36 315 0.0 07/23/2015 13:03:39 69 0.0 8.36 343 0.0 07/23/2015 13:04:49 69 0.0 8.36 341 0.0 07/23/2015 13:05:59 69 0.0 8.36 310 0.0 07/23/2015 13:07:09 68 0.0 8.36 329 0.0 07/23/2015 13:08:19 67 0.0 8.36 361 0.0 07/23/2015 13:09:29 68 0.0 8.36 326 0.0 07/23/2015 13:10:39 68 0.0 8.36 337 0.0 07/23/2015 13:11:49 68 0.0 8.36 361 0.0 07/23/2015 13:12:59 69 0.0 8.36 315 0.0 Page 3 013 Well Wer lob stint oatenlob Number 1D-145 1D-145 Kuparuk ]ul/23/2015 oPhlllips DDKA-00020/7689 Time Treating Wow Density WISP SOW Message -_---- 24-hr Pressure Rate LB/6 PSI Volume dock PSI B/M BBL 07/23/2015 13:15:19 68 0.0 8.36 375 0.0 07/23/2015 13:16:29 69 0.0 8.36 322 0.0 07/23/2015 13:17:39 68 0.0 8.36 325 0.0 07/23/2015 13:18:49 68 0.0 8.36 335 0.0 07/23/2015 13:19:59 68 0.0 8.36 -10 0.0 07/23/2015 13:21:09 68 0.0 8.36 -16 0.0 07/23/2015 13:22:14 69 0.0 8.36 -16 0.0 rlg pump down,lined up to cementers 07/23/2015 13:22:19 69 0.0 8.36 -16 0.0 07/23/2015 13:22:29 84 0.3 8.36 -2 0.0 start 5 bbls water ahead 07/23/2015 13:23:29 99 0.0 8.35 4 0.0 07/23/2015 13:24:39 123 0.2 8.35 25 0.1 07/23/2015 13:25:49 130 0.0 8.36 36 0.2 07/23/2015 13:28:09 185 2.5 8.35 50 3.1 07/23/2015 13:29:19 102 0.0 8.36 6 3.4 07/23/2015 13:29:22 102 0.0 8.36 6 3.4 Reset Total,Vol=5.0 bbl 07/23/2015 13:30:29 225 0.0 8.36 131 0.0 07/23/2015 13:30:30 260 0.0 8.36 166 0.0 low pressure stag 07/23/2015 13:31:27 480 0.0 8.36 385 0.0 High PT to 4000 07/23/2015 13:31:39 546 0.0 8.37 448 0.0 07/23/2015 13:32:49 3977 0.0 8.36 3891 0.0 07/23/2015 13:33:36 4203 0.0 8.36 4122 0.0 bleed off,good test 07/23/2015 13:33:59 1938 0.0 8.36 1853 0.0 07/23/2015 13:35:09 105 0.0 8.36 8 0.0 07/23/2015 13:36:05 114 0.0 8.36 23 0.0 start 75 bbls CW-100 07/23/2015 13:36:19 124 1.7 8.37 21 0.2 07/23/2015 13:37:29 376 5.2 8.36 126 4.6 07/23/2015 13:38:39 371 5.1 8.36 125 10.3 07/23/2015 13:39:49 430 5.7 8.36 160 16.4 07/23/2015 13:40:27 433 5.7 8.36 160 19.9 now out 18% 07/23/2015 13:40:59 439 5.7 8.36 163 22.8 07/23/2015 13:42:09 445 5.7 8.36 164 29.1 07/23/2015 13:43:19 438 5.7 8.36 162 35.5 07/23/2015 13:44:29 440 5.7 8.36 166 41.8 07/23/2015 13:45:39 453 5.7 8.36 164 48.2 07/23/2015 13:46:49 454 5.7 8.36 176 54.5 07/23/2015 13:47:59 468 5.8 8.36 180 60.9 07/23/2015 13:49:09 384 4.4 8.36 155 67.1 07/23/2015 13:50:19 336 4.3 8.37 129 71.8 07/23/2015 13:51:29 110 0.0 8.36 22 75.3 07/23/2015 13:52:05 118 0.0 8.35 23 75.3 down on pump,CW-100 pumped 07/23/2015 13:52:10 117 0.0 8.35 25 75.3 Reset Total,Vol o 75.3 bbl 07/23/2015 13:52:39 118 0.0 8.36 18 0.0 07/23/2015 13:53:49 123 0.0 8.34 15 0.0 07/23/2015 13:54:59 125 0.0 8.26 20 0.0 07/23/2015 13:56:09 125 0.0 8.25 12 0.0 07/23/2015 13:56:14 125 0.0 8.45 12 0.0 start batching MPII 07/23/2015 13:57:19 125 0.0 11.10 12 0.0 07/23/2015 13:58:29 126 0.0 11.19 12 0.0 07/23/2015 13:59:39 125 0.0 11.17 11 0.0 07/23/2015 14:00:49 126 0.0 11.12 6 0.0 07/23/2015 14:01:59 110 4.1 10.82 13 0.0 07/23/2015 14:02:02 112 4.1 10.81 12 0.0 start pumping MPII 07/23/2015 14:03:09 310 3.8 11.43 126 3.4 07/23/2015 14:04:19 319 3.7 10.71 141 7.7 Page 4 of 13 Wait Rat lob Start ___ lob Number 1D-145 1D-145 Kuparuk Jul/23/2015 ocOPhfBips DDKA-00020/7689 Data Vino Treating Row Density INNS WIMP Message 24.41r PrepSara Rata 1.11/8 PSI Volume dodc PSI p/M reef. 07/23/2015 14:06:39 463 5.5 9.07 192 16.2 07/23/2015 14:07:49 582 6.9 11.74 232 22.9 07/23/2015 14:08:59 596 6.9 10.99 235 30.7 07/23/2015 14:10:09 580 6.9 10.50 246 38.5 07/23/2015 14:11:19 569 6.9 10.42 239 46.3 07/23/2015 14:12:24 559 6.5 10.68 226 53.6 return flow 20%going down with pipe 07/23/2015 14:12:29 538 6.4 10.69 224 54.1 07/23/2015 14:13:39 514 6.4 10.69 212 61.4 07/23/2015 14:14:49 528 6.4 10.63 226 68.8 07/23/2015 14:15:59 189 0.0 10.59 66 72.9 07/23/2015 14:16:24 130 0.0 10.54 29 72.9 Down on pump,start hatching lead 07/23/2015 14:17:09 137 0.0 0.42 27 73.0 07/23/2015 14:18:19 92 0.0 10.43 -8 73.0 07/23/2015 14:19:29 91 0.0 9.01 -8 73.0 07/23/2015 14:20:39 114 0.0 9.84 -5 73.0 07/23/2015 14:20:59 115 0.0 10.74 -2 73.0 lead cement wet 07/23/2015 14:21:49 115 0.0 11.03 -5 73.0 07/23/2015 14:22:59 115 0.0 10.93 -5 73.0 07/23/2015 14:24:09 115 0.0 10.95 -3 73.0 07/23/2015 14:24:37 115 0.0 10.94 -4 73.0 Reset Total,Vol a 72.9 bbl 07/23/2015 14:25:06 108 0.0 10.96 -2 0.0 start pumping lead cement 07/23/2015 14:25:19 144 4.1 10.95 16 0.3 07/23/2015 14:26:29 495 4.7 10.89 199 5.6 07/23/2015 14:27:39 770 6.7 10.90 294 11.8 07/23/2015 14:28:49 821 7.1 10.91 306 19.9 07/23/2015 14:29:59 825 7.1 10.97 312 27.9 07/23/2015 14:31:09 851 7.1 10.90 318 35.9 07/23/2015 14:32:19 834 7.1 10.81 297 44.0 07/23/2015 14:33:29 815 7.1 10.88 313 52.1 07/23/2015 14:34:39 819 7.1 10.96 305 60.2 07/23/2015 14:35:49 841 7.1 11.08 306 68.2 07/23/2015 14:36:59 841 7.1 11.05 303 76.3 07/23/2015 14:38:09 857 7.1 11.06 307 84.3 07/23/2015 14:39:19 853 7.1 11.04 306 92.4 07/23/2015 14:39:28 852 7.1 11.04 295 93.4 20%return flow,going down 07/23/2015 14:40:29 854 7.1 11.03 295 100.4 07/23/2015 14:41:39 833 7.1 11.04 296 108.5 07/23/2015 14:42:49 864 7.3 11.02 284 116.7 07/23/2015 14:43:59 854 7.3 11.05 307 124.9 07/23/2015 14:45:09 895 7.2 11.08 322 133.1 07/23/2015 14:46:19 878 7.3 11.08 321 141.4 07/23/2015 14:47:29 876 7.2 11.07 306 149.6 07/23/2015 14:48:39 865 7.2 11.09 305 157.7 07/23/2015 14:49:49 853 7.3 11.04 283 165.9 07/23/2015 14:50:57 858 7.3 10.96 282 173.9 silo swap 07/23/2015 14:50:59 864 7.3 10.96 295 174.1 07/23/2015 14:52:09 807 7.3 10.79 259 182.4 07/23/2015 14:53:19 782 7.3 11.09 244 190.7 07/23/2015 14:54:29 827 7.3 11.09 247 198.9 07/23/2015 14:55:39 816 7.3 10.99 245 207.1 07/23/2015 14:55:56 803 7.3 10.99 233 209.1 cement scaled @ 11*during batch up 07/23/2015 14:56:49 740 7.1 11.00 210 215.3 07/23/2015 14:57:59 758 7.1 11.01 209 223.3 07/23/2015 14:59:07 752 7.2 11.02 207 231.1 CW-100 0 shoe Page 5 of 13 Well _._ 1 lob Start •., ,, ._� Job Number 10-145 1D-145 Kupanik Jul/23/2015 • ocoPhillips DDKA-00020/7689 Daft Time Treating Flew Density WNP Stage Message 24-hr Pressure Rete LB/8 PSI Volume clock PSI 3/M BBL 07/23/2015 15:00:19 753 7.1 11.00 205 239.4 07/23/2015 15:01:29 750 7.1 11.03 218 247.5 07/23/2015 15:02:39 778 7.1 11.05 212 255.6 07/23/2015 15:03:49 783 7.1 11.03 220 263.6 07/23/2015 15:04:59 769 7.1 11.05 219 271.6 07/23/2015 15:06:09 763 7.1 10.98 203 279.7 07/23/2015 15:07:19 781 7.1 11.04 212 287.7 07/23/2015 15:08:29 811 7.1 11.09 223 295.7 07/23/2015 15:09:39 798 7.1 11.10 226 303.6 07/23/2015 15:10:30 792 7.1 11.07 225 309.4 MP II 0 shoe 07/23/2015 15:10:49 777 7.1 11.05 204 311.6 07/23/2015 15:11:59 842 7.3 11.01 227 319.7 07/23/2015 15:13:09 848 7.3 11.02 236 327.9 07/23/2015 15:14:19 837 7.4 11.09 238 336.1 07/23/2015 15:15:29 839 7.4 11.12 231 344.3 07/23/2015 15:16:39 844 7.3 11.08 238 352.4 07/23/2015 15:17:49 805 7.4 11.17 215 360.6 07/23/2015 15:18:59 857 7.4 11.03 262 368.7 07/23/2015 15:19:57 850 7.4 11.02 270 375.4 bottom plug landed 07/23/2015 15:20:09 862 7.4 11.01 266 376.8 07/23/2015 15:21:19 826 7.4 11.11 247 385.0 07/23/2015 15:22:01 814 7.4 11.14 241 389.8 cement 81 shoe 07/23/2015 15:22:29 840 7.4 11.15 240 393.1 07/23/2015 15:23:39 803 7.4 11.12 236 401.2 07/23/2015 15:24:49 863 7.3 11.15 228 409.3 07/23/2015 15:25:59 861 7.4 11.07 238 417.4 07/23/2015 15:27:09 886 7.4 11.24 257 425.5 07/23/2015 15:28:19 323 3.4 11.07 77 429.9 07/23/2015 15:29:29 98 0.0 11.04 6 432.2 07/23/2015 15:29:39 99 0.0 11.05 6 432.2 down on pump 07/23/2015 15:29:44 100 0.0 11.05 6 432.2 Reset Total,Vol:432.2 bbl 07/23/2015 15:30:39 100 0.0 11.07 3 0.0 07/23/2015 15:31:49 100 0.0 10.12 2 0.0 07/23/2015 15:32:59 100 0.0 10.07 6 0.0 07/23/2015 15:34:09 100 0.0 9.93 5 0.0 07/23/2015 15:35:19 100 0.0 9.93 3 0.0 07/23/2015 15:36:29 99 0.0 8.40 2 0.0 07/23/2015 15:37:39 98 0.0 10.52 7 0.0 07/23/2015 15:38:49 98 0.0 12.00 7 0.0 07/23/2015 15:39:59 97 0.0 11.30 0 0.0 07/23/2015 15:41:09 97 0.0 11.91 4 0.0 07/23/2015 15:42:19 139 4.6 12.05 7 0.1 07/23/2015 15:43:29 456 4.7 12.18 93 5.5 07/23/2015 15:44:39 514 4.7 12.15 125 10.9 07/23/2015 15:45:49 524 4.7 12.10 139 16.2 07/23/2015 15:45:58 509 4,7 12.09 142 16.9 tag mudscaled 0 124 07/23/2015 15:46:59 550 4.7 12.09 144 21.5 07/23/2015 15:48:09 538 4.7 12.06 149 26.8 07/23/2015 15:49:19 525 4.7 12.16 147 32.2 07/23/2015 15:50:29 551 4.7 12.15 157 37.5 07/23/2015 15:51:39 563 4.7 12.11 155 42.8 07/23/2015 15:52:49 525 4.7 12.06 147 48.1 07/23/2015 15:53:59 535 4.7 12.06 148 53.4 07/23/2015 15:55:09 490 4.7 12.01 1I0 58.8 i Page 6 of 13 Well -... "de lob Startlob Number 10-145 10-145 Kuparuk Jul/23/2015oPhillips DDKA-00020/7689 __ _.__._.._ .___..- Date Time Treating Flow I Density WHIP Stage_- Nasfa9e 24-hr Pressure Rate 1.B/6 PSI Volume clock PSI B/M BBL 07/23/2015 15:57:29 280 1.8 12.07 60 66.4 07/23/2015 15:58:39 172 1.5 12.12 23 68.1 07/23/2015 15:59:17 106 0.0 12.03 2 68.9 Reset Total,Vol=68.9 bbl 07/23/2015 15:59:49 L- 107 0.0 12.01 4 0.0 07/23/2015 16:00:59 106 0.0 12.00 3 0.0 07/23/2015 16:02:09 105 0.0 11.99 6 0.0 07/23/2015 16:03:19 106 0.0 11.97 4 0.0 07/23/2015 16:03:46 106 0.0 11.97 4 0.0 start 10 bbls water behind 07/23/2015 16:04:29 550 7.2 11.98 185 3.0 07/23/2015 16:04:49 459 7.2 11.99 114 5.2 still reciprocating 07/23/2015 18:05:39 136 0.0 12.00 8 9.4 07/23/2015 16:05:57 66 0.0 12.00 -13 9.4 down on pump,rig is lining up 07/23/2015 16:06:49 73 0.0 12.02 -10 9.4 07/23/2015 16:07:59 79 0.0 11.98 364 9.4 07/23/2015 16:09:09 199 0.0 11.99 323 9.4 07/23/2015 16:10:19 160 0.0 11.99 328 9.4 07/23/2015 16:11:29 73 0.0 11.99 343 9.4 07/23/2015 16:12:39 72 0.0 8.66 354 9.4 07/23/2015 16:13:49 74 0.0 9.19 340 9.4 07/23/2015 16:14:59 75 0.0 9.20 375 9.4 07/23/2015 16:16:09 72 0.0 9.53 372 9.4 07/23/2015 16:17:19 73 0.0 10.35 365 9.4 07/23/2015 16:18:29 73 0.0 11.12 394 9.4 07/23/2015 16:19:39 73 0.0 11.18 400 9.4 07/23/2015 16:20:44 73 0.0 11.15 395 9.4 1090 strokes away 07/23/2015 16:20:49 73 0.0 11.12 390 9.4 07/23/2015 16:20:55 73 0.0 11.11 398 9.4 8 bpm 07/23/2015 16:21:59 73 0.0 11.18 410 9.4 07/23/2015 16:22:00 73 0.0 11.18 408 9.4 return flow 23% 07/23/2015 16:23:09 73 0.0 11.31 401 9.4 07/23/2015 16:24:19 73 0.0 11.30 410 9.4 07/23/2015 16:25:29 72 0.0 8.70 418 9.4 07/23/2015 16:26:39 72 0.0 8.59 422 9.4 07/23/2015 16:27:49 195 0.0 -3.11 414 9.4 07/23/2015 16:28:59 208 0.0 7.84 429 9.4 07/23/2015 16:30:09 78 0.0 7.99 455 9.4 07/23/2015 16:31:19 104 0.0 5.76 455 9.4 07/23/2015 16:32:29 77 0.0 8.26 448 9.4 07/23/2015 16:33:39 86 0.0 8.31 463 9.4 07/23/2015 16:34:49 86 0.0 8.33 459 9.4 07/23/2015 16:35:59 73 0.0 8.42 450 9.4 07/23/2015 16:37:09 73 0.0 8.42 482 9.4 07/23/2015 16:38:19 92 0.0 8.39 506 9.4 07/23/2015 16:39:29 295 0.0 8.39 500 9.4 07/23/2015 16:40:39 73 0.0 8.40 518 9.4 07/23/2015 16:41:49 72 0.0 8.42 549 9.4 07/23/2015 16:42:59 72 0.0 8.44 540 9.4 07/23/2015 16:44:09 300 0.0 8.43 548 9.4 07/23/2015 16:45:19 75 0.0 8.41 583 9.4 07/23/2015 16:46:29 72 0.0 8.40 586 9.4 07/23/2015 16:47:39 72 0.0 8.35 566 9.4 07/23/2015 16:48:49 72 0.0 8.34 587 9.4 07/23/2015 16:49:59 256 0.0 8.38 602 9.4 07/23/2015 16:51:09 76 0.0 8.39 277 9.4 Page 7 of 19 Well Job Startcustom301,Number 1D-145 10-145 Kuparuk 7u1/23/2015 °Phillips DDKA-00020/7689 Data Time Treating Flow Density WHP Stage Message 24-hr Pressure Rate L8/4 nal Warns clock PSI 8/M 881. 07/23/2015 16:53:29 178 0.0 8.40 279 9.4 07/23/2015 16:54:39 115 0.0 8.38 858 9.4 07/23/2015 16:55:49 88 0.0 8.41 852 9.4 07/23/2015 16:56:28 98 0.0 8.41 851 9.4 bumped plug @ 3584 strokes away 07/23/2015 16:56:59 74 0.0 8.41 851 9.4 07/23/2015 16:58:09 72 0.0 8.39 851 9.4 07/23/2015 16:59:19 72 0.0 8.02 851 9.4 07/23/2015 17:00:29 246 0.0 8.35 814 9.4 07/23/2015 17:01:39 173 0.0 8.35 -19 9.4 07/23/2015 17:02:49 194 0.0 8.36 -19 9.4 07/23/2015 17:03:59 118 0.0 8.36 -18 9.4 07/23/2015 17:05:09 81 0.0 8.36 -11 9.4 07/23/2015 17:07:29 84 0.0 -3.11 -17 9.4 07/23/2015 17:08:39 72 0.0 0.10 -17 9.4 07/23/2015 17:09:49 70 0.0 0.11 -17 9.4 07/23/2015 17:10:59 70 0.0 0.11 -18 9.4 07/23/2015 17:12:09 70 0.0 0.06 -18 9.4 07/23/2015 17:13:19 71 0.0 0.09 -17 9.4 07/23/2015 17:14:29 70 0.0 0.06 -17 9.4 07/23/2015 17:15:39 72 0.0 0.06 -14 9.4 07/23/2015 17:16:49 70 0.0 0.06 -1 9.4 07/23/2015 17:17:59 70 0.0 0.06 -16 9.4 07/23/2015 17:19:09 70 0.0 0.06 -16 9.4 07/23/2015 17:20:19 70 0.0 0.06 -16 9.4 07/23/2015 17:21:29 70 0.0 0.06 -16 9.4 07/23/2015 17:22:39 70 0.0 0.06 -16 9.4 07/23/2015 17:23:49 70 0.0 0.06 -16 9.4 07/23/2015 17:24:59 69 0.0 0.06 -16 9.4 07/23/2015 17:26:09 69 0.0 0.06 -16 9.4 07/23/2015 17:27:19 70 0.0 0.06 -16 9.4 07/23/2015 17:28:29 69 0.0 0.06 -16 9.4 07/23/2015 17:29:39 69 0.0 0.06 -10 9.4 07/23/2015 17:30:49 69 0.0 0.06 -11 9.4 07/23/2015 17:31:59 70 0.0 0.06 -11 9.4 07/23/2015 17:33:09 69 0.0 0.06 -12 9.4 07/23/2015 17:34:19 69 0.0 0.06 -11 9.4 07/23/2015 17:35:29 69 0.0 0.06 -11 9.4 07/23/2015 17:36:39 69 0.0 0.05 -11 9.4 07/23/2015 17:37:49 69 0.0 0.06 -11 9.4 07/23/2015 17:38:59 69 0.0 0.06 -11 9.4 07/23/2015 17:40:09 69 0.0 0.06 -8 9.4 07/23/2015 17:42:29 69 0.0 0.06 -11 9.4 07/23/2015 17:43:39 69 0.0 0.06 -16 9.4 07/23/2015 17:44:49 69 0.0 0.06 -15 9.4 07/23/2015 17:45:59 69 0.0 0.06 -16 9.4 07/23/2015 17:47:09 69 0.0 0.06 -15 9.4 07/23/2015 17:48:19 69 0.0 0.06 -11 9.4 07/23/2015 17:49:29 69 0.0 0.06 -11 9.4 07/23/2015 17:50:39 69 0.0 0.06 -9 9.4 07/23/2015 17:51:49 69 0.0 0.06 -4 9.4 07/23/2015 17:52:59 69 0.0 0.06 -10 9.4 07/23/2015 17:54:09 69 0.0 0.06 -11 9.4 07/23/2015 17:55:19 69 0.0 0.05 -7 9.4 07/23/2015 17:56:29 69 0.0 0.05 -15 9.4 ! 8 Pageof 13 1 Well Job Start Job Number. 10-145 10-145 Kuparuk Jul/23/2015 ocoPhillips DDKA-00020/7689 Pate Thee Treating Few penalty WMP Stage Message 24-hr Pressure bb 18/6 PSI Volume dodt PSI BIN 9a4 07/24/2015 01:37:19 68 0.0 0.04 -3746 9.4 07/24/2015 01:37:26 69 0.0 0,05 -3746 9.4 re-spotted for top job 07/24/2015 01:38:29 68 0.0 0.05 -3746 9.4 07/24/2015 01:39:39 68 0.0 0.05 -3746 9.4 07/24/2015 01:40:49 68 0.0 0.04 -3746 9.4 07/24/2015 01:41:59 68 0.0 0.05 -3746 9.4 07/24/2015 01:42:18 68 0.0 0.05 -3746 9.4 mixing tap out with small tub only 07/24/2015 01:43:09 68 0.0 0.05 -3746 9.4 07/24/2015 01:45:29 68 0.0 0.05 -3746 9.4 07/24/2015 01:46:39 68 0.0 0.04 -3746 9.4 07/24/2015 0I:47:49 94 0.0 0.05 -3746 9.4 07/24/2015 01:48:59 76 0.0 0.05 -3746 9.4 07/24/2015 01:50:09 165 0.0 8.34 -3745 9.4 07/24/2015 01:51:19 70 0.0 8.35 -3745 9.4 07/24/2015 01:52:29 69 0.0 8.35 -3745 9.4 07/24/2015 01:53:39 69 0.0 8.33 -3745 9.4 07/24/2015 01:54:49 133 0.0 8.35 -3745 9.4 07/24/2015 01:55:59 161 0.0 8.35 -3745 9.4 07/24/2015 01:57:09 71 0.0 8.34 -3745 9.4 07/24/2015 01:58:19 71 0.0 8.36 -3745 9.4 07/24/2015 01:59:29 85 0.0 8.35 -3744 9.4 07/24/2015 02:00:39 70 0.0 8.35 -3745 9.4 07/24/2015 02:01:49 70 0.0 8.36 -3745 9.4 07/24/2015 02:02:59 70 0.0 8.36 -3745 9.4 07/24/2015 02:03:15 69 0.0 8.36 -3745 9.4 Reset Total,Vol=9.5 bbl 07/24/2015 02:04:09 69 0.0 8.36 -3744 0.0 07/24/2015 02:05:19 69 0.0 8.36 -3745 0.0 07/24/2015 02:06:29 70 0.0 8.36 -3744 0.0 07/24/2015 02:07:39 69 0.0 8.36 -3744 0.0 07/24/2015 02:08:49 69 0.0 8.36 -3745 0.0 07/24/2015 02:09:59 69 0.0 8.36 -3745 0.0 07/24/2015 02:11:09 69 0.0 8.36 -3745 0.0 07/24/2015 02:12:19 69 0.0 8.36 -3745 0.0 07/24/2015 02:13:29 69 0.0 8.36 -3745 0.0 07/24/2015 02:14:39 69 0.0 8.36 -3745 0.0 07/24/2015 02:15:49 69 0.0 8.36 -3745 0.0 07/24/2015 02:16:59 69 0.0 8.36 -3745 0.0 07/24/2015 02:18:09 146 0.3 8.35 -3745 0.0 07/24/2015 02:18:17 149 0.4 8.35 -3744 0.0 start pumping water ahead 07/24/2015 02:19:37 109 0.4 8.34 -3744 0.0 have returns In the cellar 07/24/2015 02:20:29 107 0.4 8.34 -3745 0.0 07/24/2015 02:21:39 106 0.3 8.35 -3745 0.0 07/24/2015 02:22:49 105 0.3 8.35 -3745 0.0 07/24/2015 02:23:59 145 0.6 8.35 -3745 0.0 07/24/2015 02:25:09 136 0.6 8.34 -3745 0.0 07/24/2015 02:26:19 133 0.5 8.35 -3745 0.0 07/24/2015 02:27:29 201 0.8 8.35 -3745 0.0 07/24/2015 02:28:39 189 0.8 8.34 -3745 0.0 07/24/2015 02:29:49 189 0.8 8.35 -3745 0.0 07/24/2015 02:30:59 188 0.8 8.39 -3745 0.0 07/24/2015 02:32:09 188 0.8 8.35 -3744 0.0 07/24/2015 02:33:19 188 0.8 8.35 -3744 0.0 07/24/2015 02:34:29 186 0.8 8.35 -3745 0.0 07/24/2015 02:35:39 186 0.8 8.35 -3744 0.0 Page 9 of 13 Well Job Start •. lob Number 1D-145 1D-145 Kuparuk I Jul/23/2015 • ocoPhillips DDKA-00020/7689 Data Time Treating Plow Density WNP Rage Message 24-hr Pressure Rata We PSI Volume clock PSI B/M BBL 07/24/2015 02:37:59 186 0.8 8.35 -3745 0.0 07/24/2015 02:39:09 187 0.8 8.34 -3745 0.0 07/24/2015 02:40:19 186 0.8 8.34 -3744 0.0 07/24/2015 02:41:29 188 0.8 8.35 -3745 0.0 07/24/2015 02:42:39 186 0.8 8.34 -3744 0.0 07/24/2015 02:43:49 239 0.9 8.34 -3744 0.0 07/24/2015 02:44:59 236 0.9 8.34 -3745 0.0 07/24/2015 02:46:09 236 0.9 8.34 -3745 0.0 07/24/2015 02:47:19 235 0.9 8.34 -3745 0.0 07/24/2015 02:48:29 237 0.9 8.35 -3744 0.0 07/24/2015 02:49:39 238 0.9 8.35 -3744 0.0 07/24/2015 02:50:49 238 0.9 8.34 -3745 0.0 07/24/2015 02:51:59 239 0.9 8.35 -3745 0.0 07/24/2015 02:53:09 238 0.9 8.34 -3745 0.0 07/24/2015 02:55:29 236 0.9 8.35 -3744 0.0 07/24/2015 02:56:39 237 0.9 8.35 -3744 0.0 07/24/2015 02:57:49 238 0.9 8.34 -3745 0.0 07/24/2015 02:58:59 236 0.9 8.34 -3744 0.0 07/24/2015 03:00:09 236 0.9 8.35 -3744 0.0 07/24/2015 03:01:19 236 0.9 8.34 -3745 0.0 07/24/2015 03:02:29 237 0.9 8.34 -3745 0.0 07/24/2015 03:03:39 236 0.9 8.34 -3744 0.0 07/24/2015 03:04:49 235 0.9 8.34 -3745 0.0 07/24/2015 03:05:59 238 0.9 8.34 -3745 0.0 07/24/2015 03:07:09 238 0.9 8.35 -3745 0.0 07/24/2015 03:08:19 238 0.9 8.34 -3744 0.0 07/24/2015 03:09:29 238 0.9 8.34 -3745 0.0 07/24/2015 03:10:39 242 0.9 8.35 -3745 0.0 07/24/2015 03:11:49 241 0.9 8.35 -3744 0.0 07/24/2015 03:12:59 186 0.0 8.35 -3744 0.0 07/24/2015 03:13:44 67 0.0 8.35 -3744 0.0 Reset Total,Vol=45.0 bbl 07/24/2015 03:14:09 66 0.0 8.35 -3745 0.0 07/24/2015 03:15:19 66 0.0 -3.11 -3745 0.0 07/24/2015 03:16:10 65 0.0 -3.11 -3746 0.0 start batching cement 07/24/2015 03:16:29 65 0.0 -3.09 -3745 0.0 07/24/2015 03:17:39 -390 0.0 -3.12 -3748 0.0 07/24/2015 03:18:49 88 0.0 -3.11 -3747 0.0 07/24/2015 03:19:59 -560 0.0 -3.11 -3748 0.0 07/24/2015 03:21:09 100 0.0 -3.08 -3748 0.0 07/24/2015 03:22:19 67 0.0 -3.10 -3747 0.0 07/24/2015 03:23:29 67 0.0 -3.12 -3748 0.0 07/24/2015 03:23:56 67 0.0 -3.11 -3747 0.0 Reset Total,Vols 0.05 bbl 07/24/2015 03:24:39 67 0.0 -3.11 -3747 0.0 07/24/2015 03:25:49 66 0.0 -3.11 -3747 0.0 07/24/2015 03:26:59 66 0.0 -3.09 -3748 0.0 07/24/2015 03:28:09 143 0.0 -3.10 -3747 0.0 07/24/2015 03:30:29 130 0.6 -3.10 -3747 0.0 07/24/2015 03:31:39 133 0.6 -3.09 -3747 0.0 07/24/2015 03:32:49 134 0.6 -3.11 -3747 0.0 07/24/2015 03:33:27 134 0.6 -3.12 -3747 0.0 scale 11.3 07/24/2015 03:33:59 133 0.6 -3.11 -3747 0.0 07/24/2015 03:35:09 133 0.6 -3.11 -3747 0.0 07/24/2015 03:36:19 134 0.5 -3.11 -3747 0.0 07/24/2015 03:37:29 136 0.6 -3.12 -3748 0.0 Page 10 of 13 Well 704 Start Cu Job Number 1D-145 10-145 Kuparuk Jul/23/2015 • ocoPhillips DDKA-00020/7689 Pate Time Treating Flow Density WM. Stagei Message 24-hr Pressure Rate ism PSI Volume clock PSI S/M SBL 07/24/2015 03:39:49 133 0.6 -3.11 -3748 0.0 07/24/2015 03:40:59 134 0.5 -3.11 -3747 0.0 07/24/2015 03:42:09 133 0.5 -3.11 -3747 0.0 07/24/2015 03:43:19 132 0.6 -3.10 -3747 0.0 07/24/2015 03:44:29 136 0.6 -3.11 -3747 0.0 07/24/2015 03:45:39 193 0.5 -3.11 -3748 0.0 07/24/2015 03:46:49 133 0.6 -3.11 -3748 0.0 07/24/2015 03:47:59 134 0.5 -3.11 -3747 0.0 07/24/2015 03:49:09 132 0.6 -3.11 -3747 0.0 07/24/2015 03:50:19 152 0.5 -3.11 -3747 0.0 07/24/2015 03:51:29 214 0.5 -3.11 -3747 0.0 07/24/2015 03:52:39 212 0.5 11.27 -3746 0.0 07/24/2015 03:53:49 209 0.5 11.13 -3746 0.0 07/24/2015 03:54:59 167 0.5 10.91 -3746 0.0 07/24/2015 03:56:09 166 0.5 10.95 -3746 0.0 07/24/2015 03:57:19 170 0.5 10.96 -3746 0.0 07/24/2015 03:58:29 165 0.5 10.98 -3746 0.0 07/24/2015 03:59:39 165 0.5 11.01 -3746 0.0 07/24/2015 04:00:49 164 0.5 11.09 -3746 0.0 07/24/2015 04:01:59 168 0.5 11.12 -3746 0.0 07/24/2015 04:03:09 171 0.5 11.11 -3746 0.0 07/24/2015 04:04:19 171 0.5 11.11 -3746 0.0 07/24/2015 04:05:29 171 0.5 11.01 -3746 0.0 07/24/2015 04:06:39 165 0.5 11.00 -3746 0.0 07/24/2015 04:07:49 164 0.6 11.04 -3746 0.0 07/24/2015 04:08:59 163 0.5 11.06 -3746 0.0 07/24/2015 04:10:09 163 0.6 11.07 -3746 0.0 07/24/2015 04:11:19 162 0.5 11.14 -3746 0.0 07/24/2015 04:12:29 169 0.5 11.06 -3746 0.0 07/24/2015 04:13:39 165 0.5 11.02 -3746 0.0 07/24/2015 04:14:49 162 0.5 10.99 -3746 0.0 07/24/2015 04:15:59 200 0.6 10.95 -3746 0.0 07/24/2015 04:17:09 241 0.7 10.98 -3746 0.0 07/24/2015 04:18:19 244 0.8 10.87 -3746 0.0 07/24/2015 04:19:29 257 0.8 10.83 -3746 0.0 07/24/2015 04:20:39 277 0.8 11.10 -3746 0.0 07/24/2015 04:21:49 327 0.8 11.03 -3746 0.0 07/24/2015 04:22:59 329 0.8 11.03 -3746 0.0 07/24/2015 04:24:09 322 0.8 8.07 -3746 0.0 07/24/2015 04:25:19 288 0.8 -3.11 -3747 0.0 07/24/2015 04:26:29 314 0.8 -3.11 -3748 0.0 07/24/2015 04:27:39 287 0.8 -3.10 -3748 0.0 07/24/2015 04:28:49 273 0.8 -3.12 -3748 0.0 07/24/2015 04:29:59 310 0.8 -3.11 -3747 0.0 07/24/2015 04:31:09 263 0.8 -3.12 -3747 0.0 07/24/2015 04:32:19 241 0.8 -3.10 -3747 0.0 07/24/2015 04:33:29 239 0.8 -3.11 -3747 0.0 07/24/2015 04:34:39 337 0.8 -3.10 -3747 0.0 07/24/2015 04:35:49 332 0.8 -3.11 -3747 0.0 07/24/2015 04:36:59 317 0.5 -3.11 -3747 0.0 cement to surface 07/24/2015 04:38:09 247 0.5 -3.11 -3747 0.0 07/24/2015 04:39:19 226 0.5 -3.11 -3747 0.0 07/24/2015 04:40:29 259 0.5 -3.11 -3747 0.0 07/24/2015 04:41:39 193 0.5 -3.12 -3747 0.0 Page 11 of 13 WMR - .tab Start Jab Number 1D-145 1D-145 Kuparuk Jul/23/2015 oPhillips DDKA-00020/7689 Date -_..lime TmetMg Wow Density WMP -._ 1 Stage NtMaaSe 24-hr Pressure Rah We PSI 1 Volume clock PSI S/M I BBL 07/24/2015 04:43:59 182 0.5 -3.11 -3747 0.0 07/24/2015 04:45:09 168 0.5 -3.11 -3747 0.0 07/24/2015 04:46:19 233 0.5 -3.11 -3747 0.0 07/24/2015 04:47:29 238 0.5 -3.11 -3747 0.0 07/24/2015 04:48:39 234 0.5 -3.11 -3748 0.0 07/24/2015 04:49:49 227 0.5 -3.11 -3747 0.0 07/24/2015 04:50:59 287 0.5 -3.11 -3748 0.0 07/24/2015 04:52:09 241 0.5 -3.11 -3747 0.0 07/24/2015 04:53:19 221 0.5 -3.11 -3747 0.0 07/24/2015 04:54:29 216 0.5 -3.11 -3747 0.0 07/24/2015 04:55:39 208 0.5 -3.11 -3747 0.0 07/24/2015 04:56:49 254 0.5 -3.10 -3747 0.0 07/24/2015 04:57:59 271 0.5 -3.10 -3747 0.0 07/24/2015 04:59:09 264 0.5 -3.10 -3747 0.0 07/24/2015 05:00:19 259 0.5 -3.09 -3747 0.0 07/24/2015 05:01:29 279 0.5 -3.10 -3748 0.0 07/24/2015 05:02:39 259 0.5 -3.11 -3747 0.0 07/24/2015 05:03:49 256 0.5 -3.10 -3747 0.0 07/24/2015 05:04:59 251 0.5 -3.11 -3747 0.0 07/24/2015 05:06:09 240 0.5 -3.10 -3747 0.0 07/24/2015 05:07:19 238 0.5 -3.08 -3747 0.0 07/24/2015 05:07:29 236 0.5 -3.10 -3747 0.0 11#cement to surface 07/24/2015 05:08:29 81 0.0 -3.11 -3747 0.0 07/24/2015 05:09:39 67 0.0 -3.11 -3747 0.0 07/24/2015 05:10:49 67 0.0 -3.11 -3747 0.0 07/24/2015 05:11:59 66 0.0 -3.11 -3747 0.0 07/24/2015 05:13:09 70 0.0 -3.11 -3747 0.0 07/24/2015 05:14:19 76 0.0 -3.11 -3747 0.0 07/24/2015 05:15:29 78 0.0 -3.11 -3747 0.0 07/24/2015 05:16:39 62 0.0 -3.11 -3747 0.0 07/24/2015 05:17:49 62 0.0 -3.13 -3747 0.0 07/24/2015 05:18:59 62 0.0 -3.08 -3747 0.0 07/24/2015 05:20:09 62 0.0 -3.11 -3747 0.0 07/24/2015 05:21:19 66 0.0 -3.11 -3747 0.0 07/24/2015 05:22:29 60 0.0 -3.11 -3747 0.0 07/24/2015 05:23:39 64 0.0 -3.11 -3747 0.0 07/24/2015 05:24:49 59 0.0 -3.11 -3747 0.0 07/24/2015 05:25:59 66 0.0 -3.11 -3747 0.0 07/24/2015 05:27:09 65 0.0 -3.11 -3747 0.0 07/24/2015 05:28:19 65 0.0 -3.12 -3747 0.0 07/24/2015 05:29:29 66 0.0 -3.07 -3747 0.0 07/24/2015 05:30:39 65 0.0 -3.12 -3747 0.0 07/24/2015 05:31:49 142 0.0 -3.11 -3747 0.0 07/24/2015 05:32:59 187 0.0 -3.09 -3747 0.0 07/24/2015 05:34:09 67 0.0 -3.11 -3747 0.0 Pepe 12 of 13 Well Fl Sob Start lob Number 1D-145 10-145 Kuparuk 1uV23/2015 oPhillips DDKA-00020/7689 Post yob Summary Average Pump Rates,bid/min Volume of Fluid Injected,bbl Slurry 1 N2 Mud Maximum Rate Total Slurry Mud Spacer N2 --- _ 2.9 7.7 558.1 0.0 150.0 Treating Pressure Pressure Summary,psi Breakdown Fluid Maximum Final Average Bump Piug to Breakdown Type Volume Density 4267 81 156 800 bbl Ib/gal Avg.N2 Percent Designed Slurry Volume Displacement Mix Water Temp Cement Circulated to Surface? Eil Volume bbl % 0.0 bbl 10.0 bbl 80 degF Washed Than Pa's 0 To ft Customer or Authorized Representative Schlumberger Supervisor Circulation Lost 0 lob Completed ❑X Lee Martin John Morrison ,- Page 13 of 13 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg \? l (11(6 DATE: 7/24/2015 P. I. Supervisor FROM: Matt Herrera SUBJECT: Surface Casing Top Job Petroleum Inspector KRU 1D-145 • PTD 2141380 CPAI Doyon Rig 25 July 24, 2015: AOGCC was notified on 7/23/15 of the failure to get cement to surface after cementing the surface casing string in Kuparuk River Unit well 1 D-145 (email notice in the well file). I traveled to KRU 1 D-145 to verify the top of cement after CPAI/Doyon 25 pumped a surface casing top-job. Approval of the top job was verbally granted by AOGCC Engineer Victoria Loepp on 7/23/15. Estimated top of cement prior to the top-job was at 130 feet below the top of conductor. The top-job was pumped as follows (prior to my arrival): - tagged top of cement in preparation for the top-job at 130' MD with 34-inch tubing; - observed cement back at surface after pumping 55bbls, continued pumping for a . total of 57.1 bbls of 11 ppg Lead cement. On 7/24/15 I visually observed top of cement at 32 inches from the top of the conductor , pipe. Summary: I verified the top of cement in the surface casing by conductor annulus in well KRU 1D-145 after CPAI/Doyon 25 pumped a surface casing top-job the day before. , Attachments: none , 2015-0724_Surface_csg_Topjob KRU 1 D-145_mh.docx Page 1 of 1 PV or • • api' I//j,�s THE STATE Alaska Oil and Gas of e T CKA Conservation Commission '. f1- . _= 333 West Seventh Avenue - GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 oFALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-145 ConocoPhillips Alaska, Inc. Permit No: 214-138 revised Surface Location: 222.1' FNL, 418.1' FEL, SEC. 23, T11N, R10E, UM Bottomhole Location: 4968.79' FNL, 194.46' FEL, SEC. 11, T11N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated October 28, 2014. 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this/0 day of April, 2015. RECEIVED STATE OF ALASKA OW OIL AND GAS CONSERVATION C i ON APR 0 7 2015 PERMIT TO DRILL '' II 20 AAC 25.005 -Fa/15h1- 11/4/5_ AOGCC 1 a.Type of Work: lb.Proposed Well Class: Development-Oil 0' Service- Winj ❑ Single Zone 0 A 1 c.Specify if well is proposed for: Drill 0 e Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 . Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59_52_180 , ji1L 1D-145 3.Address: 6. Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 9483'" TVD: 3797' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 222.1'FNL 418.1'FEL,Sec.23 Twn 11N Rng 10 E,UM ' ADL 25650,25649 West Sak Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4680.9'FNL 6.6'FEL,Sec.14 Twn 11N Rng 10E,UM ' ALK 468,467 07/26/2015 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 4968.79'FNL 194.46"FEL,Sec.11 Twn 11N Rng 10E,UM . _Sat ---2560-- > 1 mile 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I 106.4 , feet 15. Distance to Nearest Well Open Surface: x-560670.8 y- 5959444.1 Zone-4 • GL Elevation above I 66.9 - feet to Same Pool: 96 ft 16. Deviated wells: Kickoff depth: 450 feet - 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 92.55 degrees • Downhole: 1857 psi , Surface: 1439 psi • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 34" 20" 94# K55 Welded 80' 39.5' 39.5' 120' 120' 200 cf of ArcticCRETE 16" 13.375" 68# L-80 Hydril 563 2533' 39.5' 39.5' 2572' 2487' 1423sx Lead,245sx Tail DeepCRETE 12.25" 9.625" 40# L-80 Hydril 563 4432' 39.5' 39.5' 4471' 3739' 635 sx Class'G' 6.75" 4.5" 11.6# L-80 Hydril 563 5212' 4271' 3705' 9483' 3797' Screened Liner Completion(no cement) 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v.Depth Plot El , Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: April 2,2015,, /,� Date I wt��//�, 22. I hereby certify that the foregoing is true and correct. Kelsey Hallford @ 26 1 7 Contact kelsev.hallford(a�cop.com Email Printed Name G.Alvord Title Alaska Drilling Manager Signature A .. Cj,.,k Phone 265-6120 Date 4 (6 ( +S Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number:/y4 $i I'Cv;' ci. 50-024-2352 to^Oc-OC.) Date: \0/2'/201' requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane/gas hydrates,or gas contained in shales: Other: ,50P r G'S f 74-0 , .5---.0e2 p5 • Samples req'd: Yes❑ No[ Mud log req'd:Yes❑ JJo pg v` r p r V« fel- /-r"s f 71-6 75-60951-12S measures: Yes Ef No❑ Directional svy req'd:Yes aNo E]Spacing exception req'd: Yes❑ Nog Inclination-only svy req'd:Yes❑ No SA1P` �� APPROVED BY r/�/"3 Approved by: l COMMISSIONER�(� THE COMMISSION Date: 1 (/ !�-- #1 I a RfedioNAtErrom? 1/7-h5 Submit Form and Form 10-401(Revised 1 /201 Th the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • RECEIVED ConocoPhillips• APR 0 7 2015 Alaska AOGCC Post Office Box 100360 Anchorage, Alaska 99510-0360 Kelsey Hallford Phone (907) 265-1577 April 2, 2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Revised Application for Permit to Drill (PTD 214-138), West Sak Producer, 1D-145 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby Revises the Permit to Drill 1D-145 (214-138) due to recent results seen while drilling 1D-142 (214-149). After setting surface casing on 1D-142 and drilling out our shoe track to do our LOT, ConocoPhillips struggled to get a good LOT due to the location of our surface casing shoe. Due to the difficultly experienced to get a good LOT, ConocoPhillips revises our permit to drill for 1D-145 to set deeper surface casing to hopefully prevent similar results for 1D-145 surface casing LOT. Setting deeper surface casing also adjusted our directional plan. Please find attached for the review of the Commission, form 10-401 and the information required by 20 ACC 25.005 for the wellbore of 1D-145 (214-138). Sincerely, Kelsey Hallfor West Sak Drilling Engineer *Application for Permit to Drill,Well 1 D-145 Revision No.0 Saved:2-Apr-15 Permit It - West Sak Well #1D-145 ire r.w +'x Application for Permit to Drill Document 117-44 IaxWell Mpximize Well Value Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 (f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005 (c)(5) 3 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005 (c)(9) 5 10.Seismic Analysis 5 Requirements of 20 AAC 25.005 (c)(10) 5 11.Seabed Condition Analysis 6 Requirements of 20 AAC 25.005 (c)(11) 6 1D-145 PERMITWP09.doc Page 1 of 7 Printed:2-Apr-15 *Application for Permit to Drill,Well 1 D-145 Revision No.0 Saved:2-Apr-15 12.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 13.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Cement Loads and CemCADE Summary 7 Attachment 4 Well Schematic 7 1. Well Name Requirements of 20 AAC 25.005 (t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1D-145. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) 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 identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, referenced to governmental section lines (8)the coordinates of the proposed location of the well 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 Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 222.1' FNL 418.1' FEL Sec. 23 Twn 11N Rng 10 E UM^ ASP Zone 4 NAD 27 Coordinates RKB Elevation 106.4'AMSL' Northings 5,959,444.6 Eastings:560,670.8 Pad Elevation 66.9'AMSL. Location at Top of Productive Interval 4680.9' FNL 6.6' FEL, Sec. 14 Twn 11N Rng 10E, UM (West (West Sak"B"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 4471' Northings: 5,960,268.47 Eastings:561,075.04 Total Vertical Depth, RKB: 3738' Total Vertical Depth, SS: 3632' Location at Total Depth 4968.8' FNL 194.5' FEL Sec. 11 Twn 11N Rng 10E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 9483' Northings: 5,965,258.35Eastings: 560,843.08 Total Vertical Depth, RKB: 3797' Total Vertical Depth, SS: 3690' 1D-145 PERMIT_WP09.doc Page 2 of 7 Printed:2-Apr-15 application for Permit to Drill,Well 1 D-145 Revision No.0 Saved:2-Apr-15 and (D)other information required by 20 AAC 25.050(6); Requirements of 20 AA C 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 1D-145 and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those 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 by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. 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 identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 MC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP st ck will be utilized to drill and complete well 1D-145. Please see information on the Doyon Rig 25'blowout prevention equipment placed on file with the Commission. 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 following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1D area are 0.489 psi/ft, or 9.4 ppg EMW ✓ (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak"D"sand formation is 1,439 psi, calculated thusly: MPSP = (3797 ft TVD)(0.489 - 0.11 psi/ft) = 1,439 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: 1D-145 Drilling Hazards Summary. 4. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) 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 identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(0; 1D-145 PERMIT_WP09.doc Page 3 of 7 Printed:2-Apr-15 SApplication for Permit to Drill,Well 1 D-145 Revision No.0 Saved:2-Apr-15 1D-145 will be completed with a 9-5/8" intermediate casing landed in the West Sak B sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the"Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. 5. 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 identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 34 94 K55 Welded 80 39.5/ 39.5 120/ 120 Cemented to surface with 200 cf ArcticCRETE Cemented to Surface with 13.375 16 68 L-80 Hydril 563 2533 39.5 / 39.5 2572/ 2487 1423 sx DeepCRETE Lead, 245 sx DeepCRETE Tail Cement Top planned @ 2900' 9.625 12.25 40 L-80 Hydril 563 4432 39.5 / 39.5 4471 / 3739 MD/2809'TVD Cemented w/ 635 sx 15.8 ppg Class'G' 4.5 6.75 11.6 L-80 Hydril 563 5212' 4271 / 3705 9483/ 3797 screens-no cement screens 6. 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,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1D-145 surface hole. Please see diagrams of the Doyon 25 diverter system on file with the Commission. 1D-145 PERMIT_WP09.doc Page 4 of 7 Printed:2-Apr-15 • SApplication for Permit to Drill,Well 1 D-145 Revision No.0 Saved:2-Apr-15 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on 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 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (Drilplex AR) Spud to Surface TD Value Density(ppg) 8.5 —9.2 LSYP 30 - 50 API Fluid Loss No Control (cc/30 min) Chlorides < 1000 pH 10.8 — 11.2 Lateral Mud Program (MI FazePro OBM) Intermediate Hole Mud Program (LSND) Value Density(ppg) 9.6 Fann 35 6 RPM 4 8 10.75"Csg Shoe to 7-5/8"Csg Point (lb/100 ft2) Value HTHPFIuid Loss Density(ppg) 9.2 - 9.6 ' (mL/30 min) <5 Fann 35 6 RPM 12 - 16 Drill Solids <2% (Ib/100 ft2) API Filtrate Oil Water Ratio 70:30 _ (cc/30 min) <6 Electrical >400 pH 9.5 — 10.0 Stability(mV) Drill Solids <7 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 25. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) 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 identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) 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 identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1D-145 PERMIT_WP09.doc Page 5 of 7 Printed:2-Apr-15 !Application for Permit to Drill,Well 1D-145 Revision No.0 Saved:2-Apr-15 10.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) 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 identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 11.Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) 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 identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20"x 34" insulated conductor to +/- 80' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 25JInstall 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 2572' MD/ 2487'TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13.375", 68#, L80, Hydril 563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. 5. Remove diverter system, install and test 13-5/8"x 5,000 psi BOP's to 3500 psi (annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 12.25"bit and 8"drilling assembly, with MWD. RIH, clean out cement to top of float equipment and test casing to 3000 psi for 30min. 7. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test to 11.0ppg EMW, recording results. 8. Directionally drill to 9-5/8"casing point at 4471' MD/ 3739'TVD. Pull out of hole on elevators to the surface casing shoe. 9. Perform clean out run prior to running casing. 10. Run 9.625", 40# L80, Hydril 563 casing to surface. (top of cement to be 2900' MD/ 2809'TVD which corresponds to 500'above the Ugnu B formation). 11. Install wellhead x 9.625" packoff and test to 3500 psi. 12. Flush 13.375"x 9.625"annulus with water, followed by diesel. 13. PU 6.75" PDC Bit and 4.5"drilling assembly, with MWD and LWD logging tools. RIH, clean out cement to top of float equipment. Test casing to 3000 psi for 30 minutes. 14. Drill out cement and 20'of new hole. Displace hole to lateral drilling FazePro OBM system. Perform formation integrity test to 11.0ppg EMW, recording results. 15. Directionally drill 6.75" hole to West Sak B Sand to TD at +/- 9483' MD/ 3797'TVD as per directional plan. 1D-145 PERMIT_WP09.doc Page 6 of 7 Printed:2-Apr-15 • *Application for Permit to Drill,Well 1D-145 Revision No.0 Saved:2-Apr-15 16. BROOH to 9.625"shoe. TIH and perform final circulations. POOH. 17. PU and run 4-1/2"screened liner. 18. Once all the liner is in the hole, rig up false rotary table and trip 2 7/8 wash pipe string into the entire length of the liner. Make up liner hanger running tool. 19. Finish running liner to TD to land liner and set liner hanger @ +/-4271'MD/3705'TVD, then displace well to Schlumberger acid through wash pipe (9% formic acid for 1D-145). 20. Allow acid to act on the filter cake. Once break time has been achieved, circulate out the formic acid and replace with inhibited brine. 21. Set liner top packer. POOH across fluid loss control valve (FLCV) to shift FLCV closed. Displace packer fluid and then continue to POOH. 22. PU 4.5"tubing and outer ESP housing and RIH 1000'. 23. RIH with ESP (pump and motor) and land in outer housing using slick line. 24. Continue running in hole with 4.5"tubing. Land tubing. Set BPV 25. Nipple down BOPE, nipple up tree and test. Pull BPV. 26. Freeze protect well with diesel by pumping into 4.5"x 9.625"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 27. Set BPV and move rig off. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an 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 25.080 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. All cuttings generated will be disposed of by hauling 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. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic 1D-145 PERMIT_WP09.doc Page 7 of 7 Printed:2-Apr-15 I S 1 D-1 45w 09 6. p 571 Plan Summary 19 5/8"x 12-1/J / >5- A .' -5 / - co i m _ / (Pis -.... - I\ i . • rn 0 I '( r 1 1 1 1 I I 1 I 0 ( 0,',1 ���o ' � 0 2500 5000 7500 �' 1 I'I\��-/ 113-3/8"x 161' r ��"'%`j-- Measured Depth r 1)���‘;.� o- Geodetic Datum: North American Datum 1983 -. ill11111114,1"\N 0° 113-3/8"x 161 Depth Reference: Plan:66.9.39.5 @ 106.40usft(Doyon 25) / / Rig: Doyon 25 , 0 1000 i 0 2D° 1O 0 19 5/8"x 12-1/41 I k -�9 14 1/2"x 6-3/4"1 itiii ��T10° r I ft 4 p pOro o°t CO i I 1 1 I I 1 ( 1 1 (W 1 0 1 I 1 1 I 1 , I g'I 1 I 1 'I , I .�I .40....-. 450 0 700 1400 2100 2800 3500 4 00 4900 5600 6300 7000 0 450- 640 Horizontal Departure , ,4 r;�. 330 ♦ •~�� 0 30 640- 840 f Amt,!p<b��'• •if 840 - 1030 co III d,{Villi f'r� 'ir .. ,. 1030 - 1220 15 .•" ...._ ����� �1�i 1 ����111�11�1iIW 1 �.4 �(�\ 1220 - 1420 I ®� 111 III0111111tI 1111 1101 U-4 L3wp15 o O�pp m 60 .r.;--,' 11111114111111 1 t1 A:it 411�. 1420 - 1610 � (V� 1�� (�� (i �� 300 r . .�1,0; tIkV i1! � I i .111 III�I1� Uu 01411plgkHi 11, I .._ - • i f%'�! // +' �flfi�C�� 1610 1800 U) I P II1 18 i , '�®�1� 1800 - 2130 W11kV 11I�11I X1' I� I111 ° 1D-14 L2wp15 r.. '- �.� �0/ 2130 2150 :.: '111 111111111N11111111$111 111 III • �� 4p.� ; * : 2450- 2780 U 30- 1) - "w, v p®n11i11111111 �I{ ( ` �',�110� rel ��, o �1, � ,/ �[_. iiia��li� 1111glOill 270 , P ` :99 2780 - 3100 l o, 111 /'MM�a'�/'%Il V ��� ®�j��11 lAIrli� 3100 - 3430 u v -, x pL ••nuwdt�+j..�/!Cr♦ 3430- 3750 �,m - r 3750 - 4080 4080 - 4400 0 I I I I I I I I I I I I I I I I I I I I I t '', w 4400 - 5040 0 1500 3000 4500 6000 7500 9000 240 E 120 5040 - 5670 SURVEY PROGRAM 5670 - 6310 Surface Location •®,���� 1 T' 6310 - 6940 lepth From Depth To Survey/Plan Tool North/Y: 5959195.59 East/X: 170070278 6940 - 7580 39.50 1400.00 1D-145wp09(Plan:1D-145) GYD-GC-SS 210 - 150 1400.00 2400.00 1D-145wp09(Plan:1D-145) MWD Pad Elevation:66.90 -�Oi. 7580 8210 1400.00 2571.68 1D-145wp09(Plan:1D-145) MWD+IFR-AK-CAZ-SC CASING DETAILS 180 8210 - 8850 2571.68 4071.68 1D-145wp09(Plan:10.145) MWD - 8850 - 9483 2571.68 4470.51 1D-145wp09(Plan:1D-145) MWD+IFR-AK-CAZ-SC TVD MD Name 4470.51 5970.51 1D-145wp09(Plan:1D-145) MWD 2487.40 2571.68 13-3/8"x 16" Magnetic Model: BGGM2014 TM 4470.51 9482.50 1D-145wp09(Plan:11D-145) MWD+IFR-AK-CAZ-SC 3738.40 4470.51 95/8"x 12-1/4 Magnetic Model Date: 20-Jun-15 A 3796.40 9482.50 4 1/2"x 6-3/4" Magnetic Declination: 18.89° To convert a Magnetic Direction to a True Direction,Add 18.89°East SECTION DETAILS Sec MD Inc Azi TVD i-N/-S -FE/-W Dleg TFace VSect Target Annotation 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 2 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,95°1F,for 300' 3 750.00 4.50 95.00 749.69 -1.03 11.73 1.50 95.00 -3.05 Start 2.5°/100'DLS,15°TF,for 350' 4 1100.00 13.15 104.97 1095.24 -12.53 63.97 2.50 15.00 -23.44 Start 2.731100'DLS,60.73°TF,for 539.75' 5 1639.75 24.00 138.00 1607.40 -110.49 197.45 2.73 60.73 -143.10 Hold for 109.46' 6 1749.21 24.00 138.00 1707.40 -143.58 227.25 0.00 0.00 -180.86 Start 3.51100'DLS,110.08°TF,for 115.05' 7 1864.26 22.91 147.75 1812.98 -179.93 254.86 3.50 110.08 -221.45 Hold for 211.37" 8 2075.63 22.91 147.75 2007.67 -249.52 298.77 0.00 0.00 -297.61 Start 4.7°/100'DLS,-155.65°TF,for 445.4' 9 2521.03 9.24 81.17 2437.40 -318.13 381.28 4.70 -155.65 -379.51 Hold for 70.92• 10 2591.95 9.24 81.17 2507.40 -316.39 392.54 0.00 0.00 -379.74 Start 4.71100'DLS,-90.42°TF,for 1350.06' 11 3942.01 63.76 355.35 3584.58 375.95 457.30 4.70 -90.42 290.83 Hold for 70.42' 12 4012.43 63.76 355.35 3615.72 438.91 452.18 0.00 0.00 353.72 Start 4.71100'DLS,-9.98°TF,for 458.07' 13 4470.51 85.00 351.69 3738.40 874.57 401.96 4.70 -9.98 791.48 1D-145 DL 24Jun14 Heel Hold for 20' 14 4490.51 85.00 351.69 3740.14 894.29 399.08 0.00 0.00 811.40 Start 21100'DLS,26.83'TF,for 242.42' 15 4732.93 89.33 353.88 3752.13 1134.42 368.68 2.00 26.83 1053.16 Hold for261.93' 16 4994.86 89.33 353.88 3755.20 1394.83 340.75 0.00 0.00 1314.47 Start 21100'DLS,-86.51°TF,for 544.84' P Frost 17 5539.69 90.00 343.00 3758.40 1927.80 231.71 2.00 -86.51 1858.28 1D-145 MW 20Apr14 CP2 Start 3.5°/100'DLS,-19.65°TF,for 77.22' 18 5616.92 92.55 342.09 3756.69 2001.44 208.58 3.50 -19.65 1934.82 Hold for 293.73' 19 5910.64 92.55 342.09 3743.64 2280.66 118.32 0.00 0.00 2225.47 Start 3.51100'DLS,119.82°TF,for 260.59' 20 6171.23 88.00 350.00 3742.40 2533.29 55.55 3.50 119.82 2485.16 1 D-145 MW 20Apr14 CP3 Start 4°/100'DLS,130.52°TF,for 266.3' 21 6437.54 81.12 358.18 3767.67 2796.59 28.17 4.00 130.52 2749.21 Hold for 16.78' 22 6454.32 81.12 358.18 3770.26 2813.16 27.65 0.00 0.00 2765.62 Start 41100'DLS,-1.25°TF,for 214.48' 23 6668.80 89.70 357.99 3787.40 3026.64 20.50 4.00 -1.25 2977.10 1D-145 MW 20Apr14 CP4 Start 21100'DLS,56.35°TF,for 39.18' 24 6707.98 90.13 358.64 3787.46 3065.80 19.35 2.00 56.35 3015.86 Hold for 1419.95' 25 8127.92 90.13 358.64 3784.13 4485.34 -14.30 0.00 0.00 4419.68 Start 21100'DLS,116.4°TF,for 75.79' 26 8203.71 89.46 0.00 3784.40 4561.12 -15.20 2.00 116.40 4494.46 1 D-145 MW 20Apr14 CP5 Adjust TF to 90.05°,for 747.76' 27 8951.47 89.47 14.96 3791.45 5300.39 81.84 2.00 90.05 5205.65 Hold for 531.03' 28 9482.50 89.47 14.96 3796.40 5813.40 218.88 0.00 0.00 5687.07 10-145 MW 24Apr14 CP6 TD:9482.5'MD,3796.4'TVD ►By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified otherwise,all targets have a 100 feet lateral tolerance. 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C, K LLLLN LLN N W •dU § 2rN N Nr 1 NLL LL 1 K • . iii R O O O O O 000000 O O O 88 8 '.:5 Q 0. 0 2 2 2 2 2 2 2 2 2 22 2 2 2 2 2 22 0) N N N N N N N N N N N N N N N N N N R R R R R R COCO R R R CLICOCOCOM COM a a a a a a a a a a. a a a a a a a s .0 a o O 0 a O a) N E O 80806 0 '6 O O 0 O O 0 O N O NO 00 o o u 000 00 at 00000 at 0 M E co0000000 C co R co C co R C RcoC C co U 2'.0 LL R LL LL R LL u_ LL 2 LL LL 0 LL CO R Li- ca N 0) N 0) N N m N N a) N E 0) N N .E N R o p a p o 0 o 0 0 'p o a p o p o o E c c c c c c c c c c c E R N 2 N R 2 R R R N R R N 2 N 2 2 R C co c R c 01 c co N co C co co c co c co c co N N NN N N N N N N N N N N N N N 0 N 0 0 0 U 0 0 0 0 U 0 0 0 0 0 0 0 U U V CO O O O V O O CO N N- )0 O N N- )0 O N (O O O 0) CO 00 CO N NI,- N V N N- r CO(O I O _O) 6) (O V V O) N- N- r CO CO O 6) r co )0 00 C o O M (O N (O O r r N r N r r r r O W U N r r CO CO N` CO r R R N LL 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 00 -0 0 0 Cl 0 0 0 0 0 0 0 0 0 0 0 0 C. 0 0 v o U) o 0 0 0 o ui (n ui ui U) U) o 0 0 0 ((i C Y r O N O (NO O NU) O () N(- rm N6)- IV]- (N ((O O O U) O R ❑C = rrrr r r r O co- .- r r r r 2V co V U) co r V co r N M M CO V 00 N O Nr-- C O 6O) CO V O O 6) 6) O (O O CO (O CO V N r a o CO M CO O N N CO V N { f 6 MN M V M V M rrNrM rrNr O RN w a— rn O o O o O O 0) CO (O N- (O O N- (O CO N- CO )0 O 131.1 V O V V CO V CO 60 0) (O CO 0 CO O) CO N r N- 0 W o 6 o W0 0) (fi ui O (0 N CO' CO N CO V N 0LV NO NMVON cow N+y O CO 0 N (O (O (O (O O aR jr ,_ r r rr r (.6 O) r r r r s- a e m E r N- I"- V O V O 00 00 CO V CO CO CO N CO CO N C (O CO O (O CO (O CO )0 (O CO N (O r 4) r r O V E 0 O O) O V (0 V (O (O 6 CO (0 (O M M CO O O N 0 CM M M M M M M V V M V V (O )0 N CO CO CO C E oR+ N 01 O C N O^ E ❑ CL co a a co O O O O CO O CO CO O N- N CO N- 0) CO n CO (O LI) V O V V M V M O) O) (O 00 CO (O 6J M N r r 'Cr Up Gad L Y O) O M O 00 O OO fO O N O V 6 W CO V 0. co V CO O) O (O O CO CO N. N- CO V CO (n (O O CO G ' O COO COO (tCOCO. O O 1 O o r &' o 1 L L() 0 (O W d z E r R 6 1 m 6 Ci ❑ C N co ✓ m a o c C • L. L 7 N (O (O (O (O CES , 0) o0. 0 a a Cl 0. c ❑Y ❑ Y (3.O Z L a U • E ` LL R (I) NERZ . :..-J JN.. COJ MJ r r a M co M co O- O- ^ ^ N N v V v V a a V' CO O co O O0• aNcU ari °_)o mmr ❑ ❑ O ❑ N N ❑ ❑V v rL R R R OJJ J 0 O 0 ' J J J aR M 0 U ❑ 7U ^. YY VVMMMM M (O (O R NN NN CO CO CCC) J •E ... v .5( R so' o aOC 0 E Nq ❑ ❑ ❑ ❑ ❑ ❑ ❑ o V V V ❑ ❑ a 0 0 6 Zas d ` mmmmmm C a m 6 °) r L = d co co N aaaa aaLLmm (' EEE E •— t C O CO CO CO COJ JNJ J J N O N O N CV VV V V V V V V V V N N N N elL Zi; 000010 ❑ ❑ rr rrrVV V V as Q C0 13 C c .. iU d aKZ a CONN V V V V . . . "• 0 ❑ ❑ ❑ ❑ ❑ ❑ ❑ R co R R R co R 0) 0) CO 0) (n v a E E a E a a E E E _ _Q • Fcc RR R a' N N • • r=sC 0 x 0 a a. o U • a ers dcA a a 0 u 0 0 0 U o m 0 1.1 Y Y (I) Q Q Q U U U LL u. lL 0 T T T r � � � � � � 0 R E q T W S ) C O 0o/ ct d u) in N •Zr a.o. a n. a o .am w 3 3 3 3 3 3 3 I iO LO )O LO LO lO LO o v v v v v v v f ❑ ❑ ❑ ❑ 0 ❑ ❑ U 0) f.. Po L2 E C w o O ao au O ,NY' 3 N W r o o CO. co LO �n C C 1 oonnN- rmC d m U0 Favvu) ovrnv *<-5 , m 2 r V s- N N V V' LO m 0 0) 0 r 9 N E 0) C O U1 C N C Cu o "O B ❑ 2 N 0) Z a E _ a 000 z � 0. 0 m a. lO O O (O (O iO LO = O 4 C r C O 42 L 0 0 O O N C = 2 'N ''K M Ls) Lc) V N N .� d o N N L7 C L LL 7 N N V V' O V .� 0) ,ted, N /� O v N 3 LLo N 01 N N V 3 y N U N LL Q d -o 2 0) M c U 0 C N 3 N W ' a c 0 VI 07• C U U ` co N 07 C C N y d w 0 U a cS o M O O N N 0) LL U N 4 2 N 0) O O O W N G N i N N S (0 0) N Q W U 0 Et U Q • • 1 D-145w 09 Ladder View pThe Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. a (ll si N 121 3 mE ma n m a d®o ar indo Ziaaa a a a a a d 300 ' I's a --. J--.,'Jd 1 ' _:'r 11111 11. W.'' � ;rid IL 0 Hi I 1 i I irI I' t I rl !I I I 1141 I - c /�d yytl i ' 1 G ...y�y g`k � 1_ _ -=.i..lF .111111Ai IIIDIIIc1 1I1tll. edauunlmll " "u I III�11 (ltll►` II �11,11�\l��II�I�._ l�IIIIIII - „„no iu mlllllw.. �111� , w� I'� .. O 150 -. ,1 nplll III 9 I 1 iiI Milli I'� .1„rIIII i u II Ili!{ i pI ,1IIIIIIII;11111111 'l � ilil�l v _ 1.lnmmanllil111111111111IIII{III�I1!11i- I, III; it IIS 1 Yli�".1,��. I�� 11. - Equivelant Magnetic Distance�1011I. II Ai �� ii,iii IN mo f'' . 1 1 Migulauliall All '11 '11 I III 0 1500 3000 4500 6000 7500 9000 Displayed interval could be less than entire well:Measured Depth 39.50 To 9482.50 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations, interval:25.00 Depth Range From: 39.50 To 9482.50 Results Limited By: Centre Distance: 1144.30 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.50 1400.00 1D-145wp09(Plan: 1D-145) GYD-GC-SS 1400.00 2400.00 1D-145wp09 (Plan: 1D-145) MWD 1400.00 2571.68 1D-145wp09 (Plan: 1D-145) MWD+IFR-AK-CAZ-SC 2571.68 4071.68 1D-145wp09 (Plan: 1D-145) MWD 2571.68 4470.51 1D-145wp09 (Plan: 1D-145) MWD+IFR-AK-CAZ-SC 4470.51 5970.51 1D-145wp09 (Plan: 1D-145) MWD 4470.51 9482.50 10-145wp09 (Plan: 1D-145) MWD+IFR-AK-CAZ-SC CASING DETAILS s„1D-1, TVD MD Name Size -41,1D 2487.40 2571.68 13-3/8"x 16" 13-3/8 -41,PIe 3738.40 4470.51 9 5/8"x 12-1/4 9-5/8 1c-10£ 3796.40 9482.50 4 1/2"x 6-3/4" 4-1/2 1c-10£ 1C-12: ID-01, U-UI VI/ - IU-ILU,IU-ILU,IU-ILU VL - IU-J4,IU-64,IU-d4 Vb ID-02, D-02 V11 -481- 1D-121,10-121,10-121 V2 -A- 1D-34,1D-34L1,1D-34L1 V3 ID-04, D-04 V7 -X- 1D-122,1D-122,1D-122 V2 - 1D-34,1D-34L1PB1,1D-34L1PB1 V4 ID-04A 1D-04A VO -13- 1D-123,1D-123,1D-123 V2 -f- 1D-36,10-36,1D-36 V4 ID{MA r1, 1D-04AL1 VO $ 10-124,1D-124,1D-124 V2 -8- 1D-36,1D-36,1D-36WP4(Baker)V1 ID-04A.1-01,1D-04AL1-01 VO -0- 1D-125,1D-125,1D-125 V2 --0- 1D-36,1D-36L1,1D-36L1 V3 ID-04A 1-02,1 D-04AL1-02 VO -X- 10-125,1D-125A,1 D-125A VO $- 1 D-36,ID-36L2,1D-36L2 V1 ID-05,TD-05 V6 - 1D-126,1D-126,1 D-126 V2 $- 1D-37,10-37,1D-37 V4 ID-06, D-06 V6 -A- 10-126,Plan:1D-126A,1D-126A(xp02)VO $ 1 D-37,1 D-37L1,1D-37L1 V1 ID-09, D-09 V5 -A- 1D-127,1D-127,1D-127 V2 -e- 1D-37,1D-37L2,1D-3712 V3 ID-10, D-10 V2 -X- 1D-128,1D-128,1D-128 V2 - 1D-37,1D-37L2PB1,1D-37L2PB1 V1 1D-10,1D-101 V1 -X- 1D-129,10-129,1 D-129 V2 --I-- 1D-38,1D-38,1D-38 V2 1D-10E,1D-102 V6 $- 1D-130,1D-130,1D-130 V2 4i-- 1D-39,1D-39,1D-39 V2 1D-101.L1,1D-102L1 V1 $- 10-131,1D-131,1D-131 V2 -e- 10-40,1D-40,1D-40 V4 1D-10EPB1,1D-102PB1 V9 - 1D-135,1D-135,1D-135 V2 --9- 1D-40,1D-40A,1D-40A V1 1D-10:PB2,1D-102PB2 V1 -e- 1D-136,1D-136,10-136 VO -e_ 1D-41,1D-41,10-41 V1 1D-10^PB3,1D-102PB3 V1 -0- 1D-138,1D-138PB1,1D-138 WP2 V1 -A- 1D-41,1D-41PB1,1D-41PB1 V4 1D-10E„1 D-105 V30 -I- 1D-140,10-140,10-140 VS -X- 1D-41,1 D-41 PB2,1 D-41 PB2 V1 1D-105A,1D-105A V36 -9- 10-140,1D-140L1,10-140 L1 VO -8- 1D-42,1D-42,1D-42 V2 1D-10E,1D-106 V2 $- 1D-140,1D-140PB1,1D-140PB1 V4 -e- 10-42,1D-42,1D-42(Baker)V1 1D-10-,In/0''' $ .pint,ID 1,11t,ln-1•11 WV 4.- .p 1121D 1191 t,'0 "1 WI ID-11,1D-11 V2 -1-- 1D-141,1D-141A,1D-141A VO -6.- 10-42,1D-42L1PB1,1D-42L1PB1 V1 ID-11L1.1D-11L1 V1 1D-141.1D-141APB1.1D-141APB1 VO ---X--- Plan:1D-143.Plan 1D-143 1D-143xn15V0 • • 10-145w 09 Ladder View pThe Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. N g 12-B 3 mm9 Q ®q Rrt-ero W"= Ym U'.,,-4 O 2 N 2 i - aide) :Ci -ii, ac d d 8c 65 a iimnlgi4 001 300 Il 4 I / xi I '11111111 +I c 11 J I , 11 4 av) a ..:.i I ,r"n6d I II I 1150_ nn t h 1'1 r � ■ 1 1 _ a IId I)lli 1 1"Ill i ' �I _ � 1 ,�� � I - ' e Ill: DU •b,u � 1 i Ill air cI,I1i , 'j111III0 �I11�iI � (c - '...""nn9miniillllIIliilllil. ll ql� I IIIi IU IInnll�' iI mr"'"IilllllIIIIll .P .III �lr_ IIIIIINI I ® ,' mnlnmn111I[IIIIIIIIIIIfUiNtkelli � inI [r.6.r II.,,,_---."allaiI � SIDi 0 `rte' ` I I , I I I I I I I I I I I I Equivelant Magnetic Distance I 0 1500 3000 4500 6000 7500 9000 Displayed interval could be less than entire well:Measured Depth 39.50 To 9482.50 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations, interval:25.00 Depth Range From: 39.50 To 9482.50 Results Limited By: Centre Distance: 1144.30 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.50 1400.00 1D-145wp09(Plan: 1D-145) GYD-GC-SS 1400.00 2400.00 1D-145wp09 (Plan: 1D-145) MWD 1400.00 2571.68 1D-145wp09 (Plan: 1D-145) MWD+IFR-AK-CAZ-SC 2571.68 4071.68 1D-145wp09(Plan: 1D-145) MWD 2571.68 4470.51 1D-145wp09(Plan: 1D-145) MWD+IFR-AK-CAZ-SC 4470.51 5970.51 1D-145wp09 (Plan: 1D-145) MWD 4470.51 9482.50 1D-145wp09 (Plan: 1D-145) MWD+IFR-AK-CAZ-SC CASING DETAILS a 1D-1. TVD MD Name Size .41,,p 2487.40 2571.68 13-3/8" x 16" 13-3/8 -41,PIE 3738.40 4470.51 9 5/8"x 12-1/4 9-5/8 1c-10t 3796.40 9482.50 4 1/2"x 6-3/4" 4-1/2 1C-10(. 1C-12i ID-01, U-UI VI, 'yr 1U-ILU,IU-ILII,IU-ILU VL I1,-J4,I1J-J4,I1J-J4 Vb ID-02, 0-02 V11 -9- 1D-121,1D-121,1D-121 V2 $- 1D34,1D-34L1,1D-34L1 V3 ID-04, 0-04V7 -e- 1D-122,1D-122,1D-122 V2 -X- 1D-34,1D-34L1PB1,1D-34L1PB1 V4 ID-04A 1D-04A VO -A- 1D-123,1D-123,1D-123 V2 -X- 1D-36,1D-36,1D-36 V4 ID-04A-1, 1 D-04AL1 VO -A- 10-124,10-124,1 D-124 V2 -A- 1D-36,1D-36,1 D36WP4(Baker)V1 ID-04A-1-01,1 D-04AL1-01 VO -B- 1D-125,1D-125,1D-125 V2 $- 10-36,1D-36L1,1D-36L1 V3 ID-04A-1-02,1 D-04AL1-02 VO -e- 1 D-125,1 D-125A,1 D-125A VO - - 1D-36,1D-361.2,1 D36L2 V1 ID-05, D-05 V6 -e- 1D-126,1D-126,1D-126 V2 --- 1D-37,1D-37,1D-37 V4 I D-06, D-06 V6 -0- 1 D-126,Plan:1D-126A,1D-126A(wp02)VO -9-- 1D-37,1 D-37L1,1 D37L1 V1 ID-09,'D-09 V5 -0- 1D-127,1D-127,1 D-127 V2 -1- 1D-37,1D-371.2,1D-37L2 V3 ID-10,'0-10 V2 -e- 1D-128,1D-128,1 D-128 V2 -X- 10-37,1 D-37L2PB1,1 D-37L2PB1 V1 1D-10,1D-101 V1 --9- 1D-129,10-129,1D-129 V2 - 1D-38,1D-38,1D-38 V2 10-10:,1D-102 V6 10-130,10-130,1D-130 V2 -0-- 1D-39,1D-39,1D-39 V2 1D-10:L1,1D-102L1 V1 $- 10-131,10-131,10-131 V2 - 1D-40,1D-40,1D-40 V4 1D-10:PB1,1D-102PB1 V9 -X- 1D-135,1D-135,1D-135 V2 -A- 1D-40,1D-40A,ID-40A V1 1D-10?PB2,1D-102PB2 V1 10-136,10-136,1D-136 V0 -9- 1D-41,10-41,10-41 V1 1D-10?PB3,1D-102PB3 V1 -8- 1D-138,1D-138PB1,1D-138 WP2 V1 -e- 1D-41,1D-41PB1,1D-41PB1 V4 1D-10(,1D-105 V30 -X- 1D-140,1D-140,1D-140 VO -e- 10-41,1 D-41 PB2,1 D-41 PB2 V1 1 D-10SA,1D-105A V36 -A- 1D-140,1D-140L1,1D-140 L1 VO -- 10-42,10-42,1D-42 V2 10-10(,1D-106 V2 1D-140,1 D-140PB1,1 D-140PB1 V4 - 1D-42,1D-42,1D-42(Baker)V1 10-10-,1n 1571n +p int,1p lel In 1,1 Vo .4i).. 15 e2,15nol�1p n211 v1 ID-11,10-11 V2 -Y- 1D-141,1D-141A,1D-141A VO -9- 1D-42,1D-42L1PB1,1D-42L1PB1 V1 ID-11L1.1D-11L1 V1 T 1D-141.1D-141APB1.1D-141APB1 VO -A- Plan.10-143 Plan:1D-143.1D-143wo15VO • • Ladder View 1 D-145w 09 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. I 1 I 1 60 rI_ -_ ,",, 130 ."1111 - \I -Equivelant Magnetic Distance .,_.. . _. ......_.,...... 0 -.1. I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I 0 500 1000 1500 2000 2500 3000 3500 Displayed interval could be less than entire wellVeasured Depth 39.50 To 9482.50 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval:25.00 Depth Range From: 39.50 To 9482.50 Results Limited By: Centre Distance: 1144.30 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.50 1400.00 1D-145wp09 (Plan: 1D-145) GYD-GC-SS 1400.00 2400.00 1D-145wp09 (Plan: 1D-145) MWD 1400.00 2571.68 1D-145wp09 (Plan: 1D-145) MWD+IFR-AK-CAZ-SC 2571.68 4071.68 1D-145wp09 (Plan: 1D-145) MWD 2571.68 4470.51 1D-145wp09 (Plan: 1D-145) MWD+IFR-AK-CAZ-SC 4470.51 5970.51 1D-145wp09 (Plan: 1D-145) MWD 4470.51 9482.50 1D-145wp09 (Plan: 1D-145) MWD+IFR-AK-CAZ-SC CASING DETAILS \,1D-i TVD MD Name Size -41,1D 2487.40 2571.68 13-3/8"x 16" 13-3/8 -41,Pk 3738.40 4470.51 9 5/8"x 12-1/4 9-5/8 is-io<< 3796.40 9482.50 4 1/2"x 6-3/4" 4-1/2 is-1o<. IC-12i ID-01, U-Ill VIr - 111-1211,111-1211,111-1211 VL -V- 111,14,IUd4,1U-64 Vb 1D-02, D-02 V11 -9'- 1D-121,1D-121,1D-121 V2 -0- 10-34,1D-34L1,1D-34L1 V3 ID-04, D-04 V7 -e- 1D-122,1D-122,1D-122 V2 -X-- 10-34,1034L1 PB1,1 D-34L1 PB1 V4 ID-04A 10-04A VO -- 1D-123,10-123,1D-123 V2 - 10-36,10-36,ID-36 V4 ID-04A I, 1D-04AL1 VO -A- 10-124,1D-124,1D-124 V2 -A- 10-36,10-36,1D-36WP4(Baker)Vi ID-04A_1-01,1D-04AL1-01 VO -B- 1D-125,10-125,1D-125 V2 $ 1D-36,10-36L1,1D-36L1 V3 ID-04A_1-02,10-04AL1-02 VO -e- 1D-125,1D-125A,1D-125A VO -%- 1 D-36,10-3612,1D-36L2 V1 10-05, D-05 V6 -e- 1D-126,10-126,1 D-126 V2 -A- ID-37,1D-37,1D-37 V4 ID-06, D-06 V6 -0- 1 D-126,Plan:1 D-126A,1D-126A(wp02)VO -9- 1D-37,1D-37L1,1D-37L1 V1 ID-09, D-09 V5 -0- 1D-127,10-127,1 D-127 V2 1D-37,10-3712,1D-371.2 V3 ID-10, D-10 V2 -e- 10-128,10-128,10-128 V2 -X- 10-37,1D-37L2PB1,1D-37L2PB1 V1 1D-10,10-101 V1 -e- 1D-129,1D-129,1D-129 V2 - - 10-38,1D-38,1D-38 V2 113-10:,1D-102 V6 -i- 1D-130,1D-130,1 D-130 V2 1D-39,1D-39,1D-39 V2 1 D-10:L1,1D-102L1 V1 -0- 10-131,10-131,1D-131 V2 1D-40,1D-40,1D-40 V4 1D-102PB1,1D-102PB1 V9 -X- 10-135,10-135,1D-135 V2 -A-- 10-40,1D-40A,1D-40A V1 1D-10:PB2,1D-102PB2 Vi 10-136,1D-136,10-136 VO -9- 1D-41,1D-41,1D-01 V1 1D-10?PB3,1D-102PB3 Vi -13- 10-138,1D-138PB1,1D-138 WP2 V1 -00- 1D-41,10-41PB1,1D-41PB1 V4 1D-10!,1 D-105 V30 -X- 1D-140,10-140,1D-140 VS -e- 1D-41,1 D-41 PB2,1 D-41 PB2 V1 10-106A,1D-105A V36 -g- 10-140,1D-140L1,1D-140 L1 VO -A- 1D-42,1D-42,1D-42 V2 1D-10E,10-106 V2 1D-140,1D-140PB1,1D-140PB1 V4 -1-- 1D-42,1D-42,10-42(Baker)V1 1D-10 ,n 157117 ...6.. +n_,nl 1,1.41,Ip 141 112 -e- 1D nv,1DA2,,10.4211111 ID-11,1D-11 V2 -x- 1D-141,1D-141A,1D-141AVO $ 1D-42,10-42L1PB1,1D-42L1PB1 V1 ID-11L1.1D-11L1 V1 1D-141.1D-141APB1.10-141APB1 V0 -A- Plan:10-143.Plan:1D-143.1D-143wn15VO • MD Inc Azi TVD +N/-S +E/-W Ding TFac VSect Target 4U 45U 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 1 D-145wp09 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 450 640 750.00 4.50 95.00 749.69 -1.03 11.73 1.50 95.00 -3.05 39.50 To 9482.50 7700.00 13.75 104.97 1095.24 12.53 63.97 2.50 15.00 23.44 640 840 1639.75 24.00 138.00 1607.40 -110.49 197.45 2.73 60.73 -143.10 1749.21 24.00 138.00 1817027...946780 -143.58 227.25 0.00 0.00 -180.86 1864.26 22.91 147.76 -231147419693....3305,238 179.93 254.86 3.50 110.09 -221.45 840 1030 2075.63 22.91 747.75 2007249.52 298.77 0.00 0.00 -297.61 16:09,March 11 2015 2521.03 9.24 81.17 2437.40 318.13 381.28 4.70 -11-153000,....00600,08 155.65 ----233292779299701....i4814315 379.51 1030 1220 2591.95 9.24 81.17 2507.40 376.39 32229:542671...:5278249763 92.54 0.00 0.00 -379.74 3942.01 63.76 355.35 3584.58 375.95 457.30 4.70 -90.42 290.83 1220 1420 SURVEY PROGRAM 4012.43 63.76 355.35 3615.72 438.91 452.18 0.00 0.00 353.72 �.P1n From Depth To suNevm"� 7001 4470.51 85.00 351.69 3738.40 874.57 401.96 4.70 -9.98 797.48 1 D-745 DL 24Jun14 Heel 39 50 1aao.00 1D-145wPoolPlan:re-m g cro-ccs 4490.51 85.00 351.69 3740.14 894.29 399.08 0.00 0.00 811.40 1420 1610 1aao.00 2400.0o 10-rar, 9(Plan:to-reel mwo 4732.93 89.33 353.88 3752.13 1134.42 368.68 2.00 26.83 1053.16 1000.00 2571.fi8 1D-145,091PIan:ID-1057 05 10-Cu-x 8994.86 89.33 333,35351..886889 53.88 3755.20 1394.83 340.75 0.00 0.00 1314.47 2571.48 4071.sr 10-roe- 09_„,,1D-115) mwo 1610 1800 2671.44 a4ro.s1 10-145.Pos lPlan:1D-1457 mwwlcn-accaz-x 5539.69 90.00 343.00 3758.40 1927.80 231.71 2.00 -86.51 1858.28 1D-145 MW 20Apr14 CP2 vro.s1 507051 on-i ,00a Io°an:re-145) mwo 5616.92 92.55 342.09 3756.69 2001.44 208.56 3.50 -19.65 1934.82 44ro.s1 eaerso 10-10.5wp09(PWn:10-105) mwD.iPa-axcaz-sc 5910.64 92.55 342.09 3743.64 2280.66 118.32 0.00 0.00 2225.47 1800 2130 6771.23 88.00 350.00 3742.40 2533.29 55.55 3.50 119.82 2485.16 1D-145 MW 20Apr14 CP3 CASING DETAILS 6437.54 81.12 358.18 3767.67 2796.59 28.17 4.00 130.52 2749.21 2130 2450 6454.32 81.12 358.18 3770.26 2813.16 27.65 0.00 0.00 2765.62 ND MD Name Size 6668.80 89.70 357.99 3787.40 3026.64 20.50 4.00 -1.25 2977.10 1D-145 MW 20Apr14 CP4 2450 2780 2487.40 2571.68 13..'/8"x 16" 13-3/8 6707.98 90.13 358.64 3787.46 3065.80 19.36 2.00 5061.:032055 6.35 3015.86 3738.40 4470.51 95/8"x 12-1/4 9-5/8 8127.92 90.13 358.64 3784.13 4485.34 -14.30 0.00 0.00 4479.68 3796.40 9462.50 4 1/2°x 6-3/4" 4-1/2 8203.71 89.46 0.00 3784.40 4561.12 -15.20 2.00 116.40 4494.461 10-145 MW 20Apr14 CP5 2780 3100 8951.47 89.47 14.96 3791.45 5300.39 81.84 2.00 90.05 5205.65 9482.50 89.47 14.96 3796.40 5813.40 218.88 0.00 0.00 5687.07 1D-145 MW 24Apr14 CP6 3100 3430 3430 3750 3750 '� 4080 0/360 4 „� 4080 4400 i.': n:,1 1P °��m•s ---r13-1:;2 4400 5040 30/33ir, ''' \ 403, 30 5040 - 5670 rU , 1 5670 6310 51 �irf O'"0�9`r,; •'r s4? 1-j_ ,S;i9ficit ,fi4itfi 1a �,5x // k Option Wp06(02'z7;o6;.310 6940 " . ' 4, 1 ,,r. ,wp06 6940 7580 �8 � � ;� " --,-',,..::,:-,1,-,#10:1.444,-.., -.,:.1 7580 8210 -s, \V' �%� .. �� � 8210 8850 60/�301 - v-: ,0� �� i!Q- ^T:TI 8850 9483 �L30 ,/,,,c1,,,`' _ �4 a+' ..�� Nin ��' � �4r. 3ilY f 7 _ �< V gyp\ rN - % I I( y ..�/►��%-•' - , ?. _-- s�lL_' ` �,//i 1 /I l itl u!t�,,l-...s•-v- . 'C. 1. /,'/r-.01-111%'illfill '/ " :,,!,f, moi • 1 •:1'.?',,'.. ' r //..I4.1 .,#` 4 lea r' 111 is I.ii 1I I :( `� 1����� i,/. i� 90/2 r n 4. 4 ,�.' !,:4!):,, /44"...;.";:',"11/10 .-..,-",41-, "' Y/4.01\y ' Irdi r ir �L'�i. �i .�. / 14 y,1'111 ��� ArF1ii- • �i> //� '� s qua -120/2 i.. [ ''i. p;'WI; 13 el �w. Jr :�,, % ''� ,. x�. l-_ _ cif -7,-!•-"Z.---!. ,,y r��Nr�Et .,Ale= >z �/ - O 411,14, ��i' --%.:-.-!Z".,,,,..'7".','-7,:',.." r^, /�Ltv/ID SLS -- ° -VII-4.!"..:1:001,..- �sl'-r - L' =.;psi®+� _ l'IlL -150/210 X50 s !,," -180/180 a,n.,n,., . � w5r�n�l w D„a re-ire an -tr -ft- -A 1190L1 tOZOLI V2 '.' LI 10-32LI Vi -6- $ ,o-,5x,alm twos vao �- waz+awsu vow "' - I -If , l.loaatP4lw 'if $ , Dema ro,mn Yx } wzo,,wmw $ , 4€ ,Ds,,1Da,rD-ea ve $ -3- t 0.1Tl,1w2R V2 $ t -3- t IMI 04 -j(- VD- '} D-141 1D-141 V2 ' 161w1L1w $ w21,wNV2 t $ t 6xv+PNeerer vm -K- ni. -� t D1,1R 161116 Is Dt'2x,w25 V2 '} I eeozr6101P➢@Vo t $ $ t 61t,a,,61fa,'1�4 Dtx6,to6i Y6 V1w -f- I $ ��n�.iaaa;�;;� t ;ai .rra;1w;i1,1f,�,.��o :8;:;,;r156; l;oi;�;��� ,a .,flix aa�� • MD Inc Azi ND +N/-S +E/-W Dleg TFa• VSect Target 4U 4)U 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 1 D-145wp09 50.00 4.50 95.00 749.69 -1.03 111.73 1.50 0.00 95.00 -3.05 450 640 39.50 To 9482.50 00.00 13.15 104.97 1095.24 -12.53 63.97 2.50 15.00 -23.44 640 840 1639.75 24.00 138.00 1607.40 -110.49 197.45 2.73 60.73 -143.10 1749.21 24.00 138.00 1707.40 -143.58 227.25 0.00 0.00 -180.86 1864.26 22.91 147.75 1812.98 -179.93 254.86 3.50 110.08 -221.45 840 1030 2075.63 22.91 147.75 2007.67 -249.52 298.77 0.00 0.00 -297.61 11:45,March 23 2015 2521.03 9.24 81.17 2437.40 318.13 381.28 4.70 -155.65 379.51 1030 1220 2591.95 9.24 81.17 2507.40 -316.39 392.54 0.00 0.00 -379.74 3942.01 63.76 355.35 3584.58 375.95 457.30 4.70 -90.42 29083 1220 1420 SURVEY PROGRAM 4012.43 63.76 355.35 3615.72 438.91 452.18 0.00 0.00 353..72 1eptn Fran Depth To S0u4VPM. Toe, 4470.51 85.00 351.69 3738.40 874.57 401.96 4.70 -9.98 791.48 1D-145 DL 24Jun14 Heel 9900 1440.00 10.146wp09(P4n:16115] GVD-GC-ss 4490.51 85.00 351.69 3740.14 89429 399.08 0.00 0.00 811.40 1420 1610 1400.00 2400.00 16i45wp09(Ram,D--14S) MWD 4732.93 89.33 353.88 3752.13 1134.42 368.68 2.00 26.83 1053.16 ,449.00 2571.68 10las) MwD+im-AKCAz9C 4994.86 89.33 353.88 3755.20 1394.83 340.75 0.00 0.00 1314.47 1610 1800 4571.66 4071.69 10-145wp09(Plan:1D-14S) MWD 2",,,M, 4.10.01 1D-145wp09(Km:10-1459 MWo.irR4X-CAz-SC 5539.69 90.00 343.00 3758.40 1927.80 231.71 2.00 -86.51 1858.28 1D-145 MW 20Apr14 CP2 4470 51 5910.51 10-1.30w,09(Man:1D-145) MWD 5616.92 92.55 342.09 3756.69 2001.44 208.56 3.50 -19.65 1934.82 4471.5, 0402.50 1D10.5wp09(Rm:1D-145) MwwiFn-accu-sc 5910.64 92.55 342.09 3743.64 2280.66 118.32 0.00 0.00 2225.47 1800 2130 6171.23 88.00 350.00 3742.40 2533.29 55.55 3.50 119.82 2485.16 1D-145 MW 20Apr14 CP3 CASING DETAILS 6437.54 81.12 358.18 3767.67 2796.59 28.17 4.00 130.52 2749.21 2130 2450 6454.32 81.12 358.18 3770.26 2813.16 27.65 0.00 0.00 2765.62 ND MD Name Size 6668.80 89.70 357.99 3787.40 3026.64 20.50 4.00 -125 2977.10 1D-145 MW 20Apr14 CP4 2450 2780 2487.40 2571.68 13-3/8"x 16" 13-3/8 6707.98 90.13 358.64 3787.46 3065.80 19.35 2.00 56.35 3015.86 3738.40 4470.51 9 5/8"x 12-1/4 9-5/8 8127.92 90.13 358.64 3784.13 4485.34 -14.30 0.00 0.00 4419.68 3796.40 9482.50 41/2"a 6-3/4" 4-1/2 8203.71 89.46 0.00 3784.40 4561.12 -15.20 2.00 116.40 4494.46 1D-145 MW 20Apr14 CP5 2780 3100 8951.47 89.47 14.96 3791.45 5300.39 81.84 2.00 90.05 5205.65 9482.50 89.47 14.96 3796.40 5813.40 218.88 0.00 0.00 5687.07 10-145 MW 24Apr14 CP6 3100 3430 3430 3750 3750 -- 4080 0/360 ® •,.,.--7- -.1.74080 4400 II',,' -1004 5 , 4400 5040 o 1, -30/331. \Neil ie ,: d'► is P 4 s 30 5040 .. 5670 ` o A�/trr " z ,�:.,....'1,;.,,.%/,,,,V,-,....._3 5670 6310 �, - �" - ; dr-',2••'''''',///-4X i1 O,,rltt i x1141 c 11f:', ';A 1 74i►►�..,-..,.....,:,,..-'....F.;;?..,... ;',. i6 �t)�4 'v ' vt Option W 6 02/2,-- .r r r1 �y 1h D+ 4 ,t,..„, aD t .310 6940 � ;,ei.♦ " ♦ 0'k //(r 4 Ls�et )i� ► 1�o P7 y,�/r�f� f� X11 a�-' s e4 <"s _. t lr �O'1 ,SS j 1 . s �`�,r/ �1 .� P t P ..OitC/��I� �� �j f d7 y��� 8. i� .. .„, .rr; ��''ifi I- 1 ♦ P s !►'r , rJ�17 i���.rs . 6940 7580 c. c�.r 4, is ule r I//f"wrritj ` -..„-_,T. ti ��'� � � � ..�.3 7580 8210 .,are .4` •• . ,1.`0�i10�110f sitiir)ri�►�' "1.�1.` flittf .•.„3 she v►r d •1 `4i4� ,64'01,"< ga ,4 ��* ;;boa lir 8210 8850 _- ,A - 4D .�.ti I.e .�rl'` ° fa`is`.®s•!e<•�l�44: �1'NI{►� A` f, ° t �K -60/300 .• •�' 4�" .,� 4/��s• _ e . + .tea � 8850 9483 .G - 4 imik\ ro.....ii„,,, 46.::-.40... ,..,, . �_1 700.� � 1i�, .,r410 4 ,t. �i •,..,�� ,,,,.�mow �N�� ....." .::::,..,,,,,11,1r,.N..4.4.. -w741,,,..,00, /0-mw..*0704,71., -14,1.- ., 0, . . .-4=-4:71.17:11::::,...seigt.1,,i,104,,,,,...,, = '''' -'-''---='- 4110,1W VW i%TO ar AVIA,A --- 4 raitiN !�, 'hd .f •, •vs a�.�y/��1�11410.44'4wI�iL��4.0, \. A Nk ,.......%-::;„:..*:,,,,, • Pe, ,40.- fila,.(0.7,04.7,‘,., tt1 ri'-MF t 90/2 • ► .♦ ,I __+ �ti_ his ��Is►t,i+ i,IN..wAitt ..►, ,� .h•P�1ii /ii /.a• -.. $ '1'114**-- t�P .ff1��J� '�a��� �,���►i . i ' 7 Ria /:r': •:„`,�111-- i.\�;I 1^47, .aa. •� `,�I•� ' X 10/ �'/ 1:',, •s ' / c3� �/ • - t. / ,ix . f19. �Rd/ ,..,•a •• ♦.� / / f/Irr 4 r> _ _.t.. ������ .4„,,,,,,,> < ' ♦ 4a :\HIS �' � ; .�'- a.��'�L� asT/� ti +F s.a!, it -120/2'la i i / ((ii:( � � tO -yp/ �T�._ e�° 4®jli�" , t��117'2 e 13V1 11 11 iIIII.,..!:,,,:re-/-p‘,..,....:47„,.(9,--,,0I-' ��� .o v..4.y�1�1�1Ji�` �..". t • P rd-/m • �f�4 ,4. b.i!1 1 �„ti,„'/'y ..44 4fk,!.1{ , _ -4E44% • , F, + tiolr Il`f x-42 '�X / ••ti,A- /l.p 001.10.-:-"4".1.4,-;:4C:;,,,,.' 1'0 0 t,�, iarl a J. �' :J 150/21050 -180/180 "f' t¢tek t0.i35 to-r oo va �- -le$ 10 138.10.M0.01. ens v, i0..,t0.9.Lt,,¢Jatw -} i- , ¢,0,4,40000 ,jE- o-,az eD,zuw� -34- , o,,¢,+a,o-,aw 9 1D<a,no-m,Pen,1Daz,Per W $ 1.1 -6- , wos4,10-reeve $ -A--0- 10.108.1.106.16.rs $ -E- if- , 9- wes no-n zvz -� ,o-u�,,w+men r,vaPe ipso,nasema, wai,Pe,o $ -X- was,are,lo,,,va $ -A- , aoeParm,enw $ a la $ 10.11.1..161.vs $ a,es.,o-iaa,waVR ,,¢0 ,, -O- $ $ , enseno.,ai4P®w } wroeu,I¢xu vi -El- rc,o 9 ¢ia¢issvo , n , .10 I ;aiii.iaiii.iaiii1 * iai�i.R11 ,0'-..nw I ;aili.11116i!';aiililgi0 1 I.,10.7.i1' J'1 t MD Inc Azi TVD +N/-S +E/-W Dleg TFac- VSect Target 'I ' / 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 1 D-1 45wp09 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 450 _ 640 750.00 4.50 95.00 749.69 -1.03 11.73 1.50 95.00 -3.05 1100.00 13.15 104.97 1095.24 -12.53 63.97 2.50 15.00 -23.44 640 840 39.50 To 5500.00 1639.75 24.00 138.00 1607.40 -110.49 197.45 2.73 60.73 -143.10 1749.21 24.00 138.00 1707.40 -143.58 227.25 0.00 0.00 -180.86 1864.26 22.91 147.75 1812.98 -179.93 254.86 3.50 110.08 -221.45 840 1030 2075.63 22.91 147.75 2007.67 -249.52 298.77 0.00 0.00 -297.61 11:47.March 23 2015 2521.03 9.24 81.17 2437.40 318.13 381.28 4.70 -155.65 379.51 1030 1220 2591.95 9.24 81.17 2507.40 -316.39 392.54 0.00 0.00 -379.74 3942.01 63.76 355.35 3584.58 375.95 457.30 4.70 -90.42 290.83 j 220 1420 auea a pnaan 4012.43 63.76 355.35 3615.72 438.91 452.18 0.00 0.00 353.72 1eath From Death Ta surveymmn tool 4470.51 85.00 351.69 3738.40 874.57 401.96 4.70 -9.98 791.48 1D-145 DL 24Jun14 Heel 49s0 1400.00 111-145wp09(Plan:109 c1•13-0c-ss 4490.51 85.00 351.69 3740.14 894.29 399.08 0.00 0.00 811.40 1420 1610 1400.00 2400.00 ,13-145wp09(P0n(10-145) MD 4732.93 89.33 353.88 3752.13 1134.42 368.68 2.00 26.83 1053.16 1500.00 4071.60 1a145wp09(Pla11:10495) 89W13 en-accnz-SC 4994.86 89.33 353.88 3755.20 1394.83 340.75 0.00 0.00 1314.47 1610 1800 2571.68 4470.59 1D-145wp09(Plan:104145) MWO 2470.64 5970.51 1D-14swp0s(Plan:11344.5) 81W13 pH-a<cnz-sc 5539.69 90.00 343.00 3758.40 1927.80 231.71 2.00 -86.51 1858.28 1D-145 MW 20Apr14 CP2 4470.51 99Vo.s0 10,45 p49Ielan(10445) .wD 5616.92 92.55 342.09 3756.69 2001.44 208.56 3.50 -19.65 1934.82 1800 2130 4570.51 saersa 1alaswp4s(Plan(104 ) MWO•IFA-914 -sc 5910.64 92.55 342.09 3743.64 2280.66 118.32 0.00 0.00 2225.47 6171.23 88.00 350.00 3742.40 2533.29 55.55 3.50 119.82 2485.16 1D-145 MW 20Apr14 CP3 CASING DETAILS 6437.54 81.12 358.18 3767.67 2796.59 28.17 4.00 130.52 2749.21 2130 2450 6454.32 81.12 358.18 3770.26 2813.16 27.65 0.00 0.00 2765.62 TVD MD Name Size 6668.80 89.70 357.99 3787.40 3026.64 20.50 4.00 -1.25 2977.10 12-145 MW 20Apr14 CP4 2450 2780 2487.40 2571.68 13-3/8"x 16" 13-3/8 6707.98 90.13 358.64 3787.46 3065.80 19.35 2.00 56.35 3015.86 3738.40 4470.51 9 5/8"x 12-1/4 9-5/8 8127.92 90.13 358.64 3784.13 4485.34 -14.30 0.00 0.00 4419.68 3796.40 9482.50 41/2"x 6-3/4" 4-1/2 8203.71 89.46 0.00 3784.40 4561.12 -15.20 2.00 116.40 4494.46 12-145 MW 20Apr14 CP5 2780 3100 8951.47 89.47 14.96 3791.45 5300.39 81.84 2.00 90.05 5205.65 9482.50 89.47 14.96 3796.40 5813.40 218.88 0.00 0.00 5687.07 1D-145 MW 24Apr14 CP6 3100 ' 3430 3430 3750 0/360 3750 4080 4080 -----"-" 4400 1D-1,.2`"•' ►�v'� yid" 4400 5040 lioreg�ii►�+ViltaV) 30 -30/330 �.=argil,70 5040 5670 �. �1��, ®r 65 5670 6310 t '�� ` ®•i®80 6310 6940 o'���� ��N ��>�,® j 6940 7580 l/17��1°'i®®'•I l�T�'=- �®�l�50 7580 8210 AAL,./.4.7 14��,',��'.,MA®�414W�+ /•,®�45 8210 8850 -60/Frwrum� ,'leiiii►; r4'1 ��.,1I���40 -- 60 8850 9483 X41]`I , V,.I®'"411 � in \ dir#0111 30 �his, 4iumr,p-4/1,�%►„lIi��4.:4 Alvi Ala lAtitillWilMA*12111444*dig/01111 ����A �� il=fi 0,011111 . fP,IliiiP111-7004.4 4' 1 / . a sar,......,,,,..„,,,,..,,v,,,,,,..4,..,,,,44, 20 , ; �`, ,„,,,,A,,,,,,,,,..„‘„,,,.....,....„..„,,,,,,,,, , 4 NfillAdi.,-4A;s*IA:'4:4Mnblige'40411144i ii A. . 10.1 .11.,.."114,40,40,4 !4.►v iii/��>i 4 /) riilthrtik4VilliiVO; Ant& sAtes symi44 -90/270 i i, v7 1 . . .. o, 90 ` fie® 'rgrA, •, 'P- Vr /1"..1411424111 i ► . ! 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'I,/1 1�`aa\ eia�e a ae.e A/0 �.®A , i b .� -120/240 ®��,������,0,►4A44,P'Aim . �� � ���►������� i 120 ....4"'A..,Itari.;:.. ..;„-e4ktilik cow-. �/ A ®ia � ow ycew11A -150/210 ilimillir ®rt•�otrfill®,ll�,b/ ° ,t`p�1�1�1�1�l�tjl•* 150 '4441rPVie, iVlpi. -180/180 ,,,7,4a1 $ x $ $ ; + 40.1 -9- o $ o a( o $ � a -o- -e- I $ I + I $ 1 $ - 1 vi -0- so so.salotsool.volaloes v0 -8. 10138, W w vi -0- $ , , -34- -X- 0,90 es-,a0 VO $ 1l'.v, $ 41,1 -e- 10 -X- 10 uo,lam,ID In vz -h- Is $ 10 -& 450.1 $ I $ I } 1 ,vs $ 1 $ -X- 1 $ 1 -tr is las,law,1 o s al vs -X- , 113e1 444 $ $ 10 ii,la,so ll V2 -6- ,D j( 113 141,10141A,ID 14IAVO 446 ,D -9- 4€ 1,11..11, $ 154 124,154124,10124 Vs 1 stiapsls-vsr V, $ -e- 1.21.10,1,10m, $ 101 55,10125,10126. 1014,101410592.ID 14155132 VO $ ,0 $ s ID -13- t 1 V1 $ $ , 0 -3- a 6,1,loa5L2 vi -Q- n. -6- 1, $ 1D -X- 10- .A- ,0 4. 1 ;B;;I.;Q;,l.1B;1 g $ 11P31"�',4�1 4,I, ,,.m„Va I 1 ill',R11,Gif�,R111Gff><g I ,Q11,,Q1Xl,R NX ° MD Inc A. TVD +N/-S +E/-W DIeg TFa• VSect Target 4U LIDU • 390.50 0.00 0.090 39.50 0.00 0.00 0.00 0.00 0.00 1 D-145wp09 459.00 0.00 0.66 456.00 6.00 0.00 0.00 0.00 0.00 450 640 750.00 4.50 95.00 749.69 -1.03 11.73 1.50 95.00 -3.05 5500.00 To 9482.50 1100.00 13.15 104.97 1095.24 2.53 63.97 2.50 15.00 23.44 640 840 1639.75 24.00 138.00 1607.40 -110.49 197.45 2.73 60.73 -143.10 1749.21 24.00 138.00 1707.40 -143.58 227.25 0.00 0.00 -180.86 1864.26 22.91 147.75 1812.98 -179.93 254.86 3.50 110.08 -221.45 840 1030 2075.63 22.91 147.75 2007.67 -249.52 298.77 0.00 0.00 -297.61 16:11, March 11 2015 2521.03 9.24 81.17 2408743157...7452800 318.13 381.28 4.70 -155.65 379.51 1111i;00000 030 1220 2591.95 9.24 81.17 4 -316.39 392.54 0.00 0.00 -379.74 3942.01 6993...722644 3.76 355.35 35375.95 457.30 4.70 -90.42 290.83 1220 1420 SURVEY PROGRAM 4012.43 63.76 355.35 36 . 438.91 452.1 B 0.00 0.00 353.72 eegn From Depth 1a Survey/11180 tool 4470.51 85.00 351.69 3738.40 874.57 401.96 4.70 -9.98 791.48 1D-145 DL 24Jun14 Heel 09.50 14ro.00 1o.ree, e(Plain10.195) 4.,,,,,,,,,A.-- 4490.51 85.00 351.69 3740.14 894.29 344908291.1091868 99.08 0.00 0.00 811.40 1420 26811:000 1400.00 2400.00 104488909lPlan:tO-195) 4732.93 89.33 353.88 3752.13 1134.42 368.68 2.00 2-06090..,.8099000398 6.83 1053.16 14ro.oa 2sn.oe iPl9swpo9lP�arelo1as1 mvm.iPR-accaz-sc 4994.86 89.33 353.88 3755.20 1394.83 340.75 0.00 0.00 1314.47 1610 25n.fi8 40n.68 ata5wpo91Plen:10-115) MWD 2snse 992o.r 1a14swp091P1aa:10-1a5) nnvD.iPR-acaaz-sc 5539.69 90.00 343.00 3758.40 1927.80 231.71 2.00 -86.51 1858.28 10.-145 MW 20Apr14 CP2 4ams w2as1 1alaswp09�Ran:1a145) MWO 5616.92 92.55 342.09 3756.69 2001.44 208.56 3.50 -19.65 1934.82 99]0.51 9982.50 16145wp09,Ran:1a195) enm.iPn-accaz-sc 5910.64 92.55 342.09 3743.64 2280.66 118.32 0.00 0.00 2225.47 1800 6171.23 88.00 350.00 3742.40 2533.29 55.55 3.50 119.82 2485.16 1D-145 MW 20Apr14 CP3 CASING DETAILS 6437.54 81.12 358.18 3767.67 2796.59 28.17 4.00 130.52 2749.21 2130 2450 6454.32 81.12 358.18 3770.26 2813.16 27.65 0.00 0.00 2765.62 TVD MD Name Size 6668.80 89.70 357.99 3787.40 3026.64 20.50 4.00 -1.25 2977.10 11 D-145 MW 20Apr14 CP4 2450 2780 2487.40 2571.68 13-3/8"x 16" 13-3/8 6707.98 90.13 358.64 3787.46 3065.60 19.35 2.00 56.35 3015.86 3738.40 4470.51 9 5/8"x 12-1/4 9-5/8 8127.92 90.13 358.64 3784.13 4485.34 -14.30 0.00 0.00 4419.68 3796.40 9482.50 4 1/2"x 6-3/4" 4-1/2 8203.71 89.46 0.00 3784.40 4561.12 -15.20 2.00 116.40 4494.46 1 D-145 MW 20Apr14 CP5 2780 3100 8951.47 89.47 14.96 3791.45 5300.39 81.84 2.00 90.05 5205.65 9482.50 89.47 14.96 3796.40 5813.40 218.88 0.00 0.00 5687.07 12-145 MW 24Apr14 CP6 3100 3430 3430 3750 0/360 3750 4080 4080 --- 4400 225 4400 5040 -30/330 ?+n 30 5040 5670 =��'= 5670 6310 �_�` 6310 6940 6940 7580 --- 7580 8210 _, � 8210 8850 60/300 �\ \ 60 8850 9483 -„4_,-,-,-1:._•,----:",,,,,,,,,,, .......4,..*_::" T . ' N;;' ,.:„.:' - ..,', ' 4,' \ ) V ''''' \ .nR• di \,"4"7,„,,./;/-4.. - gni _ s ei. d41 pt/ ii ' �s ��,:1rt�; �� .-fs h...`7;$.10/ 9/$: it 90 -90/270 <�,,.� n w nd•,1' �1�P 4 s 7 «; e;§, '.4:: Ott , ,�. ��gg � j s`rri ti�;1; ::::, \ l\ %►4 If4+' A1C ;,/,'. ,/ / �����,` '''.r.'::' eAt\ '''''',.'>;,:,:::':' '' ''''''' 120/240 ,: Ile„ j 120 3, '2;40411\,..k ''i-1,-.T-,:,-c-,_:-'-,--.,:::;t,.1 ,,,_,,,,... j-,,,,,,---.1"-, ::,:, 4 ,tr t-%9,, j' �� T LL1\\\\ _ _t 150/210 _ ,-150 -180/180 � ,a,'-,n'.-,n,,-4, -�- 4-1 w + , Pxw a ;D ,w o- PM -;- ,w4a,¢l4n muovo -x- , e,,,cosine,vl -X- $ ,005,10.1089,t¢tmA VD tD1x0.1PIx0.,P120 V2 $ tDN0.to-f40.1,t6,90 Ltw 44- 10ae c $ ,PoI44 -34- $ ,¢txR,D,xA tDtb 42 } 1 tnAb¢,�Iw } 1 u000va3¢ $ 366w1448ty, $ -� , Dnlq t¢ttlxw $ o-tx8 t¢t28,Ptz5 vz $ t $ $ $ , tt,lclIt t¢tt9w�e j(- IP,z6,14.154',o,xssw -� 10I9,,,P,91L, P41LIVO w $ ID�,,¢r,,n rv9 Q- orn 411111(11111111 ;�,�9.'���;1 �,�, ;�;1,.;�;1;GB�;�;fiG��i�d ;9 .;Q� ;C�;L7a t 9 • MD Inc Az, TVD +N/-S +E/-W Dleg TFac• VSecl Target 4U 43U 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 1 D-145wp09 450.00 9.69 0.00 450.00 0.00 0.00 0.00 0.00 0.00 450 -' 640 750.00 4.50 95.00 749.69 -1.03 11.73 1.50 95.00 -3.05 5500.00 To 9482.50 1100.00 .100 104.97 1095.24 10.43 63.97 2.50 15.00 -23.44 640 840 1100.00 2423. 5 104.97 1095.24 -110.49 197.45 2.73 5.00 -123. 1749.21 24.00 138.00 1707.40 -143.58 227.25 0.00 0.00 -180.86 1864.26 22.91 147.75 1812.98 -179.93 254.86 3.50 110.08 -221.45 840 1030 2075.63 22.91 147.75 2007.67 -249.52 298.77 0.00 0.00 -297.61 11:46,March 23 2015 2521.03 9.24 81.17 2437.40 -318.13 381.28 4.70 -155.65 -379.51 1030 1220 2591.95 9.24 81.17 2507.40 -316.39 392.54 0.00 0.00 -379.74 3942.01 63.76 355.35 3584.58 375.95 457.30 4.70 -90.42 290.83 1220 1420 SURVEY PROGRAM 4012.43 63.76 355.35 3615.72 438.91 452.18 0.00 0.00 353.72 9gnn Prom oegn ro SurvrylPbn Tote. 4470.51 85.00 351.69 3738.40 874.57 401.96 4.70 -9.98 791.48 1 D-145 DL 24Jun14 Heel 09so 1aoo.00 10-laswpo9(Ran:10-14s) Gvoccss 4490.51 85.00 351.69 3740.14 894.29 399.08 0.00 0.00 811.40 1420 1610 1400.00 2400.00 16r ,,,p09(Ram 10.145) MWD 4732.93 89.33 353.88 3752.13 1134.42 368.68 2.00 26.83 1053.16 1400.00 2571.68 16145v409(Ram 16145) MWO.im-A-CA6SC 4994.86 89.33 353.88 3755.20 1394.83 340.75 0.00 0.00 13)4.47 2571.68 4071.88 6145wp09(Ran:10-145) MWD 1610 1800 2571.68 .70.51 10.145wp00(Ran:10.1.) mW0.IFR-AEGAz-e9 5539.69 90.00 343.00 3758.40 1927.80 231.71 2.00 -86.51 1858.28 10-145 MW 20Apr14 CP2 4400.51 5970.51 1614.909(Ran(10.14.5) MWD 5616.92 92.55 342.09 3756.69 2001.44 208.56 3.50 -19.65 1934.82 4470s1 9482s0 10.145wp09(Ren(16145) MW13,1m-a•aaz-sc 5910.64 92.55 342.09 3743.64 2280.66 118.32 0.00 0.00 2225.47 1800 2130 6171.23 88.00 350.00 3742.40 2533.29 55.55 3.50 119.82 2485.16 1D-145 MW 20Apr14 CP3 CASING DETAILS 6437.54 81.12 358.18 3767.67 2796.59 28.17 4.00 130.52 2749.21 2130 2450 6454.32 81.12 358.18 3770.26 2813.16 27.65 0.00 0.00 2765.62 TVD MD Name Size 6668.80 89.70 357.99 3787.40 3026.64 20.50 4.00 -1.25 2977.10 13-145 MW 20Apr14 CP4 2450 2780 2487.40 2571.68 13-3/8"x 16" 13-3/8 6707.98 90.13 358.64 3787.46 3065.80 19.35 2.00 56.35 3015.86 3738.40 4470.51 9 5/8"x 12-1/4 9-5/8 8127.92 90.13 358.64 3784.13 4485.34 -14.30 0.00 0.00 4419.68 3796.40 9482.50 4 1/2"x 6-3/4" 4-1/2 8203.71 89.46 0.00 3784.40 4561.12 -15.20 2.00 116.40 4494.46 10-145 MW 20Apr14 CP5 278U 3100 8951.47 89.47 14.96 3791.45 5300.39 81.84 2.00 90.05 5205.65 9482.50 89.47 14.96 3796.40 5813.40 218.88 0.00 0.00 5687.07 10-145 MW 24Apr14 CP6 3100 3430 3430 3750 0/360 3750 4080 4080 ---- 4400 225 4400 5040 -30/330 210 30 5040 5670 195 5670 6310 -- 180 6310 6940 /r 165 6940 ^ 7580 // ' 150 ' 7580 8210 �' - 8210 8850 -60/300 �� , 12 1 60 8850 9483 10 • 1 �',,, � is (%,:§ I,i4. �l,) ESN ieff.gfi.''t!'%4141"4"4:41,!": ----.-=';'/,'' i 54 � 90/270 ' , ..T ii 90 ---7-7-,-.77---;,,„.1W--11-111Filiga / 1 \ ,,-.:..'','''''2-- ,I0'737 MI./ �N74. 111 (( I i 1444::1At\ .. �r7 ,x,61 �l��� = � � �, sf.�s X41. �: I i iIkl,y,igiii,. _= 1 riI /I' - 120/2ao iillilii(0. / 1pllt1/ - , - ' ,', 120 1,i,4,A 11,,1 7f. 1'I I AAY III'1 I/ .._,,,,,,e,._. <f i,-4.0...:10,,,..4 ••" . l 1 -4 �// IIID t'1i �1!!��' 64,1� Atop" ��� I v � ,, ' 'N. 1--- -'44:;,;:...,... .,-0,/,- zde, . r'Y' , N, ellPit-4,:`:"%'r!_----.; \to \,,,,_. Niti 150/210 150 -180/180 .ry-,ry-1400., .. oor r,o9)Ve $ , 44 -- , $ D3o.la34.,ob s -4-$ ,w0z,weose1,100,oper 59 -e- 2.1.12,10.2'vs V2 44- re-rOa1.14510-135. -A- -A- roma 1.ovez,1012p92 Cr -B- 2.,0,at 1O1ar VO } 1.13,1.13410roan, $ $ -- mmz ml�e9,,o12pe v, $ 1w $ 1.1x4,wase,.roam wpa vl -9• las.laaa,,usa,v, -A- v9 i- 1.105,1.1.1.1. 0 -94- o,az 1.102 V, -94- 1.1.0.,,wosy, $ las.lasupol,,oaarpe,V1 $ -} 1.105,t0,05>10-105A3( ,,ose V35 - - 10-120,1.120,10-120v, -A- ,D,aq,0,4ar.1.140u V0 $ 10.34,1.34.10-34 VG -6- -A- re,o5,.,45 nolo vs $ $ re-roy larawor,,.rope,V. -9 10-3.1,10-340 V3 t -9(- 10 $ 1.221.122.1.122 V2 •,e, 1. -3(- ,o x,Pe,v4 $ $ 10 -e- 1.123,101230.123 V2 i(- 10 141,10.191A,1.141A i(- ,os $ .34- , -e- .124,1.12,1.124 V2 -- , -tr ro35,,ax,lasrvvoss nv, $ 4 es,some 1es11s vs -9- .2snw2 to-row $ 1 $ roas,reCar,,6awu va $$ $ , ,v $ 0.25.1.254.1.,2sA vo 9- 3- , x2 00x2 $ 1v1 -A- , $ -3(- , -A- 1637.10-37.1.37 v4 -Y 1Q;11. - 3Z 1Q;,1.;9;,?l1; $ ;B i �;fir,�' 2a,,.�2�2n X ;0;:,21155, �1lak 1 1I1i.I�1kd.IIINN I • 0 Northing (3000 usft/in)12 Jill , 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 I 1 1 1 1 in N 74 - =o CD E G) I' 0 6 a N 6 i. rz- J 0 co P • rl .! - CL ., _ o n ilia N'. p 'co �pp J'I' d . Y T m ^ 3• C— CL N a m CO C CA 7 - 1- NQ a m 7 , J I' N v1 C - Q �\ ( a �/*1 ri L� 401 c0 T C CO s‘s LLJ W d�. 11011.: mCO QOrr ,g AM,- M Cl- r _ J Tr-�y 0 a 0 ... i / • Cs1rT in LO 1 Al 7- (// fr- F-r'm 2 all Y O i O O ii - = 0 ,_ r p� 1, m - 0 Alio 7/1/ \, \ c`l0 co r N _ M p CO ■J A.xi" Q�� Qv P- 0 0 a \ 70 T N r r ,i —.10 - Z s1 1 ;O'.1' - ' (1) — 1 in U •?. (52 _ ` 1 I 1 1 I 1 I 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1I 1111 I 1111 I 1111 I 1111 I 11 I I I I I I I I 1 I 1 I 1 I I I r (u!/llsn OOOE) Bu141aoN <o • Tollerable Collision Risk Worksheet • S ConocoPhillips Conocflisio ips Alaska, Inc Drilling Anti-Collision Management Alaska Tolerable Collision Generic name of scenario: Collision of the B lateral of 1D-145 with the A4 and D laterals of 1D-143. Risk Worksheet Description: (Be specific.Include all factors which affect either the cost of collision or the cost of reducing the risk) based on Rev.1-29 Jul 99 Well 1D-145 fails anti-collision with the planned A4 and D laterals of 1D-143 based on WP09. The B lateral will be geosteered using periscope so risk of leaving the zone is minimal. And if we Use this sheet to describe a well interference scenario where ORA do not leave the B zone we can't hit the A4 or D laterals of 1D-143. There is no immediate danger maybe applicable.Check first that the scenario really is different to life or impact on the environment if well 1D-145 intersects 1D-143 as 1D-143 has the same from those described on existing worksheets. pressures as 1D-145 so we will have kill weight mud in the hole. If 10-145 intersects 1D-143 there will be damage to the expensive 10-143 well we just drilled and 10-145 would have to be plugged Prepared by: Kelsey Halliard ^•+:' ✓ back and sidetracked. No risk of a well control issue exists because well 10-145 will have kill ., Weight mud in the hole. Authorized by: Daniel BeardensTo Do the consequences Are the "° of collision include a ()Yes One consequences risk to personnel or the environment? of collision 1 Major risk 7 ' `.��• List all the consequences of collision and the necessary Oyu remedial action: Cost of Collision: No HSE risks exist with 10-145 intersecting 10-143 while drilling as 1D-145 will have kill weight mud in the hole. An economic concern exists and it would $8,000,000 be the cost of losing one or two of the 10-143 laterals and tire cost of plugging back and sidetracking 1D-145 The only way we will intersect 10-143 is if we drill out of zone while drilling the B lateral. Tire chance of this is very low as we will be geosteering the well with periscope and if we are approaching exiting the sand we will turn in a manner to stay in the B sand. How could theprobabilityof collision or the severityEstimate the total cost of collision C= $8,000,000 of the consequences be reduced?How might this impact the drilling operation? Cost: Is there a practical way Oyes to substantially reduce "o Estimate the NPV of + O either the probability of the planned well collision or the severity V= $7,000,000 of the consequences? Accepting a finite risk of collision will reduce the NPV of the planned well.What reduction,as a fraction of the total NPV,are you prepared to tolerate?(Guideline=0.05) + F= 0.01 Estimate the total cost of substantially reducing V= $0 • the risk V F/C= 0.00875 Given the uncertainty in the above estimates,by how II V F then close approach tolerances need not be set many times must the savings made from not reducing the risk outweigh he risk itself?(Guideline=20) f v F g C < then Tolerable Collision Risk=1 In C I V F M= 20 F= 1 /M= 0.05 Tolerable Collision Risk= 1 in 114 • • P ConocoPh i 11 i ps Coi-C oPhillips Alaska, Inc Drilling Anti-Collision Management Alaska A Tolerable Collision Generic name of scenario: Collision of 1D-145 with the existing dual lateral 10-140(Laterals in the B and D sands) Risk Worksheet Description: (Be specific.Include all factors which affect either the cost of collision or the cost of reducing the risk) based on Rev.1-29 Jul99 Well 1D-145 fails anti collision with 1D-140 and 1D-140L1 based on WI 10-145 will have a lateral in the B sand. While drilling the B lateral,magnetic interference wi be closely monitored,if Use this sheet to describe a well interference scenario where QRA interference is picked up we will assume we are approaching 10-140 and we will drill away from may be applicable.Check first that the scenario really is different the well. There is no immediate danger to life or impact on the environment if well 10-145 from those described on existing worksheets, intersects 1D-140. If 1D-145 intersects 1D-140 there would be damage to the liner of 1D-140 but I({f this well is currently suspended waiting abandonment so the only cost impact would be to plug Prepared by: Kelsey Hallford 1 '�' ..!4,,( back the lateral we are currently drilling. No risk of a well control issue exists because well 1D-140 • is shut in awaiting abandonment. Authorized by: Daniel Bearden ---Y .' - Do the consequencesr, /41,..:,,.. i,.,. Are the O �I F •Ne of collision include a Ores ONe , il risk to personnel or the consequences environment? of collision Major risk List all the consequences of Ones collision and the necessary remedial action: Cost of Collision: No HSE risks exist with 1D-145 intersecting 10-140 while drilling as 10-140 is shut in awaiting abandonment. An economic concern exists and it would be $750,000 the cost of plugging back and sidetracking the lateral that we are drilling. 4 How could the probability of collision or the severity Estimate the total cost of C_ $750,000 of the consequences be reduced?How might this collision impact the drilling operation? Cost: Is there a practical way Ones to substantially reduce O No Estimate the NPV of O either the probability of the planned well collision or the severity V= $7,000,000 of the consequences? Accepting a finite risk of collision will reduce the NPV of the planned well.What reduction,as a fraction of the total NPV,are you prepared to tolerate?(Guideline=0.05) F= 0.01 Estimate the total cost of substantially reducing V= $0 the risk V F/C= 0.093333333 1 Given the uncertainty in the above estimates,by how VF hen close approach tolerances need not be set many times must the savings made from not reducing V If VF the risk outweigh he risk itself?(Guideline=20) C I then Tolerable Collision Risk=I in C/V F M= 20 F=1/M= 0.05 ' Tolerable Collision Risk= 1 in 11 As - built • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 5 11/27/14 KRP JFC PER K140162ACS 6 2/20/15 JFC MBS PER K150013ACS N 33i 34 35 36 31 32 GRAPHIC SCALE ' , T12N 100 4i0 i, a .- : d � '/2KIC T11N o W ---I 'It 5 _ 4KUPARUKP 3 2 1 6 WS 24A 4:4 I imd 1 inch = 200 ft. AIRSTRIP •• ^ i— 'S=IB. •i'?PT1 _ �+.� 0 NPELp1E .,ATI SPINE :1131 �4 11 . 1 z 7 ROAD ,•, INE P°9a PROJECT SITE e r '` LOCATION 18 17 DS1 D r--- -\ I ., Cip- DS1E\, DS1D DS1 21 .22 23 24 19 20 l • 1 VICINITY MAP 12 • 14 SCALE: N.T.S. 101 • • 102 105• 140 +\\\\\', • i 2 ee®'`� ��,i'. toe: 107 -e'P•...............` . .�j®, • 109 Ar Gj.*. '. h•...1.57 vA 141: 311 14 13 — i ` 49th i\ `• ♦#I 112e 23 24 i• 113 �• �� 0 114• 115 0 118if117 III ♦ •?JEREMIAH F. CORNELL A ♦ LS-12663 r 9 i 119 �F � ..g/-Z.,//,,5'' .... c2 120• e♦ 'Sn��."✓Z�`�,� 5 ~ • 121 .4 O�••••Y ' ....•• \O • e4 1zz• 123 145® ,,,FES\\�eoe 142® 13 • . 124 125• 143® •127. 126 1460 • 128 SURVEYOR'S CERTIFICATE / ,7 • . 6 •28 • 129 •30 / HEREBY CERTIFY THAT I AM PROPERLY REGISTERED 131• 130 •32 AND LICENSED TO PRACTICE LAND SURVEYING IN • 132 133• •34 THE STATE OF ALASKA AND THAT THIS PLAT • 18 •36 REPRESENTS A SURVEY DONE BY ME OR UNDER MY 7 • 19 37.38 DIRECT SUPERVISION AND THAT ALL DIMENSIONS 134. 135 39•4o AND OTHER DETAILS ARE CORRECT AS OF 20 • •10 41 •42 FEBRUARY 20, 2015. 21 • 11 • a• 136 137• • 138 139• 7;; X01- LEGEND: Q��� 0 AS-BUILT CONDUCTOR LOCATION -\-- --N 5 • EXISTING CONDUCTOR LOCATION 0. LOUNSBURY o SEE PAGES 2 & 3 FOR LOCATIONS �, & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA:1D MODULE: XXXX UNIT: 01 Conoco hiIIisDS1D WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6104D33 12/18/00 CEA—D1 DX-6104D33 1 OF 3 6 0 S REV DATE BY CI< APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 5 11/27/14 KRP JFC PER K140162ACS 6 2/20/15 JFC MBS PER K150013ACS NOTES: 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. 6. GEOGRAPHIC COORDINATES ARE NAD 2Z 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN 7. DATE OF RE—DRAFT: 11/30/00 SEA LEVEL. THIS PLAT IS A RE—DRAFT & CONSOLIDATION OF EXISTING DRILL SITE CONSTRUCTION DRAWINGS 3. ALL DISTANCES SHOWN ARE TRUE. NSK-3.5-1, CEA—D1DX-6104D10, CEA—D1DX-6104D13, CEA—D1DX-6104D15, 4. BASIS OF LOCATIONS AND ELEVATIONS ARE DS1D CEA—D1DX-6104D16, CEA—D1DX-6104D18, MONUMENTS PER LOUNSBURY & ASSOCIATES. CEA—D1DX-6104D20, CEA—D1DX-6104D23, CEA—D1DX-6104D26, AND CEA—D1DX-6104D28. 5. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 14 & 23, TOWNSHIP 11 NORTH, RANGE 10 EAST, U.M. ALASKA. CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 14, T11N, R1OE Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset 'y' 'X' LAT. LONG. F.S.L.F.E.L. PAD O.G. 1 5,959,904 560,490 70' 18' 03.67" 149' 30' 36.26" 240' 595 70.8' 61.1' 2 5,959,785 560,490 70' 18' 02.50" 149' 30' 36.29" 120' 596' 70.8' 62.1' 3 5,959,665 560,490 70' 18' 01.32" 149' 30' 36.32" 0' 597' 70.7' 62.0' 12 5,959,888.87 560,490.53 70' 18' 03.521" 149' 30' 36.243" 224' 594' 70.8' 61.1' 14 5,959,873.87 560,490.50 70' 18' 03.373" 149' 30' 36.248" 209' 595' 70.8' 61.2' 101 5,959,859.23 560,490.42 70' 18' 03.229" 149' 30' 36.254" 194' 595' 70.7' 61.4' 102 5,959,844.00 560,490.59 70' 18' 03.079" 149' 30' 36.252" 179' 595' 70.7' 61.5' 103 5,959,829.35 560,490.30 70' 18' 02.935" 149' 30' 36.264" 164' 595' 70.1' 61.7' 105 5,959,798.99 560,490.57 70' 18' 02.637" 149' 30' 36.263" 134' 595' 70.5' 62.0' 106 5,959,768.93 560,490.67 70' 18' 02.341" 149' 30' 36.268" 104' 595' 70.4' 62.3' 107 5,959,753.86 560,490.70 70' 18' 02.193" 149' 30' 36.270" 89' 595' 70.7' 62.3' 108 5,959,738.82 560,490.57 70' 18' 02.045" 149' 30' 36.277" 74' 596' 70.6' 62.4' 109 5,959,723.89 560,490.60 70' 18' 01.898" 149' 30' 36.280" 59' 596' 70.4' 62.7' 110 5,959,708.86 560,490.58 70' 18' 01.750" 149' 30' 36.284" 44' 596' 70.6' 64.5' 111 5,959,693.95 560,490.60 70' 18' 01.604" 149' 30' 36.287" 29' 596' 70.6' 64.5' 140 5,959,813.97 560,490.55 70' 18' 02.784" 149' 30' 36.260" 149' 595' 70.7' 62.0' 141 5,959,678.83 560,490.62 70' 18' 01.455" 149' 30' 36.290" 14' 596' 70.7' 63.2' CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 23, T11N, R1OE Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset 'y" 'X' LAT LONG. F.N.L.F.E.L. PAD 0.G. 4 5,959,545 560,490 70' 18' 00.14" 149' 30' 36.34" 120' 598' 70.6' 64.0' 5 5,959,424 560,490 70' 17' 58.95" 149' 30' 36.38" 240' 599' 70.6' 64.2' 6 5,959,305 560,490 70' 17' 57.78" 149' 30' 36.40" 360' _ 600' 70.8' 68.1' 7 5,959,184 560,490 70' 17' 56.59" 149' 30' 36.44" 480' 601' 70.8' 68.1' 8 5,959,064 560,490 70' 17' 55.41" 149' 30' 36.46" 600' 602' 70.7' 69.8 9 5,959,528.99 560,490.59 70' 17' 59.981" 149' 30' 36.326" 136' 598' 70.6' 66.0' 10 5,959,108.97 560,490.70 70' 17' 55.850" 149' .30' 36.422" 556' 601' 70.6' 69.4' 11 5,959,078.99 560,490.78 70' 17' 55.555" 149' 30' 36.426" 586' 601' 70.8' 69.6' 13 5,959,408.94 560,490.71 70' 17' 58.800" 149' 30' 36.351" 256' 599' 70.8' 65.0' 17 5,959,318.79 560,490.94 70' 17' 5Z914" 149' 30' 36.365" 346' 599' 70.7' 6Z6' 18 5,959,198.96 560,491.16 70' 17' 56.735" 149' 30' 36.387" 466' 600' 70.7' 69.0' LOUNSBURY ..,* & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS lb )1111V AREA:1D MODULE: XXXX UNIT: D1 ConocoPhillipsDS'D WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CAREV: LK6104D33 12/18/00 DRAWING NO. CEA-D1 DX-6 1 O4D33 PART: 2 OF 3 6 0 • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 5 11/27/14 KRP JFC PER K140162ACS 6 2/20/15 JFC MBS PER K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 23, MN, R1OE Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset 'Y' 'X' LAT. LONG. F.N.L.F.E.L. PAD 0.G. 19 5.959.168.83 560491.07 70' 17' 56.439" 149' 30' 36.397" 496' 600' 70.7' 69.1' 20 5.959.123.83 560.490.97 70' 17' 55.996" 149' 30' 36.410" 541' 601' 70.7' 69.4' 21 5.959.094.25 560,490.86 70' 17' 55.705" 149' 30' 36.420" 571' 601' 70.7' 69.6' 28 5,959,309.20 560,670.72 70' 17' 5Z805" 149' 30' 31.126" 357' 419' 70.9' 67.2' 30 5,959,279.00 560,670.91 70' 17' 5Z508" 149' 30' 31.128" 387' 419' 70.9' 68.7' 32 5,959,249.09 560,670.66 70' 17' 57.214" 149' 30' 31.142" 417' 420' 70.9' 68.9' 34 5,959,218.83 560,670.62 70' 17' 56.916" 149' 30' 31.150" 447' 420' 70.9' 69.6' 36 5,959,188.94 560,670.73 70' 17' 56.622" 149' 30' 31.154" 477' 420' 70.9' 69.0' 37 5,959,174.03 560,670.65 70' 17' 56.476" 149' 30' 31.160" 492' 421' 70.9' 68.0' 38 5,959,159.04 560,670.82 70' 17' 56.328" 149' 30' 31.159" 507' 421' 70.9' 67.0' 39 5,959,144.12 560,670.96 70' 17' 56.181" 149' 30' 31.158" 522' 421' 70.9' 65.9' 40 5,959,128.85 560,670.87 70' 17' 56.031" 149' 30' 31.164" 537' 421' 70.9' 64.7' 41 5,959,114.19 560,671.14 70' 17' 55.887" 149' 30' 31.160" 552' 421' 69.5' 64.7' 42 5,959,099.20 560,670.81 70' 17' 55.740" 149' 30' 31.173" 567' 421' 70.9' 64.6' 112 5,959,648.88 560,490.65 70' 18' 01.160" 149' 30' 36.296" 16' 596' 70.6' 63.1' 113 5,959,633.93 560,490.56 70' 18' 01.013" 149' 30' 36.302" 31' 597' 70.6' 632' 114 5,959,619.07 560,490.62 70' 18' 00.867" 149' 30' 36.304" 46' 597' 70.6' 63.2' 115 5,959,603.93 560,490.68 70' 18' 00.718" 149' 30' 36.306" 61' 597' 70.4' 63.4' 116 5,959,588.90 560,490.63 70' 18' 00.570" 149' 30' 36.311" 76' 597' 70.6' 63.3' 117 5,959,573.95 560,490.65 70' 18' 00.423" 149' 30' 36.314" 91' 597' 70.4' 63.4' 118 5,959,558.95 560,490.68 70' 18' 00.276" 149' 30' 36.316" 106' 597' 70.4' 63.4' 119 5,959,513.86 560,490.72 70' 17' 59.832" 149' 30' 36.326" 151' 598' 70.6' 66.0' 120 5,959,499.01 560,490.77 70' 17' 59.686" 149' 30' 36.327" 166' 598' 70.6' 66.0' 121 5,959,483.89 560,490.67 70' 17' 59.538" 149' 30' 36.335" 181' 598' 70.5' 66.0 122 5,959,469.06 560,490.71 70' 17' 59.392" 149' 30' 36.337" 196' 598' 70.6' 64.1' 123 5,959,453.81 560,490.69 70' 17' 59.242" 149' 30' 36.341" 211' 598' 70.6' 64.2' 124 5,959,393.96 560,490.70 70' 17' 58.653" 149' 30' 36.355" 271' 599' 70.3' 65.0' 125 5,959,379.35 560,490.59 70' 17' 58.509" 149' 30' 36.361" 286' 599' 70.3' 64.3' 126 5,959,363.92 560,490.68 70' 17' 58.358" 149' 30' 36.362" 301' 599' 70.3' 64.3' 127 5,959,348.96 560,490.67 70' 17' 58.210" 149' 30' 36.366" 316' 599' 70.3' 64.3' 128 5,959,334.14 560,490.58 70' 17' 58.065" 149' 30' 36.372" 331' 599' 70.3' 64.5' 129 5,959,273.92 560,490.79 70' 17' 57.472" 149' 30' 36.380" 391' 600' 70.3' 68.2' 130 5,959,259.09 560,490.81 70' 17' 57.326" 149' 30' 36.383" 406' 600' 70.5' 68.2' 131 5,959,244.05 560,490.74 70' 17' 57.179" 149' 30' 36.389" 421' 600' 70.5' 69.9' 132 5,959,229.23 560,490.64 70' 17' 57.033" 149' 30' 36.395" 436' 600' 70.4' 69.8' 133 5,959,213.89 560,49a 68 70' 17' 56.882" 149' 30' 36.397" 451' 600' 70.4' 69.0' 134 5,959,153.84 560,490.83 70' 17' 56.291" 149' 30' 36.407" 511' 601' 70.5' 69.1' 135 5,959,139.02 560,490.80 70' 17' 56.146" 149' 30' 36.412" 526' 601' 70.5' 69.4' 136 5,959,048.98 560,490.91 70' 17' 55.260" 149' 30' 36.429" 616' 602' 70.7' 69.8' 137 5,959,034.40 560,490.80 70' 17' 55.117" 149' 30' 36.436" 631' 602' 70.7' 69.8' 138 5,959,018.76 560,490.73 70' 17' 54.963" 149' 30' 36.442" 646' 602' 70.7' 69.9' 139 5,959,003.94 560,490.58 70' 17' 54.817" 149' 30' 36.450" 661' 602' 70.7' 69.9' UD 5,959,289.02 560,490.94 70' 17' 57.621" 149' 30' 36.372" 376' 599' 70.7' 68.1' ** 142 5,959,414.03 560,670.75 70' 17' 58.836" 149' 30' 31.101" 252' 418' 66.8' 65.5' ** 143 5,959,384.08 560,670.58 70' 17' 58.542" 149' 30' 31.113" 282' 419' 66.9' 65.5' ** 145 5,959,444.08 560,670.82 70' 17' 59.132" 149' 30' 31.092" 222' 418' 66.9' 64.7' ** 146 5,959,353.83 560,670.88 70' 17' 58.244" 149' 30' 31.111" 312' 419' 67.1' 65.2' LOUNSBURY ** INDICATES CONDUCTOR ASBUILT THIS SURVEY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS ii `/ AREA:1D MODULE: XXXX UNIT: D1 ConocoPhillips DS1D WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. REV: LK6104D33 12/18/00 DRAWING NO. CEA-D1 DX-6104D33 PART: 3 OF 3 6 • 1D-1 5 Drilling Hazards Summary 16" Open Hole / 13-3/8" Casing 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" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM Intermediate Cement Top Moderate Risk of cement reaching surface casing shoe,put retarder in for first 60 bbls to extend set up time 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 Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning aided by circulation sub, 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 Anti-collision with 1D- Moderate Follow real time surveys very closely, use geological certainty 140 and 1D-143 to avoid 1D-143 and 1D-140 Fault Crossings and Moderate Use developed best practices for concretion drilling. Concretions Getting Liner to Bottom Moderate Maintain solids free oil based mud properties and lubricity while running liner lower completion, monitor torque and drag. Attachment 2-1D-145 Drilling Hazards Summary.doc 4/2/20158:54:27 AM • • 1D-145 Schlumberger CemCADE Preliminary Job Design 13 3/8" Surface Casino (V2) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 125 Volumes are based on 250%excess in the permafrost and 50% excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2,072' MD. Client: CPAI Revision Date: March 31,2015 Prepared by: Jenna Houston Location:Anchorage,AK Lead Slurry Minimum pump time: -260 min. (pump time plus 120 min.) Phone: (907)263-4207 DeepCRETE @ 11.00 ppg- 1.91 ft3/100 lb sk Mobile: (907)223-8916 email:jhouston2@slb.com 1.019 ft3/ft x 80 x 1.0 (0% excess) = 82 ft3 0.4206 ft3/ft x(1695-80)x 3.50 (250% excess) = 2378 ft3 < TOC at Surface 0.4206 ft3/ft x(2072-1695) x 1.50 (50%excess) = 238 ft3 2378 ft3+238 ft3+82 ft3= 2698 ft3 2698 ft3/ 1.91 ft3/sk= 1413 sks(--1423 sks) Have additional 11#on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: -200 min. (pump time plus 120 min.) 12.0 ppg DeepCRETE- 1.63 ft3/100Ib sk 0.4206 ft3/ft x(2572-2072) x 1.50 (50% excess) = 316 ft3 0.8407 ft3/ft x 80' (Shoe Joint) = 68 ft3 316 ft3+68 ft3 = 384 ft3 384 ft3/1.63 ft3/sk= 236 sks Round up to 245 sks BHST =72°F, Estimated BHCT=77°F. (Based on 2.1°F/100 ft. from surface) PUMP SCHEDULE < Base of Permafrost at Stage Cumulative 1,695'MD(1,658'TVD) Stage Pump Rate Volume Stage Time Time (bpm) (bbl) (min) (min) CW 100 7.0 75.0 10.7 10.7 MUDPUSH II 7.0 75.0 10.7 21.4 Pause 0.0 0.0 5.0 26.4 < Top of Tail at 11 ppg DeepCRETE 7.0 480.3 68.6 95.0 Lead 2,072'MD Surface Tail 7.0 68.2 9.7 DeepCRETE Slurry104.7 Pause 0.0 0.0 5.0 109.7 Fresh Water 5.0 10.0 2.0 111.7 Pause 0.0 0.0 5.0 116.7 Mud 8.0 353.1 44.1 160.8 Mud 3.0 10.0 3.3 164.1 < 13 3/8",68#casing MUD REMOVAL er7 in 16"OH Expected Mud Properties:9.4 ppg, Pv<20, Ty<20 TD at 2,572 MD Spacer Properties: 10.5 ppg MudPUSH* II, Pv nu 17-21, Ty 20-25 (2,488'TVD) Centralizers: As per CPAi program. Mark of Schlumberger • • 1D-145 Schlumberger CemCADE Preliminary Job Design 9 5/8" Intermediate (V2) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 25 Volume Calculations and Cement Systems Location: Kuparuk Client: CPAi Revision Date: March 31,2015 Volumes are based on 40%excess. Prepared by:Jenna Houston Location:Anchorage,AK Tail Slurry Minimum thickening time non-retarded slurry: -215 min. (pump time plus 120 Phone: (907)263-4207 min.). Minimum thickening time for retarded slurry is 720 min by COP request. Mobile: (907)223-8916 15.8 ppg Class G +adds- 1.16 ft3/sk email:jhouston2@slb.com 0.3132 ft3/ft x(4471'-2900')x 1.4 (40%excess)= 689 ft3 • Shoe Volume: 0.4258 ft3/ft x 80'x 1.00 (no excess) = 35 ft3 Totals: 689 ft3+ 35 ft3= 724 ft3 724 ft3/1.16 ft3/sk= 625 sks (635 sks) BHST =99 °F, Estimated BHCT= 80 °F. (BHST calculated using a gradient of 2.1 °F/100 ft.from surface) PUMP SCHEDULE Stage Cumulative Pump Rate Stage Time 13 3/8",45.5#casing Stage (bpm) Volume (min) Time (bbl) (min) at 2572'MD MUDPUSH II 5.0 50.0 10.0 10.0 Pause0.00.0 5.0 15.0 Tail Slurry+retarder 5.0 60.0 12.0 27.0 Tail Slurry 5.0 68.8 13.8 40.8 Pause0.0 0.0 5.0 45.8 Fresh Water 5.0 10.0 2.0 47.8 Top of Tail at end of pumping Pause 0.0 0.0 5.0 52.8 < 2900'MD Mud 6.0 313.0 52.2 105.0 Mud 3.0 10.0 3.3 108.3 MUD REMOVAL 9 5/8",40# in 12 1/4"hole Recommended Mud Properties:9.6 ppg, Pv<20, Ty<20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv 25-30, Ty 30-40 Centralizers: As per CPAi program TD at 4471 'MD (3739'TVD) Mark of Schlumberger • • •/If 11, E / / k[ (\ H ( ] /N ( § III 4 ƒ / 2 ())/k \ �» ). ) ,,i: / \•C) E e = `� [®// #) cu ! g• a « a2 \/ ) \ 2 !\\ ) \i- Tc 4 / \ ) � {/ ' ' ) E J : - \ / A TE / ;{ \ % 1) o o 2 \) \ _ ! " !! 7 ( , . . ! - ® 5E / ® _ ( 4 } � � $1?' § / CO\ )k .1::.4 op ® |{7+ L e ;y\ *§ \ \ /� _6. { ;§ ( \� \\ 4\ \ x \\- \j j\r/ \\ \e\ c..)v:.,. a . 0\;� �g) ConocoPhilips Draft kw_U!m!45(Producer) __4- 5 Well Schematic24/03/2015 Alaska • • Loepp. Victoria T (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Thursday,April 09,2015 2:21 PM To: Loepp,Victoria T(DOA) Cc: Lee, David L; Bearden,J Daniel;Alvord,Chip; Herbert, Frederick 0 Subject: 1D-143 (214-145)Contingency due to Haul Road Closure Hello Victoria, To re-cap what we discussed on the phone: 1D-143 has drilled,cased,and cemented the intermediate string section;currently testing BOP's. However,the fluid needed to drill the production section is grounded in Fairbanks due to the Dalton Hwy road closure. Upon approval of the revised PTDs for KRU 1D-145 and KRU 1D-146,we would like the option to suspend operations on 1D-143 and drill the surface hole sections for one or both of the next two wells planed on the 10 pad. We are continuing to work the challenges resulting from the over flow on the haul road and would like to have this as a backup plan. Please call or email with any questions,thank you. Kelsey Hallford Drilling Engineer I ConocoPhillips Office: +1-907-265-1577 Cell: +1-907-440-0004 Email: kelsey.hallford(a�cop.com 1 I TRANSMITTAL LETTER CHECKLIST WELL NAME: /<R UL, I 6 - I'1S PTD: c2,1 /Development _Service Exploratory Stratigraphic Test Non-Conventional FIELD: /KJ ' i / POOL: /�� AK +V F�J( (g�+ SAK ' Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, V composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • 0 III E] N O O a) a , O a), Jr) = � � C NC � � as, Q , V Q (A' �� ay , , O V c Tr co O O z. �, O, M o) W (q �� L Na o O, 0co O O' E w m' ami a) O) °j' 0 O yo. L' CO. O) x o, Tc. c, z. 0 ; a a) o: 0 3 3 co U) a c 4 of N aw — m, 3; — .52„ Tr, O, �, co ' '3. ' > d' ' �' ' t� . -o F- � 't C) y �� p O� 2� d O> D , (0, , Q. CSA, m .-, � y. 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O '0 U c E; f0 O. m cf a)' ' a 5' y O' �' Ul, o) O- 7 7 f0; N; @ 0 O N', ca T • p' '- _ c' — '0� N O, m -O I N. O, O, f0• 3, O, C0 G f0 o) 7 0' Y U) -' O' N' y' LL O m L C. 'O, V V O N C @, L, a V, a) c O •N -F0) V >, 'N1 00, L 3 N _o O. U/ c O. N 2. U C. a) c c E' C.) - N N. �� — co .0; O• L c o •3 o N p' �' f0' — N' a) = N 7 "O f0 _ c; u' f0 0 co u c, a) o. 3 0 N. C w Vi c f0. .o. >, V' .. O N' O. E a) 'c 0 N C?, tn.. Z e- c U' o U O, 0 ° ° U a) U N ° C, 0 N. >. O' - oI C0 '. f0. •) CO V) 3. (0 m' a C, co .... O • ' a); c ° ° °, '0 '>, m, m a o' a), a c, - co > > 3'. c. o, E o. > c 0- w Y; Y m 'E y N' a ca, ai o_ _1D5; 55; c'n' �' oOa, ao' 05', Q; az°' 0, in' v' v; o' c Q; �, Q; a; o; m; oav a2 ao; (aco0,, '' ns p LLI. d 0 .- N M cr If) CO I"- CO 0) 0 N M 7 U[) CO n COO) O N M V CO CO I- CO 0) r � N 0) CO CO h 00 0) e- e- c' . . . . . . . N N N N N N N N N N M 0) CO M CO C) M 0) M CO U )O I.... O Lf) a) d p O r O O_ c0 )O C f6 CV a CCN N ._ m 00 O p \ O) 0 00 0 n O y I- W `- R vE . - °'E p a) Ct. r) a) >, 0 E .J (V 'c m C G J ° Q co U 0 O_ Y OFTic • �� � THE STATE Alaska OE a d Gas }fix 333 Wet Seventh Avenue GOVERNOR SEAN PARNELL Anchorage, Alaska 99501-3572 zru.uf'*' Main: 907 279 1433 ALAS AS Fax: 907.276.7542 G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-145 ConocoPhillips Alaska, Inc. Permit No: 214-138 Surface Location: 220.02' FNL, 416.3' FEL, SEC. 23, Ti 1N, R10E, UM Bottomhole Location: 4968.79' FNL, 194.46' FEL, SEC. 11, T11N, R10E, 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. oerster Chair DATED this GB day of October, 2014. 0 0 I STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ;�/. ,, //J II 20 AAC 25.005 _ t.5L ` 414//(( ?&-; la.Type of Work: lb.Proposed Well Class: Development-Oil Q Service- Winj ❑ Single Zone ❑✓ , lc.Specify if wII is proposed for: . Drill •0 Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket j. Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59_52_180. 1D-145 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 9473.. TVD: 3789' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 220.02'FNL 416.3'FEL,Sec.23 Twn 11N Rng 10 E,UM ADL 25650,25649 West Sak Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4589.5'FNL 21.09'FEL,Sec. 14 Twn 11N Rng 10E,UM ALK 468,467 01/03/2015 Total Depth: 9.Acres in Property: 910 14.Distance to Nearest Property: 4968.79'FNL 194.46"FEL,Sec.11 Twn 11N Rng 10E,UM _5-1 2560 > 1 mile 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I 98.7 feet' 15.Distance to Nearest Well Open Surface: x-560672.5 y- 5959446.13 Zone-4 , GL Elevation above I 70.7 feet. to Same Pool: 96 ft 16.Deviated wells: Kickoff depth: 450 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93.87 degrees Downhole: 1853 psi• Surface: 1436 psi • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 34" 20" 94# K55 Welded 80' 28' 28' 108' 108' 200 cf of ArcticCRETE 16" 13.375" 68# L-80 Hydril 563 2391' 28' 28' 2391' 2300' 1365 sx Deep,245 sx DeepCRETE 12.25" 9.625" 40# L-80 Hydril 563 4462' 28' 28' 4462' 3731' 720 sx Class'G' 6.75" 4.5" 11.6# L-80 Hydril 563 5211' 4262' 3690' 9473' 3789' Screened Liner Completion(no cement` 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect. Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD 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 ❑ qt4 Shallow Hazard Analysis❑ Diverfer Sketch El Seabed Report ❑ Drilling Fluid Program 2 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date r C/P1,4-1). 22. I hereby certify that the foregoing is true and correct. David Lee @ 263-37 1 Contact david.l.lee@conocophillips.com Email Printed Name G.Alvord Title Alaska Drilling Manager Signature AL/C 1 .4- Phone 265-6120 Date to(r( ( Q- Commission Use Only Permit to Drill API Number: Permit ApprovalSee cover letter for other Number: glLi - /3 -‹ 50- 0V- ,3cRC2 -a0-OV3 Date: toIv17 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: U Other: 3 G P fc5 f 90 3 5b0 075 ', Samples req'd: Yes❑ No u Mud log req'd:Yes❑ No Li •ii-J-7 h v/ err f t S f f c7 2-5-6 D p$i HzS measures: Yes® No❑ Directional svy req'd:Yes c❑ No❑ - Spacing exception req'd: Yes❑ No❑ Inclination-only svy req'd:Yes❑ No[ APPROVED BY Approved by:( . / !� �TCOMMISSIONER THE COMMISSION Date:/Q, �/ /0 )�3/i4 t 10/d` ilk/) Submit Fon and ii Form 10-401(Revised 10/2012) This permit Is valid for 24 !!months from the date RiGichiAL Attachments in Duplicate Drl�`M/2-3LLI STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COMMON SEP .l. 7 2014 PERMIT TO DRILL 20 AAC 25.005 i- , "". la.Type of Work: lb.Proposed Well Class: Development-Oil [] • Service- Winj ❑ Single Zone ❑✓ • lc.Specify if well is proposed for: Drill Q • Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket D . Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 1D-145 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 9507' . TVD: 3789' . Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): i Surface: 237.6'FNL 419'FEL,Sec.23 Twn 11N Rng 10 E,UM, ADL 25650,25649 • ; West Sak Oil Pool Top of Productive Horizon: 8.Land Use Permit: ` 13.Approximate Spud Date: 291.8'FNL 5213.7'FEL,Sec.24 Twn 11N Rng 10E,UM ALK 468,467 3/1/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4968.8'FNL 194.5'FEL,Sec. 11 Twn 11N Rng 10E,UM . 2560 > 1 mile 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I , 93:7 feet 15.Distance to Nearest Well Open Surface: x-560670 y- 5959428.5 Zone-4. GL Elevation above I •,x/0.7 feet to Same Pool: 96 ft 16.Deviated wells: Kickoff depth: 500 feet - 17.Maximum Anticipated P essures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93.87 degrees . Downhole: 1853 psi Surface: 1436 psi • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVEY MD TVD (including stage data) 34" 20" 94# K55 Welded 80' 28' 28' ;' 108' 108' 200 cf of ArcticCRETE 16" 13.375" 68# L-80 Hydril 563 2395' 28' 2$� 2395' 2300' 1365 sx Deep,245 sx DeepCRETE 12.25" 9.625" 40# L-80 Hydril 563 4496' 28' 28' 4496' 3731' 720 sx Class'G' 6.75" 4.5" 11.6# L-80 Hydril 563 '5011' 4296' 3694' 9507' 3789' Screened Liner Completion(no cement' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program El Time v.Depth Plot ❑ Shallow Hazard Analysis El DiverterSketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 req 'ement Q 21. Verbal Approval: Commission Representative: f Date 4u41. / ?O/ 22. I hereby certify that the foregoing is true and correct. Davit Lee @ 263-3741 Contact rF david.I.Ieeconocophillips.com Email Printed Name G.Alvord Title Alaska Drilling Manager Signature ite..0w#1 Phone 265-6120 Date Q}(LS" I20 i 4- /�' Commission Use Only Permit to Drill dpi Number: _ Permit Approval See cover letter for other Number: a 1 -- ,3 ar7 50- 0 Z9 - a 3 j t,Z(o-00 -0-d Date: requirements. Conditions of approval: If bo/is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: d Other: Samples req'd: Yes 2 NoEj Mud log req'd:Yes[I] No 0 H2S measures: Yes No❑ Directional svy req'd:Yes E✓ No❑ Spacing exception req'd: Yes❑ No IA/ Inclination-only svy req'd:Yes❑ No EZ'' APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 0 IN ?lc 9l«/Iy" � Submit Form and Form 10-401(Revised 10/2012) This permit is valid for 24 mon fao �e,�at pprgval(20 AA , .005(g Attachments in Duplicate Or • ConocohiIIips Alaska F 17 2 Post Office Box 100360 � Anchorage, Alaska 99510-0360 David Lee Phone (907) 263-3741 August 12, 2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, 1D-145 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill a grass roots onshore producer well, a horizontal well in the West Sak"B"sand. ' The expected spud date for 1D-145 is, March 1st 2015. The West Sak in the 1D area is a shallow marine sequence comprised of very fine grained, single and amalgamated hummocky cross stratified sandstone beds. The 1D-145 well will be drilled in the B sand down structure to the North with a planned lateral length of approximately 5065'. The lateral will cross one down-to-the-north fault with 30-35 feet of throw. There are no known H2S issues associated with the drilling of this well or is it anticipated to see any pressures higher than 9.4'ppg equivalent during the drilling of this well. A FIT test to a minimum of 11.0 ppg will be performed after setting the surface casing and drilling out 20'of new formation, and a FIT test of 11.0 ppg equivalent will be performed after setting the intermediate string and drilling 20'of new formation. A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of the surface hole for the 1D-145. A 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete the well.It will be tested to 3500 psi (annular preventer to 2500 psi) and will be tested on a 14 day test cycle in accordance with COP and AOGCC policy while drilling the intermediate and production sections of the well. Properly sized VBR's and pipe rams will be installed to allow closing in on any size of tubular in the hole in the case of an unexpected event. Also a FOSV with proper DP crossover shall be kept on the floor in the open position at all times. Please find attached for the review of the Commission, forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. Sin ely, Nor David Lee Kuparuk Drilling Engineer • ration for Permit to Drill,Well 1D-145 Revision No.0 Saved: 12-Aug-14 Permit It - West Sak Well #1D-145 • a Application for Permit to Drill Document , Maxwell MoxirnizE Well Vgive Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 (i) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005(c)(5) 3 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (Ml VersaPro Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005 (c)(9) 5 10.Seismic Analysis 5 Requirements of 20 AAC 25.005 (c)(10) 5 11.Seabed Condition Analysis 6 Requirements of 20 AAC 25.005 (c)(11) 6 1D-145 PERMIT.doc Page 1 of 7 ORIGINAL Printed: 12-Aug-14 • /Dation for Permit to Drill,Well 1 D-145 Revision No.0 Saved: 12-Aug-14 12.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 13.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Cement Loads and CernCADE Summary 7 Attachment 4 Well Schematic 7 1. Well Name Requirements of 20 AAC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1D-145. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) 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 identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total 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 for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 237.6' FNL 419'FEL Sec. 23 Twn 11N Rng 10E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 98.7'AMSL Northings 5,959,428.5 Eastings:560,670.0 Pad Elevation 70.7'AMSL Location at Top of Productive Interval 291.8' FNL 5213.7'FEL Sec. 24 Twn 11N Rng 10E UM (West Sak"B"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 3700' Northings: 5,959,378.24 Eastings:561,155.73 Total Vertical Depth, RKB: 3425' Total Vertical Depth, SS: 3326' Location at Total Depth 4968.8' FNL 194.5'FEL Sec. 11 Twn 11N Rng 10E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 9507' Northings: 5,965,258.4 Eastings: 560,843.1 Total Vertical Depth, RKB: 3789' Total Vertical Depth, SS: 3690' 1D-145 PERMIT.doc Page 2 of 7 ��-r.,� SIN � � Printed: 12-Aug-14 01 /Dation for Permit to Drill,Well 1D-145 Revision No.0 Saved: 12-Aug-14 and (D)other information required by 20 MC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 1D-145 and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those 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 by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. 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 identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 MC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete well 1D-145. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 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 following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1D area are 0.489 psi/ft, or 9.4 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak"D"sand formation is 1,436 psi, calculated thusly: MPSP = (3789 ft TVD)(0.489 - 0.11 psi/ft) = 1,436 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: 1D-145 Drilling Hazards Summary. 4. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) 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 identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(0; 1D-145 will be completed with a 9-5/8" intermediate casing landed in the West Sak B sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the"Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. 1D-145 PERMIT.doc Page 3 of 7 ORIGINAL Printed: 12-Aug-14 • /Dation for Permit to Drill,Well 1 D-145 Revision No.0 Saved: 12-Aug-14 5. 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 identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre- perforated liner,or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 34 94 K55 Welded 80 28/ 28 108/ 108 Cemented to surface with 200 cf ArcticCRETE Cemented to Surface with 13.375 16 68 L-80 Hydril 563 2395 28/ 28 2395/ 2300 1365 sx DeepCRETE Lead, 245 sx DeepCRETE Tail Cement Top planned @ 2700' 9.625 12.25 40 L-80 Hydril 563 4496 28/ 28 4496/ 3731 MD/2600'TVD Cemented w/ 720 sx 15.8 ppg Class‘G' 4.5 6.75 11.6 L-80 Hydril 563 5011' 4296/ 3694 9507/ 3789 screens—no cement screens 6. 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,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1D-145 surface hole. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 1D-145 PERMIT.doc Page 4 of 7 Printed: 12-Aug-14 ORIGINAL • /Dation for Permit to Drill,Well 1 D-145 Revision No.0 Saved: 12-Aug-14 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on 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; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (Drilplex AR) Spud to Surface TD Value Density(ppg) 8.5 —9.2 LSYP 30 - 50 API Fluid Loss No Control (cc/30 min) Chlorides < 1000 pH 10.8 — 11.2 Lateral Mud Program (MI FazePro OBM) Intermediate Hole Mud Program (LSND) Value Density(ppg) 9.6 Fann 35 6 RPM 4 8 10.75"Csg Shoe to 7-5/8"Csg Point (lb/100 ft2) Value HTHPFluid Loss Density(ppg) 9.2 - 9.6 (mL/30 min) <5 Fann 35 6 RPM 12 - 16 Drill Solids <2% (lb/100 ft2) API Filtrate Oil Water Ratio 70:30 (cc/30 min) <6 Electrical >400 pH 9.5 - 10.0 Stability(mV) Drill Solids <7 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) 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 identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) 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 identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1D-145 PERMIT doc Page 5 of 7 0RIGRAL Printed: 12-Aug-14 110 tion for Permit to Drill,Well 1 D-145 Revision No.0 Saved: 12-Aug-14 10.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) 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 identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 11.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) 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 identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding)have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20"x 34"insulated conductor to +/- 80' RKB. Install landing ring on conductor. 2. Move in/ rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 2395' MD/ 2300'TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13.375", 68#, L80, Hydril 563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. 5. Remove diverter system, install and test 13-5/8"x 5,000 psi BOP's to 3500 psi (annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 12.25" bit and 8"drilling assembly, with MWD. RIH, clean out cement to top of float equipment and test casing to 3000 psi for 30min. 7. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test to 11.0ppg EMW, recording results. 8. Directionally drill to 9-5/8"casing point at 4496' MD/ 3731'TVD. Pull out of hole on elevators to the surface casing shoe. 9. Perform clean out run prior to running casing. 10. Run 9.625", 40# L80, Hydril 563 casing to surface. (top of cement to be 2700' MD/ 2600'TVD which corresponds to 500'above the Ugnu C formation). 11. Install wellhead x 9.625" packoff and test to 3500 psi. 12. Flush 13.375"x 9.625"annulus with water, followed by diesel. 13. PU 6.75"PDC Bit and 4.5"drilling assembly, with MWD and LWD logging tools. RIH, clean out cement to top of float equipment. Test casing to 3000 psi for 30 minutes. 14. Drill out cement and 20'of new hole. Displace hole to lateral drilling FazePro OBM system. Perform formation integrity test to 11.0ppg EMW, recording results. 15. Directionally drill 6.75" hole to West Sak B Sand to TD at +/- 9507'MD/ 3789'TVD as per directional plan. 1D-145 PERMIT.doc Page 6 of 7 Printed: 12-Aug-14 ORIGINAL • tion for Permit to Drill,Well 1 D-145 Revision No.0 Saved: 12-Aug-14 16. POOH to 9.625"shoe. TIH and perform final circulations. Pump out of Hole. 17. PU and run 4-1/2"screened liner. 18. Once all the liner is in the hole, rig up false rotary table and trip 2 7/8 wash pipe string into the entire length of the liner. Make up liner hanger running tool. 19. Finish running liner to TD to land liner and set liner hanger @ +/-4296'MD/3694'TVD, then displace well to Schlumberger acid through wash pipe (9% formic acid for 1D-145). 20. Allow acid to act on the filter cake. Once break time has been achieved, circulate out the formic acid and replace with inhibited brine. 21. Set liner top packer. POOH across fluid loss control valve (FLCV) to shift FLCV closed. Displace packer fluid and then continue to POOH. 22. PU 4.5"tubing and outer ESP housing and RIH 1000'. 23. RIH with ESP (pump and motor) and land in outer housing using slick line. 24. Continue running in hole with 4.5"tubing. Land tubing. Set BPV 25. Nipple down BOPE, nipple up tree and test. Pull BPV. 26. Freeze protect well with diesel by pumping into 4.5"x 9.625"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 27. Set BPV and move rig off. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an 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 MC 25.080 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. All cuttings generated will be disposed of by hauling 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. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic 1D-145 PERMIT doc 1113 NAL Page 7 - 7 Printed: 12-Aug-14 • __ .7ma — f ,D- 1 D 12 �, 75' e er Line ,f _ No.• � ,CS! 1451 iC : " • I } «. .. . ,} 3 # ,a 3 & 114| ' CI, I RRs% .. � k,_ 1/5 ~ D-14 ; ' ! 4• l D-7| 1D14 +I. o ID-46 \ 2 -14i 147 17 o, °Ze (`9,4 6 e oa $, a /51 ° tf@,- 3* r 37 . " 42 21 1133,1 # Llt\471 49 . | . . .37 ,4 1 y ,s f� � � � Is�- Ib/I/i' 1 D-1 45wp06 6.582 Plan Summary SURVEY PROGRAM 7 `----________\ epth From Depth To Survey/Plan Too�O I A 28.00 1500.00 1D-145wp06(Plan: 1D-145) GYD-GC-MS f ,`oli 1500.00 2400.00 1D-145wp06(Plan: 1D-145) MWD 0, , l \� 1500.00 2400.00 1D-145wp06(Plan: 1D-145) MWD+IFR-AK-CAZ-SC -; G� /o 2400.00 3400.00 1 D-145wp06 (Plan: 1 D-145) MWD _ '41. ,x\\ 1 D-145w 06 (Plan: 1 D-145) MWD+IFR-AK-CAZ-SC 1�!�s�i / 2400.00 4461.00 P �►, '' 1 4461.00 5461.00 1D-145wp06 (Plan: 1D-145) MWD ®r%'' Iiiik / 4461.00 9472.52 1D-145wp06 (Plan: 1D-145) MWD+IFR-AK-CAZ-SC -�`-iri. lii._ CASING DETAILS �� TVD MD Name Size r • , �\ 2300.00 2390.90 13-3/8"x16" 13-3/8 -,..„,. 3730.70 4461.30 9-5/8"x12-1/4" 9-5/8 -1---- 3788.70 9472.52 4-1/2"x6-3/4" 4-1/2 ' 0 9-5/8"x12-1/4" 0° 13-3/8"x16" T6- 13-38"x16" -.4 -6 0 L000- o 9-5/8'x12-1/4" d --i - 4-1/2"x6-3/4" cm icn _ Fi rasl 0 ° .�0 _ 000�m� m m,, m 0 1 ( l i i I I 1 I I I _ i 0Millirs+ttsnr_ 0 0 2500 5000 7500 0 900 1800 2700 3600 04500 5400 6300 Measured Depth Horizontal Departure 1.1{01.V1804114412..1 - ° _ ( 330 ESI 30 - m 60 ..:10111111111111,ll - _._. _.- ____ Pr .�y�. °- """.' - 1.3 m - l'1, _ 300-x y y.3ei, - U _ 1D 143L3wp12.1 igLif rte+ -A���Io-�aw.oa - 2 _ 1 D-143L2wp1 I� :•1,�!.� .--0aop c III 270 : , Ili ___ 1 �.� :���. 90 030 11 A iR�j89 3. 555151 3700 aa, - 240 ��3.Vii'120 - U44. 5100 0100 MOO 0 i r I 1 I i I I 1 1 I 1 1 1 i I I I I '_. I I r . , e � , - 3103 0 1500 3000 4500 6000 7500 9000 210 3800 6503 1Bu o.� tso SECTION DETAILS e20 -01513 Sec MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLeg TFace VSec Target - 1 28.00 0.00 0.00 28.00 -70.70 0.00 0.00 5959197.64 1700704.54 0.00 0.00 0.00 2 450.00 0.00 0.00 450.00 351.30 0.00 0.00 5959197.64 1700704.54 0.00 0.00 0.00 3 750.00 4.50 95.00 749.69 650.99 -1.03 11.73 5959196.71 1700716.28 1.50 95.00 -3.05 4 1100.00 13.15 104.97 1095.24 996.54 -12.53 63.97 5959185.63 1700768.60 2.50 15.00 -23.44 5 1630.00 24.00 138.00 1598.15 1499.45 -108.72 195.04 5959090.49 1700900.43 2.78 60.73 -140.94 6 1720.00 24.00 138.00 1680.37 1581.67 -135.93 219.54 5959063.49 1700925.14 0.00 0.00 -171.99 7 1861.28 28.37 144.14 1807.14 1708.44 -184.51 258.45 5959015.22 1700964.44 3.64 34.60 -226.59 8 1908.44 28.37 144.14 1848.64 1749.94 -202.68 271.58 5958997.17 1700977.71 0.00 0.00 -246.76 9 2390.90 12.43 121.25 2300.00 2201.30 -323.46 383.99 5958877.30 1701091.07 3.64 -163.87 -385.22 10 2410.90 12.43 121.25 2319.53 2220.83 -325.69 387.67 5958875.10 1701094.77 0.00 0.00 -388.06 11 3650.05 53.88 355.98 3395.59 3296.89 151.28 475.23 5959352.71 1701178.50 4.97 -131.44 66.46 12 3850.05 53.88 355.98 3513.48 3414.78 312.44 463.91 5959513.76 1701165.89 0.00 0.00 227.14 13 4461.30 84.00 351.50 3730.70 3632.00 872.53 400.19 5960073.27 1701097.68 4.97 -8.84 789.78 1D-145 DL 24Jun14 Heel 14 4481.30 84.00 351.50 3732.79 3634.09 892.20 397.25 5960092.92 1701094.58 0.00 0.00 809.67 15 4772.05 89.81 351.18 3748.49 3649.79 1179.10 353.55 5960379.42 1701048.58 2.00 -3.19 1099.79 16 5319.96 89.81 351.18 3750.35 3651.65 1720.52 269.51 5960920.10 1700960.21 0.00 0.00 1647.58 17 5529.03 90.00 347.00 3750.70 3652.00 1925.76 229.94 5961125.00 1700919.00 2.00 -87.35 1856.58 1D-145 MW 20Apr14 CP2 18 5764.99 93.87 338.07 3742.72 3644.02 2150.45 159.27 5961349.09 1700846.54 4.12 -66.46 2090.12 P Frost 19 5794.95 93.87 338.07 3740.70 3642.00 2178.19 148.10 5961376.74 1700835.15 0.00 0.00 2119.38 20 6161.51 88.00 352.00 3734.70 3636.00 2531.25 53.77 5961729.00 1700738.00 4.12 112.62 2483.46 1D-145 MW 20Apr14 CP3 21 6346.45 81.88 356.18 3751.00 3652.30 2714.36 34.79 5961911.93 1700717.55 4.00 145.91 2667.08 22 6443.68 81.88 356.18 3764.73 3666.03 2810.40 28.37 5962007.91 1700710.36 0.00 0.00 2762.78 23 6658.82 90.13 358.65 3779.70 3681.00 3024.60 18.73 5962222.00 1700699.00 4.00 16.74 2975.39 1D-145 MW 20Apr14 CP4 24 6659.64 90.13 358.63 3779.70 3681.00 3025.42 18.71 5962222.82 1700698.97 2.00 -95.06 2976.21 25 8117.67 90.13 358.63 3776.43 3677.73 4483.03 -16.06 5963679.97 1700652.52 0.00 0.00 4417.71 26 8193.73 89.46 0.00 3776.70 3678.00 4559.08 -16.97 5963756.00 1700651.00 2.00 116.07 4492.76 1D-145 MW 20Apr14 CP5 27 8941.49 89.47 14.96 3783.75 3685.05 5298.35 80.07 5964495.95 1700742.09 2.00 90.05 5203.95 28 9472.52 89.47 14.96 3788.70 3690.00 5811.36 217.11 5965010.00 1700875.00 0.00 0.00 5685.37 1D-145 MW 24Apr14 CP6 Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2013 T M Depth Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Magnetic Model Date: 03-Feb-14 431- System(SS)Reference: Mean Sea Level Magnetic Declination: 19.60° North/Y: 5959197.64 Ground Level/Mud Line: 70.70 To convert a Magnetic Direction to a True Direction,Add 19.60°East East/X: 1700704.54 Rig: Doyon 141 NO GLOBAL FILTER:Using user defined selection&filtering criteria ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad Plan: 1D-145 Plan: 1D-145 Plan: 1 D-145wp06 ad failed { Dtton Plan Summary � ,� ■ requIr'i 30 September,2014 Failed Anticollision. TCR Required. Minor Risk 1/200 must be applied for 1D-140 and 1D-143. 0 • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-145 Project: Kuparuk River Unit ND Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:1D-145 North Reference: True Wellbore: Plan:1D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145wp06 Database: EDM Alaska Prod 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 1D Pad,KRU Site Position: Northing: 5,959,421.20 usft Latitude: 70°18'0.267 N From: Map Easting: 1,701,118.42 usft Longitude: 149"30'30.085 W Position Uncertainty: 0.00 usft Slot Radius: 36" Grid Convergence: 0.46° Well Plan:10-145 Well Position +N/-S 0.00 usft Northing: 5,959,197.64 usft Latitude: 70'17'58.100 N +E/-W 0.00 usft Easting: 1,700,704.54 usft Longitude: 149°30'42.204 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 70.70 usft Wellbore Plan:1D-145 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°I (°) (nT) BGGM2013 2/3/2014 19.60 80.92 57.614 Design 1D-145wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 28.00 0.00 0.00 350.00 9/302014 4:42:18PM _ COMPASS 5000.1 Build 61 10-145wp06 Plan View 4-1/2"x6-3/4" 1D-145 MW 24Apr14 CP6 P 9473 9000 5000- 1D-/454P06 Or45wp06 1D-145 MW 20Apr14 GP5-- 0 8000 4000-1 � I Co z 7000 1D-145 MW 20Apr14 CP4 8000 1D-145 MW 20Apr14 CPS--- " 6000 -000 1D-145 MW 20Apr14 CP2--_ // 0 5000 1D-145 DL 24Jun14 Feel 1000- 9-5/8"x12-1/4" 00 4000 0— �^ 13-3/8"x16"_ _ �- I I I I I 3000 I I I I -4000 -3000 -2000 -1000 0 1000 2000 3000 4000 West(-)/East(+) (1000 usft/in) I • 1 D-1 45wp06 Section View 0- 0° 700- 1000 C 41400- 0 Q a) 2 2100— 000 13-3/8"x16" a) 2 1-2800— 30130 1 -145wp06 o co rx 3500— `O CP, LI) rn coo o� rn co rn �o —a p V O O 9-5/8"x12-1/4" 0 o 0 0 4-1/2"x6-3/4" 0 700 1400 2100 2800 3500 4200 4900 5600 Vertical Section at 350.00°(700 usft/in) • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-145 Project: Kuparuk River Unit II:;ryr 1111r I'S ::.+.r.}T *.;y ND Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:1D-145 A [r line,k,.. T,,,,,„ North Reference: True Wellbore: Plan:1D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145wp06 Database: EDM Alaska Prod Survey Tool Program Date 9/30/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 1,500.00 1 D-145wp06(Plan.1D-145) GYD-GC-MS Gyrodata gyrocompassing m/s 1,500.00 2,400.00 1D-145wp06(Plan:1D-145) MWD MWD-Standard 1,500.00 2,400.00 1D-145wp06(Plan:1D-145) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,400.00 3,400.00 1 D-145wp06(Plan:1 D-145) MWD MWD-Standard 2,400.00 4,461.00 1D-145wp06(Plan:1D-145) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4,461.00 5,461.00 1D-145wp06(Plan:1D-145) MWD MWD-Standard 4,461.00 9,472.52 1D-145wp06(Plan:1D-145) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) I°) (usft) (usft) (11100usft) (°) (usft)) (usft) (usft) (usft) 28.00 0.00 0.00 28.00 -70.70 0.00 0.00 5,959,197.64 1,700,704.54 0.00 0.00 100.00 0.00 0.00 100.00 1.30 0.00 0.00 5,959,197.64 1,700,704.54 0.05 0.66 200.00 0.00 0.00 200.00 101.30 0.00 0.00 5,959,197.64 1,700,704.54 0.18 0.66 300.00 0.00 0.00 300.00 201.30 0.00 0.00 5,959,197.64 1,700,704.54 0.31 0.66 400.00 0.00 0.00 400.00 301.30 0.00 0.00 5,959,197.64 1,700,704.54 0.45 0.66 450.00 0.00 0.00 450.00 351.30 0.00 0.00 5,959,197.64 1,700,704.54 0.51 0.66 Start Build 1.50 500.00 0.75 95.00 500.00 401.30 1.50 95.00 5,959,197.61 1,700,704.87 0.56 0.66 600.00 2.25 95.00 599.96 501.26 1.50 0.00 5,959,197.41 1,700,707.48 0.63 0.66 700.00 3.75 95.00 699.82 601.12 1.50 0.00 5,959,196.99 1,700,712.69 0.72 0.66 750.00 4.50 95.00 749.69 650.99 1.50 0.00 5,959,196.71 1,700,716.28 0.77 0.66 Start DLS 2.50 TFO 15.00 800.00 5.72 98.25 799.49 700.79 2.50 15.00 5,959,196.22 1,700,720.70 0.82 0.66 900.00 8.18 101.83 898.75 800.05 2.50 11.76 5,959,194.14 1,700,732.61 0.93 0.66 1,000.00 10.66 103.76 997.39 898.69 2.50 8.21 5,959,190.61 1,700,748.59 1.06 0.66 1,100.00 13.15 104.97 1,095.24 996.54 2.50 6.30 5,959,185.63 1,700,768.60 1.21 0.66 Start DLS 2.78 TFO 60.73 1,200.00 14.70 114.56 1,192.31 1,093.61 2.78 60.73 5,959,177.60 1,700,791 20 1.36 0.66 9/302014 4:42:18PM Page 3 COMPASS 5000.1 Build 61 0 • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-145 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:1D-145 North Reference: True Wellbore: Plan:1D-145 Survey Calculation Method: Minimum Curvature Design: 1 D-145wp06 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°I100usft) (°) (usft) (usft) (usft) (usft) 1,300.00 16.58 122.19 1,288.61 1,189.91 2.78 51.42 5,959,164.91 1,700,814.92 1.53 0.67 1,400.00 18.67 128.23 1,383.92 1,285.22 2.78 44.07 5,959,147.61 1,700,839.70 1.70 0.67 1,500.00 20.92 133.06 1,478.01 1,379.31 2.78 38.31 5,959,125.72 1,700,865.49 1.89 0.69 1,600.00 23.28 136.97 1,570.67 1,471.97 2.78 33.77 5,959,099.29 1,700,892.23 2.01 1.16 1,630.00 24.00 138.00 1,598.15 1,499.45 2.78 30.14 5,959,090.49 1,700,900.43 2.04 1.15 Start 90.00 hold at 1630.00 MD 1,686.43 24.00 138.00 1,649.70 1,551.00 0.00 -' 0.00 5,959,073.56 1,700,915.92 2.20 1.15 P Frost 1,700.00 24.00 138.00 1,662.10 1,563.40 0.00 0.00 5,959,069.49 1,700,919.65 2.20 1.15 1,720,00 24.00 138.00 1,680.37 1,581.67 0.00 0.00 5,959,063.49 1,700,925.14 2.26 1.16 Start DLS 3.64 TFO 34.60 • 1,800.00 26.44 141.71 1,752.74 1,654.04 3.64 34.60 5,959,037.59 1,700,947.28 2.55 1.16 1,86128 28.37 144.14 1,807.14 1,708.44 3.64 31.25 5,959,015.22 1,700,964.44 2.84 1.16 Start 47.17 hold at 1861.28 MD 1,900.00 28.37 144.14 1,841.21 1,742.51 0.00 0.00 5,959,000.40 1,700,975.33 3.06 1.16 1,908.44 28.37 144.14 1,848.64 1,749.94 0.00 0.00 5,958,997.17 1,700,977.71 3.11 1.17 Start DLS 3.64 TFO-163.87 2,000.00 25.19 141.97 1,930.37 1,831.67 3.64 -163.87 5,958,964.38 1,701,002.72 3.54 1.21 2,100.00 21.76 138.93 2,022.09 1,923.39 3.64 -161.93 5,958,933.85 1,701,028.26 3.91 1.26 2,200.00 18.40 134.83 2,116.00 2,017.30 364 -159.14 5,958,908.93 1,701,051.84 4.26 1.31 2,300.00 15.17 129.01 2,211.73 2,113.03 3.64 -155.28 5,958,889.73 1,701,073.36 4.54 1.35 2,390.90 12.43 121.25 2,300.00 2,201.30 3.64 -149.72 5,958,877.30 1,701,091.07 4.69 1.38 Start 20.00 hold at 2390.90 MD-13-318"x16" 2,400.00 12.43 121.25 2,308.89 2,210.19 0.00 0.00 5,958,876.30 1,701,092.76 4.71 1.39 2,410.90 12.43 121.25 2,319.53 2,220.83 0.00 0.00 5,958,875.10 1,701,094.77 2.60 1.34 Start DLS 4.97 TFO-131.44 2,500.00 10.05 101.87 2,406.95 2,308.25 4.97 -131.44 5,958,868.65 1,701,11064 2.55 1.36 2,600.00 9.35 72.32 2,505.58 2,406.88 4.97 -112.43 5,958,869.45 1,701,126.92 2.26 1.37 9/302014 4:42:18PM Page 4 COMPASS 5000.1 Build 61 0 • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-145 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 ta 98.70usft(Doyon 141) Well: Plan:1D-145 North Reference: True Wellbore: Plan:1D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145wp06 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (") (°) (usft) (usft) ("/100usft) p) (usft) (usft) (usft) (usft) 2,700.00 11.08 45.71 2,604.05 2,505.35 4.97 -83.28 5,958,878.75 1,701,141.48 2.03 1.38 2,800.00 14.40 28.69 2,701.61 2,602.91 4.97 -57.07 5,958,896.48 1,701,154.19 2.04 1.39 2,900.00 18.46 18.46 2,797.52 2,698.82 4.97 -40.46 5,958,922.50 1,701,164.97 2.15 1.39 3,000.00 22.87 11.93 2,891.08 2,792.38 4.97 -30.64 5,958,956.62 1,701,173.73 2.34 1.38 3,100.00 27.47 7.46 2,981.57 2,882.87 4.97 -24.53 5,958,998.59 1,701,180.41 2.63 1.38 3,200.00 32.17 4.20 3,068.30 2,969.60 4.97 -20.47 5,959,048.07 1,701,184.96 3.07 1.38 3,300.00 36.94 1.69 3,150.64 3,051.94 4.97 -17.64 5,959,104.71 1,701,187.34 3.67 1.40 3,400.00 41.75 359.69 3,227.96 3,129.26 4.97 -15.57 5,959,168.08 1,701,187.54 4.42 1.43 3,500.00 46.59 358.03 3,299.67 3,200.97 4.97 -14.02 5,959,237.69 1,701,185.55 2.92 1.35 3,600.00 51.44 356.62 3,365.24 3,266.54 4.97 -12.83 5,959,313.03 1,701,181.38 3.21 1.37 3,650.05 53.88 355.98 3,395.59 3,296.89 4.97 -11.91 5,959,352.71 1,701,178.50 3.38 1.38 Start 200.00 hold at 3650.05 MD 3,700.00 53.88 355.98 3,425.03 3,326.33 0.00 -11.52 5,959,392.94 1,701,175.35 3.55 1.40 3,800.00 53.88 355.98 3,483.98 3,385.28 0.00 0.00 5,959,473.46 1,701,169.04 3.91 1.48 3,850.05 53.88 355.98 3,513.48 3,414.78 0.00 0.00 5,959,513.76 1,701,165.89 4.09 1.53 Start DLS 4.97 TFO-8.84 3,900.00 56.34 355.52 3,542.05 3,443.35 4.97 -8.84 5,959,554.59 1,701,162.52 4.29 1.56 4,000.00 61.26 354.68 3,593.84 3,495.14 4.97 -8.58 5,959,639.71 1,701,154.53 4.72 1.64 4,100.00 66.18 353.91 3,638.11 3,539.41 4.97 -8.14 5,959,728.82 1,701,144.89 5.19 1.73 4,200.00 71.11 353.20 3,674.51 3,575.81 4.97 -7.80 5,959,821.24 1,701,133.69 5.67 1.83 4,300.00 76.04 352.53 3,702.77 3,604.07 4.97 -7.54 5,959,916.28 1,701,121.01 6.18 1.94 4,400.00 80.98 351.88 3,722.69 3,623.99 4.97 -7.35 5,960,013.22 1,701,106.94 6.69 2.07 4,461.30 84.00 351.50 3,730.70 3,632.00 4.97 -7.22 5,960,073.27 1,701,097.68 7.01 2.06 Start 20.00 hold at 4461.30 MD-9.518"x12-114" 4,481.30 84.00 351.50 3,732.79 3,634.09 0.00 0.00 5,960,092.92 1,701,094.58 7.14 2.07 Start DLS 2.00 TFO-3.19 4,500.00 84.37 351.48 _ 3,734.68 3,635.98 2.00 -3.19 5,960,111.29 1,701,091.68 7.26 2.07 4,600.00 86.37 351.37 3,742.75 3,644.05 2.00 -3.19 5,960,209.71 1,701,076.03 8.06 2.15 9/30/2014 4:42:18PM Page 5 COMPASS 5000.1 Build 61 • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-145 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28(g 98.70usft(Doyon 141) Site: Kuparuk 10 Pad MD Reference: Plan:70.7+28 Q 98.70usft(Doyon 141) Well: Plan:10-145 North Reference: True Wellbore: Plan:1D-145 Survey Calculation Method: Minimum Curvature Design: 10-145wp06 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°I100usft) (°) (usft) (usft) (usft) (ustt) 4,700.00 88.37 351.26 3,747.34 3,648.64 2.00 -3.18 5,960,308.32 1,701,060.15 9.06 2.28 4,772.05 89.81 351.18 3,748.49 3,649.79 2.00 -3.17 5,960,37942 1,701,048.58 9.86 2.40 Start 547.91 hold at 4772.05 MD 4,800.00 89.81 351.18 3,748.59 3,649.89 0.00 -3.17 5,960,407.00 1,701,044.07 10.19 2.46 4,900.00 89.81 351.18 3,748.92 3,650.22 0.00 0.00 5,960,505.68 1,701,027.94 11.42 2.68 5,000.00 89.81 351.18 3,749.26 3,650.56 0.00 0.00 5,960,604.36 1,701,011.81 12.71 2.93 5,100.00 89.81 351.18 3,749.60 3,650.90 0.00 0.00 5,960,703.04 1,700,995.69 14.05 3.20 5,200.00 89.81 351.18 3,749.94 3,651.24 0.00 0.00 5,960,801.72 1,700,979.56 15.43 3.49 5,300.00 89.81 351.18 3,750.28 3,651.58 0.00 0.00 5,960,900.40 1,700,963.43 16.83 3.79 5,319.96 89.81 351.18 3,750.35 3,651.65 0.00 0.00 5,960,920.10 1,700,960.21 17.11 3.85 Start DLS 2.00 TFO-87.35 5,400.00 89.88 349.58 3,750.57 3,651.87 2.00 -87.35 5,960,998.89 1,700,946.20 18.13 4.10 5,500.00 89.97 347.58 3,750.69 3,651.99 2.00 -87.34 5,961,096.74 1,700,925.61 10.08 2.81 5,529.03 90.00 347.00 3,750.70 3,652.00 2.00 -87.34 5,961,125.00 1,700,919.00 10.16 2.84 Start DLS 4.12 TFO-66.46 5,600.00 91.17 344.32 3,749.98 3,651.28 4.12 -66.46 5,961,193.60 1,700,900.87 10.33 2.93 5,700.00 92.81 340.53 3,746.51 3,647.81 4.12 -66.49 5,961,288.60 1,700,869.95 10.58 3.06 5,764.99 93.87 338.07 3,742.72 3,644.02 4.12 -66.62 5,961,349.09 1,700,846.54 10.73 3.15 Start 29.97 hold at 5764.99 MD 5,794.95 93.87 338.07 3,740.70 3,642.00 0.00 -66.76 5,961,376.74 1,700,835.15 10.86 3.19 Start DLS 4.12 TFO 112.62 5,800.00 93.79 338.26 3,740.36 3,641.66 4.12 112.62 5,961,381.39 1,700,833.24 10.89 3.20 5,900.00 92.19 342.07 3,735.14 3,636.44 4.12 112.64 5,961,475.03 1,700,798.62 11.33 3.34 6,000.00 90.59 345.87 3,732.71 3,634.01 4.12 112.83 5,961,570.86 1,700,770.25 11.74 3.48 6,100.00 88.99 349.66 3,733.08 3,634.38 4.12 112.93 5,961,668.38 1,700,748.28 12.12 3.63 6,161.51 88.00 352.00 3,734.70 3,636.00 4.12 112.91 5,961,729.00 1,700,738.00 12.34 3.72 Start DLS 4.00 TFO 145.91 6,200.00 86.73 352.86 3,736.47 3,637.77 4.00 145.91 5,961,767.06 1,700,732.63 12.46 3.78 9/30/2014 4:42:18PM Page 6 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc. Kup1 Local Co-ordinate Reference: Well Plan:1D-145 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:1D-145 North Reference: True Wellbore: Plan:1D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145wp06 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (^) (`) (usft) (usft) (°n00usft) (°) (usft) (usft) (usft) (usft) 6,300.00 83.42 355.12 3,745.06 3,646.36 4.00 145.87 5,961,866.03 1,700,721.41 12.76 3.93 6,346.45 81.88 356.18 3,751.00 3,652.30 4.00 145.68 5,961,911.93 1,700,717.55 12.90 4.00 Start 97.24 hold at 6346.45 MD 6,400.00 81.88 356.18 3,758.56 3,659.86 0.00 145.54 5,961,964.79 1,700,713.59 13.09 4.08 6,443.68 81.88 356.18 3,764.73 3,666.03 0.00 0.00 5,962,007.91 1,700,710.36 13.28 4.15 Start DLS 4.00 TFO 16.74 6,500.00 84.04 356.83 3,771.63 3,672.93 4.00 16.74 5,962,063.66 1,700,706.51 13.51 4.23 6,600.00 87.87 357.98 3,778.68 3,679.98 4.00 16.66 5,962,163.24 1,700,701.20 13.91 4.39 6,658.82 90.13 358.65 3,779.70 3,681.00 4.00 16.58 5,962,222.00 1,700,699.00 14.15 4.48 Start DLS 2.00 TFO-95.06 6,659.64 90.13 358.63 3,779.70 3,681.00 2.00 -95.06 5,962,222.82 1,700,698.97 14.15 4.48 Start 1458.03 hold at 6659.64 MD 6,700.00 90.13 358.63 3,779.61 3,680.91 0.00 -95.08 5,962,263.16 1,700,697.69 14.30 4.55 6,800.00 90.13 358.63 3,779.38 3,680.68 0.00 0.00 5,962,363.10 1,700,694.50 14.76 4.71 6,900.00 90.13 358.63 3,779.16 3,680.46 0.00 0.00 5,962,463.04 1,700,691.32 15.22 4.87 7,000.00 90.13 358.63 3,778.93 3,680.23 0.00 0.00 5,962,562.97 1,700,688.13 15.70 5.03 7,100.00 90.13 358.63 3,778.71 3,680.01 0.00 0.00 '5,962,662.91 1,700,684.94 16.18 5.20 7,200.00 90.13 358.63 3,778.49 3,679.79 0.00 0.00 5,962,762.85 1,700,681.76 16.67 5.36 7,300.00 90.13 358.63 3,778.26 3,679.56 0.00 0.00 5,962,862.79 1,700,678.57 17.16 5.53 7,400.00 90.13 358.63 3,778.04 3,679.34 0.00 0.00 5,962,962.73 1,700,675.38 17.66 5.70 7,500.00 90.13 358.63 3,777.81 3,679.11 0.00 0.00 5,963,062.67 1,700,672.20 18.16 5.86 7,600.00 90.13 358.63 3,777.59 3,678.89 0.00 0.00 5,963,162.61 1,700,669.01 18.67 6.03 7,700.00 90.13 358.63 3,777.36 3,678.66 0.00 0.00 5,963,262.55 1,700,665.83 19.18 6.20 7,800.00 90.13 358.63 3,777.14 3,678.44 0.00 0.00 5,963,362.49 1,700,662.64 19.70 6.37 7,900.00 90.13 358.63 3,776.92 3,678.22 0.00 0.00 5,963,462.43 1,700,659.45 20.22 6.54 8,000.00 90.13 358.63 3,776.69 3,677.99 0.00 0.00 5,963,562.37 1,700,656.27 20.74 6.71 8,100.00 90.13 358.63 3,776.47 3,677.77 0.00 0.00 5,963,662.31 1,700,653.08 21.27 6.88 97302014 4:42:18PM Page 7 COMPASS 5000.1 Build 61 s • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-145 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 ll 98.70usft(Doyon 141) Well: Plan:1D-145 North Reference: True Wellbore: Plan:1 D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145wp06 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVO TVDSS DLeg TFace Northing Easting Let.Error Vert.Error (usft) (°) (°) (usft) (usft) (°1100usft) (°) lush) (usft) (tisk) (usft) 8,117.67 90.13 358.63 3,776.43 3,677.73 0.00 0.00 5,963,679.97 1,700,652.52 21.36 6.91 Start DLS 2.00 TFO 116.07 8.193 73 89.46 360.00 3,776.70 3,678.00 2.00 116.07 5,963,756.00 1,700,651.00 21.63 7.04 Start DLS 2.00 TFO 90.05 8,200.00 89.46 0.13 3,776.76 3,678.06 2.00 90.05 5,963,762.27 1,700,650.96 21.65 7.05 8,300.00 89.46 2.13 3,777.70 3,679.00 2.00 90.05 5,963,862.25 1,700,652.12 21.92 7.22 8,400.00 89.46 4.13 3,778.65 3,679.95 2.00 90.03 5,963,962.12 1,700,656.77 22.16 7.39 8,500.00 89.46 6.13 3,779.59 3,680.89 2.00 90.01 5,964,061.77 1,700,664.90 22.39 7.57 8,600.00 89.46 8.13 3,780.54 3,681.84 2.00 89.99 5,964,161.07 1,700,676.51 22.60 7.74 8,700.00 89.46 10.13 3,781.48 3,682.78 2.00 89.97 5,964,259.91 1,700,691.57 22.78 7.91 8,800.00 89.46 12.13 3,782.43 3,683.73 2.00 89.95 5,964,358.17 1,700,710.08 22.94 8.09 8,900.00 89.46 14.13 3,783.36 3,684.66 2.00 89.93 5,964,455.71 1,700,732.00 23.08 826 8,941.49 89.47 14.96 3,783.75 3,685.05 2.00 89.92 5,964,495.95 1,700,742.09 23.13 8.33 Start 531.02 hold at 8941.49 MD 9,000.00 89.47 14.96 3,784.29 3,685.59 0.00 89.91 5,964,552.59 1,700,756.74 23.38 8.43 9,100.00 89.47 14.96 3,785.23 3,686.53 0.00 0.00 5,964,649.39 1,700,781.77 23.86 8.61 9,200.00 89.47 14.96 3,786.16 3,687.46 0.00 0.00 5,964,746.20 1,700,806.79 24.35 8.78 9,300.00 89.47 14.96 3,787.09 3,688.39 0.00 0.00 5,964,843.00 1,700,831.82 24.85 8.95 9,400.00 89.47 14.96 3,788.02 3,689.32 0.00 0.00 5,964,939.80 1,700,856.85 25.34 9.13 9,472.52 89.47 14.96 3,788.70 3,690.00 0.00 0.00 5,965,010.00 1,700,875.00 25.71 9.26 TD at 9472.62 9/3012014 4:42:18PM Page 8 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-145 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 Q 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28(498.70usft(Doyon 141) Well: Plan:1D-145 North Reference: True Wellbore: Plan:10-145 Survey Calculation Method: Minimum Curvature Design: 1D-145wp06 Database: EDM Alaska Prod Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape (1 (1 (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1 D-145 MW 20Apr14 CF 0.00 0.00 3,734.70 2,531.25 53.77 5,961,729.00 1,700,738.00 70°18'22.996 N 149°30'40.636 W -plan hits target center -Point 10-145 MW 20Apr14 Cf 0.00 0.00 3,779.70 3,024.60 18.73 5,962,222.00 1,700,699.00 70°18'27.848 N 149°30'41.658 W -plan hits target center -Point 10-145 DL 24Jun14 Het 0.00 0.00 3,730.70 872.53 400.19 5,960,073.27 1,701,097.68 70°18'6.682 N 149°30'30.536 W -plan hits target center -Point 10-145 MW 20Apr14 CF 0.00 0.00 3,776.70 4,559.08 -16.97 5,963,756.00 1,700,651.00 70°18'42.940 N 149°30'42.699 W -plan hits target center -Point 10-145 MW 20Apr14 To 0.00 0.00 3,730.70 819.18 409.08 5,960,020.00 1,701,107.00 70°18'6.157 N 149°30'30.277 W -plan misses target center by 6.97usft at 4407.68usft MD(3723.87 TVD,819.92 N,407.90 E) -Point 10-145 MW 20Apr14 CF 0.00 0.00 3,750.70 1,925.76 229.94 5,961,125.00 1,700,919.00 70°18'17.041 N 149°30'35.499 W -plan hits target center -Point 10-145 MW 24Apr14 CF 0.00 0.00 3,788.70 5,811.36 217.11 5,965,010.00 1,700,875.00 70°18'55.257 N 149°30'35.870 W -plan hits target center -Point 10-145 MW20Apr CP1 0.00 0.00 3,730.70 819.18 409.08 5,960,020.00 1,701,107.00 70°18'6.157 N 149°30'30.277 W -plan misses target center by 6.97usft at 4407.68usft MD(3723.87 TVD,819.92 N,407.90 E) -Point WP05 Surf Csg 0.00 0.00 2,300.00 -337.91 378.58 5,958,862.81 1,701,085.78 70°17'54.777 N 149°30'31.168 W -plan misses target center by 15.42usft at 2391.51usft MD(2300.60 TVD,-323.53 N,384.10 E) -Point 913012014 4:42:18PM Page 9 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-145 Project: Kuparuk River Unit ND Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk iD Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:1D-145 North Reference: True Wellbore: Plan:1 D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145wp06 Database: EDM Alaska Prod Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name ("1 (") 4,461.30 3,730.70 9-5/8"x12-114" 9-5/8 12-1/4 9,472.52 3,788.70 4-1/2'x6-3/4" 4-1/2 6-3/4 2.390.90 2,300.00 13-318"x16" 13-3/8 16 Formations I Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1 (°) 1.686 43 1.649.70 P Frost 0.00 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-145 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:1D-145 North Reference: True Wellbore: Plan:1D-145 Survey Calculation Method: Minimum Curvature Design: 1D-145wp06 Database: EDM Alaska Prod Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) '_ (usft) (usft) (usft) Comment 450.00 450.00 0.00 0.00 Start Build 1.50 750.00 749.69 -1.03 11.73 Start DLS 2.50 TFO 15.00 1,100.00 1,095.24 -12.53 63.97 Start DLS 2.78 TFO 60.73 1,630.00 1,598.15 -108.72 195.04 Start 90.00 hold at 1630.00 MD 1,720.00 1,680.37 -135.93 219.54 Start DLS 3.64 TFO 34.60 1,861.28 1,807.14 -184.51 258.45 Start 47.17 hold at 1861.28 MD 1,908.44 1,848.64 -202.68 271.58 Start DLS 3.64 TFO-163.87 2,390.90 2,300.00 -323.46 383.99 Start 20.00 hold at 2390.90 MD 2,410.90 2,319.53 -325.69 387.67 Start DLS 4.97 TFO-131.44 3,650.05 3,395.59 151.28 475.23 Start 200.00 hold at 3650.05 MD 3,850.05 3,513.48 312.44 463.91 Start DLS 4.97 TFO-8.84 4,461.30 3,730.70 872.53 400.19 Start 20.00 hold at 4461.30 MD 4,481.30 3,732.79 892.20 397.25 Start DLS 2.00 TFO-3.19 4,772.05 3,748.49 1,179.10 353.55 Start 547.91 hold at 4772.05 MD 5,319.96 3,750.35 1,720.52 269.51 Start DLS 2.00 TFO-87.35 5,529.03 3,750.70 1,925.76 229.94 Start DLS 4.12 TFO-66.46 5,764.99 3,742.72 2,150.45 159.27 Start 29.97 hold at 5764.99 MD 5,794.95 3,740.70 2,178.19 148.10 Start DLS 4.12 TFO 112.62 6,161.51 3,734.70 2,531.25 53.77 Start DLS 4.00 TFO 145.91 6,346.45 3,751.00 2,714.36 34.79 Start 97.24 hold at 6346.45 MD 6,443.68 3,764.73 2,810.40 28.37 Start DLS 4.00 TFO 16.74 6,658.82 3,779.70 3,024.60 18.73 Start DLS 2.00 TFO-95.06 6,659.64 3,779.70. 3,025.42 18.71 Start 1458.03 hold at 6659.64 MD 8,117.67 3,776.43 4,483.03 -16.06 Start DLS 2.00 TFO 116.07 8,193.73 3,776.70 4,559.08 -16.97 Start DLS 2.00 TFO 90.05 8,941.49 3,783.75 5,298.35 80.07 Start 531.02 hold at 8941.49 MD 9,472.52 3,788.70 5,811.36 217.11 TD at 9472.52 Checked By: Approved By: Date: 9/30/2014 4:42:18PM ,zage' COMPASS 5000.1 Build 61 • • 111 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad Plan: 1D-145 Plan: 1D-145 1 D-145wp06 Clearance Summary Failed n -CoIIlSlon Anticollision Report TR required 30 September,2014 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design, Kuparuk 1D Pad-Plan:1D-145-Plan:1D-145-1D-145wp06 Well Coordinates: 5,959,197.64 N,1,700,704.54 E(70°17'58.10"N,149°30'42.20"W) Datum Height: Plan:70.7028 @ 98.70usft(Doyon 141) Scan Range: 0.00 to 9,472.52 usft.Measured Depth. Scan Radius is 2,383.08 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 61 Scan Type: Failed Anticollision.TCR Required. Minor Risk Scan Type: 25.00 1/200 must be applied for 1D-140 and 1D-143. • 111 ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-145-1 D-145wp06 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:Kuparuk 10 Pad-Plan:1D-145-Plan:1D-145-1D-145wp06 Scan Range:0.00 to 9,472.52 usft.Measured Depth. Scan Radius is 2,383.08 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Kuparuk 1C Pad 1C-127-1C-127-1C-127 9,212.03 1,094.33 9,212.03 858.75 5,875.00 4.645 Clearance Factor Pass-Major Risk Kuparuk 1D Pad 1D-01-1D-01-1D-01 467.69 492.12 467.69 481.39 475.00 45.864 Centre Distance Pass-Major Risk 1D-01-1D-01-1D-01 633.18 493.84 633.18 479.13 650.00 33.562 Clearance Factor Pass-Major Risk 10.02-1D-02-1D-02 471.52 384.62 471.52 373.86 475.00 35.762 Centre Distance Pass-Major Risk 1D-02-1D-02-1D-02 566.33 385.67 566.33 372.62 575.00 29.563 Clearance Factor Pass-Major Risk 1D-04-10-04-1D-04 467.82 206.98 467.82 196.23 475.00 19.248 Centre Distance Pass-Major Risk 1D-04-1D-04-1D-04 563.07 208.24 563.07 195.20 575.00 15.973 Clearance Factor Pass-Major Risk 1D-04-1D-04A-1 D-04A 467.82 206.98 467.82 196.23 475.00 19.248 Centre Distance Pass-Major Risk 1D-04-1 D-04A-1D-04A 563.07 208.24 563.07 195.20 575.00 15.973 Clearance Factor Pass-Major Risk 1D-04-1 D-04AL1- 1 D-04AL1 467.82 206.98 467.82 196.23 475.00 19.248 Centre Distance Pass-Major Risk 1D-04-1D-04AL1- 1D-04AL1 563.07 208.24 563.07 195.20 575.00 15.973 Clearance Factor Pass-Major Risk 1D-04-1D-04AL1-01-1D-04AL1-01 467.82 206.98 467.82 196.23 475.00 19.248 Centre Distance Pass-Major Risk 1 D-04-1 D-04AL1-01-1 D-04AL1-01 563.07 208.24 563.07 195.20 575.00 15.973 Clearance Factor Pass-Major Risk 10.04-1D-04AL1-02-1D-04AL1-02 467.82 206.98 467.82 196.23 475.00 19.248 Centre Distance Pass-Major Risk 1D-04-1 D-04AL1-02-1 D-04AL1-02 563.07 208.24 563.07 195.20 575.00 15.973 Clearance Factor Pass-Major Risk 10.05-1 D-05-1D-05 491.74 181.49 491.74 170.16 500.00 16.018 Centre Distance Pass-Major Risk 1D-05-1D-05-1D-05 2,047.95 202.73 2,047.95 151.47 2,175.00 3.955 Clearance Factor Pass-Major Risk 1 D-06-1 D-06-1D-06 98.70 230.79 98.70 228.74 105.00 112.458 Centre Distance Pass-Major Risk 1 D-06-1 D-06-1D-06 587.48 233.06 587.48 219.59 600.00 17.307 Clearance Factor Pass-Major Risk 1D-09-10.09-1 D-09 98.70 199.98 98.70 197.93 111.60 97.445 Centre Distance Pass-Major Risk 1D-09-1D-09-1 D-09 884.89 201.19 884.89 186.46 925.00 13.654 Clearance Factor Pass-Major Risk 1D-10-1D-10-1D-10 2,193.67 326.14 2,193.67 276.81 2,175.00 6.612 Clearance Factor Pass-Major Risk 1D-101-1D-101-1D-101 322.72 449.05 322.72 443.40 325.00 79.461 Centre Distance Pass-Major Risk 1D-101-10.101-1D-101 422.68 449.93 422.68 442.66 425.00 61.927 Clearance Factor Pass-Major Risk 1D-102-1D-102-1D-102 2,829.99 178.82 2,829.99 107.00 3,125.00 2.490 Clearance Factor Pass-Major Risk 1D-102-1D-102L1-1D-102L1 2,829.99 178.82 2,829.99 106.92 3,125.00 2.487 Clearance Factor Pass-Major Risk 30 September,2014- 16:48 Page 2 of 10 COMPASS S • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-145-1 D-145wpO6 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-145-Plan:10-145-1D-145wp06 Scan Range: 0.00 to 9,472.52 usft.Measured Depth. Scan Radius is 2,383.08 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 1D-102-1 D-102PB1-1 D-102PB1 2,829.99 178.62 2,829.99 106.91 3,125.00 2.487 Clearance Factor Pass-Major Risk 1D-102-1D-102PB2-1 D-102PB2 2,829.99 178.82 2,829.99 106.92 3,125.00 2.487 Clearance Factor Pass-Major Risk 1D-102-1D-102PB3-1D-102PB3 2,829.99 178.82 2,829.99 106.92 3,125.00 2.487 Clearance Factor Pass-Major Risk 1D-105-1D-105-1D-105 362.15 396.04 362.15 389.63 375.00 61.779 Centre Distance Pass-Major Risk 10-105-1D-105-1D-105 461.17 396.56 461.17 388.48 475.00 49.070 Clearance Factor Pass-Major Risk 1D-105-1 D-105A-1 D-105A 347.86 396.04 347.86 389.86 350.00 64.110 Centre Distance Pass-Major Risk 1D-105-1 D-105A-1D-105A 471.26 396.74 471.26 388.48 475.00 48.064 Clearance Factor Pass-Major Risk 1D-106-10-106-1D-106 162.27 370.56 162.27 367.60 175.00 125.133 Centre Distance Pass-Major Risk 1D-106-1 0-106-1 D-106 556.60 371.69 556.60 362.36 575.00 39.826 Clearance Factor Pass-Major Risk 1D-107-1 D-107-1D-107 679.68 356.87 679.68 344.51 700.00 28.876 Centre Distance Pass-Major Risk 1D-107-1D-107-1D-107 727.37 357.28 727.37 344.28 750.00 27.471 Clearance Factor Pass-Major Risk 1D-11-1D-11-1D-11 418.15 408.19 418.15 401.09 425.00 57.453 Centre Distance Pass-Major Risk 1D-11-1D-11-1D-11 491.45 408.64 491.45 400.37 500.00 49.431 Clearance Factor Pass-Major Risk 1D-11-1D-11L1-1D-11L1 418.15 408.19 418.15 401.09 425.00 57.453 Centre Distance Pass-Major Risk 1D-11-1D-11L1-1D-11L1 491.45 408.64 491.45 400.37 500.00 49.431 Clearance Factor Pass-Major Risk 1D-11-1D-11L2-1D-11L2 418.15 408.19 418.15 401.24 425.00 58.745 Centre Distance Pass-Major Risk 1D-11-1D-11L2-1D-11L2 491.45 408.64 491.45 400.53 500.00 50.383 Clearance Factor Pass-Major Risk 10-11-1 0-11 L2PB1-10-11 L2PB1 418.15 408.19 418.15 401.09 425.00 57.453 Centre Distance Pass-Major Risk 1D-11-1D-11L2PB1-1D-11L2PB1 491.45 408.64 491.45 400.37 500.00 49.431 Clearance Factor Pass-Major Risk 10-113-1D-113-10-113 98.70 261.56 98.70 259.51 112.10 127.448 Centre Distance Pass-Major Risk 1D-113-1D-113-1D-113 161.60 261.90 161.60 258.83 175.00 85.532 Clearance Factor Pass-Major Risk 10-114-10-114-10-114 98.70 251.06 98.70 249.00 112.10 122.331 Centre Distance Pass-Major Risk 10-114-10-114-10-114 532.34 251.68 532.34 242.68 550.00 27.968 Clearance Factor Pass-Major Risk 1D-115-1D-115-1D-115 98.70 240.83 98.70 238.78 111.50 117.348 Centre Distance Pass-Major Risk 1D-115-10-115-10-115 212.20 241.18 212.20 237.30 225.00 62.179 Clearance Factor Pass-Major Risk 10-116-10-116-10-116 98.70 231.30 98.70 229.25 112.10 112.703 Centre Distance Pass-Major Risk 1D-116-1D-116-1D-116 186.60 232.03 186.60 228.56 200.00 66.828 Clearance Factor Pass-Major Risk 1D-117-1D-117-1D-117 673.22 214.38 673.22 202.69 700.00 18.336 Centre Distance Pass-Major Risk 1 D-117-1D-117-1D-117 719.93 214.88 719.93 202.38 750.00 17.179 Clearance Factor Pass-Major Risk 1D-118-1D-118-1D-118 412.30 213.66 412.30 206.80 425.00 31.167 Centre Distance Pass-Major Risk 30 September,2014-16:48 Page 3 of 10 COMPASS 0 ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-145-1 D-145wpO6 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-145-Plan:1D-145.1D-145wp06 Scan Range:0.00 to 9,472.52 usft.Measured Depth. Scan Radius is 2,383.08 tisk.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 1D-118-1D-118-1D-118 509.34 214.22 509.34 205.86 525.00 25.612 Clearance Factor Pass-Major Risk 1D-119-1D-119-1D-119 485.46 190.34 485.46 182.00 500.00 22.825 Centre Distance Pass-Major Risk 10.119-10-119-10-119 509.32 190.62 509.32 181.91 525.00 21.898 Clearance Factor Pass-Major Risk 1D-12-1D-12-1D-12 586.73 471.98 586.73 462.18 600.00 48.125 Centre Distance Pass-Major Risk 10.12-10.12-1D-12 610.46 472.14 610.46 461.98 625.00 46.477 Clearance Factor Pass-Major Risk 1D-12-1D-12L1-1D-12L1 586.73 471.98 586.73 462.17 600.00 48.120 Centre Distance Pass-Major Risk 10.12-1D-12L1-1D-12L1 610.46 472.14 610.46 461.98 625.00 46.473 Clearance Factor Pass-Major Risk 1D-12-1D-12L1PB1-1D-12L1PB1 586.73 471.98 586.73 462.17 600.00 48.120 Centre Distance Pass-Major Risk 10.12-1D-12L1PB1-1 D-12L1 PB1 610.46 472.14 610.46 461.98 625.00 46.473 Clearance Factor Pass-Major Risk 10.12-1D-12L2-1D-12L2 586.73 471.98 586.73 462.17 600.00 48.120 Centre Distance Pass-Major Risk 10.12-1D-12L2-1D-12L2 610.46 472.14 610.46 461.98 625.00 46.473 Clearance Factor Pass-Major Risk 10.120-10-120-10.120 3,548.71 183.31 3,548.71 125.40 3,425.00 3.165 Clearance Factor Pass-Major Risk 1D-120-1D-120-10.120 3,565.02 182.91 3,565.02 125.44 3,450.00 3.183 Centre Distance Pass-Major Risk 1D-121-10-121-1D-121 98.70 185.80 98.70 183.75 112.00 90.536 Centre Distance Pass-Major Risk 1D-121-10-121-1D-121 508.84 186.86 508.84 178.18 525.00 21.545 Clearance Factor Pass-Major Risk 1D-122-10-122-10.122 61.60 183.31 61.60 181.63 75.00 108.793 Centre Distance Pass-Major Risk 10.122-1D-122-10.122 311.59 185.34 311.59 179.53 325.00 31.900 Clearance Factor Pass-Major Risk 10.123-10-123-10.123 211.59 181.15 211.59 177.28 225.00 46.868 Centre Distance Pass-Major Risk 1D-123-1D-123-1D-123 261.59 181.50 261.59 176.83 275.00 38.874 Clearance Factor Pass-Major Risk 1D-124-1D-124-1D-124 485.72 186.17 485.72 177.87 500.00 22.417 Centre Distance Pass-Major Risk 10.124-1D-124-1D-124 533.50 186.57 533.50 177.55 550.00 20.685 Clearance Factor Pass-Major Risk 1 D-125-1D-125-10.125 386.88 193.24 386.88 186.35 400.00 28.027 Centre Distance Pass-Major Risk 1 D-125-1D-125-10.125 461.35 193.71 461.35 185.63 475.00 23.959 Clearance Factor Pass-Major Risk 1 D-125-1D-125A-1D-125A 373.43 193.25 373.43 186.68 375.00 29.420 Centre Distance Pass-Major Risk 1D-125-1D-125A-1D-125A 448.43 193.55 448.43 185.77 450.00 24.887 Clearance Factor Pass-Major Risk 1 D-126-1D-126-1D-126 187.40 199.59 187.40 196.35 200.00 61.531 Centre Distance Pass-Major Risk 1D-126-1D-126-1D-126 237.39 199.94 237.39 195.88 250.00 49.267 Clearance Factor Pass-Major Risk 1D-126-Plan:1D-126A-1D-126A(wp02) 187.40 199.59 187.40 196.22 200.00 59.157 Centre Distance Pass-Major Risk 1D-126-Plan:1D-126A-1D-126A(wp02) 237.39 199.94 237.39 195.75 250.00 47.737 Clearance Factor Pass-Major Risk 10-127-10.127-10-127 86.90 206.26 86.90 204.15 100.00 97.841 Centre Distance Pass-Major Risk 30 September,2014- 16:48 Page 4 of 10 COMPASS • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-145-1D-145wp06 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:10-145-Plan:1D-145-1D-145wp06 Scan Range: 0.00 to 9,472.52 usft.Measured Depth. Scan Radius is 2,383.08 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 1D-127-1D-127-1D-127 186.89 206.70 186.89 203.36 200.00 61.939 Clearance Factor Pass-Major Risk 1D-128-1D-128-1D-128 98.70 213.72 98.70 211.67 111.80 104.138 Centre Distance Pass-Major Risk 1 D-128-1D-128-1D-128 481.37 214.96 461.37 207.05 475.00 27.186 Clearance Factor Pass-Major Risk 10.129-1D-129-1D-129 212.20 249.92 212.20 246.04 225.00 64.357 Centre Distance Pass-Major Risk 1D-129-10.129-1D-129 262.19 250.27 262.19 245.58 275.00 53.358 Clearance Factor Pass-Major Risk 1D-130-1D-130-10.130 461.69 259.93 461.69 252.02 475.00 32.859 Centre Distance Pass-Major Risk 10.130-1 D-130-1D-130 533.58 260.33 533.58 251.35 550.00 28.980 Clearance Factor Pass-Major Risk 10.135-1D-135-1D-135 2,193.19 121.14 2,193.19 69.14 2,225.00 2.330 Clearance Factor Pass-Major Risk 1D-136-10.136-1D-136 2,008.85 427.43 2,008.85 382.30 1,925.00 9.473 Centre Distance Pass-Major Risk 10-136-10.136-1D-136 2,050.00 428.28 2,050.00 381.45 1,975.00 9.146 Clearance Factor Pass-Major Risk 1D-140-10.140-10-140 8,388.97 14026 8,388.97 139.69 7,775.00 244.399 Clearance Factor Pass-Minor 1/20 1D-140-1D-140L1-1D-140 Lt 6,332.73 95.68 6,332.73 95.21 5,700.00 203.683 Clearance Factor Pass-Minor 1/20 10.140-1D-140PB1-1D-140PB1 6,170.33 151.88 6,170.33 151.31 5,525.00 264.645 Clearance Factor Pass-Minor 1/20 1D-141-1D-141-10-141 1,446.64 152.59 1,446.64 118.03 1,550.00 4.415 Centre Distance Pass-Major Risk 1D-141-10.141-1D-141 1,490.81 153.80 1,490.81 116.79 1,600.00 4.156 Clearance Factor Pass-Major Risk 1 D-141-1D-141A-1D-141A 1,437.38 152.58 1,437.38 118.22 1,550.00 4.441 Centre Distance Pass-Major Risk 10.141-1D-141A-1D-141A 1,503.61 154.54 1,503.61 116.52 1,625.00 4.064 Clearance Factor Pass-Major Risk 1D-141-1D-141APB1-1D-141APB1 1,437.38 152.58 1,437.38 118.46 1,550.00 4.472 Centre Distance Pass-Major Risk 1 D-141-1D-141APB1-1D-141APB1 1,503.61 154.54 1,503.61 116.76 1,625.00 4.090 Clearance Factor Pass-Major Risk 1D-141-1D-141APB2-1 D-141APB2 1,437.38 152.58 1,437.38 118.46 1,550.00 4.472 Centre Distance Pass-Major Risk 1D-141-1 D-141APB2-1D-141APB2 1,503.61 154.54 1,503.61 116.76 1,625.00 4.090 Clearance Factor Pass-Major Risk 10.141-1D-141APB3-1D-141APB3 1,437.38 152.58 1,437.38 118.46 1,550.00 4.472 Centre Distance Pass-Major Risk 1D-141-1 D-141APB3-1D-141APB3 1,503.61 154.54• 1,503.61 116.76 1,625.00 4.090 Clearance Factor Pass-Major Risk 1D-141-1D-141L1-1D-141L1 1,446.64 152.59 1,446.64 118.03 1,550.00 4.415 Centre Distance Pass-Major Risk 1D-141-1D-14tL1-1D-141L1 1,490.81 153.80 1,490.81 116.79 1,600.00 4.156 Clearance Factor Pass-Major Risk 1D-141-1D-141L1PB1-1D-141L1PB1 1,446.64 152.59 1,446.64 118.03 1,550.00 4.415 Centre Distance Pass-Major Risk 1D-141-1D-141L1PB1-1D-141L1PB1 1,490.81 153.80 1,490.81 116.79 1,600.00 4.156 Clearance Factor Pass-Major Risk 1D-141-1D-141L1 PB2-1D-141L1PB2 1,446.64 152.59 1,446.64 118.03 1,550.00 4.415 Centre Distance Pass-Major Risk 1D-141-1D-141L1PB2-1D-141L1PB2 1,490.81 153.80 1,490.81 116.79 1,600.00 4.156 Clearance Factor Pass-Major Risk 1D-141-1D-141PB1-1D-141PB1 1,446.64 152.59 1,446.64 117.79 1,550.00 4.384 Centre Distance Pass-Major Risk 30 September,2014-16:48 Page 5 of 10 COMPASS • 41110 ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-145-1 D-145wpO6 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk'ID Pad-Plan:1D-145-Plan:1D-145-1D-145wp06 Scan Range:0.00 to 9,472.52 usft.Measured Depth. Scan Radius is 2,383.08 tisk.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 1D-141-1D-141PB1-1D-141PB1 1,490.81 153.80 1,490.81 116.55 1,600.00 4.129 Clearance Factor Pass-Major Risk 1D-28-1D-28-1D-28 894.65 109.78 894.65 95.03 900.00 7.443 Centre Distance Pass-Major Risk 1 D-28-1D-28-1D-28 945.45 110.13 945.45 94.57 950.00 7.075 Clearance Factor Pass-Major Risk 1D-28-1D-28L1-1D-28L1 894.65 109.78 894.65 95.03 900.00 7.443 Centre Distance Pass-Major Risk 10-28-1D-28L1-1D-28L1 945.45 110.13 945.45 94.57 950.00 7.075 Clearance Factor Pass-Major Risk 1D-30-1D-30-1D-30 1,671.17 105.33 1,671.17 78.61 1,650.00 3.943 Clearance Factor Pass-Major Risk 1D-30-1D-30L1-1D-30L1 1,671.17 105.33 1,671.17 78.60 1,650.00 3.941 Clearance Factor Pass-Major Risk 1D-32-1 D-32-1D-32 670.01 195.14 670.01 183.89 675.00 17.344 Centre Distance Pass-Major Risk 1D-32-1 D-32-1D-32 1,270.46 199.48 1,270.46 177.17 1,250.00 8.944 Clearance Factor Pass-Major Risk 1D-32-1D-32L1-1D-32L1 670.01 195.14 670.01 184.12 675.00 17.710 Centre Distance Pass-Major Risk 1D-32-1D-32L1-1D-32L1 1,270.46 199.48 1,270.46 177.37 1,250.00 9.025 Clearance Factor Pass-Major Risk 1D-32-1D-32L1PB1-1 D-32L1P81 670.01 195.14 670.01 183.88 675.00 17.337 Centre Distance Pass-Major Risk 1D-32-1D-32L1PB1-1D-32L1PB1 1,270.46 199.48 1,270.46 177.14 1,250.00 8.929 Clearance Factor Pass-Major Risk 1D-34-1 D-34-1D-34 493.74 225.98 493.74 217.47 500.00 26.561 Centre Distance Pass-Major Risk 1 D-34-10.34-1D-34 543.90 226.35 543.90 217.08 550.00 24.411 Clearance Factor Pass-Major Risk 1D-34-1D-34L1-1D-34L1 492.74 225.98 492.74 217.49 500.00 26.608 Centre Distance Pass-Major Risk 1D-34-1D-34L1-1D-34L1 542.90 226.33 542.90 217.08 550.00 24.447 Clearance Factor Pass-Major Risk 1D-34-1D-34L1PB1-1D-34L1PB1 492.74 225.98 492.74 217.49 500.00 26.608 Centre Distance Pass-Major Risk 1D-34-1D-34L1PB1-1D-34L1PB1 542.90 226.33. 542.90 217.08 550.00 24.447 Clearance Factor Pass-Major Risk 1 D-36-1D-36-1 D-36WP4(Baker) 393.35 257.20 393.35 250.41 400.00 37.883 Centre Distance Pass-Major Risk 10-36-1D-36-1 D-36WP4(Baker) 718.92 258.89 718.92 246.86 725.00 21.521 Clearance Factor Pass-Major Risk 1D-36-1D-36-1D-36 243.40 256.87 243.40 252.51 250.00 58.895 Centre Distance Pass-Major Risk 10-36-1D-36-1D-36 668.86 260.28 668.86 249.11 675.00 23.319 Clearance Factor Pass-Major Risk 1D-36-1D-36L1-1D-36L1 242.70 256.87 242.70 252.52 250.00 59.047 Centre Distance Pass-Major Risk 10.36-1D-36L1-1D-36L1 668.16 260.26 668.16 249.11 675.00 23.333 Clearance Factor Pass-Major Risk 1D-36-1D-36L2-1D-36L2 242.70 256.87 242.70 252.52 250.00 59.047 Centre Distance Pass-Major Risk 10-36-1 D-36L2-1 D-36L2 668.16 260.26 668.16 249.11 675.00 23.333 Clearance Factor Pass-Major Risk 1D-37-1D-37-1D-37 842.63 265.82 842.63 252.22 850.00 19.554 Centre Distance Pass-Major Risk 1D-37-1D-37-10.37 1,014.49 266.43 1,014.49 250.20 1,025.00 16.410 Clearance Factor Pass-Major Risk 1D-37-1D-37L1-1 D-37L1 841.54 265.82 841.54 252.24 850.00 19.578 Centre Distance Pass-Major Risk 30 September,2014-16:48 Page 6 of 10 COMPASS • • ConocoPhillips(Alaska)Inc.-Kupi Kuparuk River Unit Anticollision Report for Plan: 1D-145- 1 D-145wpO6 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-145-Plan:1D-145-1D-145wp06 Scan Range: 0.00 to 9,472.52 usft.Measured Depth. Scan Radius is 2,383.08 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 1D-37-10-37L1-1D-37L1 1,013.42 266.42 1,013.42 250.20 1,025.00 16.426 Clearance Factor Pass-Major Risk 1 D-37-1 D-37L2-10.37L2 841.54 265.82 841.54 252.24 850.00 19.578 Centre Distance Pass-Major Risk 1 D-37-1D-37L2-1D-37L2 1,013.42 266.42 1,013.42 250.20 1,025.00 16.426 Clearance Factor Pass-Major Risk 10.37-1D-37L2PB1-1 D-37L2PB1 841.54 265.82 841.54 252.24 850.00 19.578 Centre Distance Pass-Major Risk 1D-37-1D-37L2PB1-1D-37L2PB1 1,013.42 266.42 1,013.42 250.20 1,025.00 16.426 Clearance Factor Pass-Major Risk 1D-38-1D-38-10.38 2,230.28 131.19 2,230.28 87.80 2,200.00 3.024 Centre Distance Pass-Major Risk 1 D-38-1D-38-10.38 2,253.97 131.56 2,253.97 87.50 2,225.00 2.985 Clearance Factor Pass-Major Risk 1 D-39-1 D-39-1D-39 2,764.39 279.07 2,764.39 235.46 2,875.00 6.398 Clearance Factor Pass-Major Risk 1D-40-10.40-1D-40 770.35 313.83 770.35 301.28 775.00 25.005 Centre Distance Pass-Major Risk 1D-40-10.40-1D-40 899.33 314.56 899.33 300.01 900.00 21.623 Clearance Factor Pass-Major Risk 10-40-1 D-40A-10.40A 771.23 313.83 771.23 301.26 775.00 24.978 Centre Distance Pass-Major Risk 1D-40-1D-40A-1D-40A 900.21 314.57 900.21 300.01 900.00 21.603 Clearance Factor Pass-Major Risk 1D-41-1D-41-1D-41 112.80 331.68 112.80 329.18 125.00 132.507 Centre Distance Pass-Major Risk 1D-41-1D-41-1D-41 212.79 332.36 212.79 327.93 225.00 75.002 Clearance Factor Pass-Major Risk 1D41-1D-41PB1-1D-41PB1 112.80 331.68 112.80 329.07 125.00 126.959 Centre Distance Pass-Major Risk 1D-41-1D-41PB1-1D-41P01 212.79 332.35 212.79 327.82 225.00 73.195 Clearance Factor Pass-Major Risk 1D-41-10.41 PB2-10-41 PB2 112.80 331.68 112.80 329.07 125.00 126.959 Centre Distance Pass-Major Risk 10-41-1 D41 PB2-1 D41 PB2 212.79 332.36 212.79 327.82 225.00 73.195 Clearance Factor Pass-Major Risk 1D42-1D42-10.42 243.70 346.60 243.70 342.10 250.00 77.100 Centre Distance Pass-Major Risk 1D-42-1D-42-10.42 1,001.37 349.02 1,001.37 332.81 1,000.00 21.521 Clearance Factor Pass-Major Risk 1D42-1D-42-1D42(Baker) 1,131.07 341.93 1,131.07 323.56 1,125.00 18.617 Centre Distance Pass-Major Risk 1D-42-10.42-1D-42(Baker) 1,187.14 342.32 1,187.14 323.04 1,175.00 17.753 Clearance Factor Pass-Major Risk 1D-42-1 D-42L1-1 D-42L1 242.70 346.60 242.70 342.45 250.00 83.491 Centre Distance Pass-Major Risk 1D-42-1D-42L1-1D-42L1 1,000.37 349.01 1,000.37 333.14 1,000.00 21.987 Clearance Factor Pass-Major Risk 1D-42-1D42L1P81-1D42L1PB1 242.70 346.60 242.70 342.12 250.00 77.375 Centre Distance Pass-Major Risk 1D42-1D42LI P81-1D-42L1 PB1 1,000.37 349.01 1,000.37 332.81 1,000.00 21.542 Clearance Factor Pass-Major Risk Plan:1D-142-Plan 1D-142-1D-142wp06 1,072.74 28.43 1,072.74 10.59 1,075.00 1.594 Centre Distance Pass-Major Risk Plan:1D-142-Plan 10-142-1D-142wp06 1,146.96 28.95 1,146.96 10.05 1,150.00 1.531 Clearance Factor Pass-Major Risk Plan:10-143-Plan:10.143-1D-143wp13 1,585.40 46.90 1,585.40 38.66 1,575.00 5.693 Clearance Factor Pass-Minor 1/200 Plan:1D-143-Plan:1D-143L1-1D-143L1wp12.1 1,585.40 46.90 1,585.40 38.66 1,575.00 5.693 Clearance Factor Pass-Minor 1/200 30 September,2014-16:48 Page 7 of 10 COMPASS • i ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-145-1 D-145wpO6 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk lD Pad-Plan:1D-145-Plan:1D-145-1D-145wp06 Scan Range: 0.00 to 9,472.52 usft.Measured Depth. Scan Radius is 2,383.08 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Plan:1D-143-Plan:1D-143L2-1D-143L2wp12.1 28.00 60.00 28.00 58.77 28.00 48.996 Clearance Factor Pass-Minor 1/200 Plan:1D-143-Plan:1D-143L3-1D-143L3wp12.1 1,585.40 46.90 1,585.40 38.66 1,575.00 5.693 Clearance Factor Pass-Minor 1/200 Plan:1D-146-Plan:1D-146-1 D-146wp04 1,666.40 52.92 1,666.40 27.00 1,650.00 2.041 Clearance Factor Pass-Major Risk Survey tool orogfam From To Survey/Plan Survey Tool (usft) (usft) 28.00 1,500.00 1D-145wp06 GYD-GC-MS 1,500.00 2,400.00 1D-145wp06 MWD 1,500.00 2,400.00 1D-145wp06 MWD+IFR-AK-CAZ-SC 2,400.00 3,400.00 1D-145wp06 MWD 2,400.00 4,461.00 1D-145wp06 MWD+IFR-AK-CAZ-SC 4,461.00 5,461.00 1D-145wp06 MWD 4,461.00 9,472.52 1D-145wp06 MWD+IFR-AK-CAZ-SC 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. 30 September 2014- 16:48 Page 8 of 10 COMPASS Sec MD Inc Azi TVD *WS -,Ei-W DLeg Wace Target 1 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 28 500 1D-145wp062 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 3 7N.00 4.50 95.00 749.69 -1.03 11.73 1.50 95.00 3. 500 800 41100.00 13.15 104.97 1095.24 -12.53 63.97 2.50 15.00 -23.44 28.00 To 9472.52 51630.00 24.00 138.00 1598.15 -108.72 195.04 2.78 60.73 -140.94 61720.00 24.00 138.00 1680.37 -135.93 219.54 0.00 0.00 -171.99 800- 1000 71861.28 28.37 144.14 1807.14 -184.51 258.45 3.64 34.60 -226.59 I 1. 81908.44 28.37 144.14 1848.64 -202.68 271.58 0.00 010 -246.76 9 2390.90 12.43 121.25 2300.00 -323.46 383.99 3.64 -163e7 -385.22 WP05 Surf Csg 10 2410.90 12.43 121.25 2319.53 -325.69 387e7 0.00 100 -388.06 1600 1 11 3650.05 53.88 35518 3395.59 151.28 47523 4.97 -131.44 66.46 1000 1300 16:5September 30 2014 300 - 12 3850.05 53.88 355.98 3513.48 312.44 463.91 0.00 0.00 227.14 GLOBAL FILTER APPLIEC 13 4461.30 84.00 351.50 3730.70 872.53 40119 4.97 -8.84 789.78 1D-145 DL 24Jun14 Heel 1600 1800 144481.30 84.00 35150 3732.79 89220 39725 0.00 0.00 809.67 15 4772.05 89.81 351.18 3748.49 117110 35155 200 1.19 1099.79 1800 2100 16 5319.96 89.81 351.18 3750.35 1720.52 269.51 0.00 aoo 1647.58 17 5529.03 90.00 34710 3750.70 1925.76 229.94 2.00 e7.35 185 58 10-145 MW 20Apr14 CP2 2100 2349 Depth From Depth To SurveWrIon Tool 28.00 0016145) IMGC-212 18 5764.99 9187 338.07 3742.72 2150.45 1N.27 4.12 -N.46 2o9o.i 15 .00 12,145e206(Plan: GT 500.00 112-145wp06(Mem 10-14M MWD 19 5794.95 9187 338.07 374CI.70 2178.19 148.10 0.00 100 2119.38 12400.00 2349 - 2600 1500.00 2400.00 112-14500202 Mon:16145) MIND,621,222-22 206161.51 N.00 35210 3734.70 2531 25 53.77 4.12 112.62 2483.46 1D-145 MW 20Apr14 CP3 2400.00 1100.00 10-145w206(Men)16145) MD 21 6346.45 81.N 356.18 3751.00 271436 34.79 410 145.91 266718 2400.00 4401.00 10-145w006(Mon:161451 MWDelFP-21(622-2C 22 6443.68 81.88 356.18 376473 2 1040 28.37 0.00 010 2762.78 2600 2900 4461.00 5421.00 16145w206 Manz 10-14M MWO 23665882 90.13 358.N 3779.70 3024.60 18.73 400 16.74 2975.33 1D-145 MW 20Apr14 CP4 4421.00 9472.52 16145006 Men)161451 MWD+IFFI-PX622-22 24 6659.64 90.13 358.63 3779.70 3025.42 18.71 200 -95.0 2976.21 2900 3100 258117.67 90.13 358.63 3776.43 4483.03 -16.06 0.00 010 4417.71 CASING DETAILS 268193.73 N.46 010 3776.70 4559.08 -16.97 210 116.07 4.49276 1745-1MW 20Apr14 CP5 3100 3400 278941.49 89.47 14.96 3783.75 5298.35 80.07 2.00 90.05 520315 TVD MD Name Size 289472.52 89.47 14.96 3788.70 5811.36 217.1-_I ii0_ 00 0.00 5685.37 17-145 MW 24Apr14 CP6 - 2300.00 2390.90 13-3/8x16" 13-3/8 3400 3700 3730.70 4461.30 9-5/8"x12-1/4" 9-5/8 3788.70 9472.52 4-1/2"x6-3/4" 4-1/2 1_, 1D-141APB4 3700 3900 1 D-142wp0E1 111.141L1P131 3900 4200 ID-141P13111D'iff .?LiiikiN3 0/360 4200 4453 jt1:141C.11.B4 4.rfartal',I.rif,i'ittitr.iiiiiiVe l'i/i'''XIff f--- L J 4453 51" it D-141L 1 s,,,.,74!,.,....Asifitifig 5 F..4 EIYE,171/1graltri fit 30 5100 5800 30/330 - .." '---1,:talitgloit-oplivitlfgriralAVAPfiviz, Alktm,k,k, ...-::- -,-7_:'-''-,_:•,!:.,Z.,,tzt.t4z4•11.e;,‘,itt.1 iviweAlt.:,V,o,0;414;4.4.1%t.w4/41"0,4 0 v,,4c,.., , 11 D-146wp041 444,00.0100. --------- prillti- t,.'..:.4.4, 404.04,4.•4#0410_,:......:,...........04:01t:4,:iii:,..4 i s 5800 6500 7100 6500 7100 7800 . ,•,et A..411111rIllirlFs ...gia' 't rf". ... 0 imam* 0 : ' ‘1 1 7800 8500 t/ ( Al•Pli :Fir;0110 tak.llaw. fliait, \ 8500- 9200 fr. -oicrib„,-TA,,v A D-143- 13 1.11;-."'-'‘.."7-1-*Ilt17F'dtt / oa, 4,. 9200 9842 1,0 Aib......._-A A ----1------:: * 60 -60/300 / • / • \/ ,•emp.--..--- / --,.. ,41, • ww. / K, ' ,' '',.i- / 401091 ,00-"•/, ' '''40,,k4k4„.Nik).. kk / / 1 0-140 LI- , - As, iii„:.• •-•.• , --.. '44,411av, \.. •":;-;,,eltil-"Ptt''l'..''':.;;''. ' - 8 iii illit. 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''''.I.4';4'.4 40,00141.14'14.MWAVVAIWIff ' ii' ''''I. bAllfrijiireriiitAtigt*P0111F/ .- , ..:,....,.4Cn.44.# ... ,.'4444.4.1.4fArilli ,,(.,/,1111.1/004.46.1kek:$4,,,,,iefe.......TpAtige ',.41.1....it ;';':!i:4"'ll'Olt ,?.#:''7,1hViiii fa, i `....i.,,Iii; ,&.'/Ijk...dianO!iii.Z.1,Millgif;ii 4 ft?I''At''.:-7,-.71, '40.4'iii*,...kifjli,41111L:,:t---1=-T::,:-.'42.:(%;;Ii Ilatblilb'74anift" 411 -4,-;,e--#--.-------.-4ereAv.:-:"-• .. - ikr' - -------4;40,-.A-N40,..... 0(44%;:-‘..4..:4 •,':-•••'.- f4ti ,'' , -, -- ..:,;';';*4,11r.1'74iAtilliftf4lirr .',X1-,P4z::t"'"ritif4490,..14INT4400,..:• .....„r-it,,,,,.,..,i.,;0.11.2),-,e4ttaklailif, itt IID-1351 ..1:*,r! ..i fed.,..44110041111 4,,,,r4ti Z,2,.' .ek-WiaillINPr „.11/41011911 1 421.27!7:,...-4111V4VIVO/0., 1 50 -150/210 4:1;.:;.-.- -.:.-,7TgrAtsitilita:-.,-•,..•„...- ;=4vrot-4-i-diapi-ilog- ,::,,,,,C11:-.....7.Z...--•••-Parfr...FO.W„,,,FAr:;If f'.:',,..444,..!0,11•04..4.0,' .,VIer7 ;i7:...-4's4"..iiNfi',:;12;i:::;•,$.4;:‘,11-4717 -180/180 11D-143wp14 • • ConocoPhillips 1 D-145wp06 Schlumberger Alaska E. e3 a o o V J_ ::: of I 0 60— wesamiI.111111.� V a 1 101ro a /d - E / / j3oi 11 riIlI'Egai Magnetic Distance I --------.-- ' I 0- T l i l I i i i t I l l i , i l l i p i i i l l i i l . . 0 400 800 1200 1600 2000 2400 Displayed interval could be less than entire raptured Depth 28.00 To 9472.52 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval:25.00 Depth Range From: 28.00 To 9472.52 Results Limited By: Centre Distance:2383.08 NO GLOBAL FILTER:Using user defined selection&filtering criteria SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1500.00 1D-145wp06 (Plan: 1D-145) GYD-GC-MS 1500.00 2400.00 1D-145wp06(Plan: 1D-145) MWD 1500.00 2400.00 1D-145wp06(Plan: 1D-145) MW D+I FR-AK-CAZ-SC 2400.00 3400.00 1D-145wp06 (Plan: 1D-145) MWD 2400.00 4461.00 1D-145wp06 (Plan: 1D-145) MWD+IFR-AK-CAZ-SC 4461.00 5461.00 1D-145wp06 (Plan: 1D-145) M W D 4461.00 9472.52 1D-145wp06 (Plan: 1D-145) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2300.00 2390.90 13-3/8"x16" 13-3/8 3730.70 4461.30 9-5/8"x12-1/4" 9-5/8 3788.70 9472.52 4-1/2"x6-3/4" 4-1/2 • DD! 1 D-1 45wp05 6 . 600 Plan Summary SURVEY PROGRAM n Dep r28.00 Depthom 1000.00 11 D 145w105(Plan: 1D-145) GYD-GC Ti' I 000.00 2395.00 1D-145wp05 (Plan: 1D-145) M 'I!'11\�1`°�. 000.00 2395.00 1 D 145wp05 (Plan: 1D-145) MWD+IFR-AK-CAZ-'rp l�1� 395.00 3895.00 1D-145wp05 (Plan: 1D-145) M �i ;�� 395.00 4495.67 1 D 145wp05 (Plan: 1D-145) MWD+IFR AK CAZ ' ��°tr: 1�\ 495.67 6000.00 1D-145wp05 (Plan: 1D-145) M i l 111 \\` �� 495.67 9506.90 1D-145wp05(Plan: 1D-145) MWD+IFR-AK-CAZ-'� /001 1‘v '11,�_ ,; CASING DETAILS Of / I TVD MD Name Size 2300.00 2394.84 13-3/8"x16" 13-3/8 AAlI� ,, ` 3730.70 4495.67 9-5/8"x12-1/4" 9-5/8 ....irii.l ,.� 3788.70 9506.90 4-1/2"x6-3/4" 4-1/2 o° 9-5/8"x12-1/4" 13-3/8"x16" - o -105 13-3/8"x16" 5- ,, -5 � 20° T - 4-1/2"x6-3/4" _ 20Q6 9-5/8'x12-1/4" - - --�- 4-1/26-3/4" m i ` cb °� �� _ _.. V - %..,;' °i m o' ,..% oo o ® o ° E / 4i urn m a CO al CI 1 F`\\ 0950 1900 2850 �3800 4750 ° 5700 6650 Horizontal Departure 0 2500 5000 7500 o Measured Depth 330 ao 60-_ 1 1D 143.4wp12 ril ���p ,z 21 , ' i' l 'I►�� ! III �� f)F �1.i7' SOO 800 800 - 1000 IIii °� 111 300.r`1 „� - 1600 0) _.. :. g ?,g �._ 1800 - 2101) 2,o° 9 99999111 ._..... . e8°o m `� 13L2wp12W �,. 00 n .� `I�-_ 270 90 .. a� o 30- „l\ 3700 - 3900 EL, - 4200 „ 3900 J �� • _ 4453 240 $a $ ii, 120 - 5100 moo 6500 0 11�'i411 5800 -_0 1 I I 1 1 1 1 1 1 1 1 I I I I I I I I I I I I I 1 1 I I I I I I I it"g - - 7100 210 �; ". 150 0 800 1600 2400 3200 406-0 4800 5600 6400 7200 7100 - 7800- 8500 180 _ SECTION DETAILS 9200 - 984= Sec MD Inc Azi TVD TVDSS +N/-S +8/-W Northing Easting DLeg TFace VSec Target - 1 28.00 0.00 0.00 28.00 -70.70 0.00 0.00 5959180.00 1700702.00 0.00 0.00 0.00 2 450.00 0.00 0.00 450.00 351.30 0.00 0.00 5959180.00 1700702.00 0.00 0.00 0.00 3 700.00 3.75 100.00 699.82 601.12 -1.428.05 5959178.64 1700710.06 1.50 100.00 -2.80 4 1300.00 18.70 108.06 1286.69 1187.99 -34.84 '119.48 5959146.13 1700821.74 2.50 10.00 -55.06 5 1821.95 27.01 150.69 1770.38 1671.68 -165.20 258.21 5959016.89 1700961.50 3.45 84.29 -207.53 6 2010.70 27.01 150.69 1938.54 1839.84 -239.9 -' 300.18 5958942.49 1701004.06 0.00 0.00 -288.43 7 2393.72 12.43 121.25 2298.90 2200.20 -337.91 378.58 5958845.17 1701083.25 4.50 -159.06 -398.52 8 2413.70 12.43 121.25 2318.41 2219.71 -340,14 382.26 5958842.97 1701086.94 0.00 0.00 -401.35 9 3792.64 59.84 355.64 3475.19 3376.49 246.89 474.76 5959430.66 1701174.72 4.90 -130.47 160.69 10 3992.64 59.84 355.64 3575.66 3476.96 09.32 461.61 5959602.97 1701160.18 0.00 0.00 332.79 11 4495.67 84.00 350.50 3730.70 3632.00 p890.15 402.87 5960073.27 1701097.68 4.90 -12.34 806.67 1D-145 DL 24Jun14 Heel 12 4515.67 84.00 350.50 3732.79 3634.09 d 909.77 399.59 5960092.86 1701094.24 0.00 0.00 826.56 13 4810.19 89.82 351.42 3748.66 3649.96 ''1200.08 353.41 5960382.76 1701045.73 2.00 8.99 1120.48 14 5342.30 89.82 351.42 3750.35 3651.65:'' 1726.23 274.01 5960908.20 1700962.13 0.00 0.00 1652.42 15 5563.42 90.00 347.00 3750.70 365 1943.38 232.62 5961125.00 1700919.00 2.00 -87.65 1873.46 1D-145 MW 20Apr14 CP2 16 5799.42 93.87 338.07 3742.72 3644. 2168.11 161.94 5961349.13 1700846.52 4.12 -66.46 2107.05 17 5829.30 93.87 338.07 3740.70 364 . 0 2195.77 150.80 5961376.70 1700835.17 0.00 0.00 2136.22 18 6195.91 88.00 352.00 3734.70 36 00 2548.87 56.45 5961729.00 1700738.00 4.12 112.62 2500.35 1D-145 MW 20Apr14 CP3 19 6380.84 81.88 356.18 3751.00 3652.30 2731.98 37.47 5961911.93 1700717.55 4.00 145.91 2683.96 20 6478.08 81.88 356.18 3764.73 66.03 2828.03 31.06 5962007.91 1700710.36 0.00 0.00 2779.67 21 6693.21 90.13 358.65 3779.70 /&681.00 3042.22 21.41 5962222.00 1700699.00 4.00 16.74 2992.28 1D-145 MW 20Apr14 CP4 22 6693.50 90.12 358.65 3779.70,/3681.00 3042.50 21.40 5962222.29 1700698.99 3.00 -146.48 2992.57 23 8177.84 90.12 358.65 3776.5 3677.82 4526.43 -13.69 5963705.74 1700652.00 0.00 0.00 4460.04 24 8228.12 89.46 0.00 3776.7 3678.00 4576.70 -14.29 5963756.00 1700651.00 3.00 116.07 4509.65 1D-145 MW 20Apr14 CP5 25 8975.88 89.47 14.96 3783 5 3685.05 5315.97 82.75 5964495.95 1700742.09 2.00 90.05 5220.84 26 9506.90 89.47 14.96 378 .70 3690.00 5828.98 219.79 5965010.00 1700875.00 0.00 0.00 5702.26 1D-145 MW 24Apr14 CP6 Heel target moved 50' to Failed Anti _ Ilision. TCR Required. Minor Risk make pump tangent closer to 1/200 must be applied for 1D-140 and 1D-143. casing point Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2013 TM Depth Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Magnetic Model Date: 03-Feb-14 System(SS)Reference: Mean Sea Level Magnetic Declination: 19.60° North/Y: 5959180.00 To convert a Magnetic Direction to a True Direction,Add 19.60°East Ground Level/Mud Line: 70.70 East/X: 1700702.00 Rig: Doyon 141 ND OB L FILTER:Using user defined selection&filtering criteria • I T"" RS I as E C ns V ? o C �C YN i L 0 C d V Y Y a a RS ZS CZ a a N ORIGINAL • # a z z N 00 V r O co M b 0 O M 0) ✓ r M r O a O r C C 'a 0 > O O 0 0 N rA C O 0 0 d U 00 00 w co U d , O m j a C N d N co co Z a j U + + = y J �-' U CO — a • rr =a < coco > rn c Ec o m O N LN 7 C a C d a w a • a a w (O > > m g 'o C y J J0 a> d3 G a « U v 'rn v .a `0) C' $ co 122t co J 0 .0 cO w d C) d• mc a' Cd O N d N .0 (2 y 8 C d j U d O w d 0 d 3 = . 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O Z al ` V A a (O + +c z Q a CO a c (6 5 co t t C d d 47.C (09pC C C U O _d>. ` d O = y 0 N dN .,- Z N f2 ::4, xi- o c <0 ao ° a r c rn ? °. a ..44 a r d 0 N o v o p S :: m v m ° m 0 m 2 w d d Ad m .N c C 'C0 c CD CU N ‘ 13I ��AL i • 1 D-1 45wp05 Plan View 4-1/2"x6-3/4" 5250-- 9000 7n'r45 �'p05 4500- 8000 3750- 7000 0 r`A000 + '(-f5 6000 p250 0 co 1500- 9-5/8"x12-1/4" 5000 750— 0 4000 0 0- Z 13-3/8"x16" 3000 -2250 -1500 -750 0 750 1500 2250 West(-)/East(+) (750 usft/in) ORIGINAL • • Crit co c Q a68 N Ln `c' 0006 ,— r-%ri O _O N Nom C 0 O .� ::° -- N V CO43) O O C 1.0M 7000 0 O O G O O co N O LU co ifs' c •000 o O ;(5) 006 N CI) I 0 Q) 1.0 00600 0 0008 T a. i 4Ln ( p N I x O 000 oQ Lo T � °09 6 1 O x Q o 0 0 r- C7 I. 03 QQ. M Q O O V T M Oco --Q I O O O O O O N. 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V M (V N O 0) N N N N N- O N. V CO 0 O C W CO CO CO CO CO u) 0) I\ C0 N O C0 CO CO (0 V M O O 0 0 N W CO M 0 CO 0 d 0 M M M 0) V O) O a0 N- V V N O O 6 O O W W (O CO CO (O O ((i O r Ci N M y N 0N ,i3' N W O is 00N uO V V aV V 0V V V (0M M M uM) r •:J. IO�) N0) M 00 N C i 4 - W m N CO 0 V V .1- 000 N O 0) O V V C0 O O O O O O O O V .71- 00 ,- 00 V (O V M N N N N 6) M M O V N '- I-- 0 O O O 0 0 0 1- Cr) W- u - n V) 0) N ) 1 N- _ V N O 6) N N- Ca V' O O O O C] C] O ao r N- r 0i V' n r N N a L ' O M O M M N O O O 0) O O O O O O O O 0` I` N- N. O 0) O O (0 O (0 CO a O CO (O CO (O 'I' ,- M M N CO CO CO CO CO c0 CO s- ,- ,- ,- CO I- CO CO ,- N ro Q. 03 d 0 N N N M N N N O n O (O U) N N N N N N N M M M M N N N N u) N (0 a a 01 E V V V' V A- u) O I� O CO M CO 0) 0) O O O 0) N O M 03 CO CO CO V M O .- N O O CO 00 n N N- N. N. 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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" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM Intermediate Cement Top Moderate Risk of cement reaching surface casing shoe,put retarder in for first 60 bbls to extend set up time 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 Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning aided by circulation sub, 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 Anti-collision with 1 D- Moderate Follow real time surveys very closely, use geological certainty 140 and 1D-143 to avoid 1D-143 and 1D-140 Fault Crossings and Moderate Use developed best practices for concretion drilling. Concretions Getting Liner to Bottom Moderate Maintain solids free oil based mud properties and lubricity while running liner lower completion, monitor torque and drag. oRIGttachment 2-1D-145 Drilling Hazards Summary.doc I\ -\ _ 8/13/20146:48:20 AM 1 D-145 Schlumberger CemCADE Preliminary Job Design 13 3/8" Surface Casino (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Nabors 9ES Volumes are based on 250%excess in the permafrost and 50%excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 1895' MD. Client:CPAI Revision Date: August 6, 2014 Prepared by:Jenna Houston Location:Anchorage,AK Phone: (907)263-4207 Lead Slurry Minimum pump time: -250 min. (pump time plus 120 min.) Mobile: (907)223-8916 TE @ 11.00 ppg -1.91 ft3/100 lb sk email:jhouston2@slb.com 1.019 ft3/ft x 80 x 1.0 (0%excess) = 82 ft3 < TOC at Surface 0.4206 ft3/ft x (1700-80) x 3.50 (250%excess) = 2385 ft3 0.4206 ft3/ft x (1895-1700) x 1.50 (50%excess) = 124 ft3 2385 ft3+ 124 ft3+82 ft3= 2591 ft3 2591 ft3/1.91 ft3/sk= 1357 sks(1365 sks) Have additional ALC on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: -190 min. (pump time plus 120 min.) 12.0 ppg DeepCRETE- 1.63 ft3/1001b sk 0.4206 ft3/ft x (2395-1895) x 1.50 (50%excess) = 316 ft3 0.8407 ft3/ft x 80' (Shoe Joint) = 68 ft3 316 ft3 + 68 ft3 = 384 ft3 384 ft3/ 1.63 ft3/sk = 236 sks Round up to 245 sks BHST = 68°F, Estimated BHCT =78°F. (Based on 2.1 °F/100 ft. from surface) < Base of Permafrost at PUMP SCHEDULE 1,700'MD(1,650'TVD) Pump Rate Stage Cumulative Stage Time Stage Volume Time (bpm) (bbl) (min) (min) CW 100 7.0 75.0 10.7 10.7 MUDPUSH II 7.0 75.0 10.7 21.4 < Top of Tail at Pause 0.0 0.0 5.0 26.4 11 ppg DeepCRETE 7.0 461.1 65.9 g2 3 1,895'MD Lead Surface Tail 7.0 68.2 9.7 102.0 DeepCRETE Slurry Pause 0.0 0.0 5.0 107.0 Fresh Water 5.0 10.0 2.0 109.0 A Pause 0.0 0.0 5.0 113.0 Mud 8.0 326.6 40.8 153.8 Mud 3.0 10.0 3.3 157.1 < 13 3/8",68#casing Tp- in 16"OH MUD REMOVAL Expected Mud Properties:9.4 ppg, Pv<20, Ty<20 I TD at 2,395 MD Spacer Properties:10.5 ppg MudPUSH" II, Pv= 17-21, Ty=20-25 1, (2,300'TVD) Centralizers: As per CPAI program. * Mark of Schlumberger ORIG ! \ AL 1 D-145 Schlumberger CemCADE Preliminary Job Design 9 5/8" Intermediate (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Nabors 9ES Volume Calculations and Cement Systems Location: Kuparuk Client:CPAi Revision Date: August 6,2014 Volumes are based on 40%excess. Prepared by:Jenna Houston Location:Anchorage,AK Tail Slurry Minimum thickening time non-retarded slurry: -210 min. (pump time plus 120 Phone: (907)263-4207 min.). Minimum thickening time for retarded slurry is 480 min by COP request. Mobile: (907)223-8916 15.8 ppg Class G +adds - 1.16 ft3/sk email:jhouston2@slb.com 0.3132 ft3/ft x (4496'-2700') x 1.4 (40%excess) = 788 ft3 Shoe Volume: 0.4258 ft3/ft x 80'x 1.00 (no excess) = 35 ft3 Totals: 788 ft3+35 ft3 = 823 ft3 823 ft3/ 1.16 ft3/sk= 710 sks(720 sks) BHST= 98 °F, Estimated BHCT = 75 °F. (BHST calculated using a gradient of 2.1 °F/100 ft.from surface) PUMP SCHEDULE Stage Cumulative Pump Rate Stage Time 13 3/8",45.5#casing Stage (bpm) Volume (min) Time (bbl) (min) at 2395'MD MUDPUSH II 5.0 50.0 10.0 10.0 Pause 0.0 0.0 5.0 15.0 Tail Slurry+Retarder 5.0 46.3 9.3 24.3 Tail Slurry 5.0 100.0 20.0 44.3 Pause 0.0 0.0 5.0 49.3 Fresh Water 5.0 10.0 2.0 51.3 Top of Tail at end of pumping Pause 0.0 0.0 5.0 56.3 < 2700'MD Mud 6.0 314.9 52.5 108.8 Mud 3.0 10.0 3.3 112.1 MUD REMOVAL 9 5/8",40# in 12 1/4"hole Recommended Mud Properties:9.6 ppg, Pv<20, Ty<20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties:10.5 ppg MudPUSH* II, Pv=25 - 30, Ty=30 -40 Centralizers: As per CPAi program TD at 4496'MD (3730 TVD) * Mark of Schlumberger ORIGIN1-' ' L S 0 / likl E'- U O v �44¢ 1:•1.11 O O Y 75 OY W av.•.: w S .-i; R III4 0, N C 9 N O d O c 7 G W n N k NO-,,c, C ax W zaco E V F£ R. L c x 5.:_,,, b -. V 2iU ca O se c F. ~ . ° `? A d i A x U 4 7 m _ W �o rl b c " •m ti q x U a O i1 A N .a 8 v= 4 lc ' • \ M a 0 „, d."-- 1\ i N p C e r31 U � Mx�e ' 'a � bW U 9 r �p C M OC.N �89R .5" g ( °?CI' 9---:'i 08 q c v i.a \ ..... =F w 3§ ka cnQ a o. R F x yC 112 m u..0- L.y:o t'^x@•) 2oto N^ 3 Ct H L)g M+ N b NO zo v 5 N_ - N yL C to .-i g, a ConocoPhillips Draft Schematic 1D-145(Producer) Attachment 4-1D-143 Well Schemata.vad Alaska 8/13/2014 OIG1NAL • • Bettis, Patricia K (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> 2-J ,11/ `/3? Sent: Wednesday, October 01, 2014 4:20 PM To: Bettis, Patricia K (DOA) Cc: Jolley, Liz C; Hallford, Kelsey Subject: 1D Permits to Drill Attachments: Permit to Drill 1D-142.pdf; 1D-142wp06 -Plan Summary.pdf; Permit to Drill 1D-143 Ll.pdf; Permit to Drill 1D-143 L2.pdf; Permit to Drill 1D-143 L3.pdf; Permit to Drill 1D-143.pdf; 1D-143L1wp13 PlanSummary.pdf; 1D-143L2wp13 PlanSummary.pdf; 1D-143L3wp13 PlanSummary.pdf; 1D-143wp13 PlanSummary.pdf; Permit to Drill 1D-145.pdf; 1D-145wp06- Plan Summary.pdf; Permit to Drill 1D-146.pdf; 1D-146wp04- Plan Summary.pdf Patricia,as we discussed on the phone,the 1D wells ended up having their surface locations shifted by—17'. Attached please find the updated 10-401's for each of the wells as well as the updated directional plans with the new surface coordinates. If you have any questions or require any further information please let me know. Thanks David 1 • . I1 & Bettis, Patricia K (DOA) 2/51-13g From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Thursday, September 18, 2014 2:20 PM To: Bettis, Patricia K(DOA) Subject: RE: KRU 1D-145: Permit to Drill Application Morning Patricia, here are the logging program for each of the 1D Wells: 1D-142 Surface—Gamma, Resistivity, Density, Neutron Intermediate—Gamma, Resistivity Lateral—Gamma, Resistivity, sonic (for cement top evaluation) and periscope 1D-143 Surface—Gamma, Resistivity Intermediate—Gamma, Resistivity, density, neutron Lateral x 4—Gamma, Resistivity and periscope 1D-146 Surface—Gamma, Resistivity Intermediate—Gamma, Resistivity Lateral x 4—Gamma, Resistivity and periscope 1D-145 Surface—Gamma, Resistivity Intermediate—Gamma, Resistivity, Lateral x 4—Gamma, Resistivity and periscope Please let me know if you need anything else. Thanks David From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, September 18, 2014 9:12 AM To: Lee, David L Subject: [EXTERNAL]KRU 1D-145: Permit to Drill Application Good morning David, Please submit the logging program for each section of the proposed well. Thank you, Patricia 1 • Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, September 18, 2014 9:12 AM To: Lee, David L (David.L.Lee@conocophillips.com) Subject: KRU 1D-145: Permit to Drill Application Good morning David, Please submit the logging program for each section of the proposed well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. i • TRANSMITTAL LETTER CHECKLIST WELL NAME: / P..ik /J - OS- PTD: YSPTD: oThi - /3? Development _Service Exploratory _Stratigraphic Test Non-Conventional FIELD: 1<L�.4< IAi\A-A POOL: la c �i✓�- , �f5� SA-K Cr( Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation 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. 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