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216-039
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 15130'feet 9014'feet true vertical 6271' feet 9535', 9537'feet Effective Depth measured 15118'feet 8691'feet true vertical 6258'feet 6271'feet Perforation depth:Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" L-80 8853' 6309' Packers and SSSV (type, measured and true vertical depth)8691' 6271' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 325-028 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker Hughes Premier SSSV: None James Ohlinger james.j.ohlinger@conocophillips.com (907) 265-1102CTD Engineer 8855-8993'MD 6309-6332'TVD measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 108' Well Shut-In measured TVD 7-5/8" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-039 50-103-20739-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025604, ADL0025589, ADL0025603 Kuparuk River Field/ Kuparuk Oil Pool KRU 2S-05 Plugs Junk measured Length Liner 8992' 6097' Casing 6335' 6271' 9019' 15118' 2898' 108'Conductor Surface Production 16" 10-3/4" 80' 2927'2565' Burst Collapse Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:27 pm, Jun 11, 2025 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E= James.J.Ohlinger@cop.com Reason: I am the author of this document Location: Date: 2025.06.11 15:08:40-08'00' Foxit PDF Editor Version: 13.1.6 James J. Ohlinger RBDMS JSB 061825 JJL 6/13/25 Page 1/9 2S-05 Report Printed: 5/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/9/2025 12:00 4/9/2025 18:30 6.50 MIRU, MOVE MOB P Release from 2L-304 @ 12:00. Warm up moving system. Back off well. Pickup mats and clean up in front of well. Begin rig move from 2L to 2B Pad. Cross bridge and unhook from Dozer assistant. 4/9/2025 18:30 4/9/2025 21:30 3.00 MIRU, MOVE MOB P Continue rig move to 2S Pad. Pull on pad @ 21:30. 4/9/2025 21:30 4/10/2025 00:00 2.50 MIRU, MOVE MOB P Lay T-mats and cellar containment. Lay dance floor rig mats and transitions. Toolhouse onsite building Laydown area and setting office mud room. 4/10/2025 00:00 4/10/2025 01:30 1.50 MIRU, MOVE MOB P Finish laying out rig mats and transitions. 0.0 0.0 4/10/2025 01:30 4/10/2025 07:30 6.00 MIRU, MOVE RURD P Pull rig over well at 01:30. Spot in support equipment. Complete rig acceptance check list. Accept rig @ 03:00. Take on 8.6# Seawater. Confirm SSV is pumped open. RU circ equipment and hardline. Gather initial pressures (T/I/O) = 1120 / 1100 / 210 psi. Spot bleed trailer by cellar for OA bleeds as needed. Build Deepclean pill. PT hardline to 3500 psi. 0.0 0.0 4/10/2025 07:30 4/10/2025 11:00 3.50 MIRU, WELCTL CIRC P Bleed free gas from Tubing and IA. Pump 35 bbls Deepclean pill. 3 BPM / 504 psi. Chase with 8.6# SW. Increase rate to 4 bpm @ 762 psi , Shut down pumps. SITP = 0 psi. IA = 4 psi. EMW = 8.7#. 0.0 0.0 4/10/2025 11:00 4/10/2025 17:00 6.00 MIRU, WELCTL KLWL P Kill well with 8.8# KWM. Weight up pits to 8.8# while trucking spike fluid to rig // Pump 3bpm @ 333 psi. 0.0 0.0 4/10/2025 17:00 4/10/2025 18:00 1.00 MIRU, WELCTL OWFF P OWFF. Tubing on slight vac. IA has slight flow. Monitor for 45-min. IA not dead. Weight IA sample @ 8.7# heavy. SI and monitor pressures. IA built 6 psi. 0.0 0.0 4/10/2025 18:00 4/10/2025 23:00 5.00 MIRU, WELCTL CIRC P Weigh up pits to 8.8# heavy. Circulate well over to 8.8# heavy KW brine @ 3 BPM / 348 psi. STS volume = 372 bbls. 0.0 0.0 4/10/2025 23:00 4/10/2025 23:45 0.75 MIRU, WELCTL OWFF P OWFF. No flow from Tubing. Slight flow from IA. OA = 280 psi. Bleed off OA pressure. No flow from IA. Monitor for 30-minutes. No flow. 0.0 0.0 4/10/2025 23:45 4/11/2025 00:00 0.25 MIRU, WELCTL RURD P RD circ equipment. Pull tree cap. 0.0 0.0 4/11/2025 00:00 4/11/2025 00:15 0.25 MIRU, WELCTL MPSP P Set BPV. 0.0 0.0 4/11/2025 00:15 4/11/2025 00:30 0.25 MIRU, WELCTL PRTS P PT BPV from below to 1,000 psi. Expected rolling test due to no deep plug, but held 1,000 psi. Potential the +/ - 480' of fill in Tubing/Liner is limiting communication with Reservoir (acting like a plug). 0.0 0.0 4/11/2025 00:30 4/11/2025 05:30 5.00 MIRU, WHDBOP NUND P ND tree. Hang old tree in cellar. Inspect and confirm hanger neck threads to be 4 1/2" IBT. Got 7.5 turns w/ 4 1/2" IBT XO. Function LDS. Set test dart. NU BOP. Measure RKB's. Install riser. 0.0 0.0 4/11/2025 05:30 4/11/2025 07:00 1.50 MIRU, WHDBOP RURD P RU testing equipment. Flood lines. Purge air. Prep floor for initial BOP test. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/26/2025 Page 2/9 2S-05 Report Printed: 5/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/11/2025 07:00 4/11/2025 08:00 1.00 MIRU, WHDBOP BOPE P Perform shell test. Begin Initial BOPE test. Test BOPE to 250/3500 PSI for 5 Min each, Tested UVBR's and LVBR's w/ 3 1/2" test joints. Test annular w/ 3 1/2" test joint. Test blinds rams. Choke valve 8 fail. 0.0 0.0 4/11/2025 08:00 4/11/2025 11:00 3.00 MIRU, WHDBOP RGRP P Choke manifold valve #8 Fail/Pass, replace internals and re-tested. 0.0 0.0 4/11/2025 11:00 4/11/2025 17:00 6.00 MIRU, WHDBOP BOPE P Complete Initial BOPE test. Tested BOPE to 250/3500 PSI for 5 Min each, Tested UVBR's and LVBR's w/ 3 1/2" test joints. Test annular w/ 3 1/2" test joint. Test blinds rams.Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF floor valve and IBOP. Test 3 1/2" EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3000 PSI, after closure = 1600 PSI, 200 PSI attained = 22 sec, full recovery attained = 125 sec. UVBR's = 5 sec, LVBR’s = 4 sec. Annular = 18 sec. Simulated blinds = 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average = 2000 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Brian Bixby. 2 F/P: CMV #8 and UVBR's. Rebuilt and re-tested. 5 hours into the BOP test rock/fill plug in tubing and liner allowed formation pressure to surface. Saw 1,000 psi on IA gauge. Monitor IA pressure and complete BOP test. 0.0 0.0 4/11/2025 17:00 4/11/2025 19:30 2.50 MIRU, WHDBOP RGRP T Exceeded 10 hour BOP test time. On Trouble Time now. F/P on UVBRs. Change out upper VBRs. Re-tested. 0.0 0.0 4/11/2025 19:30 4/12/2025 00:00 4.50 COMPZN, RPCOMP RURD P RD testing equipment. Drain Stack. Pull test dart. MU landing joint. RU and PT circulating equipment for well kill. Load pits with 12.2# KWM (KWM calculated based on IA gauge pressure w/ 8.8# brine hydrostatic to top frac port = 11.9# equivalent). Wait on last truck from 1B for well kill. 0.0 0.0 4/12/2025 00:00 4/12/2025 05:30 5.50 COMPZN, RPCOMP CIRC P Wait for last load of 12.2 KWM. PJSM. Bleed IA down to 0 psi. Build back up to 200 psi. Bring pumps online ramping kill rate up to 3 BPM (pumping through BPV). At 3 BPM, ICP = 520 psi. Circulate 550 bbls of 12.2# KWM down Tubing taking IA returns to tanks. Holding approx. 100 psi backpressure at the choke. Choke pressure = 315 psi. 0.0 0.0 4/12/2025 05:30 4/12/2025 06:00 0.50 COMPZN, RPCOMP OWFF P SD pumps. Confirm 0 psi at surface. OWFF for 30-min. 0.0 0.0 4/12/2025 06:00 4/12/2025 06:30 0.50 COMPZN, RPCOMP MPSP P Equalize and pull BPV 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/26/2025 Page 3/9 2S-05 Report Printed: 5/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/12/2025 06:30 4/12/2025 07:00 0.50 COMPZN, RPCOMP RURD P Prep pipe handling equipment to pull 4 1/2" Tubing Hanger. MU landing joint (3 1/2" IF DP with 4 1/2" IBT XO). 0.0 8,750.0 4/12/2025 07:00 4/12/2025 08:00 1.00 COMPZN, RPCOMP THGR P Screw in TD. Set 10K down. BOLDS. Pull hanger to rig floor. Unseat @ 100K. Drag to floor @ 100K. 8,750.0 8,720.0 4/12/2025 08:00 4/12/2025 08:30 0.50 COMPZN, RPCOMP RURD P L/D landing joint, hanger, and pup. Pull 4 1/2" Full Joint to the floor. RU TEC wire to Halliburton spooler. 8,720.0 8,720.0 4/12/2025 08:30 4/12/2025 19:45 11.25 COMPZN, RPCOMP PULL P Pull 3 1/2" Tubing w/ TEC wire to 2,178'. 8,720.0 2,178.0 4/12/2025 19:45 4/12/2025 21:00 1.25 COMPZN, RPCOMP CIRC P Started pulling wet @ 2,178'. Pump 30 bbl dry job (13.5# pill). 2,178.0 2,178.0 4/12/2025 21:00 4/12/2025 23:30 2.50 COMPZN, RPCOMP PULL P Finish pulling 3 1/2" Tubing w/ TEC wire pre-rig cut @ 8,750'. Clean cut. Cut Joint = 3.03' long. Total clamps recovered = 283 (1 XO clamp., 2 SS bands, 9 mid-collar clamps, 271 cross collar clamps). 2,178.0 0.0 4/12/2025 23:30 4/13/2025 00:00 0.50 COMPZN, RPCOMP RURD P Clean and clear rig floor. Unload clamps and spools of TEC wire. 0.0 0.0 4/13/2025 00:00 4/13/2025 04:30 4.50 COMPZN, RPCOMP RURD P Prep to run 3 1/2" DP. Set Wear Ring. Clean and clear rig floor. Load Baker Fishing Tools. *****************At 03:15 we had a dropped object incident. Baker Toolbox was loaded on pallet cart. When raising cart to pipe shed level the pallet edge caught on the cart rails at the pit level. Toolbox fell off the pallet to the ground (approx. 17'). Box weighed approx. 200#. Had safety standdown and discussed incident with crews. Discussed action items and mitigation measures to prevent going forward. ******************. Finish Loading DC's. 0.0 0.0 4/13/2025 04:30 4/13/2025 05:30 1.00 COMPZN, RPCOMP BHAH P MU BHA #1 (3 1/2" Overshot w/ pack- off). 0.0 219.0 4/13/2025 05:30 4/13/2025 15:00 9.50 COMPZN, RPCOMP PULD P Single in hole with BHA #1 (Overshot) on 3 1/2" DP to just above top of fish @ 8,750'. 219.0 8,736.0 4/13/2025 15:00 4/13/2025 16:30 1.50 COMPZN, RPCOMP CIRC P Circulate SxS // Pump 5 bpm @ 1371 psi 8,736.0 8,736.0 4/13/2025 16:30 4/13/2025 17:30 1.00 COMPZN, RPCOMP FISH P Obtain parameters. PUW = 150K. SOW = 86K. Fully swallow fish to 8,750' ORKB (8,750' N3 RKB). PU 20K over to confirm latched. Pull fish free @ 185K total. 8,736.0 8,750.0 4/13/2025 17:30 4/13/2025 23:30 6.00 COMPZN, RPCOMP CIRC P Circ BU to clear potential packer gas. Packed off. Moved pipe and adjust pump rate to clear. Circ BU @ 1.5- 2BPM. Packed off again at 2 BPM. Possibly resetting packer element at 2 BPM and higher. Limit circ rate to 1.5 BPM for BU. 1.5 BPM @ 330 psi. Circulated until consistent 12.2# KWF around. 8,750.0 8,718.0 4/13/2025 23:30 4/14/2025 00:00 0.50 COMPZN, RPCOMP OWFF P OWFF for 30-min. Slight flow. Extend moniitor to let well balance. 8,718.0 8,718.0 4/14/2025 00:00 4/14/2025 00:45 0.75 COMPZN, RPCOMP OWFF P Cont. OWFF to see if slight flow dies off. At 12:45 flow started to increase slightly. Decision made to circulate while weighing up to 12.3#. 8,718.0 8,718.0 Rig: NORDIC 3 RIG RELEASE DATE 4/26/2025 Page 4/9 2S-05 Report Printed: 5/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/14/2025 00:45 4/14/2025 06:45 6.00 COMPZN, RPCOMP CIRC P Circ 12.2# @ 1 BPM / 458 psi while waiting on Pits #2 and #3 to be dusted up to 12.3#. Add duo-vis to prevent barite settling in pits. At 03:30AM pits up to 12.3#. Circ. 12.3# STS @ 1 BPM / xxx psi. Rate limited due to packer elements resetting at 1.5 BPM causing pack-off/pressure spikes. 8,718.0 8,718.0 4/14/2025 06:45 4/14/2025 08:00 1.25 COMPZN, RPCOMP OWFF P SD pumps. OWFF for 30-min. // Pump 30 bbl dry job 2 ppg over 8,718.0 8,718.0 4/14/2025 08:00 4/14/2025 14:00 6.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #1 (Spear ) + Fish (Packer + Tubing Tail). 8,718.0 1,000.0 4/14/2025 14:00 4/14/2025 16:00 2.00 COMPZN, RPCOMP CIRC P Circulate B/U due to mud flowing over top of pipe 1,000.0 1,000.0 4/14/2025 16:00 4/14/2025 17:00 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA# 1 and fish 1,000.0 219.0 4/14/2025 17:00 4/14/2025 19:00 2.00 COMPZN, RPCOMP BHAH P Lay down BHA# 1 and fish, inspect. Recovered Cut Joint + Packer + Tubing Tail. Recovered all packer slips. Slight damage on element protector ring. Cut Joint = 6.64'. Good cut. 219.0 0.0 4/14/2025 19:00 4/14/2025 22:00 3.00 COMPZN, RPCOMP BHAH P Load 2 7/8" handling tolls and cleanout tools (Baker Motor, Mill, 2 7/8" DP). MU BHA #2 (Cleanout) 0.0 463.0 4/14/2025 22:00 4/15/2025 00:00 2.00 COMPZN, RPCOMP TRIP P TIH w/ BHA #2 (Cleanout) to 2,000' 463.0 2,000.0 4/15/2025 00:00 4/15/2025 03:00 3.00 COMPZN, RPCOMP TRIP P Cont. TIH w/ BHA #2 (Cleanout) to just above tieback sleeve. PUW = 164K. SOW = 82K. 2,000.0 8,802.0 4/15/2025 03:00 4/15/2025 08:00 5.00 COMPZN, RPCOMP WASH P Kelly Up. TIH slowly. See top of Tieback sleeve @ 8,840' See top of 4 1/2" liner @ 8,877'. Tag @ 8884'. Set 7K down. PU off tag. Obtain parameters. Function Test motor/mill ramping up rates in 0.5 bpm increments. 1 BPM = 580 psi. 1.5 BPM = 780 psi. 2 BPM = 940 psi. 2.5 BPM = 1030 psi. 3 BPM @ 1550 psi. Cleanout 4 1/2" Liner F/ tag @ 8884 T/ 9050' w/ no issue very little fine sand 8,802.0 9,050.0 4/15/2025 08:00 4/15/2025 09:30 1.50 COMPZN, RPCOMP CIRC P Pump 15 bbls Hi vis pill around bha and drop well commander ball and open tool pump 75 bbls Hi Vis sweep @ 6 bbls min w clean 12.3 mud /1650 psi All good showed small sand returns and shut down monitor well 15 mis/pump 30 bbl dry job 9,050.0 9,050.0 4/15/2025 09:30 4/15/2025 15:00 5.50 COMPZN, RPCOMP TRIP P POOH, PUW=50K 9,050.0 463.0 4/15/2025 15:00 4/15/2025 16:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA # 2 and M/U BHA # 3 w/ 4 1/2"Mechancal cutter 463.0 239.0 4/15/2025 16:00 4/15/2025 18:00 2.00 COMPZN, RPCOMP TRIP P RIH to 3574, PUW=77K. SOW=67K 239.0 4/15/2025 18:00 4/15/2025 20:30 2.50 COMPZN, RPCOMP SLPC P Cut and Slip Drilling line /Service Rig 3,574.0 3,574.0 4/15/2025 20:30 4/15/2025 23:30 3.00 COMPZN, RPCOMP TRIP P Continue in hole, BHA #3 3574 to 9021, PUW-165K, SOW=75K 3,574.0 9,021.0 4/15/2025 23:30 4/16/2025 00:00 0.50 COMPZN, RPCOMP CPBO P Attempt cut at 9021. Pump online. Hard to get base line motor numbers with cutter below. Working rate up to 2 - 3 BPM. @ 2400 to 3600 PSI. Get pressure drop from 3200 to 1500 PSI 9,021.0 9,021.0 4/16/2025 00:00 4/16/2025 00:30 0.50 COMPZN, RPCOMP CPBO P Continue to work at cutting 4 1/2". No good indication of cut 9,021.0 9,021.0 Rig: NORDIC 3 RIG RELEASE DATE 4/26/2025 Page 5/9 2S-05 Report Printed: 5/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/16/2025 00:30 4/16/2025 02:30 2.00 COMPZN, RPCOMP CIRC P Circ BU @ 3 BPM. ICP 1800 PSI, OWFF 9,021.0 9,021.0 4/16/2025 02:30 4/16/2025 08:30 6.00 COMPZN, RPCOMP TRIP P POOH WET, BHA #3, PUW=170K 9,021.0 239.0 4/16/2025 08:30 4/16/2025 10:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA #3 and 2 7/8" Pac D.P. M/U BHA #4 w/Baker spear Baker cutter showed good indication that it cut 4 1/2"tubing posted pictures on the well file report 239.0 223.0 4/16/2025 10:00 4/16/2025 15:00 5.00 COMPZN, RPCOMP TRIP P RIH T/ 8820' freeTq is @ 8000 t/9000k up wt173k dwt 80k 223.0 8,781.0 4/16/2025 15:00 4/16/2025 18:00 3.00 COMPZN, RPCOMP CIRC P Condition Mud with 776 lub add 2% t/3% lub due to torque limit on 3 1/2" D.P. IF (Free torque needs to be around 6000k before back off) 8,781.0 8,781.0 4/16/2025 18:00 4/17/2025 00:00 6.00 COMPZN, RPCOMP CIRC P Crew change. Continue adding Lube 776 to active system. Plan to get to 2%. Recip and rotate drill string. Circulate 3 BPM @797 PSI. At midnight PUW=115K. SOW=110. Free torque down to 7K without reciping 8,781.0 8,781.0 4/17/2025 00:00 4/17/2025 03:00 3.00 COMPZN, RPCOMP CIRC P Continue adding Lube 776 to active system. Plan to get to 2%. Recip and rotate drill string. Circulate 3 BPM @797 PSI. At midnight PUW=115K. SOW=110. Free torque down to 7K without reciping 8,781.0 8,781.0 4/17/2025 03:00 4/17/2025 04:00 1.00 COMPZN, RPCOMP FISH P Obtain parameters. PUW=137K, SOW=93K, 10 RPM @ 4.8K FT. set down, PUH to 175K. Jars fire. Slack off to 150K. Rotate to left while recipiping pipe to left. 3 turns 5K, 4 turns 6 K. 13 total turns to left 5.7 K . PUH puw=50. Set back down @ 8843. PUH index to left. Set down again @ 8843. KD, Blow down top drive 8,781.0 8,846.0 4/17/2025 04:00 4/17/2025 11:30 7.50 COMPZN, RPCOMP TRIP P POOH Slow Due to High winds 8,846.0 223.0 4/17/2025 11:30 4/17/2025 14:00 2.50 COMPZN, RPCOMP BHAH P L/D BHA #4 w/ 14.1' Index Sleeve fish and M/U BHA # 5 w/ Baker Packer mill and service rig 223.0 255.0 4/17/2025 14:00 4/17/2025 18:30 4.50 COMPZN, RPCOMP TRIP P RIH Slow w/ Phase 2 Conditions Winds gusting to 50-60 mph 255.0 8,851.0 4/17/2025 18:30 4/17/2025 21:00 2.50 COMPZN, RPCOMP MILL P Kelley up, Tag up @ 8851 Set down 5 K PUW 123K SOW 80K, ROT 105K RPM 80 FT 6-8K Pumping @ 4 BBLS Pres 1360 Start Milling w/ WOB 8851 8,851.0 8,855.0 4/17/2025 21:00 4/18/2025 00:00 3.00 COMPZN, RPCOMP WAIT P Phase 3 field wide. Pull up to 8844'. Circ BU @ 4 BPM @ 1210 PSI to clean well bore. Go to 1 BPM @ 446 PSI Wait on weather 8,855.0 8,844.0 4/18/2025 00:00 4/19/2025 00:00 24.00 COMPZN, RPCOMP WAIT P Wait on Phase 3 weather conditions to improve 8,844.0 8,840.0 4/19/2025 00:00 4/19/2025 06:00 6.00 COMPZN, RPCOMP WAIT P Wait on Phase 3 weather 8,840.0 4/19/2025 06:00 4/19/2025 12:00 6.00 COMPZN, RPCOMP MILL P PJSM / Continue Milling F/ 8855' UW 128K SOW 90K ROT 105K SPM 4 BBLS min w/1250 PSI mILL T/ 8856' P/U OFF BOTTOM 8,855.0 8,856.0 4/19/2025 12:00 4/19/2025 14:00 2.00 COMPZN, RPCOMP CIRC P CIRC OUT GAS BUBBLE OUT ALL GOOD NO ISSUE MUD WT IN 12.3 T/ 12.2+ OUT 8,855.0 8,855.0 4/19/2025 14:00 4/19/2025 15:30 1.50 COMPZN, RPCOMP MILL P CONTINUE MILLING F/ 8856' T/ 8857' UW 128K SOW 90K ROT 105K SPM 160/ 4 BBLS MIN W/1250 PSI 8,856.0 8,857.0 Rig: NORDIC 3 RIG RELEASE DATE 4/26/2025 Page 6/9 2S-05 Report Printed: 5/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/19/2025 15:30 4/19/2025 16:30 1.00 COMPZN, RPCOMP CIRC P P/U OFF BOTTOM CIRC AGAIN DUE TO #2 GAS BUBBLE SHOWING SIGNS RUBBER AND SCALE 8,857.0 8,857.0 4/19/2025 16:30 4/19/2025 18:30 2.00 COMPZN, RPCOMP MILL P CONTINUE MILLING F/ 8857' T/ 8858 UW 128K SOW 90K ROT 105K SPM 165/4 BBLS MIN W/1250 PSI 8,857.0 8,858.0 4/19/2025 18:30 4/19/2025 19:30 1.00 COMPZN, RPCOMP MILL P Unable to make headway beyond 8858, Try dry milling. Milling at different pump rates. 85,858.0 8,858.0 4/19/2025 19:30 4/19/2025 21:30 2.00 COMPZN, RPCOMP CIRC P Circulate 39 BBl hi vis sweep. Chase @ 8 BPM @ 3270PSI 8,858.0 8,858.0 4/19/2025 21:30 4/19/2025 22:00 0.50 COMPZN, RPCOMP CIRC P Pump 17 BBl dry fob 8,858.0 8,858.0 4/19/2025 22:00 4/19/2025 22:30 0.50 COMPZN, RPCOMP OWFF P Observe well for flow - 30 Min 8,858.0 8,858.0 4/19/2025 22:30 4/20/2025 00:00 1.50 COMPZN, RPCOMP TRIP P Trtip out of well, PUW=142K 8,858.0 6,470.0 4/20/2025 00:00 4/20/2025 00:30 0.50 COMPZN, RPCOMP TRIP P Continue out of well 6,470.0 6,466.0 4/20/2025 00:30 4/20/2025 01:00 0.50 COMPZN, RPCOMP TRIP P Hang up @ 6466' w 30K overpull. Able to RIH Kelly up. Try to index pipe. No go. Work pipe. Get free. Dry ream 6470 to 6438 clean. 6,466.0 6,438.0 4/20/2025 01:00 4/20/2025 05:00 4.00 COMPZN, RPCOMP TRIP P Continue POOH 6,438.0 223.0 4/20/2025 05:00 4/20/2025 06:30 1.50 COMPZN, RPCOMP BHAH P L/D BHA # 5 223.0 0.0 4/20/2025 06:30 4/20/2025 07:30 1.00 COMPZN, RPCOMP BOPE P Perform Bi Weekly BOPE test 0.0 0.0 4/20/2025 07:30 4/20/2025 08:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA # 6 w/ Baker spear 0.0 220.0 4/20/2025 08:30 4/20/2025 12:00 3.50 COMPZN, RPCOMP TRIP P RIH T/ 8855' 220.0 8,859.0 4/20/2025 12:00 4/20/2025 12:30 0.50 COMPZN, RPCOMP FISH P Latch up on Fish @ 8859' Swallow 3' up wt 143k fish on up wt 148k Fish on Stand back 180' D.P no swabbing effect and monitor well 5 mins All good 8,859.0 8,648.0 4/20/2025 12:30 4/20/2025 15:30 3.00 COMPZN, RPCOMP CIRC P CBU @ 3 BBLS w/ 1000 PSI All good Monitor well 15 mins and pump 15 bbls dry job . 8,648.0 8,648.0 4/20/2025 15:30 4/20/2025 17:00 1.50 COMPZN, RPCOMP TRIP P POOH SLOW DUE TO SWABBING PUMPING OUT OF HOLE 10K 30K DRAGON OVER Pull through tight spot @ 6474 8,648.0 6,474.0 4/20/2025 17:00 4/21/2025 00:00 7.00 COMPZN, RPCOMP TRIP P Pull through tight spot @ 6474, Reduce pump rate to 2 BPM work through 6,474.0 5,597.0 4/21/2025 00:00 4/21/2025 01:30 1.50 COMPZN, RPCOMP TRIP P Continue pumping out of well 5,597.0 5,000.0 4/21/2025 01:30 4/21/2025 03:30 2.00 COMPZN, RPCOMP SLPC P PJSM, Slip and cut drilling line 5,000.0 5,000.0 4/21/2025 03:30 4/21/2025 04:00 0.50 COMPZN, RPCOMP TRIP P Continue out of well, PUW=95K 5,000.0 4,860.0 4/21/2025 04:00 4/21/2025 09:30 5.50 COMPZN, RPCOMP TRIP P Hole fill back inline. Up in more verticle wellbore area. Blow down top drive. Come out on elevators 4,860.0 223.0 4/21/2025 09:30 4/21/2025 12:00 2.50 COMPZN, RPCOMP BHAH P L/D BHA #6 and Lower completion assy Baker PKR Assy and 3 full 4 1/2" 563 Jts and 1 cut Jt 27.87' 223.0 0.0 4/21/2025 12:00 4/21/2025 13:00 1.00 COMPZN, RPCOMP SVRG P Clean up Foor Prepare to P/U BHA # 7 w/ clean out run Lower fish assembly in pictures in slide 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/26/2025 Page 7/9 2S-05 Report Printed: 5/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/21/2025 13:00 4/21/2025 15:00 2.00 COMPZN, RPCOMP BHAH P M/U BHA #7 W/ Clean out Run w/ 7 5/8" casing scraper 0.0 276.7 4/21/2025 15:00 4/21/2025 21:30 6.50 COMPZN, RPCOMP TRIP P RIH T/ 8800' 276.7 8,800.0 4/21/2025 21:30 4/22/2025 00:00 2.50 COMPZN, RPCOMP WASH P Break circulation @ 4 bbls min w/ pres @ 1350 PSI Tag Fill @ 8928 Cont Washing t/ top of stub 9025' P/U wash and ream f/ 8950' 9025' and Pumped 31 BBls High Vis sweep chase W/ 118 Sks w/ 8950 PSI Work string 80' 8,800.0 9,025.0 4/22/2025 00:00 4/22/2025 01:30 1.50 COMPZN, RPCOMP CIRC P Continue circulating well clean 7 BPM @ 2770 PSI 9,025.0 9,000.0 4/22/2025 01:30 4/22/2025 02:00 0.50 COMPZN, RPCOMP CIRC P Pump 17 BBL 14.1 PPG dry job. 9,000.0 9,000.0 4/22/2025 02:00 4/22/2025 02:30 0.50 COMPZN, RPCOMP OWFF P OWFF 30 min 9,000.0 9,000.0 4/22/2025 02:30 4/22/2025 07:30 5.00 COMPZN, RPCOMP TRIP P Trip out of well, PUW=145K. Pull wet pipe 9,000.0 3,717.0 4/22/2025 07:30 4/22/2025 08:30 1.00 COMPZN, RPCOMP CIRC P Condition mud and circulate. Pump 20 BBl dry job 3,717.0 3,717.0 4/22/2025 08:30 4/22/2025 10:30 2.00 COMPZN, RPCOMP TRIP P Continue out of well 3,717.0 276.0 4/22/2025 10:30 4/22/2025 13:30 3.00 COMPZN, RPCOMP BHAH P Lay down BHA #7, Clean Magnets and boot basket 276.0 0.0 4/22/2025 13:30 4/22/2025 14:00 0.50 COMPZN, RPCOMP BHAH P M/U CIBP, BHA #8 0.0 10.0 4/22/2025 14:00 4/22/2025 23:00 9.00 COMPZN, RPCOMP TRIP P TIH F/ 10' T/ 9000'. PUW=140K, SOW=88K. 10.0 9,000.0 4/22/2025 23:00 4/23/2025 00:00 1.00 COMPZN, RPCOMP SVRG P Call out Baker rep. Service rig. Grease TD & blocks. 9,000.0 4/23/2025 00:00 4/23/2025 01:00 1.00 COMPZN, RPCOMP MPSP P K/U, TIH. Set CIBP top @ 9014'. Push pull 50K up & down. Release from plug. L/D working single T / 9000' 9,014.0 9,000.0 4/23/2025 01:00 4/23/2025 01:30 0.50 COMPZN, RPCOMP RURD P Install TIW, R/U testing equipment. 9,000.0 9,000.0 4/23/2025 01:30 4/23/2025 02:30 1.00 COMPZN, RPCOMP PRTS P PT 7 5/8" CSG T/ CIBP @ 9014' T/ 2500 PSI for 30 Min. 9,000.0 9,000.0 4/23/2025 02:30 4/23/2025 03:00 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 9,000.0 9,000.0 4/23/2025 03:00 4/23/2025 03:15 0.25 COMPZN, RPCOMP CIRC P Pump 31 Bbls hi vis pill @ 2 BPM, 1140 PSI. 9,000.0 9,000.0 4/23/2025 03:15 4/23/2025 04:30 1.25 COMPZN, RPCOMP DISP P Displace well w/ 466 Bbls of seawater @ 7 BPM, 2250 PSI 9,000.0 9,000.0 4/23/2025 04:30 4/23/2025 05:00 0.50 COMPZN, RPCOMP OWFF P OWFF, B/D TD. 9,000.0 9,000.0 4/23/2025 05:00 4/23/2025 17:30 12.50 COMPZN, RPCOMP PULD P LDDP F/ 9000' T/ surface', PUW=143K. Well getting out of balance. Stop and circulate a few times. 9,000.0 0.0 4/23/2025 17:30 4/23/2025 18:30 1.00 COMPZN, RPCOMP RURD P Crew change out. Pull wear bushing. 0.0 0.0 4/23/2025 18:30 4/23/2025 19:00 0.50 COMPZN, RPCOMP RURD P C/O handling equipment T/ 4 1/2". 0.0 0.0 4/23/2025 19:00 4/23/2025 22:00 3.00 COMPZN, RPCOMP RURD P R/U SLB spooling unit w/ gauge wire, string over sheave. Load cannon clamps onto RF. Verify joint count & jewelry running order. 0.0 0.0 4/23/2025 22:00 4/23/2025 22:30 0.50 COMPZN, RPCOMP SFTY P PJSM w/ Baker, SLB & rig crew on 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/26/2025 Page 8/9 2S-05 Report Printed: 5/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/23/2025 22:30 4/23/2025 23:00 0.50 COMPZN, RPCOMP PUTB P M/U 4 1/2" Maxwell centralizer joints. Egged the 3rd joint. L/D bad joint. M/U Tq on 4 1/2" Hyd 563 = 3800 Ft/lbs w/ Best'O'Life 2000 AG dope. Mobilize spare Maxwell centralizer joint. 0.0 82.0 4/23/2025 23:00 4/24/2025 00:00 1.00 COMPZN, RPCOMP SVRG P Service rig. Service TBG tongs. Troubleshoot torque gauge. Strap & drift new Maxwell centralizer joint. 82.0 82.0 4/24/2025 00:00 4/24/2025 01:30 1.50 COMPZN, RPCOMP PUTB P RIH w/ last Maxwell centralizer joint. X- nipple, Packer, 3 joints, Gauge Mandrel & SOV T/ 277'. M/U Tq on 3 1/2", 9.3#. L-80, Hyd 563 = 2900 Ft/Lbs w/ Best'O'Life 2000 AG dope. 82.0 277.0 4/24/2025 01:30 4/24/2025 03:00 1.50 COMPZN, RPCOMP RURD P Hang sheave w/ wire in derrick. Connect gauge. PT gauge T/ 5000 PSI for 10 Min. 277.0 277.0 4/24/2025 03:00 4/24/2025 18:30 15.50 COMPZN, RPCOMP PUTB P Cont RIH w/ 3 1/2" Hyd 563 completion, installing cannon clamp on each connection F/ 277' T/ 8776'. M/U space out 9.72', 6.11'. M/U joint # 278. RIH T/ 8822'. PUW=102K, SOW=70K. 277 Cross Coupling Cannon Clamps Run. 277.0 8,822.0 4/24/2025 18:30 4/24/2025 19:45 1.25 COMPZN, RPCOMP PULD P M/U landing joint to hanger. M/U hanger T/ string. K/U. 8,822.0 8,823.0 4/24/2025 19:45 4/24/2025 21:30 1.75 COMPZN, RPCOMP CRIH P Circ 260 CI seawater @ 3.5 BPM, 300 PSI. Chased w/ 15 Bbls neat seawater. Terminate control line through hanger. PT hanger termination T/ 5000 PSI for 10 Min. 8,823.0 8,823.0 4/24/2025 21:30 4/24/2025 22:30 1.00 COMPZN, RPCOMP PUTB P RIH land hanger w/ bottom of mule shoe @ 8853' ORKB. RILDS 8,823.0 8,853.1 4/24/2025 22:30 4/24/2025 22:45 0.25 COMPZN, RPCOMP PRTS P PT hanger seals T/ 5000 PSI for 10 Min. 8,853.1 8,853.1 4/24/2025 22:45 4/24/2025 23:00 0.25 COMPZN, RPCOMP RURD P R/D circ equipment of top of landing joint. Drop ball & rod. 8,853.1 8,853.1 4/24/2025 23:00 4/25/2025 00:00 1.00 COMPZN, RPCOMP RURD P R/U testing equipment for TBG & IA. 8,853.1 8,853.1 4/25/2025 00:00 4/25/2025 00:15 0.25 COMPZN, RPCOMP RURD P R/U testing equipment on TBG & IA. 8,853.1 8,853.1 4/25/2025 00:15 4/25/2025 01:00 0.75 COMPZN, RPCOMP PACK P Pressure up to set Premier packer. Saw initial shear @1750 PSI. Second shear @ 2400 PSI. Final shear @ 2875 PSI. Pressure up T/ 3500 PSI & hold for 30 Min. 8,853.1 8,853.1 4/25/2025 01:00 4/25/2025 02:00 1.00 COMPZN, RPCOMP PRTS P Bleed TBG T/ 1500 PSI. PT IA T/ 2500 PSI for 30 Min. Dump TBG PSI, shear out SOV. Pump down IA @ 2 BPM, 475 PSI. 8,853.1 8,853.1 4/25/2025 02:00 4/25/2025 02:30 0.50 COMPZN, RPCOMP RURD P R/D, B/D TBG testing equipment. 8,853.1 8,853.1 4/25/2025 02:30 4/25/2025 03:00 0.50 COMPZN, RPCOMP MPSP P Set HP BPV 8,853.1 8,853.1 4/25/2025 03:00 4/25/2025 04:00 1.00 COMPZN, RPCOMP PRTS P Crew change out. PT BPV T/ 1000 PSI for 10 Min 8,853.1 0.0 4/25/2025 04:00 4/25/2025 04:30 0.50 COMPZN, WHDBOP RURD P B/D, R/D IA testing equipment. 0.0 0.0 4/25/2025 04:30 4/25/2025 06:00 1.50 COMPZN, WHDBOP NUND P Drain air boot, Pull riser. L/D Mouse hole. N/D BOP rack back 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/26/2025 Page 9/9 2S-05 Report Printed: 5/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/25/2025 06:00 4/25/2025 11:00 5.00 COMPZN, WHDBOP NUND P Nipple up tree adapter flange. Terminate SLB gauge wire through adapter flange port. PT void 5000 PSI / 10 min. Orient and install tree. M/U tree to adapter flange. Rig up U-tube manifold 0.0 0.0 4/25/2025 11:00 4/25/2025 13:00 2.00 COMPZN, WHDBOP FRZP P R/U LRS. PT lines. PT Tree 250 / 5000 - Good. Pull BPV. Line up LRS down IA taking returns from tubing. 2 BPM ICP=750 PSI, Pump 90 BBls.. FCP=900 PSI 0.0 0.0 4/25/2025 13:00 4/25/2025 13:15 0.25 COMPZN, WHDBOP RURD P Shut down - Rig down LRS. Blow down rig lines 0.0 0.0 4/25/2025 13:15 4/25/2025 14:30 1.25 COMPZN, WHDBOP RURD P U-tube well one hour, B/D lines. 0.0 0.0 4/25/2025 14:30 4/25/2025 15:30 1.00 COMPZN, WHDBOP RURD P B/D, R/D circ equipment. Secure tree & cellar. 0.0 0.0 4/25/2025 15:30 4/25/2025 17:30 2.00 DEMOB, MOVE DMOB P R/D hardline. Demob, move auxiliary equipment away from rig. 0.0 0.0 4/25/2025 17:30 4/25/2025 19:00 1.50 DEMOB, MOVE DMOB P Pull sub off well and stage on pad. 0.0 0.0 4/25/2025 19:00 4/26/2025 00:00 5.00 DEMOB, MOVE OTHR P Perform BWM. Rig released @ 0:00 Hrs. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/26/2025 Page 1/2 2S-05 Report Printed: 5/21/2025 WSR Historical - QC JOB Well Type Development Orig KB/RT (ft) 147.50 Well Status PROD Legal WellName 2S-05 API / UWI 5010320739 Field Name KUPARUK RIVER UNIT Start Date 2/15/2025 06:00 End Date Secondary Job Type BARRIER TESTING Objective Final Job Status CONTINUOUS Primary Wellbore Affected 2S-05 NETWORK Job Type Project Desc Common WellName Cost Type Network/Order Number ACQUIRE DATA 2S-05 RWO - Wells 2S-05 Expense WO 10463135 UNIT/RIG: PW ELECTRIC LINE AKE-305 - Priority Rig Accept Date 5/20/2025 Rig Release Date 5/20/2025 Rig Supervisor WORTHINGTON, BRYCE,Wells Supervisor Title Wells Supervisor Company CPAI Phone W… N/A Mobile N/A Pager N/A Job scope, work string information, or noted if job is performed during drilling operations Comment Daily Operations Report Start Date 5/20/2025 05:30 Report End Date 5/20/2025 18:00 Status at Reporting Time Reported 05/21/2025 Time Log Hrs (hr) 12.50 ZX Code ZX26 Perforating this data box is reviewed daily by engineers, supervisors, and techs. Last 24hr Summary PERFORATED FOLLOWING DEPTHS W/ GEO-DYNAMICS 2.5", 60 DEG PHASE 6 SPF GUN #2: 8963'-8983' GUN #3: 8943'-8963' HAD TO TRACTOR STARTING AROUND ~8840' LOG CORRELATED TO AK E-LINE JEWELRY LOG DATED 19-MAY-2025 WELLHEAD LEFT SECURE JOB CONTINUED 21-MAY-2025 General Remarks INITIAL T/I/O=1300/1575/220 FINAL T/I/O=1300/1575/220 weather related data when and if weather has affect on job Weather Wind T (°F) CONTRACTOR Supervisor Title Company Phone Work Mobile Pager COLLINS, SHAPHAN,E-Line Engineer E-Line Engineer AKE N/A N/A N/A TIME LOG - enter a Vendor if trouble time occurs during operation Start Time End Time Dur (hr) Cum Dur (hr) Major Equip Activity Code Time P-T-X Operation Vendor (NPT) Wellbore 05:30 06:30 1.00 1.00 EW TRAV P MEET W/ WSL AT F-WING, TRAVEL TO 2S-05 2S-05 06:30 07:00 0.50 1.50 EW TRAV P CONTACT DSO, ARRIVE ON LOCATION, INSPECT WELLSITE & EQUIPMENT (ALREADY SPOTTED) 2S-05 07:00 08:45 1.75 3.25 EW RURD P HOLD PJSM W/ WELLTEC, CRANE OPERATOR, & AK E-LINE CREWS, CYCLE SWAB & CHECK PRESSURES, BLEED OFF & REMOVE TREECAP, INSTALL FUSIBLE & NOTIFY DSO, MAKE UP & OP CHECK TOOLSTRING FOLLOWING WELLTEC PERF CHECKLIST, REMOVE SAFETY KEY & ARM GUN, STAND UP TOOLSTRING & LUB 2S-05 08:45 09:15 0.50 3.75 EW RURD P STAB ONTO WELLHEAD, PT PCE FROM 200#LP-3000#HP 2S-05 09:15 09:30 0.25 4.00 EW ELNE P OPEN SWAB, RIH W/ 1-7/16" CHD (1" FN), WELLTEC ERD, SWIVEL, & TRACTOR, CCL, SAFE SUB, SWITCH SUB, 2.5" GUN (LOADED 20' @ 60 DEG PHASING, 6 SPF W/ 11.5 GRAM CHARGES) (OAL=57', OAW=500#, MAX OD=2.66") 2S-05 09:30 10:30 1.00 5.00 EW ELNE P WELLTEC PERFORM COMM CHECK @ 1000', CONTINUE RIH 2S-05 10:30 10:45 0.25 5.25 EW ELNE P SWAP TOOL POWER TO WELLTEC & BEGIN TRACTORING FROM 8840' 2S-05 10:45 11:00 0.25 5.50 EW ELNE P LOG CORRELATION PASS UP FROM 8990'-8650', TRACTOR BACK DOWN, LOG INTO POSITION W/ PERF DEPTH=8963'-8983', CCL-TOP SHOT=7.0', CCL STOP DEPTH=8956.0', FIRE GUN W/ GOOD INDICATION AT SURFACE, LOG OUT OF POSITION, TOOLSTRING HUNG UP PULLING GUN INTO TT 2S-05 11:00 12:15 1.25 6.75 EW ELNE P TRACTOR DOWN 20', ABLE TO PULL CLEAN INTO TT, POOH 2S-05 12:15 13:30 1.25 8.00 EW ELNE P TOOLSTRING AT SURFACE, CLOSE SWAB, BLEED DOWN PCE, UNSTAB @ QTS & VERIFY GUN FIRED, LAY DOWN LUB & TOOLSTRING, PERFORM SURFACE MAINT & TOOL CHECKS, REMOVE SAFETY KEY & ARM GUN 2S-05 13:30 13:45 0.25 8.25 EW ELNE P STAND UP LUB & TOOLSTRING, STAB ONTO & PT QTS 2S-05 Job: ACQUIRE DATA Report Date: 5/20/2025 Rig: PW ELECTRIC LINE AKE-305 - Priority *filters for Intervention jobs only Page 2/2 2S-05 Report Printed: 5/21/2025 WSR Historical - QC TIME LOG - enter a Vendor if trouble time occurs during operation Start Time End Time Dur (hr) Cum Dur (hr) Major Equip Activity Code Time P-T-X Operation Vendor (NPT) Wellbore 13:45 14:00 0.25 8.50 EW ELNE P OPEN SWAB, RIH W/ 1-7/16" CHD (1" FN), WELLTEC ERD, SWIVEL, & TRACTOR, CCL, SAFE SUB, SWITCH SUB, 2.5" GUN (LOADED 20' @ 60 DEG PHASING, 6 SPF W/ 11.5 GRAM CHARGES) (OAL=57', OAW=500#, MAX OD=2.66") 2S-05 14:00 15:00 1.00 9.50 EW ELNE P WELLTEC PERFORM COMM CHECK @ 1000', CONTINUE RIH 2S-05 15:00 15:15 0.25 9.75 EW ELNE P SWAP TOOL POWER TO WELLTEC & BEGIN TRACTORING FROM 8900' 2S-05 15:15 15:30 0.25 10.00 EW ELNE P LOG CORRELATION PASS UP FROM 8990'-8650', TRACTOR BACK DOWN, LOG INTO POSITION W/ PERF DEPTH=8943'-8963', CCL-TOP SHOT=7.0', CCL STOP DEPTH=8936.0', FIRE GUN W/ GOOD INDICATION AT SURFACE, LOG OUT OF POSITION 2S-05 15:30 16:15 0.75 10.75 EW ELNE P WELLTEC UNABLE TO COMMUNICATE W/ TRACTOR AFTER FIRING, POOH 2S-05 16:15 17:15 1.00 11.75 EW RURD P TOOLSTRING AT SURFACE, CLOSE SWAB, BLEED OFF & DRAIN PCE, UNSTAB & VERIFY GUN FIRED, LAY DOWN LUB & TOOLSTRING, INSTALL & PT TREECAP, REMOVE FUSIBLE & NOTIFY DSO 2S-05 17:15 18:00 0.75 12.50 EW TRAV P TRAVEL TO F-WING, SYNC WELLVIEW 2S-05 Job: ACQUIRE DATA Report Date: 5/20/2025 Rig: PW ELECTRIC LINE AKE-305 - Priority *filters for Intervention jobs only Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:2S-05 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post rig, Set DV, Pulled B&R/ RHC 2S-05 5/12/2025 fergusp Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.25 27.5 107.5 107.5 62.50 H-40 SURFACE 10 3/4 9.95 28.5 2,927.2 2,565.1 45.50 L-80 HYD 563 INTERMEDIATE 7 5/8 6.88 26.9 9,019.4 6,335.2 29.70 L-80 Hyd 563 LINER 4 1/2 3.96 9,021.0 15,117.6 6,271.2 12.60 L-80 Hyd 563 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.1 Set Depth … 8,853.1 String Max No… 3 1/2 Set Depth … 6,308.5 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 25.1 25.1 0.00 Hanger 10.850 11' x 4.5" TUBING HANGER, HYD563 Top Thread H Profile Camero n C-SRL- CL 3.900 8,549.2 6,229.4 71.21 Mandrel – GAS LIFT 5.590 3-1/2" FO-1 KBMG, GLM SLB KBMG 2.920 8,575.9 6,237.9 71.90 Sensor - Discharge Gauge 5.470 3-1/2” SOI Solid Gauge Mandrel SLB DHG 2.920 8,691.3 6,270.8 74.96 Packer 6.870 Baker Hughes Premier 3-1/2" x 7- 5/8" Baker Premier 2.890 8,717.5 6,277.4 75.67 Nipple 3.960 2.813" X-Nipple HES X-Nipple 2.813 8,730.3 6,280.6 75.87 Centralizer 6.000 3 Ea 4-1/2" 12.6# L-80 HYD563 w/ Maxwell Centralizers Maxwell Offset Centraliz er Joints 3.958 8,851.8 6,308.2 78.33 Shoe - Mule 5.200 4 1/2" HYD563 Mule Shoe 4.500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,014.0 6,334.5 82.83 CIBP 7 5/8" CIPB set on rig 4/23/2025 0.000 9,021.0 6,335.4 82.95 CUT Mechanical Cut on rig. 4/16/2025 2.960 9,535.0 6,344.2 94.12 FISH motor bit box and crayola mill left in holetotal length 1.7'. OD of motor bitbox 2.13" - see attachements Quadco bit box and cryola mill 1/2/2024 0.000 9,536.7 6,344.1 94.11 FISH partial bha 2.13" OD, DFCV, TJ disco, 2.13 screen sub, 2.13 hydropull, XO, Stinger, OX, Down jet nozzle. see attachment. Quadco 12/31/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,549.2 6,229.4 71.21 1 GAS LIFT DMY BTM 1 0.0 5/12/2025 Incon el Latch SLB KBMG 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,045.2 6,338.2 83.39 SWELL PACKER 5.750 Baker-- "Swell Packer"- "J" (#11) SN: 050494-001-14 Baker PN H301-87 -0115, Ser # 050494-001 -14 3.900 9,269.5 6,354.3 88.86 FRAC PORT 5.610 Baker 4-1/2" Frac Sleeve #9 - (2.625" Ball, Drift w/ 2.563") PN:10437088 ( MILLED OUT TO 2.71") 1/1/24 Baker PN:104370 88 2.710 9,645.8 6,336.3 94.13 SWELL PACKER 5.770 Baker-- "Swell Packer"- "I" (#10) SN: 050494-001-17 Baker PN H301-87 -0115, Ser # 050494-001 -17 3.900 10,030.7 6,322.7 91.16 FRAC PORT 5.610 Baker 4-1/2" Frac Sleeve #8 - (2.563" Ball, Drift w/ 2.5") PN:10437087 Baker PN:104370 87 2.531 10,408.2 6,324.4 87.76 SWELL PACKER 5.750 Baker-- "Swell Packer"- "H" (#9) SN: 050494-001-20 Baker PN H301-87 -0115, Ser # 050494-001 -20 3.900 10,909.7 6,322.3 90.03 FRAC PORT 5.750 Baker 4-1/2" Frac Sleeve #7 - (2.50" Ball, Drift w/ 2.438") PN:10437086 Baker PN:104370 86 2.468 11,207.4 6,322.7 89.93 SWELL PACKER 5.790 Baker-- "Swell Packer"- "G" (#8) SN: 050494-001-40 Baker PN H301-87 -0115, Ser # 050494-001 -40 3.900 11,550.5 6,326.5 89.57 FRAC PORT 5.750 Baker 4-1/2" Frac Sleeve #6 - (2.438" Ball, Drift w/ 2.375") PN:10437085 Baker PN:104370 85 2.406 2S-05, 5/16/2025 3:01:13 PM Vertical schematic (actual) LINER; 9,021.0-15,117.6 Hydraulic Fracture; 15,008.2 Hydraulic Fracture; 14,492.6 Hydraulic Fracture; 13,970.2 Hydraulic Fracture; 13,411.4 Hydraulic Fracture; 12,931.8 Hydraulic Fracture; 12,410.8 Hydraulic Fracture; 11,550.5 Hydraulic Fracture; 10,909.7 Hydraulic Fracture; 10,030.7 FISH; 9,536.7 FISH; 9,535.0 CUT; 9,021.0 INTERMEDIATE; 26.9-9,019.4 CIBP; 9,014.0 Nipple; 8,717.5 Packer; 8,691.3 Sensor - Discharge Gauge; 8,575.9 Mandrel – GAS LIFT; 8,549.2 SURFACE; 28.5-2,927.2 CONDUCTOR; 27.5-107.5 Hanger; 25.1 KUP PROD KB-Grd (ft) 27.50 RR Date 6/7/2016 Other Elev… 2S-05 ... TD Act Btm (ftKB) 15,130.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032073900 Wellbore Status PROD Max Angle & MD Incl (°) 94.25 MD (ftKB) 13,809.28 WELLNAME WELLBORE2S-05 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,888.0 6,328.2 89.42 SWELL PACKER 5.750 Baker-- "Swell Packer"- "F" (#7) SN: 050494-001-23 Baker PN H301-87 -0115, Ser # 050494-001 -23 3.900 12,068.0 6,327.5 92.31 SWELL PACKER 5.750 Baker-- "Swell Packer"- "K" (#6) SN: 050494-001-32 Baker PN H301-87 -0115, Ser # 050494-001 -32 3.900 12,410.8 6,308.8 92.10 FRAC PORT 5.740 Baker 4-1/2" Frac Sleeve #5 - (2.375" Ball, Drift w/ 2.313") PN:10437084 Baker PN:104370 84 2.343 12,667.2 6,304.9 90.49 SWELL PACKER 5.750 Baker-- "Swell Packer"- "E" (#5) SN: 050494-001-41 Baker PN H301-87 -0115, Ser # 050494-001 -41 3.900 12,931.8 6,301.7 90.72 FRAC PORT 5.730 Baker 4-1/2" Frac Sleeve #4 - (2.313" Ball, Drift w/ 2.25") PN:10437083 Baker PN:104370 83 2.281 13,187.6 6,300.3 90.17 SWELL PACKER 5.750 Baker-- "Swell Packer"- "D" (#4) SN: 050494-001-43 Baker PN H301-87 -0115, Ser # 050494-001 -43 3.900 13,411.4 6,298.2 90.89 FRAC PORT 5.740 Baker 4-1/2" Frac Sleeve #3 - (2.25" Ball, Drift w/ 2.188") PN:10437082 Baker PN 10437082 2.218 13,707.5 6,291.4 92.73 SWELL PACKER 5.750 Baker -- "Swell Packer"- "C" (#3) SN: 050494-001-18 Baker PN H301-87 -0115, Ser # 050494-001 -18 3.900 13,970.2 6,273.5 94.05 FRAC PORT 5.730 Baker 4-1/2" Frac Sleeve #2 - (2.188" Ball, Drift w/ 2.125") PN:10437081 Baker PN 10437081 2.135 14,228.0 6,267.4 88.11 SWELL PACKER 5.750 Baker-- "Swell Packer"- "B" (#2) SN: 050494-001-22 Baker PN H301-87 -0115, Ser # 050494-001 -22 3.900 14,492.6 6,272.4 89.12 FRAC PORT 5.620 Baker 4-1/2" Frac Sleeve #1 - (2.125" Ball, Drift w/ 2.00") PN:10437070 Baker PN 10437070 2.073 14,750.0 6,275.4 90.18 SWELL PACKER 5.760 Baker -- "Swell Packer"- "A" (#1) SN: 050494-001-6 Baker PN H301-87 -0115, Ser # 050494-001 -6 3.900 15,008.2 6,271.8 90.34 FRAC PORT 5.610 4-1/2" Baker Alpha Pressure Sleeve Baker PN: H810- 07-0027, Control # 10412242 3.010 15,021.2 6,271.7 90.34 SLEEVE 5.000 4-1/2" Baker Wellbore Isolation Valve (H036784300) Baker PN: H809- 89-0011, Control # FPSC 1717 1.250 15,075.1 6,271.4 90.34 COLLAR 4.500 4-1/2" 12.6 ppf L-80 Weatherford Float Collar Weatherf ord Model 402E, Weatherford PN: 577478, HT 931869 3.885 15,076.4 6,271.4 90.34 XO - Threads 4.500 4-1/2" 12.6 ppf L-80 liner crossover jt Ibt-m box x Hyd 563 pin 3.958 Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 15,008.2 15,009.2 1 Hydraulic Fracture 6/23/2016 500,000.0 101,000.0 2,254.00 2,357.00 14,492.6 14,493.6 2 Hydraulic Fracture 6/23/2016 500,000.0 100,500.0 1,486.00 1,589.00 13,970.2 13,971.2 3 Hydraulic Fracture 6/23/2016 500,000.0 100,000.0 1,731.00 1,833.00 13,411.4 13,412.4 4 Hydraulic Fracture 6/23/2016 500,000.0 102,100.0 1,467.00 1,572.00 12,931.8 12,932.8 5 Hydraulic Fracture 6/23/2016 500,000.0 100,000.0 1,602.00 1,704.00 12,410.8 12,411.8 1 Hydraulic Fracture 6/26/2016 500,000.0 99,500.0 1,591.00 1,693.00 11,550.5 11,551.5 2 Hydraulic Fracture 6/26/2016 500,000.0 100,000.0 1,502.00 1,604.00 10,909.7 10,910.7 3 Hydraulic Fracture 6/26/2016 500,000.0 99,500.0 1,458.00 1,560.00 10,030.7 10,031.7 4 Hydraulic Fracture 6/26/2016 500,000.0 101,000.0 1,477.00 1,580.00 9,269.5 6,270.5 5 Hydraulic Fracture 6/26/2016 500,000.0 101,200.0 1,464.00 1,568.00 2S-05, 5/16/2025 3:01:14 PM Vertical schematic (actual) LINER; 9,021.0-15,117.6 Hydraulic Fracture; 15,008.2 Hydraulic Fracture; 14,492.6 Hydraulic Fracture; 13,970.2 Hydraulic Fracture; 13,411.4 Hydraulic Fracture; 12,931.8 Hydraulic Fracture; 12,410.8 Hydraulic Fracture; 11,550.5 Hydraulic Fracture; 10,909.7 Hydraulic Fracture; 10,030.7 FISH; 9,536.7 FISH; 9,535.0 CUT; 9,021.0 INTERMEDIATE; 26.9-9,019.4 CIBP; 9,014.0 Nipple; 8,717.5 Packer; 8,691.3 Sensor - Discharge Gauge; 8,575.9 Mandrel – GAS LIFT; 8,549.2 SURFACE; 28.5-2,927.2 CONDUCTOR; 27.5-107.5 Hanger; 25.1 KUP PROD 2S-05 ... WELLNAME WELLBORE2S-05 ORIGINATED TRANSMITTAL DATE: 5/30/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5458 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5458 2S-05 50103207390000 Perf Record 19-May-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 216-039 T40510 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.30 13:15:41 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 15130'662 9535' 9537' Casing Collapse Conductor Surface Production Slotted Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-265-1102 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Staff CTD Engineer Subsequent Form Required: Suspension Expiration Date: L-80 James Ohlinger 6/15/2025 2898' 9019' Perforation Depth MD (ft): james.j.ohlinger@conocophillips.com 8853'None 8992' 4-1/2" None Perforation Depth TVD (ft): MD 6335' 2927' 15118'6258' 7-5/8" 16" Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size 8691'MD/6271'TVD 108' Baker Baker Premier SSSV: None 6271' MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 2565' Burst 3-1/2" Kuparuk River Field Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY Tubing Grade:Tubing MD (ft): Current Pools: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25604, ADL 25589, ADL25603 216-039 P.O. Box 100360, Anchorage, AK 99510 50-103-20739-00-00 ConocoPhillips Alaska, Inc KRU 2S-05 8716' 9014' 10-3/4" 80' TVD 15118'6097' 108' 6271' m n P s 2 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:50 pm, Apr 28, 2025 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E= James.J.Ohlinger@cop.com Reason: I am the author of this document Location: Date: 2025.04.28 12:19:44-08'00' Foxit PDF Editor Version: 13.1.6 James J. Ohlinger 325-263 9:12 am, Apr 30, 2025 Fracture Stimulate JJL 5/14/25 SFD 6/9/2025 DSR-4/29/25 CDW 05/21/2025 Include a PRV on OA or hold an open bleed on OA during fracture treatment. Test tubing PRV, IA PRV, and pump trips to the set pressures detailed in the section 7 table. 6/15/2025 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.10 15:20:36 -08'00'06/10/25 RBDMS JSB 061225 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 28, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: James J Ohlinger Staff CTD/RWO Wells Engineer ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to frac KUP Producer 2S-05 (PTD# 216-039-0). Well 2S-05 was originally spud in 5/16/16 and rig released 6/6/16.The well has primarily been a Kuparuk A-sand and C-sand Producer.The well has developed AnnComm issues that moved it to being a RWO candidate due to leaks. If you have any questions or require any further information, please contact me at +1-907-229-3338. The tubing will be pulled, and the 7-5/8" casing cleared and plugged at the casing shoe. We're plugging off the 4-1/2" liner due to a hole in the liner that is producing rocks. A new 3.5" completion will be installed with a new packer to recomplete the well. We are going to perforate the same A-sand interval that the existing liner is in. perforate the same A-sand interval that the existing liner is in 2S-05 A-Sand Producer Proposed Wellbore Schematic post Rig Workover 2S-05 Proposed RWO Completion Producer COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 108 108 16 15.25 62.5 H-40 Surface 2927 2565 10-3/4 9.95 45.5 L-80 HYD 563 Intermediate 9019 6335 7-5/8 6.88 29.7 L-80 HYD 563 Tubing 8719 3-1/2 2.992 9.3 L-80 HYD 563 Liner 15117.6 6271.2 4.5 3.96 12.6 L-80 HYD 563 Upper Completion Cameron 11" x 4-1/2" HYD563 Tubing Hanger XO, 4-1/2" 12.6# L-80 HYD563 x 3-1/2" 9.3# L-80 HYD563 @ 26' RKB 3-1/2" 9.3# L-80 HYD563 Tubing 3.5" x 1" KBMG @ 8549' Schlumberger Gauge Carrier @ 8576' RKB 3.5" x 7-5/8" "Premier" Packer @ 8691' RKB 3-½" X-nipple at 8717' RKB (2.813" min ID) 4-1/2" 12.6# w/ (MMM# 13914615) Maxwell Centralizers (Future CTD KO) 4-1/2" Mule Shoe 7-5/8" Cast Iron Bridge Plug (Baker Hughes) ~9014' MD Surface Casing Intermediate Casing ~9019' RKB Conductor ! "#$ % % !" ##$ % &! " & '( & ' Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). Exhibit 2 is the list of names and addresses of all landowners, surface owners and operators of record of all properties within the Notification Area. March 24, 2025 VIA E-MAIL To: Operator and Owners (shown on Exhibit 2) Re: Notice of Operations for 2S-05 Well ADL 025603 & ADL 025604 Kuparuk River Unit, Alaska CPAI Contract No. 203828 Pursuant to 20 AAC 25.283, ConocoPhillips Alaska, Inc. (“CPAI”) as Operator of the Kuparuk River Unit, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing in accordance with 20 AAC 25.280 (“Application”) for the 2S- 05 Well (the “Well”). The Application will be filed with the Alaska Oil and Gas Conservation Commission on or about March 24, 2025. The Well is currently planned to be drilled as a directional horizontal well on lease ADL 025603, and ADL 025604 as depicted on Exhibit 1, and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 3,037’ 1,381’ T10N R8E 17 Umiat Top Open Interval 4,920’ 2,810’ T10N R8E 16 Umiat Bottom Open Interval 4,722’ 2,763’ T10N R8E 16 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well (“Notification Area”), which includes the reservoir section. Exhibit 2 is a list of the names and addresses of all owners, landowners, surface owners, and operators of record at the time of this Application for all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require any additional information, please contact the undersigned. Sincerely, Ryan C. King, CPL Interim Land Manager Ryan C. King, CPL Interim Land Manager Land & Business Development P.O. Box 100630 Anchorage, AK 99510-0360 Office: 907-265-6106 Fax: 907-263-4966 ryan.c.king@cop.com Exhibit 2 List of the names and addresses of all owners, landowners, surface owners, and operators of record of all properties within the Notification Area. Operator & Owner: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO-1480 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attn: GKA Asset Development Manager Owner (Non-Operator): ConocoPhillips Alaska, Inc. II ExxonMobil Alaska Production Inc. 700 G Street, Suite ATO 1226 PO Box 196601 Anchorage, Alaska 99510 Anchorage, AK 99519 Attn: GKA Asset Development Manager Attn: Todd Griffith Landowners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501 Attention: Derek Nottingham, Director Surface Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501 Attention: Derek Nottingham, Director Section 2 – Plat 20 AAC 25.283 (a)(2) Plat 1: 2S-05 Landowners; for new Sundry Application Section 2 – Plat 20 AAC 25.283 (a)(2) Plat 1: 2S-05 Landowners; from original Sundry 316-309 Table 1: Wells within .5 miles Well Name Status Symbology Well in Frac Port 1/ 2 mi Buffer Open Interval in Frac Port 1/2 mi Buffer KRU 21-10-8 PA Plugged and Abandoned Yes - P&A Yes - P&A 2S-315 ACTIVE Oil 2S-02 ACTIVE Injector Miscible Water Alternating Gas Yes Yes 2S-07 ACTIVE Injector Miscible Water Alternating Gas Yes Yes 2S-10 ACTIVE Injector Miscible Water Alternating Gas Yes Yes 2S-13 PA Plugged and Abandoned 2S-13A ACTIVE Injector Produced Water 2S-13L1 PA Plugged and Abandoned 2S-13AL1 ACTIVE Injector Produced Wate r 2S-13PB1 PA Plugged and Abandoned 2S-04 ACTIVE Injector Miscible Water Alternating Gas 2S-04PB1 PA Plugged and Abandoned 2S-08 ACTIVE Injector Miscible Water Alternating Gas 2S-01 ACTIVE Oil 2S-03 ACTIVE Oil Yes Yes 2S-03PB1 PA Plugged and Abandoned Yes - P&A Yes - P&A 2S-11 ACTIVE Oil 2S-14 ACTIVE Oil 2S-05 ACTIVE Oil Yes Yes 2S-12 ACTIVE Oil 2S-12PB1 PA Plugged and Abandoned 2S-06 ACTIVE Oil 2S-09 PA Plugged and Abandoned 2S-09A ACTIVE Oil SECTION 3 – FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), “That portions of the aquifers on the North Slope described by a ¼ mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field”. SECTION 4 – PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. SECTION 5 – DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. SECTION 6 – ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10-3/4” casing cement pump report on 5/18/2016 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg Lead Deep Crete cement and 15.8 ppg tail cement. Full returns were seen throughout the job. The plug bumped at 1,500 psi and the floats were checked and they held. The 7-5/8” casing cement report on 5/27/2016 shows that the job was pumped as designed, indicating competent cementing operations. The first stage was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 570 psi and the floats were checked and they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. 203 bbl cement returns to surface. CDW 05/21/2025 25.52(b) 151 bbl Shark slurry 15.8 ppg, 53 bbl 15.8 ppg via stage collar. No CBL - volumetric calcs. CDW 05/21/2025 SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 5/20/2016 the 10 & 3/4” casing was pressure tested to 3500 psi. On 5/29/2016 the 7 & 5/8” casing was pressure tested to 3500 psi. On 04/23/2025, the 7-5/8” casing was pressure tested to 2500 psi CCOPA System Pressures Pressure (psi)Equation Notes Maximum allowed working pressure (MAWP) 7500 WellCat SO load case Proposed (low DF) Tubing ePRV 7125.0 MAWP * 0.95 COP stim manual Highest pump trip 6625 ePRV – 500 COP stim manual Maximum Predicted Treating Pressure (MPTP) 6125 Highest pump trip – 500 Tubing pressure Test 3125 (MPTP - IA) + 500 Greater of:+500 (COP) or 110% (AOGCC) Annulus pressure test 3850 IA pressure * 1.1 AOGCC requirement ePRV Annulus setpoint (relieves tubing) during frac 3750 IA pressure + 100 psi +150 psi Annulus PRV (mechanical) setpoint during frac 3600 IA pressure + 100 psi COP stim manual Annulus pressure during frac 3500 WellCat IA load case Annulus pressure in the evening between frac day 500 Bleed off to 500 psi in the evening SECTION 8 – PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & ¾” 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8” 29.7 L-80 6,890 psi 4,790 psi 3.5” 9.3 L-80 10,160 psi 10,540 psi Table 2: Pressure Ratings Stimulation Surface Rig-Up Tree Saver SECTION 9 – DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone, the Kuparuk A4 sand interval, is approximately 27’ TVT, with the top of the Kuparuk A4 at 6,160’ TVDSS (8,850’ MD). The Kuparuk A interval is composed of multiple packages of very fine grained, quartz rich sandstone, separated by laterally continuous shale interbeds. The estimated fracture pressure for the Kuparuk A is 13.1 ppg. The overlying confining zone has an overall thickness of 334’ TVT (867’ MD) and consists of HRZ and Kalubik mudstones. Top HRZ was encountered at 5,820’ TVDSS (7,980’ MD). The estimated fracture pressure for the overlying confining layer is 16 ppg. The underlying confining zone consists of the Miluveach interval, a marine shale, approximately 500’ thick. The estimated fracture pressure for the Miluveach is 15.5 ppg. The top of the Miluveach is located at approximately 6,263’ TVDSS at the heel (the Miluveach interval was not penetrated in the 2S-05 wellbore). SECTION 10 – LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 2S-03: The 7-5/8” casing cement report on 2/11/2016 shows that the job was pumped as designed, indicating competent cementing operations. The first stage was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1,103 psi and the floats were checked and they held. 2S-07: The 7 & 5/8 casing cement pump report on 8/6/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.3 ppg cement, displaced with 10.6 ppg mud. The plug bumped at 1,251 psi and the floats were checked and they held. 2S-02: The 7 & 5/8 casing cement pump report on 7/1/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 10.4 ppg LSND. The plug bumped at 1,505psi and the floats were checked and they held. Losses occurred during cementing operations. However, the interpreted TOC on the SonicScope cement evaluation log is about 4900' MD.SFD 2S-10: The 7 & 5/8 casing cement pump report on 9/2/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 10.5 ppg mud. The plug bumped at 1,450 psi and the floats were checked and they held. 2S-01: The 7-5/8” casing cement report on 1/3/2016 shows that the job was pumped as designed, indicating competent cementing operations. The first stage was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1,100 psi and the floats were checked and they held. KRU 21-10-8: KRU 21-10-8 was plugged and abandoned as per state regulations on 4/28/1989. SECTION 11 – LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) From the original frac sundry, CPAI has formed the opinion based on seismic, well, and other subsurface information currently available that there are 13 mapped faults that transect the Kuparuk A interval and enter the confining zone within one half mile radius of the wellbore trajectory for 2S-05. The existing 2S-05 wellbore will be plugged with a cast iron bridge plug at 9015’ MD. The north-south trending faults between 2S-05 and 2S-07 terminate in the Cairn interval, which consists of sands, silts, and shales in this area with an estimated fracture pressure of >12 ppg. Three faults intersect the 2S-05 wellbore and terminate within the confining layer (Fault #1, #2, and #3). Faults #4 and #5 terminate at the C-35. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of ~16ppg. No losses were observed at any of the fault crossings during drilling of the 2S-05 lateral section. Fracture gradients within the confining zone (Kalubik and HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining layer is discussed in Section 9. $ % ! & ' ( % ) *+,+- # *- % ) *+,+- # *- % ) *+,+- # # *- % ) *+,+- # # *- % ) *+,+- # # *- ,, 13 mapped faults that transect theypp Kuparuk A interval and enter the confining zone within one half mile radius of the wellborep trajectory for 2S-05. Two mapped faults within the half mile radius intersect the offset 2S-07 wellbore in the Kuparuk A sands. They also intersect the 2S-05 wellbore and correspond to faults #4 and #5. Both faults terminate in the C-35. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of ~16ppg. No losses were observed at any faults during drilling of the 2S-07 lateral section. The 2S-05 lateral is greater than 1500’ from the 2S-07 wellbore. The 2S-05 lateral now ends at ~9019’ MD. $ ' ( & ) ' * +,-,. +. ' * +,-,. +. Two mapped faults within the half mile radius intersect the offset 2S-02 wellbore in the Kuparuk A sands. Fault #2 intersects the 2S-05 wellbore and corresponds to Fault #4 in 2S- 05. Both faults terminate in the C-35. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of ~16ppg. No losses were observed at the fault during the drilling of the 2S-02 lateral section. The 2S-05 lateral is greater than 1500’ west of the 2S-02 wellbore. The 2S-05 lateral now ends at ~9019’ MD. $ ' ( & ) ' * +,-,. +. ' * +,-,. ## +. Plat 2: Fault Analysis SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 2S-05 was completed in 2016 as horizontal producer in the Kuparuk A sand formation. The well will be completed with 3-1/2” tubing and then perforations added. We will pump a single stage frac out these perforations. It has now been completed post rig workover with 3-1/2” tubing, and a cast iron bridge plug at 9014’ MD. New perforations will be added in the A4 and interval. Proposed Procedure: Halliburton Pumping Services: (A Sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000’ TVD. 3. Ensure stinger tree saver is installed and tested to 10,000psi 4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 5. MIRU 1-2 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100º F seawater for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 6. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 7. MIRU HES Frac Equipment. 8. PT Surface lines to 9,000 psi using a Pressure test fluid. 9. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 10. Bring up pumps and increase annulus pressure from 2,500 psi to 3,000 psi as the tubing pressures up. 11. Pump the single stage Frac job by following attached HES schedule @ ~25bpm with a maximum expected treating pressure of 5,500 psi. 12. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 13. Well is ready for Post Frac well prep and flowback SECTION 12 – PROPOSED FRACTURE DESCRIPTION 20 AAC 25.283(a)(12)(F) The effective frac half-length is estimated to be 500’, with 55ft of height and an average width of 0.325”. All of the fractures will be longitudinal, running parallel to the 2S-05 wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. single stage frac 5,500 psi. 3,000 psi SECTION 13 – POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) Hydraulic Fracturing Fluid Product Component Information Disclosure 2025-04-08 Alaska HARRISON BAY 50-103-20739-00-00 CONOCOPHILLIPS 2S 05 -150.15479712 70.21968880 NAD83 none Oil 6344 95247 Hydraulic Fracturing Fluid Composition: Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Ingredient Mass lbs Comments Company First Name Last Name Email Phone SEAWATER (SG 8.52)Operator Base Fluid Density = 8.52 BC-140 X2 Halliburton Initiator BE-6(TM) Bactericide Halliburton Microbiocide CL-28M CROSSLINKER Halliburton Crosslinker LoSurf-300D Halliburton Non-ionic Surfactant MO-67 Halliburton pH Control OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker WG-36 GELLING AGENT Halliburton Gelling Agent Ceramic Proppant - Wanli Wanli Proppant SAND, COMMON BROWN 100 MESH Halliburton Proppant Calcium Chloride Customer Salt Solution Ingredients Water 7732-18-5 95.00%83.04632%811505 Corundum 1302-74-5 60.00%6.14017%60000 Sodium chloride 7647-14-5 5.00%4.37086%42711 Mullite 1302-93-8 40.00%4.09345%40000 Calcium Chloride 10043-52-4 100.00%1.02336%10000 Crystalline silica, quartz 14808-60-7 100.00%0.64637%6317 Guar gum 9000-30-0 100.00%0.35910%3509 Water 7732-18-5 100.00%0.15695%1534 Borate salts Proprietary 60.00%0.07283%712 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871- 6226 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Ethanol 64-17-5 60.00%0.04667%456 Ammonium persulfate 7727-54-0 100.00%0.02558%250 Monoethanolamine borate 26038-87-9 100.00%0.02391%234 Heavy aromatic petroleum naphtha 64742-94-5 30.00%0.02333%228 Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.02333%228 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Sodium hydroxide 1310-73-2 30.00%0.02308%226 Oxyalkylated phenolic resin Proprietary 10.00%0.00778%76 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Oxylated phenolic resin Proprietary 30.00%0.00768%75 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Ethylene glycol 107-21-1 30.00%0.00717%71 Potassium chloride 7447-40-7 5.00%0.00607%60 Inorganic mineral 1317-65-3 5.00%0.00607%60 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, branched 127087-87-0 5.00%0.00389%38 Naphthalene 91-20-3 5.00%0.00389%38 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00154%15 Polymer Proprietary 1.00%0.00121%12 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Calcium magnesium carbonate 16389-88-1 1.00%0.00121%12 Gluteraldehyde 111-30-8 1.00%0.00121%12 Inorganic mineral Proprietary 1.00%0.00121%12 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00078%8 Sodium chloride 7647-14-5 1.00%0.00077%8 Methanesulfonic acid, 1-hydroxy-, sodium salt 870-72-4 0.10%0.00012%2 Sodium bisulfate 7681-38-1 0.10%0.00012%2 C.I. pigment Orange 5 3468-63-1 1.00%0.00005%1 2,7-Naphthalenedisulfonic acid, 3- hydroxy-4-[(4-sulfor-1- naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00002%1 Magnesium nitrate 10377-60-3 0.01%0.00001%1 Magensium chloride 7786-30-3 0.01%0.00001%1 5-Chloro-2-methyl-3(2H)- Isothaiazolone 26172-55-4 0.01%0.00001%1 2-Methyl-4-isothiazolin-3-one 2682-20-4 0.01%0.00001%1 * Total Water Volume sources may include fresh water, produced water, and/or recycled water _ ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.5 All component information listed was obtained from the supplier’s Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration’s (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D. Production Type: True Vertical Depth (TVD): Total Water Volume (gal)*: MSDS and Non-MSDS Ingredients are listed below the green line Well Name and Number: Longitude: Latitude: Long/Lat Projection: Indian/Federal: Fracture Date State: County: API Number: Operator Name: CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.21968881LEASE2S-05SALES ORDERBHST (°F)LONG-150.1547971FORMATIONKuparukDATE Max Pressure (psi)7000*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval CL-28M Losurf-300D MO-67 BC-140X2 WG-36 OPTIFLO-III OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer CrosslinkerInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In1:58:44 1-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:58:44 1-3 Shut-In Shut-In1:53:58 1-4 35# Linear DFIT 15 1,680 40 40 0:02:40 1:53:58 1.00 35.00 2.00 0.500.151-5 Shut-In Shut-In1:51:18 1-6 35# Linear Step Rate Test 15 3,360 80 80 0:05:20 1:51:18 1.00 35.00 2.00 0.500.151-7 35# Hybor G Minifrac - Establish Fluid 15 8,400 200 200 0:13:20 1:45:58 1.25 1.00 0.80 0.25 35.00 2.00 0.500.151-8 35# Hybor G Minifrac - Treatment 25 12,500 298 298 0:11:54 1:32:38 1.25 1.00 0.80 0.25 35.00 2.00 0.500.151-9 35# Linear Minifrac - Flush 25 2,710 65 65 0:02:35 1:20:44 1.00 35.00 2.00 0.500.151-10 Shut-In Shut-In1:18:09 1-11 35# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 1:18:09 1.25 1.00 0.80 0.25 35.00 2.00 0.500.151-12 35# Hybor G Conditioning Pad 100M 0.25 25 25,000 595 602 6,250 0:24:05 1:04:49 1.25 1.00 0.80 0.25 35.00 2.00 0.500.151-13 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 25 5,000 119 124 5,000 0:04:59 0:40:44 1.25 1.00 0.80 0.25 35.00 2.00 0.500.151-14 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 7,500 179 195 15,000 0:07:48 0:35:45 1.25 1.00 0.80 0.25 35.00 2.00 0.500.151-15 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 25 8,000 190 216 24,000 0:08:40 0:27:58 1.25 1.00 0.80 0.25 35.00 2.00 0.500.151-16 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.50 25 8,000 190 220 28,000 0:08:50 0:19:18 1.25 1.00 0.80 0.25 35.00 2.00 0.500.151-17 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 7,000 167 196 28,000 0:07:53 0:10:28 1.25 1.00 0.80 0.25 35.00 2.00 0.500.151-18 35# Linear Flush 25 2,710 65 65 0:02:35 0:02:35 1.00 35.00 2.00 0.500.151-19 Shut-In Shut-In101,260 2,411 2,524 106,250Design Total (gal)Design Total (lbs)CL-28M Losurf-300D MO-67 BC-140X2 WG-36 OPTIFLO-III OPTIFLO-II BE-689,800100,000(gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs)10,4606,250Initial Design Material Volume 112.3 100.3 71.8 22.5 3,509.1 200.5 50.1 15.0-1,000-Whole Units to be ordered--CL-28M Losurf-300D MO-67 BC-140X2 WG-36 OPTIFLO-III OPTIFLO-II BE-6-(gpm) (gpm) (gpm) (gpm) ppm ppm ppm ppm-Max Additive Rate 2.1 1.1 0.8 0.3 36.8 2.1 2.1 0.2-Min Additive Rate1:58:44 Interval 1@ 8850 - 9015 ft - °FProppant TypeWanli 16/20 Ceramic100M---Fluid Type35# Hybor G35# LinearSeawaterFreeze Protect----Liquid AdditivesDry Additives50-103-20739Conoco Phillips - 2S-05Planned Design1 Stage Job Size (lb) Top MD (ft) Top TVD (ft) Propped Half- Length (ft) Fracture Height (ft) Avg Fracture Width (in) 1 106,250 8,850 6,288 500 55 0.325 Disclaimer Notice: KRU 2S-05 This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Conoco Phillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results From:Ohlinger, James J To:Davies, Stephen F (OGC) Cc:Dewhurst, Andrew D (OGC); Neely, Thomas G; Coberly, Jonathan Subject:RE: [EXTERNAL]RE: KRU 2S-05 (PTD 216-039, Sundry 325-263) - Question Date:Monday, June 9, 2025 4:37:48 PM Attachments:image001.png I would put it very low (unlikely). 2S-03 is ~316’ TVD above the 2S-05 lateral where the bottom of this frac interval is planned; ~9019’ MD. The production interval of 2S-03 starts ~9200’ MD, which is ~765’ to the South in the 2S-03 lateral. There are no known issues between these 2 wells from the original much larger frac in 2S-05. From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, June 9, 2025 4:02 PM To: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]RE: KRU 2S-05 (PTD 216-039, Sundry 325-263) - Question CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Thank you, James and Thomas. I appreciate your help. In CPAI’s opinion, what is the likelihood of an induced fracture reaching the Kuparuk in very nearby well 2S-03? Why or why not? If any likelihood, what monitoring and mitigation measures will CPAI take? Thanks Again and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Sent: Monday, June 9, 2025 1:27 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: KRU 2S-05 (PTD 216-039, Sundry 325-263) - Question Afternoon My answers are in the red text, my geo Thomas Neely in blue. I’ve reworded and redone the tables and map for Section 11. I’m reviewing CPAI’s Sundry Application for the planned single-stage frac of the Kuparuk A sands in KRU 2S-05, and I need a bit of clarification. CPAI’s fault analysis map accompanying the application displays many separate fault segments that are not labeled. For clarity, could CPAI please provide a revised map and associated tables with each of the fault segments labeled so that corresponding entries in the associated tables are more easily understood? I have attached new schematic after my new writeup of section 11. On CPAI’s map, there is also a short, black line drawn through the 2S-05 wellbore. I’m assuming that this mark represents Faults 1 through 3 in the 2S-05 Faults table. Correct? Yes, I commented on those in the map and writeup. Has CPAI mapped three faults in that wellbore between 10,562’ and 10,585’ MD, or am I miss-understanding that table? I labeled them as Fault 1-2-3 Are the vertical displacements for Faults 1 through 3 less than 4 feet, or am I miss- understanding that table? It’s a stair step fault, totaling 7-8’ of throw. • What is the lateral extent for each of these faults? (Is it just a few hundred feet?) The estimate of lateral extents are as mapped. These faults are sub-seismic and were not observed in offset wells 2S-07 or 2S-02. • To make certain that I understand the northeast-trending faults that lie between 2S-07 and 2S-05, what is the direction of displacement for these faults? What is their vertical displacement? I believe they terminate upward in the Cairn interval, correct? These two NNE-striking faults form a structural graben. The western of the two dips east- southeast, and the eastern of the two dips west-northwest. Vertical displacements on the two faults range between 10-25’, as currently mapped in 3D seismic data. Both faults terminate vertically several hundred feet above the Kuparuk Formation into the HRZ and Torok Formation. What is CPAI’s expected azimuth of propagation growth for the fractures that will be induced during the planned operations? Between 330° and 350° (North-Northwest) Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Ohlinger, James J To:Davies, Stephen F (OGC) Cc:Dewhurst, Andrew D (OGC) Subject:KRU 2S-05 (PTD 216-039, Sundry 325-263) - Question Date:Monday, June 9, 2025 1:27:10 PM Attachments:SECTION 11.docx Afternoon My answers are in the red text, my geo Thomas Neely in blue. I’ve reworded and redone the tables and map for Section 11. I’m reviewing CPAI’s Sundry Application for the planned single-stage frac of the Kuparuk A sands in KRU 2S-05, and I need a bit of clarification. CPAI’s fault analysis map accompanying the application displays many separate fault segments that are not labeled. For clarity, could CPAI please provide a revised map and associated tables with each of the fault segments labeled so that corresponding entries in the associated tables are more easily understood? I have attached new schematic after my new writeup of section 11. On CPAI’s map, there is also a short, black line drawn through the 2S-05 wellbore. I’m assuming that this mark represents Faults 1 through 3 in the 2S-05 Faults table. Correct? Yes, I commented on those in the map and writeup. Has CPAI mapped three faults in that wellbore between 10,562’ and 10,585’ MD, or am I miss-understanding that table? I labeled them as Fault 1-2-3 Are the vertical displacements for Faults 1 through 3 less than 4 feet, or am I miss- understanding that table? It’s a stair step fault, totaling 7-8’ of throw. • What is the lateral extent for each of these faults? (Is it just a few hundred feet?) The estimate of lateral extents are as mapped. These faults are sub-seismic and were not observed in offset wells 2S-07 or 2S-02. • To make certain that I understand the northeast-trending faults that lie between 2S-07 and 2S-05, what is the direction of displacement for these faults? What is their vertical displacement? I believe they terminate upward in the Cairn interval, correct? These two NNE-striking faults form a structural graben. The western of the two dips east- southeast, and the eastern of the two dips west-northwest. Vertical displacements on the two faults range between 10-25’, as currently mapped in 3D seismic data. Both faults terminate vertically several hundred feet above the Kuparuk Formation into the HRZ and Torok Formation. What is CPAI’s expected azimuth of propagation growth for the fractures that will be induced during the planned operations? Between 330° and 350° (North-Northwest) Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov SECTION 11 – LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion based on seismic, well, and other subsurface information currently available that there are no mapped faults that transect the Kuparuk A interval and enter the confining zone within one half mile radius of the wellbore trajectory for 2S-05. The existing 2S- 05 wellbore will be plugged with a cast iron bridge plug at 9015’ MD. The north-south trending faults between 2S-05 and 2S-07 terminate in the Cairn interval, which consists of sands, silts, and shales in this area with an estimated fracture pressure of >12 ppg. No losses were observed at any of the fault crossings during drilling of the 2S-05 lateral section. Fracture gradients within the confining zone (Kalubik and HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining layer is discussed in Section 9. Faults 1, 2, and 3 are a stair step fault. (see cross section in lower right corner of attached map) 2S-05 Faults MD SSTVD Throw Fault #1 (A4/A4) 10562 6182 2 (DTS) Fault #2 (A4/A4) 10570 6182 2 (DTS) Fault #3 (A4/A4) 10585 6183 4 (DTS) Fault #A (A4/A4) 11958 6181 21 (DTS) Fault #B (A4/A4) 13684 6146 8 (DTS) Two mapped faults within the half mile radius intersect the offset 2S-07 wellbore in the Kuparuk A sands. They also intersect the 2S-05 wellbore and correspond to faults #A and #B. Both faults terminate in the C-35. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of ~16ppg. No losses were observed at any faults during drilling of the 2S-07 lateral section. The 2S-05 lateral is greater than 1500’ from the 2S-07 wellbore. The 2S-05 lateral now ends at ~9019’ MD. 2S-07 Fault MD SSTVD Throw Fault #A (A4/A4) 11350 6167 29 (DTS) Fault #B (A4/A4) 13022 6142 5 (DTS) Two mapped faults within the half mile radius intersect the offset 2S-02 wellbore in the Kuparuk A sands. Fault #A intersects the 2S-05 wellbore. Both faults terminate in the C-35. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of ~16ppg. No losses were observed at the fault during the drilling of the 2S-02 lateral section. The 2S-05 lateral is greater than 1500’ west of the 2S-02 wellbore. The 2S-05 lateral now ends at ~9019’ MD. 2S-02 Fault MD SSTVD Throw Fault #A (A4/A4) 17488 6214 25 (DTS) 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 2S-05 (PTD No. 216-039; Sundry No. 325-263) Paragraph Sub-Paragraph Section Complete? AOGCC Page 1 June 9, 2025 (a) Application for Sundry Approval (a)(1) Affidavit Provided with application. SFD 6/8/2025 (a)(2) Plat Provided with application. SFD 6/8/2025 (a)(2)(A) Well location Provided with application. Well lies in Sections 17, 21, 16, and 9 of T10N, R8E, UM. SFD 6/8/2025 (a)(2)(B) Each water well within ½ mile None: According to the Water Estate map available through DNR’s Alaska Mapper application (accessed online June 8, 2025), there are no wells are used for drinking water purposes are known to lie within ½ mile of the surface location of KRU 2S-05. There are no subsurface water rights or temporary subsurface water rights within 19 miles of the surface location of KRU 2S-05. SFD 6/8/2025 (a)(2)(C) Identify all well types within ½ mile Provided with application. SFD 6/8/2025 (a)(3) Freshwater aquifers: geological name; measured and true vertical depth None. This well lies within the Kuparuk River Unit (KRU). 40 CFR 147.102(b)(3) exempts aquifers within the KRU as follows: “That portions of the aquifers on the North Slope described by a ¼ mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field”. SFD 6/8/2025 (a)(4) Baseline water sampling plan None required. SFD 6/8/2025 (a)(5) Casing and cementing information Provided with application. Proposed schematic attached. CDW 05/21/2025 (a)(6) Casing and cementing operation assessment 10-3/4” surface casing cemented to plan with full returns and 203 bbl cement to surface. 7-5/8” intermediate (now production) casing cemented to plan with full returns. 2 stage cement, stage tool at 6465 ft CDW 05/21/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 2S-05 (PTD No. 216-039; Sundry No. 325-263) Paragraph Sub-Paragraph Section Complete? AOGCC Page 2 June 9, 2025 and TOC estimated at 5965 ft. Shoe at 9019 ft and cement top estimated as 7244 ft. 3.5” tubing new with workover. Packer at 9014 ft. No CBL – volumetric calcs and cement reporting of circ spacer off stage tool etc infers no issues with cement for the upcoming stimulation. (a)(6)(A) Casing cemented below lowermost freshwater aquifer and conforms to 20 AAC 25.030 Only exempt freshwater aquifers present. (See Section (a)(3), above.) SFD 6/8/2025 (a)(6)( B) Each hydrocarbon zone is isolated Yes, cement isolates each hydrocarbon zone. Surface casing (10-3/4”) was set at 2,927’ MD (-2,417’ TVDSS) and cemented with 203 barrels of cement returns at surface. For KRU 2S-05, 7-5/8” intermediate casing shoe is set at 9,019’ MD (-6,188’ TVDSS), and cemented in two stages with the collar at 6,465’ MD (-4,789’ TVDSS). Both stages were pumped as expected. There are no cement evaluation logs. The operator’s estimated tops of cement are 7,244’ and 5,965’ MD (-5,353’ and -4,427’ TVDSS), respectively. The Kuparuk interval extends from 8,782’ to TD of the well at 15,130’ MD (-6,145’ to -6,124’ TVDSS), so cement isolates the Kuparuk and associated confining intervals. SFD 6/9/2025 (a)(7) Pressure test: information and pressure-test plans for casing and tubing installed in well Provided with application. 3850 psi MITIA planned, 3125 psi MITT plan. CDW 05/21/2025 (a)(8) Pressure ratings and schematics: wellbore, wellhead, BOPE, treating head Provided with application. 10K psi tree saver. Max. frac. Pressure 5500 psi. Pump shut downs and PRV’s ePRV 3750 psi, Annulus PRV 3600 psi, tree saver test 10K psi, lines test CDW 05/21/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 2S-05 (PTD No. 216-039; Sundry No. 325-263) Paragraph Sub-Paragraph Section Complete? AOGCC Page 3 June 9, 2025 9000 psi. Max allowed working pressure of 7500 psi., tubing ePRV 7125 psi. (a)(9)(A) Fracturing and confining zones: lithologic description for each zone (a)(9)(B) Geological name of each zone (a)(9)(C) and (a)(9)(D) Measured and true vertical depths (a)(9)(E) Fracture pressure for each zone Upper confining zones: HRZ and Kalubik mudstones that have an aggregate thickness of about 335’ true vertical thickness (TVT). The top of HRZ lies at 7,980’ MD (-5,823’ TVDSS). Fracture gradient expected to range from about 0.83 psi/ft (16 ppg EMW). Fracturing Zone: Fracturing zone is the Kuparuk A sand at 8,850’ MD (-6,160’ TVDSS) consisting of very fine-grained sandstone separated by laterally continuous shales. The thickness of this sand is about 27’ TVT. Fracture gradient expected to be about 0.68 psi/ft (13.1 ppg EMW). Lower confining zone: Miluveach Shale (not intersected by this well) has an aggregate TVT of about 500’ in this area. Fracture gradient expected to be about 0.81 psi/ft (15.5 ppg EMW). SFD 6/9/2025 (a)(10) Location, orientation, report on mechanical condition of each well that may transect the confining zones and sufficient information to determine wells will not interfere with containment of hydraulic fracturing fluid within ½ mile of the proposed wellbore trajectory It is highly unlikely that any of the wells or wellbores within a ½-mile radius will interfere with hydraulic fracturing fluids from this operation because of cement isolation and / or separation distance from proposed fracture interval. There are 24 wells within ½ mile of KRU 2S-05 and 6 wells that penetrate the confining intervals within ½ mile. CPAI has evaluated each well. AOGCC evaluated all wells that transect the fracturing and confining zones within the KRU 2S-05 Area of Review and found it highly unlikely that any of these wells will interfere with fracturing fluids due to cement-isolation and/or separation distance or direction. CDW 05/21/2025 / SFD 6/9/2025 (a)(11) Faults and fractures, Sufficient information to determine no interference It is unlikely that any faults will interfere with containment of the injected fracturing fluids; however, if there are indications that a fracture has intersected a fault or natural-SFD 6/9/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 2S-05 (PTD No. 216-039; Sundry No. 325-263) Paragraph Sub-Paragraph Section Complete? AOGCC Page 4 June 9, 2025 with containment of the hydraulic fracturing fluid within ½ mile of the proposed wellbore trajectory fracture interval during frac operations, the operator will go to flush and terminate the stage immediately. This single stage fracturing operation will be conducted through perforations to be placed above a cast iron bridge plug set at 9,014’ MD (-6,187’ TVDSS). The operator has identified 5 faults within the ½-mile buffer surrounding the proposed fracturing interval. The nearest of these lies about 800’ to the west of the planned fracturing perforations. This fault dips WNW and has 10’ to 25’ of vertical displacement. Three faults (labeled Faults 1-2-3 on the operator’s Frac Lease Plat) lie about 1,500’ north of the fracturing interval. The remaining NNE-trending fault within the buffer lies about 1,500’ west of the fracturing interval, is downthrown to the ESE, and has a vertical displacement of 10’ to 25’. Given that the modeled half-length of the induced fractures is estimated to be about 500’ and the anticipated azimuth for induced fracture growth is expected range from 330 to 350 degrees, it is highly unlikely that induced fractures will reach any of these faults and interfere with fracturing fluid containment. (a)(12) Proposed program for fracturing operation Provided with application. CDW 05/21/2025 (a)(12)(A) Estimated volume Provided with application. 2524 bbl total dirty vol. 106K lb total proppant CDW 05/21/2025 (a)(12)(B) Additives: names, purposes, concentrations Provided with application. CDW 05/21/2025 (a)(12)(C) Chemical name and CAS number of each Provided with application. Halliburton disclosure provided. Proprietary chemicals on file at AOGCC CDW 05/21/2025 (a)(12)(D) Inert substances, weight or volume of each Provided with application. CDW 05/21/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 2S-05 (PTD No. 216-039; Sundry No. 325-263) Paragraph Sub-Paragraph Section Complete? AOGCC Page 5 June 9, 2025 (a)(12)(E) Maximum treating pressure with supporting info to determine appropriateness for program Simulation shows max surface pressure 5500 psi. Max. 7500 psi allowable treating pressure. With 3500 psi back pressure IA (IA popoff set 3600 psi), max tubing differential should be 2000 psi. ePRV 3750 psi, Annulus PRV 3600 psi, tubing ePRV 7125 psi. CDW 05/21/2025 (a)(12)(F) Fractures – height, length, MD and TVD to top, description of fracturing model Provided with application. The anticipated half-lengths of the induced fractures are 500’ according to the Operator’s computer simulation. Computer simulation indicates the anticipated height of the induced fractures will be 55’. The shallowest perforation will be about 8,850’ MD (-6,160’ TVDSS) and the fracture expected to be confined beneath the base of the overlying Kalubik confining interval at 8,471’ MD (-6,054’ TVDSS). SFD 6/8/2025 (a)(13) Proposed program for post-fracturing well cleanup and fluid recovery Well cleanout and flowback procedure provided with application. No disposal identified. CDW 05/21/2025 (b)Testing of casing or intermediate casing Tested >110% of max anticipated pressure 3500 psi back pressure, plan to test to 3850 psi, popoff set as 3600 psi CDW 05/21/2025 (c) Fracturing string (c)(1) Packer >100’ below TOC of production or intermediate casing 3.5” tubing will be anchored with a packer set at approx. 8691 ft with perforations planned for 8850-9015 ft. TOC in 7-5/8” casing at 7244 ft so packer set >100 ft below TOC. CDW 05/21/2025 (c)(2) Tested >110% of max anticipated pressure differential Tubing test of 3125 psi. Max pressure differential is estimated as 2000 psi (5500psi with 3500 psi backpressure) so test of 3125 psi satisfies 110% CDW 05/21/2025 (d) Pressure relief valve Line pressure <= test pressure, remotely controlled shut-in device 9000 psi line pressure test, max est frac pressure 5500 psi, ePRV 7125 psi. IA PRV set as 3600 psi. CDW 05/21/2025 (e) Confinement Frac fluids confined to approved formations Provided with application. CDW 05/21/2025 (f) Surface casing pressures Monitored with gauge and pressure relief device IA PRV set at 3600 psi. Surface annulus open. Frac pressures continuously monitored. CDW 05/21/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 2S-05 (PTD No. 216-039; Sundry No. 325-263) Paragraph Sub-Paragraph Section Complete? AOGCC Page 6 June 9, 2025 (g) Annulus pressure monitoring & notification 500 psi criteria During hydraulic fracturing operations, all annulus pressures must be continuously monitored and recorded. If at any time during hydraulic fracturing operations the annulus pressure increases more than 500 psig above those anticipated increases caused by pressure or thermal transfer, the operator shall: CDW 05/21/2025 (g)(1) Notify AOGCC within 24 hours (g)(2) Corrective action or surveillance (g)(3) Sundry to AOGCC (h) Sundry Report (i) Reporting (i)(1) FracFocus Reporting (i)(2) AOGCC Reporting: printed & electronic (j) Post-frac water sampling plan Not required (see Section (a)(3), above). SFD 6/8/2025 (k) Confidential information Clearly marked and specific facts supporting nondisclosure Non-confidential well. SFD 6/8/2025 (l) Variances requested Modifications of deadlines, requests for variances or waivers No plan for post fracture water well analysis. Commission may require this depending on the performance of the fracturing operation. ORIGINATED TRANSMITTAL DATE: 2/19/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5294 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5294 2S-05 50103207390000 Tubing Cut Record 11-Feb-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 216-039 T40106 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.19 15:26:17 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 15130'662 9535' 9537' Casing Collapse Conductor Surface Production Slotted Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Subsequent Form Required: Suspension Expiration Date: L-80 James Ohlinger 3/16/2025 2898' 9019' Perforation Depth MD (ft): james.j.ohlinger@conocophillips.com 8874'None 8992' 4-1/2" None Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6335' 2927' Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size 8757'MD/6287'TVD 8841'MD/6306'TVD Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 2565' Burst KRU 2S-05 Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25604, ADL 25589, ADL25603 216-039 P.O. Box 100360, Anchorage, AK 99510 50-103-20739-00-00 ConocoPhillips Alaska, Inc 107.5' Baker Baker Premier Baker HRD-E ZXP SSSV: None 6271'15118'6258' 7-5/8" 16" 15118'6277' 107.5' 6271' None 10-3/4" 80' m n P 2 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Contact Phone: 907-265-1102 CTD Staff Engineer By Grace Christianson at 12:24 pm, Jan 23, 2025 325-028 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E= James.J.Ohlinger@cop.com Reason: I am the author of this document Location: Date: 2025.01.23 11:15:24-09'00' Foxit PDF Editor Version: 13.0.0 James J. Ohlinger X JJL 2/5/25 10-404 SFD 1/24/2025 DSR-1/31/25 AOGCC Witnessed BOP and Annular Test to 2500 psi. Pipe rams required that fit the size of drill pipe, tubing, or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars. *&: 2/5/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.05 15:53:27 -09'00' RBDMS JSB 020625 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 23, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: James J Ohlinger Staff CTD/RWO Wells Engineer ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 2S-05 (PTD# 216-039-0). Well 2S-05 was originally spud in 5/16/16 and rig released 6/6/16.The well has primarily been a Kuparuk A-sand and C-sand Producer.The well has developed AnnComm issues that moved it to being a RWO candidate due to leaks. If you have any questions or require any further information, please contact me at +1-907-229-3338. The tubing will be pulled, and the 7-5/8" casing cleared and plugged at the casing shoe. We're plugging off the 4-1/2" liner due to a hole in the liner that is producing rocks. A new 3.5" completion will be installed with a new packer to recomplete the well. We are going to perforate the same A-sand interval that the existing liner is in. A frac sundry will be submitted soon. 2S-05 RWO Procedure Kuparuk Producer PTD #216-039 Page 1 of 5 General Well info: Wellhead type/pressure rating: Cameron 11” MBS, 5M psi top flange on Tubing head and Casing head Production Engineer: Mandy Pogany Reservoir Development Engineer: Grace Knock Estimated Start Date: 3/16/2025 Workover Engineer: James J Ohlinger (+1-907-265-1102/ James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to the pre-rig cut ~8750’ MD. Mill/remove the packer and liner inside the 7-5/8” casing. Set a bridge plug at the casing shoe in the 7-5/8”. Install a new 3-1/2” completion with new packer. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram / Drilling Spools Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed 06/30/2016 IC POT & PPPOT Failed – 7/01/2016 MPSP: 662 psi using 0.1 psi/ft gradient Static BHP: 1290 psi / 6281’ TVD measured on 8/22/22 Pre-Rig Work 1. IC-POT, IC-PPPOT, T-PPPOT and T-POT tests. 2. Tubing drift run 3. SBHP 4. MIT-OA & IA 5. Open lowest GLM in upper completion. Dummy off other GLMs. 6. Cut the Premier Packer for release 7. Cut the tubing nominally at ~8750 RKB in the middle of the pup joint above the Premier Packer. 8. Prepare well within 48 hrs of rig arrival. 2S-05 RWO Procedure Kuparuk Producer PTD #216-039 Page 2 of 5 Rig Work MIRU 1. MIRU Nabors Nordic 3 on 2S-05. (No BPV will be installed due to risk assessment done for MIRU/RDMO on N3w/o BPV.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut (~8750’ RKB). a. If not all tubing comes due to subsidence, then work additional steps below to clear buckled 7-5/8”, then pull remaining completion. b. *Depending on drifts, go to “Contingency for Subsidence on 7-5/8”. Remove Packer and ZXP Liner Hanger; clear out 7-5/8” Casing 6. Spear the Baker Premier Packer and remove the lower section of the 3-1/2” tubing completion. a. Will have been cut to release during pre-rig 7. Clean out 4-1/2” liner, known rock production due to liner collapse 8. Cut 4-1/2” liner ~9015’, casing shoe at 9019’ MD. 9. Spear the Tie back extension and remove 10. Mill ZXP, spear in the lower ZXP body or Hanger body and pull it out 11. Clean out 7-5/8” casing 12. Set Cast Iron Bridge plug ~9015’ MD. Install in 3-½” Completion 13. MU 3 ½” completion with Big tail pipe, packer, nipples, downhole gauge and GLMs. RIH with completion. 14. Once on depth, space out as needed. Reverse circulate in CI fluid at opportune time as needed. 15. Drop ball and rod to set packer 16. Pressure test tubing to 3000 psi for 30 minutes and chart. 17. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 18. Confirm pressure tests, then shear out SOV with pressure differential. 19. Install BPV. 20. ND BOPE. NU tree. PT tree. 21. Pull BPV, freeze protect well at opportune time, and set BPV if necessary. 22. RDMO. Post-Rig Work 23. Pull Ball & Rod 24. Perforate 7-5/8” casing 8850-9015’ MD 25. Frac A4 sand (Sundry in progress) 26. Install GLD. 27. Turn over to operations. 2S-05 RWO Procedure Kuparuk Producer PTD #216-039 Page 3 of 5 Contingency for Subsidence on 7-5/8” Pull Subsided 7-5/8” Casing 28. Set storm packer or plug in 7-5/8” casing and PT to confirm as barrier. 29. ND BOPE. ND old tubing spool. NU BOPE and test flange break. a. Grow/stretch and Cut 7-5/8” casing at surface as necessary to deal with subsidence in this step. b. Can’t test flange break with test-joint since packoffs are removed and 7-5/8” is above flange. Test 11” 3k flange break to 3000 psig at earliest opportunity. 30. Pull storm packer or plug. Condition fluid as needed. 31. RU Eline and log 7.0” casing for OA cement from Arctic Pack job. 32. Cut 7.0” casing with cutter above OA cement. a. Circulate out Arctic Pack diesel/slurry as needed. 33. Pull 7.0” casing down to cut (~2000’). a. Make addition cut/pulls/BHA runs as necessary to remove 7”. b. Test 11” 3k flange to 3000 psig if not already done so. Bore out 10-3/4” and run 7-5/8” Tie-Back 1. PU mills and bore out 10-3/4” as necessary to obtain drift for new 7-5/8” tie-back. a. As drift is regained, pull any additional 7-5/8” or 3.5” tubing as needed to get 7-5/8” removed down to cement in OA. 2. Run new 7-5/8” tie-back casing with overshot. 3. Test casing to 2500 psig. 4. Cement OA to surface. 5. Perform 30 minute no flow test, split stack and land slips, cut excess casing and install IC packoffs. Installed Tie- back spool and terminate 7-5/8”. Land stack and MU to casing flange. a. Test flange break to BOPE test pressure. 6. Mill plugs in cementer. 7. Circulate out sand on IBP or any lower plug. 8. Pull any lower plugs or remaining 3.5”. 9. Return to “Install in 3-½” Completion”. * Note: Setting of referenced plug(s) omitted from steps above. - JJL * Note: There is no 7" casing in well. 7" references are meant to be 7 5/8". - JJL * Ensure cement to surface or OA is freeze protected. - JJL 2S-05 RWO Procedure Kuparuk Producer PTD #216-039 Page 4 of 5 2S-05 Existing RWO Completion Producer COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 108 108 16 15.25 62.5 H-40 Surface 2927 2565 10-3/4 9.95 45.5 L-80 HYD 563 Intermediate 9019 6335 7-5/8 6.88 29.7 L-80 HYD 563 Tubing 8874 6313 3-1/2 2.992 9.3 L-80 EUE-M Liner 15117.6 6271.2 4.5 3.96 12.6 L-80 Hyd 563 Upper Completion Cameron 11" x 4-1/2" IBT-m Tubing Hanger XO, 4-1/2" 12.6# L-80 IBTM x 3-1/2" 9.3# L-80 EUE @ 67' RKB 3-1/2" 9.3# L-80 EUE 8rd Tubing 3-1/2" Camco KBMG mandrels @ 4346',8021', 8522' RKB Baker 3½" CMU w/ 2.813" DS Profile Schlumberger Gauge Carrier 3.5" x 7-5/8" Premier Packer @ 8757' RKB 3-½" Camco D landing nipple at 8783' RKB (2.75" min ID) Baker 7.625" x 3.5" Shear pinned Fluted No-Go Sub-- Large OD Baker 7.625" x 3.5" Shear pinned Fluted No-Go Sub-- small OD WLEG @ 8872' RKB 4-1/2" Liner Completion Baker HRD-E ZXP @ 8841' RKB Baker 5.5" RS PO Seal Nipple @ 8865' RKB Baker 5.5"x7.63" FlexLock @ 8868' RKB Surface Casing Intermediate Casing ~9019' RKB Conductor 8841' ZXP 8757' Premier 8783' D-NippleC-Sand ~8780'-8820' A5-Sand ~8820'-8850' A4-Sand ~8850'-9015' ~8750' Tubing Cut TAGGED ROCKS AT 8784' CTMD, MOTOR/VENTURI DOWN TO 8811',CTMD. RECOVERED SEVERAL CUPS OF LARGE AND SMALL ROCKS, & SOME METAL, JOB IN PROGRESS 2S-05 RWO Procedure Kuparuk Producer PTD #216-039 Page 5 of 5 2S-05 Proposed RWO Completion Producer COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 108 108 16 15.25 62.5 H-40 Surface 2927 2565 10-3/4 9.95 45.5 L-80 HYD 563 Intermediate 9019 6335 7-5/8 6.88 29.7 L-80 HYD 563 Tubing 8874 6313 3-1/2 2.992 9.3 L-80 EUE-M Liner 15117.6 6271.2 4.5 3.96 12.6 L-80 Hyd 563 Upper Completion Cameron 11" x 4-1/2" HYD563 Tubing Hanger XO, 4-1/2" 12.6# L-80 HYD563 x 3-1/2" 9.3# L-80 HYD563 @ xx' RKB 3-1/2" 9.3# L-80 HYD563 Tubing 3.5" x 1" KBG-2-9 @ xxxx' Schlumberger Gauge Carrier 3.5" x 7-5/8" "Premier" Packer @ xxxx' RKB 3-½" Camco D landing nipple at xxxx' RKB (2.75" min ID) 4-1/2" 12.6# w/ (MMM# 13914615) Maxwell Centralizers (Future CTD KO) Surface Casing Intermediate Casing ~9019' RKB Conductor C-Sand ~8780'-8820' A5-Sand ~8820'-8850' A4-Sand ~8850'-9015' 40' 30' 65' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:2S-05 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Rock Screen 2S-05 5/4/2024 rogerba Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.25 27.5 107.5 107.5 62.50 H-40 SURFACE 10 3/4 9.95 28.5 2,927.2 2,565.1 45.50 L-80 HYD 563 INTERMEDIATE 7 5/8 6.88 26.9 9,019.4 6,335.2 29.70 L-80 Hyd 563 LINER 4 1/2 3.96 8,840.7 15,117.6 6,271.2 12.60 L-80 Hyd 563 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.1 Set Depth … 8,873.5 Set Depth … 6,312.5 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-m 8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.1 25.1 0.00 HANGER 10.850 Cameron 11" x 4-1/2" IBT-m Tubing Hanger Camero n Ser # 1206629 70-1, PN: 2220453 6-25-01 3.900 67.4 67.4 0.38 XO Reducing 4.500 XO, 4-1/2" 12.6# L-80 IBTM box x 3- 1/2" 9.3# L-80 EUE pin CPAI MM# 1054194 7 2.992 4,346.1 3,501.2 48.91 GAS LIFT 5.390 Camco 3½" x 1" KBMG GLM #1 w/ DV, BK-5 latch 4346' md/ 3501 TVD Camco KBMG 2.925 8,020.8 5,993.3 57.51 GAS LIFT 5.390 Camco 3½" x 1" KBMG GLM #2 w/ DV, BK-5 latch 8021' md 5993' TVD Camco KBMG 2.925 8,521.7 6,220.4 70.35 GAS LIFT 5.390 Camco 3½" x 1" KBMG GLM #3, BEK-2 latch w/ DCK-2 SOV 2500 psi csg-tbg 8522'md 6220' TVD. Camco KBMG 2.925 8,675.5 6,266.7 74.54 SLEEVE 4.500 Baker 3½" CMU in closed position w/ 2.813" DS Profile Baker PN: H810-79 -4430, Control No.: 1051462 01-02, CPAI 2.813 8,731.5 6,280.9 75.89 GAUGE 4.844 Schlumberger Gauge Carrier 3½" EUE P X P (measured w/ collar on top) Schlumb erger ser #C15GM -0411, PN 1009872 38 2.913 8,756.7 6,287.0 76.25 PACKER 6.590 Baker Premier Production Packer Baker H784-63 -008, Control No.: 1052720 51 2.880 8,783.2 6,293.2 76.62 NIPPLE 4.500 Camco 2.75 D nipple 4½" OD Camco ser #T05113 7, PN 1342751 2.750 8,836.6 6,305.1 77.84 LOCATOR 6.410 Baker 7.625" x 3.5" Shear pinned Fluted No-Go Sub-- Large OD Baker 3.000 8,837.6 6,305.3 77.87 LOCATOR 5.670 Baker 7.625" x 3.5" Shear pinned Fluted No-Go Sub-- small OD Baker 3.000 8,872.5 6,312.3 79.00 SHOE 3.500 Mule shoe WLEG, 3-1/2" IBT box 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,535.0 6,344.2 94.12 FISH motor bit box and crayola mill left in holetotal length 1.7'. OD of motor bitbox 2.13" - see attachements Quadco bit box and cryola mill 1/2/2024 0.000 9,536.7 6,344.1 94.11 FISH partial bha 2.13" OD, DFCV, TJ disco, 2.13 screen sub, 2.13 hydropull, XO, Stinger, OX, Down jet nozzle. see attachment. Quadco 12/31/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,346.1 3,501.2 48.91 1 GAS LIFT GLV BK 1 1,881.0 7/4/2016 0.188 8,020.8 5,993.3 57.51 2 GAS LIFT DMY BK 1 0.0 7/5/2016 0.000 8,521.7 6,220.4 70.35 3 GAS LIFT OV BK 1 0.0 7/5/2016 0.313 2S-05, 5/5/2024 7:36:33 AM Vertical schematic (actual) LINER; 8,840.6-15,117.6 Hydraulic Fracture; 15,008.2 Hydraulic Fracture; 14,492.6 Hydraulic Fracture; 13,970.2 Hydraulic Fracture; 13,411.4 Hydraulic Fracture; 12,931.8 Hydraulic Fracture; 12,410.8 Hydraulic Fracture; 11,550.5 Hydraulic Fracture; 10,909.7 Hydraulic Fracture; 10,030.7 FISH; 9,536.7 FISH; 9,535.0 INTERMEDIATE; 26.9-9,019.4 NIPPLE; 8,783.2 PACKER; 8,756.7 SLEEVE; 8,675.5 GAS LIFT; 8,521.7 GAS LIFT; 8,020.8 GAS LIFT; 4,346.1 SURFACE; 28.5-2,927.2 CONDUCTOR; 27.5-107.5 HANGER; 25.1 KUP PROD KB-Grd (ft) 27.50 RR Date 6/7/2016 Other Elev… 2S-05 ... TD Act Btm (ftKB) 15,130.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032073900 Wellbore Status PROD Max Angle & MD Incl (°) 94.25 MD (ftKB) 13,809.28 WELLNAME WELLBORE2S-05 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,840.6 6,306.0 77.97 PACKER 6.540 Baker HRD-E ZXP 5.5" x 7.63" Flex-Lock Liner top packer L-80 Hyd 521 pin Baker PN: H296- 45- 0093ST1, Control # 104893445- 01 4.810 8,863.6 6,310.6 78.71 XO Threads 5.500 Crossover 5.5" Hyd 521 box x 4- 1/2" Hyd 563 CPAI PN: NS S1500241, SO No.: 53217A-1 4.830 8,865.4 6,311.0 78.77 NIPPLE 5.500 Baker 5.5" "RS" Packoff Seal Nipple 17# Q-125 Hyd 563 box x box Baker PN: H294- 01-95AM, UMA No.: 24669-1-1, CPAI MM# 136 4.250 8,877.2 6,313.2 79.15 XO - Threads 5.500 Crossover 5.5" Hyd 563 box x 4- 1/2" Hyd 563 CPAI CPAI MM# 13523635 3.890 9,045.2 6,338.2 83.39 SWELL PACKER 5.750 Baker-- "Swell Packer"- "J" (#11) SN: 050494-001-14 Baker PN H301-87 -0115, Ser # 050494-001 -14 3.900 9,269.5 6,354.3 88.86 FRAC PORT 5.610 Baker 4-1/2" Frac Sleeve #9 - (2.625" Ball, Drift w/ 2.563") PN:10437088 ( MILLED OUT TO 2.71") 1/1/24 Baker PN:104370 88 2.710 9,645.8 6,336.3 94.13 SWELL PACKER 5.770 Baker-- "Swell Packer"- "I" (#10) SN: 050494-001-17 Baker PN H301-87 -0115, Ser # 050494-001 -17 3.900 10,030.7 6,322.7 91.16 FRAC PORT 5.610 Baker 4-1/2" Frac Sleeve #8 - (2.563" Ball, Drift w/ 2.5") PN:10437087 Baker PN:104370 87 2.531 10,408.2 6,324.4 87.76 SWELL PACKER 5.750 Baker-- "Swell Packer"- "H" (#9) SN: 050494-001-20 Baker PN H301-87 -0115, Ser # 050494-001 -20 3.900 10,909.7 6,322.3 90.03 FRAC PORT 5.750 Baker 4-1/2" Frac Sleeve #7 - (2.50" Ball, Drift w/ 2.438") PN:10437086 Baker PN:104370 86 2.468 11,207.4 6,322.7 89.93 SWELL PACKER 5.790 Baker-- "Swell Packer"- "G" (#8) SN: 050494-001-40 Baker PN H301-87 -0115, Ser # 050494-001 -40 3.900 11,550.5 6,326.5 89.57 FRAC PORT 5.750 Baker 4-1/2" Frac Sleeve #6 - (2.438" Ball, Drift w/ 2.375") PN:10437085 Baker PN:104370 85 2.406 11,888.0 6,328.2 89.42 SWELL PACKER 5.750 Baker-- "Swell Packer"- "F" (#7) SN: 050494-001-23 Baker PN H301-87 -0115, Ser # 050494-001 -23 3.900 12,068.0 6,327.5 92.31 SWELL PACKER 5.750 Baker-- "Swell Packer"- "K" (#6) SN: 050494-001-32 Baker PN H301-87 -0115, Ser # 050494-001 -32 3.900 12,410.8 6,308.8 92.10 FRAC PORT 5.740 Baker 4-1/2" Frac Sleeve #5 - (2.375" Ball, Drift w/ 2.313") PN:10437084 Baker PN:104370 84 2.343 12,667.2 6,304.9 90.49 SWELL PACKER 5.750 Baker-- "Swell Packer"- "E" (#5) SN: 050494-001-41 Baker PN H301-87 -0115, Ser # 050494-001 -41 3.900 12,931.8 6,301.7 90.72 FRAC PORT 5.730 Baker 4-1/2" Frac Sleeve #4 - (2.313" Ball, Drift w/ 2.25") PN:10437083 Baker PN:104370 83 2.281 13,187.6 6,300.3 90.17 SWELL PACKER 5.750 Baker-- "Swell Packer"- "D" (#4) SN: 050494-001-43 Baker PN H301-87 -0115, Ser # 050494-001 -43 3.900 13,411.4 6,298.2 90.89 FRAC PORT 5.740 Baker 4-1/2" Frac Sleeve #3 - (2.25" Ball, Drift w/ 2.188") PN:10437082 Baker PN 10437082 2.218 13,707.5 6,291.4 92.73 SWELL PACKER 5.750 Baker -- "Swell Packer"- "C" (#3) SN: 050494-001-18 Baker PN H301-87 -0115, Ser # 050494-001 -18 3.900 13,970.2 6,273.5 94.05 FRAC PORT 5.730 Baker 4-1/2" Frac Sleeve #2 - (2.188" Ball, Drift w/ 2.125") PN:10437081 Baker PN 10437081 2.135 14,228.0 6,267.4 88.11 SWELL PACKER 5.750 Baker-- "Swell Packer"- "B" (#2) SN: 050494-001-22 Baker PN H301-87 -0115, Ser # 050494-001 -22 3.900 14,492.6 6,272.4 89.12 FRAC PORT 5.620 Baker 4-1/2" Frac Sleeve #1 - (2.125" Ball, Drift w/ 2.00") PN:10437070 Baker PN 10437070 2.073 14,750.0 6,275.4 90.18 SWELL PACKER 5.760 Baker -- "Swell Packer"- "A" (#1) SN: 050494-001-6 Baker PN H301-87 -0115, Ser # 050494-001 -6 3.900 2S-05, 5/5/2024 7:36:34 AM Vertical schematic (actual) LINER; 8,840.6-15,117.6 Hydraulic Fracture; 15,008.2 Hydraulic Fracture; 14,492.6 Hydraulic Fracture; 13,970.2 Hydraulic Fracture; 13,411.4 Hydraulic Fracture; 12,931.8 Hydraulic Fracture; 12,410.8 Hydraulic Fracture; 11,550.5 Hydraulic Fracture; 10,909.7 Hydraulic Fracture; 10,030.7 FISH; 9,536.7 FISH; 9,535.0 INTERMEDIATE; 26.9-9,019.4 NIPPLE; 8,783.2 PACKER; 8,756.7 SLEEVE; 8,675.5 GAS LIFT; 8,521.7 GAS LIFT; 8,020.8 GAS LIFT; 4,346.1 SURFACE; 28.5-2,927.2 CONDUCTOR; 27.5-107.5 HANGER; 25.1 KUP PROD 2S-05 ... WELLNAME WELLBORE2S-05 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) 15,008.2 6,271.8 90.34 FRAC PORT 5.610 4-1/2" Baker Alpha Pressure Sleeve Baker PN: H810- 07-0027, Control # 10412242 3.010 15,021.2 6,271.7 90.34 SLEEVE 5.000 4-1/2" Baker Wellbore Isolation Valve (H036784300) Baker PN: H809- 89-0011, Control # FPSC 1717 1.250 15,075.1 6,271.4 90.34 COLLAR 4.500 4-1/2" 12.6 ppf L-80 Weatherford Float Collar Weatherf ord Model 402E, Weatherford PN: 577478, HT 931869 3.885 15,076.4 6,271.4 90.34 XO - Threads 4.500 4-1/2" 12.6 ppf L-80 liner crossover jt Ibt-m box x Hyd 563 pin 3.958 Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 15,008.2 15,009.2 1 Hydraulic Fracture 6/23/2016 500,000.0 101,000.0 2,254.00 2,357.00 14,492.6 14,493.6 2 Hydraulic Fracture 6/23/2016 500,000.0 100,500.0 1,486.00 1,589.00 13,970.2 13,971.2 3 Hydraulic Fracture 6/23/2016 500,000.0 100,000.0 1,731.00 1,833.00 13,411.4 13,412.4 4 Hydraulic Fracture 6/23/2016 500,000.0 102,100.0 1,467.00 1,572.00 12,931.8 12,932.8 5 Hydraulic Fracture 6/23/2016 500,000.0 100,000.0 1,602.00 1,704.00 12,410.8 12,411.8 1 Hydraulic Fracture 6/26/2016 500,000.0 99,500.0 1,591.00 1,693.00 11,550.5 11,551.5 2 Hydraulic Fracture 6/26/2016 500,000.0 100,000.0 1,502.00 1,604.00 10,909.7 10,910.7 3 Hydraulic Fracture 6/26/2016 500,000.0 99,500.0 1,458.00 1,560.00 10,030.7 10,031.7 4 Hydraulic Fracture 6/26/2016 500,000.0 101,000.0 1,477.00 1,580.00 9,269.5 6,270.5 5 Hydraulic Fracture 6/26/2016 500,000.0 101,200.0 1,464.00 1,568.00 2S-05, 5/5/2024 7:36:35 AM Vertical schematic (actual) LINER; 8,840.6-15,117.6 Hydraulic Fracture; 15,008.2 Hydraulic Fracture; 14,492.6 Hydraulic Fracture; 13,970.2 Hydraulic Fracture; 13,411.4 Hydraulic Fracture; 12,931.8 Hydraulic Fracture; 12,410.8 Hydraulic Fracture; 11,550.5 Hydraulic Fracture; 10,909.7 Hydraulic Fracture; 10,030.7 FISH; 9,536.7 FISH; 9,535.0 INTERMEDIATE; 26.9-9,019.4 NIPPLE; 8,783.2 PACKER; 8,756.7 SLEEVE; 8,675.5 GAS LIFT; 8,521.7 GAS LIFT; 8,020.8 GAS LIFT; 4,346.1 SURFACE; 28.5-2,927.2 CONDUCTOR; 27.5-107.5 HANGER; 25.1 KUP PROD 2S-05 ... WELLNAME WELLBORE2S-05 • • Z .Q —O39 Nov RECEIVED ConocoPhillips Alaska SEP 2 6 2017 P.O. BOX 100360 pt"�f"'`('�' ANCHORAGE,ALASKA 99510-0360 AOGCC September 24, 2017 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 scApMED t_ Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. 71Sin rely, Roger Winter ConocoPhillips Well Integrity Field Supervisor • 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/25/2017 2S pad Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2S-05 501032073900 216-039-0 22" 0.05 11" 6/7/2017 1.7 9/10/2017 2S-06 501032074700 216-085-0 4' 0.25 15" 6/10/2017 3.4 9/10/2017 2S-07 501032071300 215-079-0 22" 0.16 11" 6/7/2017 3.4 9/10/2017 2S-08 501032072200 215-174-0 17" 0.10 13" 6/7/2017 3.4 9/10/2017 2S-09A 501032074901 216-128-0 39" 0.30 12" 6/10/2017 4.25 9/20/2017 2S-10 501032071700 215-110-0 10' 1.50 9" 6/10/2017 1.7 9/10/2017 2S-11 501032073200 215-219-0 20" 0.10 10" 6/7/2017 3.4 9/10/2017 2S-12 501032074300 216-074-0 25" 0.10 13" 6/7/2017 4.8 9/10/2017 , 2S-13A 501032072001 216-104-0 30" 0.40 9" 6/7/2017 3.4 9/10/2017 2S-14 501032073300 215-220-0 27" 0.24 12" 6/7/2017 3.9 9/10/2017 • • 1.,5,_ soo 9 o 0 N 9 a) N N z c O O O m O wC N O O .9 .E0 •E E .Z • E a G „ N N U NO N N Nn cox 0 O.C _ pU _ r D m Q Qc QO Q Qzzz Uz 0 +_ V o m a aO 0 0- 0 0 0 0 o o ,;w 0 00 o0UUU (75 (7) (7) 0 c aa) aao aauw > H i c c c1 b Z Z E E .-8 Ea) E E LC) (C) l0 (C) UC) N N N d (n �', N CO c'70 c.0 C c cm O 9- O N O O In cn U) I l--' a) � mo a) a) 0m Q C m Cl C tl a- LL w it fa LL(/j N to N N'O N N NI Q-' NI Ni d' 0� 0� 0� 0� 0g a - -<' Wi aM a a a 9i 00. 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W 0z V C.) O Z 8 Q "8N — d 3 J o co 0- COo 2oLP O N n Ev V0 wo J Q l aaa 0 H co H I- z C o GN Co re O CO CO Q 0 IC( a Y o Y a> Q C 0 115 Zo E U z d N M j m o F- v t- 3 NN d re M- V U - a c7 0 • • ,2�1 S—ci F Zt O,10 Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.co aU1+ i , Sent: Monday, August 15, 2016 3:08 PM 2 To: Cook, Guy D (DOA) Cc: Regg,James B (DOA); CPF2 DS Lead Techs NSK; NSK Fieldwide Operations Supt Subject: RE: KRU 2S-05 Deficiency Report Attachments: 2S-05 Deficiency Rpt complete 08-15-16.pdf; 2S-05 sign 08-15-16.pdf e t- reS'LC Guy-After thinking about it I went ahead and revised your deficiency report to show my positions information instead of the SVS Tech's. Please let the other inspectors know to use this information when submitting these reports. Enclosed you will find the completed deficiency report for the wellhouse sign on 2S-05 and an accompanying photo showing that it has been installed. If you need any further information please let us know. Thanks Darrell Humphrey/ Bob Christensen Production Engineering Specialist Conocophillips Alaska Inc. n1139@conocophillips.com Office (907) 659-7535 Pager(907) 659-7000#924 From: Cook,Guy D (DOA) [mailto:guy.cook@alaska.gov] Sent: Monday, August 08, 2016 8:35 PM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Cc: NSK SVS Tech<n2062@conocophillips.com>; Regg,James B (DOA)<jim.regg@alaska.gov> Subject: [EXTERNAL]RE: KRU 2S-05 Deficiency Report Darrell, J Sorry for the inconvenience, I meant to send this to you and cc Lou since I had just/Poke to him on the phone regarding this report. In the future I will send all the deficiency reports to your office onl ' Attached is the deficiency report for KRU 2S-05 not having an identifying 'ell sign. This is provided for your records and to ensure the deficiency is corrected. Please provide photo evidence • the well sign after installation when you return the completed deficiency report (date corrected). Thank you, Guy Cook Petroleum Inspector AOGCC 907-227-2614 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 1 • • I State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: KRU 2S-05 Date: 8/7/2016 PTD: 2160390 Operator: CPAI Type Inspection: SVS Operator Rep: Humphrey/Christensen Inspector: Guy Cook , Position: Prod. Engineering Specialist Op.Phone: 907-659-7535 Correct by(date): 9/7/2016 Op. Email: n1139@conocophillps.com Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Missing well sign;refer to 20 AAC 25.040 ,- Well House sign has been installed as of 8/15/16.A picture is enclosed with the email. / 8/15/2016 Operator Rep Signatures: �-� r-�•-`'l/` AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention:Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 12/2015 »...ma,x�y:. ,?;` ,: N. 41( .. . c:t'r'Y 't:••,,,„.,, --_:..:-iwwwr.e. t!,:t•ti^' .-- ii w"' ; . w'ir,'�Y.'t�i S;f4"` i .Wti Y •ate, - ;.�-,i W �` .� .wt M1 '!'":::441,C14";'-41•:,• ,44#0071''''''' 'y s".,lya.`, _�,.:, _'»`«,�"Y"^'� .(r ;s, :,a. ..R w- ''�M1»j �µ' ro ,- . ,.'rt, t,.rt.:,M.c n :£M,yn, :• ."'.. ' - '- �.x. • c,, «�.•. � :',,�'..1 :Lj' �, ,�y." �mow'' ��:, - ' .tttf't •• , ; `%it, r' _w"*.•„ir,, ',,',;.o ---.�' ' ' rj ,••7•9;-: "• a ',y ,; -...:,,:,47„'"„*".ti',: ;t, ".;• ':t'~ .. i. i". ■ " y til::•`r use t a5•y, yf,• Y:;.' . ,�„'•:. •'.:` -.rix•,-, :;:. «, a.' iT"s',i,', st= • �, . �,•5 3` !'�F' .4.. "," :1,,. �/ ” yt+.!": Sx's.'{; • 7�- wLJ1 tJ{.,f y .1w. ':i:'»,»,`Y • ' N•Y.: CM,:"+,, ,. MS ,.`,'x,3„ I : •STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION 2 7 5 4 8 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate Pull r Operations Shutdown r Performed: Suspend Perforate p r r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: n 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 216-039 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20739-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25604, 25589,25603 KRU 2S-05 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Kuparuk River Field/Kuparuk Oil Pool 11.Present Well Condition Summary: Total Depth measured 15130 feet Plugs(measured) > iErEWED true vertical 6258 feet Junk(measured) N/A Au G 11 2016 Effective Depth measured 15116 feet Packer(measured) 8757', 8840' r true vertical 6271 feet (true vertical) 6287', 6306' AOCCC�"/ Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 107.5' 107.5' Surface 2887' 10-3/4" 2927' 2565' Intermediate 8979' 7-5/8" 9019' 6335' Liner 6269' 4-1/2" 8841'- 15118' 6306'-6271' Perforation depth: Measured depth: Frac Ports 9269', 10031', 10910', 11550', 12411', 12932', 13411', 13970', 14492', 15008' True Vertical Depth: Frac Ports 6354', 6323', 6322', 6326',6309', 6302', 6298', 6273',6272', 6272' Tubing(size,grade,MD,and TVD) 3.5", L-80, 8873' MD/6312'TVD Packers&SSSV(type,MD,and TVD) Production Pkr @ 8757' MD/6287'TVD No-Go Subs @ 8837' MD/6305'TVD; 8838' MD/6305'TVD NO SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9269'- 12411' ; 12932'- 15008' Treatment descriptions including volumes used and final pressure: Total 10 Stages-see attached Schematic for full Frac Details 65,000#100 Mesh Sand; 1,004,800#16/20 Carbolite Proppant 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 768 833 Subsequent to operation 2888 8069 51 1393 366 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory f Development f Service r Stratigraphic r Copies of Logs and Surveys Run r al.1 16.Well Status after work: Oil 17 Gas f WDSPL r R-inted and Bectronic Fracture Stimulation Data P GSTOR r WINJ r WA r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-309 Contact Adam Klem, 907-263-4529 Email Adam.Klem(c�conocophillips.com Printed Name Adam K Title Sr. Completions Engineer Signature 42' Date 08/09/16 i,-rt g/2 /l C.1:4-4 °1I7/20/4 %8/i Form 10-404 Revised 5/2015 RBDMS LL AUG i 2 2016Submit Original Only 1 I • r 2S-05 DTTMSI JOBTYP SUMMARYOPS 6/22/16 FRACTURING Completed rig up of frac equipment and performed pressure test. Sheared open Alpha sleeve at 6286 psi, established injectivity into formation of 4.7 bpm @ 2250 psi. Secure equipment; will return in A.M. to perform frac treatment. 6/23/16 FRACTURING ASSIST WITH FRAC 6/23/16 FRACTURING PUMPED MINIFRAC AND STAGES 1-5 PLACING ALL PROPPANT AS DESIGNED. TOTAL AMOUNTS: SILICA FLOUR: 4,300LBS, 100MESH: 32,500LBS, 16/20: 501,500LBS 6/26/16 FRACTURING 6/26/16 FRACTURING PUMPED STAGES 6-10 PLACING ALL PROPPANT AS DESIGNED. TOTAL AMOUNTS: SILICA FLOUR: 4,350LBS, 100MESH: 32,500LBS, 16/20: 493,300LBS 6/29/16 FRACTURING ASSIST SLICKLINE AS DIRECTED (JOB COMPLETE) MITT PASSED 3000PSI 6/29/16 FRACTURING DISPLACE TBG W/97 BBLS CRW SW FOLLOWED BY 25 BBLS DIESEL; BRUSH n' FLUSHED DOWN THRU D-NIPPLE @ 8783' RKB; SET 2.75" CA-2 PLUG © 8783' RKB; MITT (PASS) & DDT FAILED; MAKE SEVERAL ATTEMPTS TO PULL CA-2 PLUG. IN PROGRESS. 6/30/16 FRACTURING ASSIST SLICKLINE AS DIRECTED, MITT PASS 3000, DDT PASS (JOB COMPLETE) 6/30/16 FRACTURING ATTEMPT TO PULL CA-2 PLUG © 8783' RKB; TIE INTO GLM ©4346' RKB & SET 3 1/2 RBP (SER#CPP35056 & CPEQ35002) @ 4378' RKB; DEPLOY AVA CATCHER; MITT AND DDT (PASS); PULLED DV @ 4346' RKB (LATCH MODERATELY ERODED FROM FRAC). READY FOR DHD. 7/1/16 FRACTURING (MISC) : T-POT (PASSED). T-PPPOT (PASSED). INTERMEDIATE POT (PASSED). INTERMEDIATE PPPPOT (PASSED). IC-POT(FAILED). IC-PPPOT (FAILED). TEST BPV TO 1000 PSI (PASSED). TxIA-DDT TO 0 PSI (PASSED). 7/2/16 FRACTURING (MISC) SHELL TEST POST TREE SWAP, PASSED. 7/4/16 FRACTURING ASSIST SLICKLINE AS DIRECTED 7/4/16 FRACTURING PULLED AVA CATCHER & RBP ©4378' RKB; SET BAITED PULLING TOOL ON CA-2 PLUG @ 8783' RKB; SET GLV @ 4346' RKB & PULLED DV © 8021' RKB (LATCH SEVERELY ERODED FROM FRAC). IN PROGRESS. 7/5/16 FRACTURING SET DV© 8021' RKB. PULLED DV FROM 8522' RKB, SET 5/16" OV @ SAME. BLEED IA DOWN TO CONFIRM VALVES ARE SET. PULLED BAITED PULLING TOOL W/CA-2 8/3/16 PUMPING PUMP 10 BBLS DSL DOWN TBG TO FLUSH TREE, PUMP 10 BBLS DSL DOWN FL TO TRACKING FLUSH SL. (JOB COMPLETE) nnn v �, t KUP PROD i .5 ConocoPhillips Well Attributes IMax Angle Si MD TD a. Alaska,Inc, Wellbore APIIUWI Field Name Wellbore Status rax (°) MD(ftKB) Act Btm(ftKB) Caerocophipips 501032073900 KUPARUK RIVER UNIT PROD 94.25 13,809.28 15,130.0 ° --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2S-05,8/9/20162:18:08 PM SSSV: NONE Last WO: 27.50 6/7/2016 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;25.1-. Last Tag: _ Rev Reason:SET PLUG,CATCHER 8 GLV C/O pproven 7/13/2016 I 11 8Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread [L' CONDUCTOR 16 15.250 27.5 107.5 107.5 62.50 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread XO Reducing;67.4 SURFACE 10 3/4 9.950 28.5 2,927.2 2,565.1 45.50 L-80 HYD 563 'fiTCasing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread -A-e,CONDUCTOR;27.5-107,5- INTERMEDIATE 75/8 6.875 26.9 9,019.4 6,335.2 29.70 L-80 Hyd 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ■ 1s LINER 41/2 3.958 8,840.7 15,117.6 6,271.2 12.60 L-80 Hyd 563 SURFACE;28.5-2,927.2 Liner Details Nominal ID GAS LIFT;4,346.1 Top(ftKB) Top(ND)(HKB) Top Incl(°) Item Des Com (in) � 8,840.6 6,306.0 77.97 PACKER Baker HRD-E ZXP 5.5"x 7.63"Flex-Lock Liner top 4.810 CATCHER:4,374.8 \''till/ PLUG;4,378.0 packer L-80 Hyd 521 pin 8,865.4 6,311.0 78.77 NIPPLE Baker 5.5""RS"Packoff Seal Nipple 17#Q-125 4.250 Hyd 563 box x box 8,867.8 6,311.4 78.85 HANGER Baker 5.5"x 7.63"Flex-Lock Liner hanger P-110 4.800 GAS LIFT;8,020.8 Hyd 563 pin x pin 9,045.2 6,338.2 83.39 SWELL Baker-"Swell Packer"-"J"(#11) SN:050494-001- 3.900 GAS LIFT;8,521.7bill 4 PACKER 14 . 9,269.5 6,354.3 88.86 FRAC PORT Baker 4-1/2"Frac Sleeve#9-(2.625"Ball,Drift w/ 2.593 SLEEVE;8,675.5 ,4, 2.563")PN:10437088 at 9,645.8 6,336.3 94.13 SWELL Baker-"Swell Packer"-"I"(#10) SN:050494-001- 3.900 in IIIP PACKER 17 GAUGE;8,731.5 XO Threads;8,747.2 II 10,030.7 6,322.7 91.16 FRAC PORT Baker4-1/2"Frac Sleeve#8-(2.563"Ball,Drift NA,/ 2.531 PACKER;8,758.7 2.5")PN:10437087 XO Threads;8,763.3 l� - 10,408.2 6,324.4 87.76 SWELL Baker-"Swell Packer-"H"(#9) SN:050494-001- 3.900 PLUG;8.783.0 '1':'". PACKER 20 tim - 10,909.7 6,322.3 90.03 FRAC PORT Baker 4-1/2"Frac Sleeve#7-(2.50"Ball,Drift w/ 2.468 LOCATOR;8,836.6 2.438")PN:10437086 LOCATOR;8,837.6 IMIW II 11,207.4 6,322.7 89.93 SWELL Baker-"Swell Packer"-"G"(#8) SN:050494-001- 3.900 PACKER 40 11,550.5 6,326.5 89.57 FRAC PORT Baker 4-1/2"Frac Sleeve#6-(2.438"Ball,Drift w/ 2.406 ...I 2.375")PN:10437085 SHOE;6,872.5 11,888.0 6,328.2 89.42 SWELL Baker-"Swell Packer"-"F"(#7) SN:050494-001- 3.900 PACKER 23 I ii, 12,068.0 6,327.5 92.31 SWELL Baker-"Swell Packer-"K"(#6) SN:050494-001- 3.900 I 1 PACKER 32 INTERMEDIATE;26.8-9,019.4 , 12,410.8 6,308.8 92.10 FRAC PORT Baker 4-1/2"Frac Sleeve#5-(2.375"Ball,Drift w/ 2.343 2.313")PN:10437084 --- 12,667.2 6,304.9 90.49 SWELL Baker-"Swell Packer-"E"(#5) SN:050494-001- 3.900 PACKER 41 g • 12,931.8 6,301.7 90.72 FRAC PORT Baker 4-1/2"Frac Sleeve#4-(2.313"Ball,Drift w/ 2.281 2.25")PN:10437083 13,187.6 6,300.3 90.17 SWELL Baker-"Swell Packer-"Cr(#4) SN: 050494-001- 3.900 PACKER 43 13,411.4 6,298.2 90.89 FRAC PORT Baker 4-1/2"Frac Sleeve#3-(2.25"Ball,Drift w/ 2218 .11 2.188")PN:10437082 13,707.5 6,291.4 92.73 SWELL Baker-"Swell Packer"-"C"(#3) SN: 050494- 3.900 I PACKER 001-18 13,970.2 6,273.5 94.05 FRAC PORT Baker 4-1/2"Frac Sleeve#2-(2.188"Ball,Drift w/ 2.135 2.125") PN:10437081 14,228.0 6,267.4 88.11 SWELL Baker-"Swell Packer"-"B"(#2) SN: 050494-001- 3.900 - PACKER 22 14,492.6 6,272.4 89.12 FRAC PORT Baker 4-1/2"Frac Sleeve#1-(2.125"Ball,Drift w/ 2.073 ' 2.00")PN:10437070 14,750.0 6,275.4 90.18 SWELL Baker-"Swell Packer"-"A"(#1) SN:050494-001 3.900 III PACKER -6 15,008.2 6,271.8 90.34 FRAC PORT 4-1/2"Baker Alpha Pressure Sleeve 3.010 15,021.2 6,271.7 90.34 SLEEVE 4-1/2"Baker Wellbore Isolation Valve(H036784300) 1.250 1 1 15,075.1 6,271.4 90.34 COLLAR 4-1/2"12.6 ppf L-80 Weatherford Float Collar 3.885 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Iblft) Grade Top Connection TUBING 4 1/2 X 31/2( 3 1/21 2.9921 25.1 8,873. 51 6,312.51 9.301 L-80 I EUE-m 8rd 1 I Completion Details Nominal ID Top(MB) Top(ND)(ftKB) Top not(1 Item Des Com (in) 25.1 25.1 0.00 HANGER Cameron 11"x 4-1/2"IBT-m Tubing Hanger 3.900 67.4 67.4 0.38 XO Reducing XO,4-1/2"12.6#L-80 IBTM box x 3-1/2"9.3#L-80 EUE 2.992 .11. pin 8,675.5 6,266.7 74.54 SLEEVE Baker 3%"CMU in closed position w/2.813"DS Profile 2.813 8,731.5 6,280.9 75.89 GAUGE Schlumberger Gauge Carrier 3'/::"EUE P X P(measured 2.913 w/collar on top) Hyd Frac-Gelletlwater;12,932.0 a a 8,756.7 6,287.0 76.25 PACKER Baker Premier Production Packer 2.880 8,783.2 6,293.2 76.62 NIPPLE Camco 2.75 D nipple 4%"OD 2.750 8,836.6 6,305.1 77.84 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 3.000 Large OD I 8,837.6 6,305.3 77.87 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 3.000 small OD 8,872.5 6,312.3 79.00 SHOE Mule shoe WLEG,3-1/2"IBT box 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I ITop(TVD) Top Incl Top(ftKB) (ftKB) r) Des Corn Run Date ID(in) 4,374.8 3,520.0 48.86 CATCHER 2.72"AVA CATCHER(OAL 32") 6/30/2016 0.000 LINER;8,840.8-15,117.6 KUP PROD • •05 ConocoPhillips a Alaska,Inc. C.om.:401alBps 2S-05,8/9/2016 3'.01/5 PM Vertical schematic(actual) - HANGER,25.1-. m...,.,,„ ,, ,.,a.e ,. ..a..e,n,,R.n....n., i.. nat..e,Other In Hole(Wireline retrievable plugs,valves,pumps,tish,etc.) Top(TVD) Top Incl Top(ftKB) (ftK8) (°) Des Com Run Date ID(in) I 4,378.0 3,522.1 48.86 PLUG 3-1/2”RBP(2.725"OD/OAL 8.93'),(S 8 CPP35056 6/30/2016 0.000 XO Reducing;67.4 7 &CPE035002) 8,783.0 6,293.1 76.62 PLUG 2.75"CA-2 PLUG W/SOFT SET,SPARTEK 6/14/2016 0.000 -A.".CONDUCTOR;27.5-107.5- GAUGES,(1"POCKET GAUGE&1.25"GAUGE BOTH SET FOR 5 SEC SAMPLE RATE)(OAL LIH= 1 E 102") SURFACE;28.5.2,927.2 Stimulations&Treatments GAS LIFT;4,348.1 Min Top Max Btm �5.. Depth Depth Top(TVD) Btm(TVD) CATCHER;4,374.8 It (ftKB) (ftKB) (RKB) (ftKB) Stg# Type Date Com PLUG;4,378.0 / 12,932.0 15,008.0 6,301.7 6,271.8 Hyd Frac- 6/23/2016 PUMPED MINIFRAC AND STAGES 1-5 PLACING Gelledwater 503,600#OF 16/20 CARBOLITE AND 32,5008 OF 100 MESH 9,269.0 12,441.0 6,354.3 6,307.8 Hyd Frac- 6/26/2016 PUMPED STAGES 6-10 PLACING 501,200#OF Gelledwater 16/20 CARBOLITE AND 32,5008 OF 100 MESH GAS LIFT;8,020.8 - Mandrel Inserts st GAS LIFT;8,521.7 ati 'M on Top(TVD) Valve Latch Port Size TRO Run SLEEVE;8,875.5 N Top(ftKB) (RKB( Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 4,346.1 3,501.2 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/6/2016 I ME al 2 8,020.8 5,993.3 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/6/2016 GAUGE;8,731.5 DOTnrmds:e,747.2 II it 3 8,521.7 6,220.4 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/14/2016 PACKER;8,756.7, XO Threads;8,763.3 Mt PLUG;8.783,0 i m• Br LOCATOR;8,836.6 LOCATOR;8,637.6 iii d # ae �i' SHOE;8,872.5 L`}■ :) I I INTERMEDIATE;26.9-9,019.4 I+ Iiiill o Ll D Hyd Frac-Gelledwater,9,259.0 D D Mall D D Mill Elim 0 0 IIIIIII IH ° ' iiim iiiwil Hyd Fisc-Gelledwater;12,932.0 Li D liiil El El 1 3 t fil El LINER,8,840.6-15,117.6 1 • I • Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 6/22/2016 Job End Date: 6/26/2016 State: Alaska County: Harrison Bay � � API Number: 50-103-20739-00-00Frac Operator Name: ConocoPhillips Company/Burlington Resourcestherrki 13"e ' Well Name and Number: 2S-05 Latitude: 70.21963500 Longitude: -150.15483000 Datum: NAD83 � Oil&Gas Federal Well: NO Indian Well: NO True Vertical Depth: 671,679 Total Base Non Water Volume' 0 14ytlrrt, rc Fra•chtfirm mid Composftion Chemical Maximum Maximum Abstract Service Ingredient Ingredient Trade Name Supplier Purpose Ingredients Concentration in Concentration in Comments Number Additive HF Fluid (CAS#) (%by mass)** (%by mass)** Sea Water Operator 3ase Fluid NA NA 100.00000 83.6715aoensity=8.540 CarboLite 16/20 CARBO Ceramics Proppant NA NA SS-200 Halliburton Proppant NA NA BE-6 MICROBIOCIDE,Halliburton Additive,Biocide, CL-22 UC,CL-31 Breaker,Crosslinker, CROSSLINKER, Gelling Agent, _OSURF-300D,MO- Microbiocide,Non- 37,OPTIFLO-II onic Surfactant,pH DELAYED RELEASE Control Additive, BREAKER,OPTIFLO- Proppant II DELAYED RELEASE BREAKER, SAND-COMMON WHITE-100 MESH, SSA-2,100 LB SACK (100002158),SP BREAKER,WG-36 GELLING AGENT NA NA • ! Ingredients shown above are subject to 29 CFR 1910 1200(1)and appear on Material Safety Data Sheets(MSDS).Ingredients shown below are Non-MSDS. -lazardousand Non- Hazardous Ingredients Ceramic materials and wares, 66402-68-4 100.00000 14.65680 chemicals Crystalline silica,quartz 14808-60-7 100.00000 1.08052 Guar gum 9000-30-0 100.00000 0.31294 Water 7732-18-5 100.00000 0.09734 Potassium formate 590-29-4 60.00000 0.06386 Borate salts Confidential 60.00000 0.06386 'Ethanol 64-17-5 60.00000 0.04081 Potassium metaborate 13709-94-9 60.00000 0.03056 Oxyalkylated phenolic resin Confidential 30.00000 0.02720 Ammonium persulfate 7727-54-0 100.00000 0.02197 Heavy aromatic petroleum 64742-94-5 30.00000 0.02040 naphtha Bentonite,benzyl(hydrogenated 121888-68-4 5.00000 0.01565 tallow alkyl)dimethylammonium stearate complex Sodium hydroxide 1310-73-2 30.00000 0.01046 Cured acrylic resin Confidential 30.00000 0.00659 Surfactant mixture Confidential 1.00000 0.00626 Naphthalene 91-20-3 5.00000 0.00340 Poly(oxy-1,2-ethanediyl),alpha-127087-87-0 5.00000 0.00340 (4-nonylphenyl)-omega- hydroxy-,branched Silica gel 112926-00-8 1.00000 0.00313 Potassium hydroxide 1310-58-3 5.00000 0.00255 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00000 0.00175 Sodium chloride 7647-14-5 1.00000 0.00141 Sodium carboxymethyl cellulose 9004-32-4 1.00000 0.0010E Acrylate polymer Confidential 1.00000 0.00106Denise Tuck,Halliburton, 3000 N.Sam Houston Pkwy E., Houston,TX 77032,281- 871-6226 Sodium glycollate 2836-32-0 1.00000 0.00106 1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00068 Sodium persulfate 7775-27-1 100.00000 0.00044 Crystalline Silica,Quartz 14808-60-7 0.10000 0.00031 Sodium sulfate 7757-82-6 0.10000 0.00000 *Total Water Volume sources may include fresh water,produced water,and/or recycled water **Information is based on the maximum potential for concentration and thus the total may be over 100% Note:For Field Development Products(products that begin with FDP),MSDS level only information has been provided. • Ingredient information for chemicals subject to 29 CFR 1910.1200(i)and Appendix D are obtained from suppliers Material Safety Data Sheets(MSDS) • ZS-cis Zf ,O 0 Regg, James B (DOA) From: Cook, Guy D (DOA) Sent: Monday, August 08, 2016 8:35 PM �gqd�/ ((Di I� To: NSK Prod Engr Specialist " C Cc: NSK SVS Tech; Regg,James B (DOA) Subject: RE: KRU 2S-05 Deficiency Report Attachments: Deficiency_Report_KRU2S-05.xlsx Darrell, Sorry for the inconvenience, I meant to send this to you and cc Lou since I had just spoke to him on the phone regarding this report. In the future I will send all the deficiency reports to your office only. • Attached is the deficiency report for KRU 2S-05 not having an identifying well sign. This is provided for your records and to ensure the deficiency is corrected. Please provide photo evidence of the well sign after installation when you return the completed deficiency report (date corrected). Thank you, Guy Cook Petroleum Inspector AOGCC 907-227-2614 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 Guy Cook at 907-659-2714 or guv.cook@alaska.gov. From: NSK Prod Engr Specialist [mailto:n1139Pconocophillips.com] Sent: Monday, August 08, 2016 5:04 PM To: Cook, Guy D (DOA) Cc: NSK SVS Tech Subject: FW: KRU 2S-05 Deficiency Report Guy- Lou is correct that all deficiency reports must go through my office. Also for your information the missing sign for 2S-05 was previously noted by Brian Bixby.The sign has been ordered and should arrive this week for installation. If you wish you can still file the deficiency report but please do it through my office. Resend the report if electronic is acceptable if not drop it by my office and I'll sign it a make you a copy. Thanks, 1 • Darrell Humphrey/ Bob Christensen Production Engineering Specialist Conocophillips Alaska Inc. n1139@conocophillips.com Office (907) 659-7535 Pager(907) 659-7000#924 From: NSK SVS Tech Sent: Monday, August 08, 2016 4:45 PM To: 'Cook, Guy D (DOA)' <guy.cook@alaska.gov> Cc: NSK Prod Engr Specialist<n1139@conocophillips.com> Subject: RE: KRU 2S-05 Deficiency Report Guy,These forms have to be sent to Darrel my possession isn't authorized to handle these. I will forward this to Darrel, His email is N1139@conocophillips.com Lou Laubenstein/Brian Martin Office 659-7229 Truck 943-1171 Cell 715-6912 pgr 927 N2062@conocophillips.com From: Cook, Guy D (DOA) [mailto:guy.cook©alaska.gov] Sent: Monday, August 08, 2016 3:25 PM To: NSK SVS Tech Cc: Regg, James B (DOA); Cook, Guy D (DOA) Subject: [EXTERNAL]KRU 2S-05 Deficiency Report Attached is the deficiency report for KRU 2S-05 not having an identifying well sign. This is provided for your records and to ensure the deficiency is corrected. Please provide photo evidence of the well sign after installation when you return the completed deficiency report (date corrected).Thank you. Guy Cook Petroleum Inspector AOGCC 907-227-2614 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 Guy Cook at 907-659-2714 or. 2 • State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: KRU 2S-05 - Date: 8/7/2016 PTD: 2160390 Operator: CPAI Type Inspection: SVS Operator Rep: Lou Laubenstein Inspector: Guy Cook Position: SVS Tech Lead Op. Phone: 907-659-7229 Correct by(date): 9/7/2016 , Op. Email: n2062@conocophillps.com Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Missing well sign; refer to 20 AAC 25.040 Operator Rep Signatures: AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention: Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 12/2015 i 216039 • 27 354 RECEIVED ConocoPhiflips DATA LOGGED —p—v2o1G JUL 2u,J K.BENDER AOGCC'" TRANSMITTAL FROM: Sandra D. Lemke, ATO3-0346 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2S-05 DATE: 07/01/2016 Transmitted: Kuparuk River Unit, Alaska 2S-05 1 CD (.pdf) &1 color prints each log: 2" MD Formation Evaluation log 2" MD Drilling Engineering log 2" MD Gas ration log Please promptly sign, scan and return electronically to Sandra.D.Lemke@Conocophihips.com CC: 2S-05 transmittal folder, production well files, eSearch Receip, ' A4,24441-0--, —ei ate: �•a . GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 • STATE OF ALASKA • jut_ Q 6 Z016 ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED WELL COMPLETION OR RECOMPLETION REPORT ANWQC la.Well Status: Oil • Gas Cl SPLUG El Other ❑ Abandoned ❑ Suspended ❑ lb.Well Classr 20AAC 25.105 20AAC 25.110 Development 0 ° Exploratory❑ GINJ ❑ WINJ❑ WAG❑ 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.: 6/6/2016 216-039/ 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 5/16/2016 50-103-20739-00 • 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3037'FNL, 1378'FEL,Sec 17,T1ON, R8E, UM 6/1/2016 KRU 2S-05 ' Top of Productive Interval: 9. Ref Elevations: KB:147.5 17. Field/Pool(s): 4963'FNL,2835'FEL,Sec 16,T1ON, R8E, UM GL: 120 BF: Kupurak River Field/Kuparuk Oil Pool, Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: 4115 FNL, 1202 FEL,Sec 9,T1ON, R8E,UM N/A ADL 25603,ADL 25604,ADL 25589 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 481192 y- 5930011 Zone- 4 15130/6271 2677,2678,2675 TPI: x- 485016 y- 5928077 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 486646 y- 5934201 Zone- 4 N/A 1396/1375 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ 13.Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) I N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res COMPLETION DATE W I ILP VERIFIED LL- 23. CASING,LINER AND CEMENTING RECORD . WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16 62.5 H-40 27.5 107.5 27.5 107.5 24 pre-driven,cement to surface 10 3/4 45.5 L-80 28.5 2927 28.5 2565 13.5 1236 sx 11.0ppg LiteCrete, 238 sx 15.8ppg ClassG 7 5/8 29.7 L-80 26.9 9019 26.9 6335 9.875 Stage 1:730 sx 15.8ppg ClassG. Stage 2:256 sx 15.8ppg ClassG 41/2 12.6 L-80 8840.7 15118 6306 6271 6.75 Liner 24.Open to production or injection? Yes RI No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/ND of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4 1/2 8873 8757/6287 FRAC PORT 9269 MD=6354 ND,FRAC PORT 10031 MD=6323 ND 8840/6306 FRAC PORT 10910 MD=6322 ND, FRAC PORT 11550 MD=6326 ND 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. FRAC PORT 12411 MD=6309 ND, FRAC PORT 12932 MD=6302 ND Was hydraulic fracturing used during completion? Yes❑ No El FRAC PORT 13411 MD=6298 ND, FRAC PORT 13970 MD=6273 ND FRAC PORT 14492 MD=6272 ND, FRAC PORT 15008 MD=6272 ND Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting on hook-up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - Form 10-407 Rev sed 11/2015 1/7-1.. 9`ZG I 1 L C NTINUED ON PAGE 2 RBDMS c'' JUL 6 201Submit ORIGINIAL only �x.3 1Waftf 1 S- �/�G, b 6 • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1396 1375 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 8782 6293 information, including reports,per 20 AAC 25.071. W Sak D 1942 1846 • Base W Sak 2840 2508 C-80 3491 2939 C-37 6328 4836 Top HRZ 8043 6006 Base HRZ 8312 6137 Lower Kalubik 8471 6203 Kuparuk C 8782 6293 Kuparuk A5 8822 6302 Kuparuk A4 8851 6308 TD(Kuparuk A4) 15130 6271 Formation at total depth: Kuparuk A4 31. List of Attachments: Daily Operations Summary, Definitive Survey,Cement Report,Schematic 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: Jake Voss 265-6935 Email: jake.vossacop.com Printed Name: G.L.Alvord� n /� / Title: Alaska Drilling Manager [ Signature: ��(,14 �V/ Phone: 265-6120 Date: �T(S1ZaI(, // INSTRUCTIONS General: This form and the required attachments rovide 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,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and ND 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 11/2015 Submit ORIGINAL Only KUP P 0D 2S-05 ConocoPhillips a Well Attribu� Max Angle TD Alaska inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ft ) Act Btm(ftKB) Cgrpgpp mot, 501032073900 KUPARUK RIVER UNIT PROD 9425 13,809.28 15,130.0 -.- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 28-05,6/29/2016 a 3617 AM SSSV: NONE Last WO: 27.50 6/7/2016 Vertical schematic(,actuap Annotation Depth(ftKB( End Date Annotation Last Mod By End Date HANGER;25 ,r.-a.. Last Tag: Rev Reason:NEW WELL lehallf 6/15/2016 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread "'CONDUCTOR 16 15.250 27.5 107.5 107.5 62.50 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 28.5 2,9272 2,565.1 45.50 L-80 HYD 563 XO Reducing;67.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ■ INTERMEDIATE 75/8 6.875 26.9 9,019.4 6,335.2 29.70 L-80 Hyd 563 .".h.CONDUCTOR;27.5-107.5- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 8,840.7 15,117.6 6,271.2 12.60 L-80 Hyd 563 t Liner Details SURFACE,28.5-2,927.2 Nominal ID Xi Top(ftKB) Top(ND)(ftKB) Top Inoi(3 Item Des Com (in) GAS LIFT;4,346.1 pi 8,840.6 6,306.0 77.97 PACKER Baker HRD-E ZXP 5.5"x 7.63"Flex-Lock Liner top 4.810 11 packer L-80 Hyd 521 pin ill I Inv 8,865.4 6,311.0 78.77 NIPPLE Baker 5.5""RS"Packoff Seal Nipple 17#Q-125 4250 GAS LIFT;8,020.8 tm Hyd 563 box x box M8,867.8 6,311.4 78.85 HANGER Baker 5.5"x 7.63"Flex-Lock Liner hanger P-110 4.800 ?E Hyd 563 pin x pin Si GAS LIFT;8,521.7 9,045.2 6,338.2 83.39 SWELL Baker-"Swell Packer"-"J"(#11) SN:050494-001- 3.900 PACKER 14 SLEEVE;8,675.5 .41. 9,269.5 6,354.3 88.86 FRAC PORT Baker 4-1/2"Frac Sleeve#9-(2.625"Ball,Drift w/ 2.593 1 2.563")PN:10437088 GAUGE,8,731.5 9,645.8 6,336.3 94.13 SWELL Baker-"Swell Packer"-1"(#10) SN: 050494-001- 3.900 XO Threads;8,7472_ PACKER 17 PACKER;8,756.7 nig In Xo Threads;8,763.3 I 10,030.7 6,322.7 91.16 FRAC PORT Baker 4-1/2"Frac Sleeve#8-(2.563"Ball,Drift w/ 2.531 2.5")PN:10437087 2- 10,408.2 6,324.4 87.76'SWELL Baker-"Swell Packer"-"H"(#9) SN:050494-001- 3.900 LOCATOR;8,836.6 PACKER 20 LOCATOR;8,837.6 1. 10,909.7 6,322.3 90.03 FRAC PORT Baker 4-1/2"Frac Sleeve#7-(2.50"Ball,Drift w/ 2.468 12.438")PN:10437086 `11:. 11,207.4 6,322.7 89.93 SWELL Baker-"Swell Packer"-"G"(#8) SN: 050494-001- 3.900 -L PACKER 40 SHOE;8,8725 I'@ I. k I Il 11,550.5 6,326.5 89.57 FRAC PORT Baker 4-1/2"Frac Sleeve#6-(2.438"Ball,Drift w/ 2.406 2.375")PN:10437085 " 11,888.0 6,328.2 89.42 SWELL Baker-"Swell Packer"-"F"(#7) SN: 050494-001- 3.900 PACKER 23 # 12,068.0 6,327.5 92.31 SWELL Baker-"Swell Packer"-"K"(#6) SN:050494-001- 3.900 INTERMEDIATE;26 9-9,019.4 PACKER 32 ...___. 12,410.8 6,308.8 92.10 FRAC PORT Baker 4-1/2"Frac Sleeve#5-(2.375"Ball,Drift w/ 2.343 2.313")PN:10437084 12,667.2 6,304.9 90.49 SWELL Baker-"Swell Packer"-"E"(#5) SN: 050494-001- 3.900 PACKER 41 12,931.8 6,301.7 90.72 FRAC PORT Baker 4-1/2"Frac Sleeve#4-(2.313"Ball,Drift w/ 2.281 .-� - 2.25")PN:10437083 li IT 13,187.6 6,300.3 90.17 SWELL Baker-"Swell Packer'-"D"(#4) SN:050494-001- 3.900 PACKER 43 13,411.4 6,298.2 90.89 FRAC PORT Baker 4-1/2"Frac Sleeve#3-(2.25"Ball,Drift wl 2.218 2.188")PN:10437082 13,707.5 6,291.4 92.73 SWELL Baker-"Swell Packer"-"C"(#3) SN:050494- 3.900 PACKER 001-18 13,970.2 6,273.5 94.05 FRAC PORT 'Baker 4-1/2"Frac Sleeve#2-(2.188"Ball,Drift w/ 2.135 2.125")PN:10437081 14,228.0 6,267.4 88.11 SWELL Baker-"Swell Packer"-"B"(#2) SN:050494-001- 3.900 PACKER 22 11 1111 14,492.6 6,272.4 89.12 FRAC PORT Baker 4-1/2"Frac Sleeve#1-(2.125"Ball,Drift w/ 2.073 2.00")PN:10437070 14,750.0 6,275.4 90.18 SWELL Baker-"Swell Packer"-"A"(#1) SN:050494-001 3.900 PACKER -6 i 15,0082 6,271.8 90.34 FRAC PORT '4-1/2"Baker Alpha Pressure Sleeve 3.010 15,021.2 6,271.7 90.34 SLEEVE ,4-1/2"Baker Wellbore Isolation Valve(H036784300) 1.250 illi4 15,075.1 6,271.4 90.34(COLLAR 4-1/2"12.6 ppf L-80 Weatherford Float Collar 3.885 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection © TUBING 41/2 X 31/2 3 1/2 2.992 25.1 8,873.5 6,312.5 9.30 L-80 EUE-m 8rd Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top incl(1) Item Des Com (in) 25.1 25.1 0.00 HANGER Cameron 11"x 4-1/2"IBT-m Tubing Hanger 3.900 67.4 67.4 0.38 XO Reducing XO,4-1/2"12.6#L-80(BTM box x 3-1/2"9.3#L-80 EUE 2.992 pin iiiiiiiDI 8,675.5 6,266.7 74.54 SLEEVE Baker 3%,"CMU in closed position w/2.813"DS Profile 2.813 t 8,731.5 6,280.9 75.89 GAUGE Schlumberger Gauge Carrier 3'/,"EUE P X P(measured 2.913 w/collar on top) 8,756.7 6,287.0 76.25 PACKER Baker Premier Production Packer 2.880 ` 8,783.2 6,293.2 76.62 NIPPLE Camco 2.75 D nipple 4'/"OD 2.750 8,836.6 6,305.1 77.84 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub-- 3.000 C7 Large OD 8,837.6 6,305.3 77.87 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 3.000 small OD 8,872.5 6,312.3 79.00 SHOE Mule shoe WLEG,3-1/2"IBT box 3.000 11 ❑ 11 El LINER,8,840.6-15,117.6- ,1 t KUP 4013 2S-05 ConocoPhillips Alaska,ir1i, C, h9lips • •• 28-05,6/29/2016 6.36.18 AM Verpcal s66em005(actua4 HANGER;25.1-. ..�.. I 1t. Mandrel Inserts at h °^ Top(TVD) Valve Latch Port Size TRO Run N Top IRKS) (85KB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com 00 Reducing;67.4 - 1 4,346.1 3,501.2 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/6/2016 M CONDUCTOR;27.5-107.5 2 8,020.8 5,993.3 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/6/2016 3 8,521.7 6,220.4 Camco 'KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/14/2016 SURFACE;28.5-2,927.2 GAS LIFT;4,348.1 GAS LIFT;8,028.6 GAS LIFT;8,521.7 �- SLEEVE;8,675.5 GAUGE;8,731.5 00 Threads;8,747.2- PACKER;8,756.7 XO Threads;8,783.3 LOCATOR;8,836.6- LOCATOR,8,837.6 21 17 SHOE;8,872.5 I i' R tit I t l INTERMEDIATE;26.93,019.4 U U 7 IT MI H LINER;8,840.8-15,117.6- I 7/4// ,,!'„, • . Operations Summary (with Timelog Depths) 2S-05 Conoopfteilips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End lime Our(hr) Phase Op Code Activity Code 'time P-T-X Operation (MKS) End Depth(ftK8); 5/13/2016 5/13/2016 2.50 MIRU MOVE MOB P PJSM-Disconnect boiler,motor,pump 0.0 0.0 15:00 17:30 complexes and pipe sheds and stage on 2G pad. 5/13/2016 5/13/2016 1.00 MIRU MOVE MOB P Pick up mats.Rig up yoke on sub.Pull 0.0 0.0 17:30 18:30 sub off of well 2G-03 and stage on pad.Install rider shack and rear spreader bar on sub. 5/13/2016 5/14/2016 5.50 MIRU MOVE MOB P Move support complexes,shop and 0.0 0.0 18:30 00:00 ROC to 2S pad.Stage support complexes on 2S pad and spot shop and ROC. Berm ROC. Sim-ops/Clean up location on 2G pad,Prep to move sub and load out trucks.Set liner and mats around well 2S-05. 5/14/2016 5/14/2016 0.75 MIRU MOVE MOB P Continue to load trucks. Set ROC and 0.0 0.0 00:00 00:45 shop 5/14/2016 5/14/2016 1.00 MIRU MOVE MOB P Mobilize sub-base and pipe sheds 0.0 0.0 00:45 01:45 from 2G-03 to 2B pad 5/14/2016 5/14/2016 0.75 MIRU MOVE MOB P Stop at 2B pad to fuel trucks, 0.0 0.0 01:45 02:30 pipesheds and sub-base 5/14/2016 5/14/2016 1.25 MIRU MOVE MOB P Move sub-base and pipesheds from 0.0 0.0 02:30 03:45 2B pad to 2S-05. Concurrent operation: Lay rig mats around well, Set diverter spool,diverter and knife valve 5/14/2016 5/14/2016 2.75 MIRU MOVE RURD P Cut VSM in path of diverter line. Set 0.0 0.0 03:45 06:30 two pieces of diverter line and set wellhead equipment in cellar 5/14/2016 5/14/2016 0.75 MIRU MOVE MOB P Turn sub-base around and removed 0.0 0.0 06:30 07:15 driving shack and steering arms 5/14/2016 5/14/2016 1.50 MIRU MOVE MOB P Spot sub-bse over well and level 0.0 0.0 07:15 08:45 5/14/2016 5/14/2016 1.00 MIRU MOVE MOB P Level pad and set mats for motor 0.0 0.0 08:45 09:45 complex 5/14/2016 5/14/2016 1.50 MIRU MOVE MOB P Spot pit,mud pump,motor and boiler 0.0 0.0 09:45 11:15 complexes 5/14/2016 5/14/2016 0.75 MIRU MOVE MOB P Spot rockwasher 0.0 0.0 11:15 12:00 5/14/2016 5/14/2016 1.00 MIRU MOVE MOB P Continue to spot rockwasher. Spot 0.0 0.0 12:00 13:00 pipeshed 5/14/2016 5/14/2016 4.00 MIRU MOVE RURD P Work on rig acceptance checklist. 0.0 0.0 13:00 17:00 Plug in electrical connections.Hook up air,steam,water and fuel lines. Berm rock washer,and boiler room. Set envirovac.Set diverter line. Change out hydraulic line on TD. Rig accepted @ 1700 hrs 5/14/16 5/14/2016 5/14/2016 3.00 MIRU MOVE RURD P PJSM-Nipple up diverter in cellar. 0.0 0.0 17:00 20:00 Perform derrick inspection.Off load pipe shed.Set bell nipple. 5/14/2016 5/15/2016 4.00 MIRU MOVE RURD P Load and strap pipe shed with 5"DP. 0.0 0.0 20:00 00:00 Install 5"elevators.Pick up 5"FOSV. Install mouse hole.Change out saver sub to 4 1/2 IF.Fuel rig. 5/15/2016 5/15/2016 0.50 MIRU MOVE SVRG P Service rig and top drive 0.0 0.0 00:00 00:30 5/15/2016 5/15/2016 0.25 MIRU MOVE RURD P Mobilize drums to rig floor for thread 0.0 0.0 00:30 00:45 protectors Page 1/26 Report Printed: 6/15/2016 . Operations Summary (with Timelog Depths) 1.0 2S-05 Conocaehitgps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 5/15/2016 5/15/2016 3.25 MIRU MOVE PULD P Pick up and rack back 38 stands of 5" 0.0 0.0 00:45 04:00 HWDP 5/15/2016 5/15/2016 4.00 MIRU MOVE RURD P Clear rig floor of 4"handling 0.0 04:00 08:00 equipment. Clear rig floor. Change hammer union on mud pump suction line. Prep mud pits for spud mud. 5/15/2016 5/15/2016 0.75 MIRU MOVE BOPE P Function test diverter. Concurrent 0.0 0.0 08:00 08:45 operation-rig up MWD 5/15/2016 5/15/2016 1.25 MIRU MOVE SLPC P Slip and cut 39'of drilling line. 0.0 0.0 08:45 10:00 Concurrent operation-spot MWD shack on pit complex. Continue rigging up MWD. Wellhead rep energized diverter adapter seals,with 1200 psi packing the grease,500 psi 15 min test on casing head seals, witnessed by Company Man. 5/15/2016 5/15/2016 2.00 MIRU MOVE BOPE P Performed diverter test. Test gas 0.0 0.0 10:00 12:00 alarms. Bag closed in 36 seconds. Knife valve opened in 12 seconds. Accumulator test: System pressure=2900 psi Pressure post closure=1900 psi 200 psi attained in 33 seconds Full pressure attained in 142 seconds Nitrogen bottles average=2000 psi Witnessed by Guy Cook,AOGCC Concurrent operations-wellhead rep continued energizing diverter adapter seals. Energized seals with 1200 psi. Tested seals with 500 psi for 15 minutes 5/15/2016 5/15/2016 2.50 MIRU MOVE RURD P PJSM-Install SLB Smartool 0.0 0.0 12:00 14:30 transducer on stand pipe.Sim-ops/Mix spud mud. 5/15/2016 5/15/2016 1.25 MIRU MOVE PULD P PJSM-Load,strap,pick up and rack 0.0 0.0 14:30 15:45 back 5 std's 5"HWDP. 5/15/2016 5/15/2016 0.75 MIRU MOVE SEQP P Rig up and test mud lines to 3500 psi. 0.0 0.0 15:45 16:30 Sim-ops/Mobilize handling tools to rig floor. 5/15/2016 5/15/2016 2.00 MIRU MOVE RURD P Rig up SLB MWD.Sim-ops/Add shim 0.0 0.0 16:30 18:30 to top drive grabber.Mix spud mud. 5/15/2016 5/15/2016 0.75 MIRU MOVE SFTY P Conduct pre-spud meeting with Day 0.0 0.0 18:30 19:15 crew. 5/15/2016 5/15/2016 3.25 MIRU MOVE RURD P Con't to rig up MWD.Sim-ops/Mix 0.0 0.0 19:15 22:30 spud mud.Spot pipeshed Tioga heater. 5/15/2016 5/15/2016 1.25 MIRU MOVE WAIT T Wait on BHA tools to arrive on location 0.0 0.0 22:30 23:45 from Deadhorse D&M shop..Work on MP2's 5/15/2016 5/16/2016 0.25 MIRU MOVE RURD P Load BHA tools into pipeshed.Crew 0.0 0.0 23:45 00:00 change. 5/16/2016 5/16/2016 1.50 MIRU MOVE BHAH P Continue to load,strap and prep SLB 0.0 0.0 00:00 01:30 equipment. Mobilize BHA tools to the rig floor 5/16/2016 5/16/2016 0.75 MIRU MOVE BHAH P Make up BHA per DD: 13-1/2"bit, 0.0 0.0 01:30 02:15 mud motor, 12-1/8"stab,XO 5/16/2016 5/16/2016 0.75 MIRU MOVE CIRC P Flood conductor and clean out to 107'. 0.0 107.0 02:15 03:00 Circulate @ 460 gpm,400 psi,40 rpm. Rotary torque=1.5 K ft-lbs Page 2/26 Report Printed: 6/15/2016 • • Operations Summary (with Timelog Depths) 2S-05 ConocoPhil Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth MKS) 5/16/2016 5/16/2016 2.00 SURFAC DRILL DDRL P Drill from 107'to194'MD. ADT=1.33 107.0 194.0 03:00 05:00 hrs,Bit hrs=1.33 hrs, P/U=45 K, S/O=45 K, Rot=45 K,Torque on=2 K,Flow out=80%,WOB=7-10,470 gpm, 110 spm, 100 psi. 5/16/2016 5/16/2016 0.50 SURFAC DRILL SHAH P Stand back HWDP and BHA. Blow 194.0 34.0 05:00 05:30 down top drive 5/16/2016 5/16/2016 2.50 SURFAC DRILL BHAH P Pick up BHA. Make up GyroPulse, 34.0 194.0 05:30 08:00 MWD,arcVision,x-o,NMDC,stab, NMDC,stab,NMDC. 5/16/2016 5/16/2016 4.00 SURFAC DRILL DDRL P Drill from 194'to 490'MD. TVD= 194.0 490.0 08:00 12:00 490'. AST=.73 hrs,ART= 1.32 hrs, ADT=2.05 Bit=3.38 hrs.P/U=61 K, S/O=61 K,Rot=60 K,Torque on=2 -4 K,Torque off=1.5 K, Flow out= 77%,WOB=15-20 K,RPM=50 rpm, 535 gpm, 126 spm,950 psi 5/16/2016 5/16/2016 6.00 SURFAC DRILL DDRL P Drill from 490'to 856'MD. TVD= 490.0 856.0 12:00 18:00 855'. AST= 1.28 hrs,ART=1.76 hrs, Bit=6.42 hrs.Jar hrs=3.04 P/U=81 K,S/O=80 K,Rot=82 K,Torque on =2-5 K,Torque off=3 K, Flow out= 87%,WOB= 18-25 K,RPM=50,540 gpm, 127 spm, 1100 psi 5/16/2016 5/17/2016 6.00 SURFAC DRILL DDRL P Drill from 856'to 1340'MD. TVD= 856.0 1,340.0 18:00 00:00 1326'. AST=2.67 hrs,ART=1.39 hrs,Bit=10.48 hrs.Jar hrs=7.10 P/U =86 K,S/O=83 K,Rot=82 K, Torque on=2-8 K,Torque off= 1-4 K, Flow out=66%,WOB=20-30 K, RPM=50,600 gpm, 142 spm, 1525 psi 5/17/2016 5/17/2016 6.00 SURFAC DRILL DDRL P Drill from 1340'to 2112'MD. TVD= 1,340.0 2,112.0 00:00 06:00 1994'. AST=2.34 hrs,ART= 1.63 hrs, Bit= 14.45 hrs.Jar hrs=11.07 P/U=95 K,S/O=85 K,Rot=92 K, Torque on=4-7 K,Torque off=1-4 K, Flow out=67%,WOB=15-20 K, RPM=70,715 gpm, 170 spm,2200 psi 5/17/2016 5/17/2016 6.00 SURFAC DRILL DDRL P Drill from 2112'to 2560'MD. TVD= 2,112.0 2,560.0 06:00 12:00 2308'. AST=2.11 hrs,ART= 1.28 hrs, Bit=17.84 hrs.Jar hrs=14.46 P/U=109 K,S/O=88 K, Rot=91 K, Torque on=6-8 K,Torque off=2-6 K, Flow out=68%,WOB=20-25 K, RPM=70,749 gpm, 176 spm,2400 psi 5/17/2016 5/17/2016 3.50 SURFAC DRILL DDRL P Drill from 2560 to 2938'MD. TVD= 2,560.0 2,938.0 12:00 15:30 2308'. AST=.23 hrs,ART=2.51 hrs, Bit=20.58 hrs.Jar hrs=17.20 P/U =110 K,S/O=96 K,Rot=98 K, Torque on=5-9 K,Torque off=5 K, Flow out=67%,WOB=20-30 K, RPM=70,750 gpm, 176 spm,2520 psi 5/17/2016 5/17/2016 2.00 SURFAC CASING CIRC P Survey at TD.Pump 32 bbls nut plug 2,938.0 2,723.0 15:30 17:30 sweep.CBU x3.Rack back stand of DP each BU to 2723'MD.730 gpm, 2200 psi,70 rpm,5K tq. Page 3/26 Report Printed: 6/15/2016 • .• ? • • r Operations Summary (with Timelog Depths) - r_ 2S-05 ConocoPhillips a. Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth(ftKE); 5/17/2016 5/17/2016 5.50 SURFAC CASING BKRM P PJSM-BROOH f/2723'MD 112442' 2,723.0 1,420.0 17:30 23:00 MD.780 gpm,2350 psi,50 rpm,5- 10K tq.BROOH f/2442'MD 111420' MD.750 gpm,2100 psi,60 rpm,4-8K tq. Calc disp= 10.77 bbls Act disp=15.24 bbls. 5/17/2016 5/17/2016 0.25 SURFAC CASING OWFF P Monitor well.Static. 1,420.0 1,420.0 23:00 23:15 5/17/2016 5/18/2016 0.75 SURFAC CASING TRIP P POOH on elevators f/1420'MD 1,420.0 1,140.0 23:15 00:00 1/1140'MD. PU=95K. 5/18/2016 5/18/2016 2.25 SURFAC CASING TRIP P Cont.to POOH f/1140'MD to 115' 1,140.0 115.0 00:00 02:15 MD.Calculated displacement=23.8 bbls,Actual displacement=28.6 bbls 5/18/2016 5/18/2016 2.25 SURFAC CASING BHAH P L/D BHA#2 as per SLB rep. 115.0 0.0 02:15 04:30 5/18/2016 5/18/2016 1.00 SURFAC CASING BHAH P Clean and clear rig floor. L/D SLB 0.0 0.0 04:30 05:30 tools and XO's. 5/18/2016 5/18/2016 0.50 SURFAC CASING WWWH P M/U stack washer and flush out 0.0 0.0 05:30 06:00 landing ring on conductor. 5/18/2016 5/18/2016 1.00 SURFAC CASING RURD P R/U to run 10-3/4"casing.Pick up and 0.0 0.0 06:00 07:00 R/U GBR Volant tool,bail extensions, elevators,slips and floor valve. 5/18/2016 5/18/2016 0.25 SURFAC CASING SFTY P Hold PJSM on running 10-3/4" 0.0 0.0 07:00 07:15 Dopeless Hyd 563 casing. 5/18/2016 5/18/2016 1.25 SURFAC CASING PUTB P M/U Shoe track and 2 casing pup 0.0 147.0 07:15 08:30 joints t/147'MD.Fill pipe and test floats,good. 5/18/2016 5/18/2016 3.50 SURFAC CASING PUTB P RIH w/10-3/4"45.5# L-80 Dopeless 147.0 1,456.0 08:30 12:00 Hydril 563 casing f/147'MD to 1456' MD. 5/18/2016 5/18/2016 1.00 SURFAC CASING CIRC P PJSM-Circulate casing volume.Stage 1,456.0 1,456.0 12:00 13:00 pump up to 5.5 bpm, 150 psi.PU 86K SO 75K. 5/18/2016 5/18/2016 3.50 SURFAC CASING PUTB P RIH w/10-3/4"45.5# L-80 Dopeless 1,456.0 2,895.0 13:00 16:30 Hydril 563 casing f/1456'MD to 2895' MD.PU=165K SO=95K 5/18/2016 5/18/2016 1.00 SURFAC CASING HOSO P Make up hanger and landing joint. 2,895.0 2,927.0 16:30 17:30 Break circ @ 2.5 bpm,275 psi. Attempt to reciprocate.Shallow overpull observed after moving string up 3'. Decision made to land casing. Ran total of 70 jts casing.Ran 36 bowspring centralizers,one each on FS joint and FC joint on stop rings 10' up and then every other joint.0 remakes,0 rejects 5/18/2016 5/18/2016 3.50 SURFAC CEMENT CIRC P Rig up cement line.Circulate and 2,927.0 2,927.0 17:30 21:00 condition mud for cement job.Stage pump up to 7 bpm,500 psi.Sim- ops/PJSM on cement job. Page 4/26 Report Printed: 6/15/2016 perations Summary (with Timelogtpths) ,tii -' 2S-05 ch��ps " Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Ame End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKB) 5/18/2016 5/19/2016 3.00 SURFAC CEMENT CMNT P Pump 65 bbl nut plug mud marker pill. 2,927.0 2,927.0 21:00 00:00 Pump 5 bbls water.Test lines to 3500 psi.Pump 20 bbls 8.35 ppg CW-100. Pump 75 bbls 10.5 ppg MPII w/red dye at 4 bpm, 130 psi.Drop bottom plug. Pump 421 bbls of 11 ppg lead cement at 6 bpm,450 psi.At 390 bbls pumped packed off at hanger.Line up and take returns to cellar box 5/19/2016 5/19/2016 2.75 SURFAC CEMENT CMNT P Cont Surface cement job:Pumped 57 2,927.0 0.0 00:00 02:45 bbls of tail 15.8 ppg cement @ 2 bpm, shut down and drop top plug.Kicked top plug out with 3 bbls of tail cement followed by 10 bbls of H2O.Displaced cement w/rig pumps @ 2-5 bpm w/ 175 to 100 psi pump pressure.Pump rate had to be adjusted due to Vac trucks sucking out the cellar.Slowed pumps back to 3 bpm and bumped the plug @ 2580 strokes.FCP= 1000 psi. Pressured up to 1500 psi for 5 min then bled off and checked floats, good.CIP @ 2:30 am.203 bbls returns to surface 5/19/2016 5/19/2016 0.50 SURFAC CEMENT RURD P Blow down cement lines and R/D 0.0 0.0 02:45 03:15 cement line around cellar box. 5/19/2016 5/19/2016 1.25 SURFAC CEMENT RURD P Flush surface riser with black water 0.0 0.0 03:15 04:30 and drain riser.Clean out packed hanger flutes and connection on landing joint. 5/19/2016 5/19/2016 0.75 SURFAC CEMENT RURD P UD GBR casing equipment from rig 0.0 0.0 04:30 05:15 floor. 5/19/2016 5/19/2016 3.25 SURFAC CEMENT NUND P N/D surface riser and diverter. 0.0 0.0 05:15 08:30 5/19/2016 5/19/2016 1.75 SURFAC WHDBOP NUND P N/U Cameron MBS wellhead and 0.0 0.0 08:30 10:15 verify orientation.Test seals to 5000 psi f/10 min,good. 5/19/2016 5/19/2016 1.75 SURFAC WHDBOP NUND P N/U BOPE 0.0 0.0 10:15 12:00 5/19/2016 5/19/2016 3.00 SURFAC WHDBOP MPDA P PJSM-N/D dutch riser flange.R/U 0.0 0.0 12:00 15:00 RCD flange and air valve. 5/19/2016 5/19/2016 1.00 SURFAC WHDBOP MPDA P R/U scaffold in cellar. 0.0 0.0 15:00 16:00 5/19/2016 5/19/2016 5.00 SURFAC WHDBOP MPDA P Con't to N/U RCD and MPD lines.Add 0.0 0.0 16:00 21:00 9"to trip nipple and install same. 5/19/2016 5/19/2016 1.00 SURFAC WHDBOP NUND P Con't to N/U BOPE.Install secondary 0.0 0.0 21:00 22:00 annulus valve.Torque all bolts. 5/19/2016 5/19/2016 0.50 SURFAC WHDBOP RURD P P/U split rotary bushings,test plug and 0.0 0.0 22:00 22:30 wear bushing.Change out solid body rotary bushing with split rotary bushings. 5/19/2016 5/19/2016 0.50 SURFAC WHDBOP SVRG P Service rig. 0.0 0.0 22:30 23:00 5/19/2016 5/20/2016 1.00 SURFAC CEMENT PULD P PJSM-P/U 8 stands 5"DP and stand 0.0 0.0 23:00 00:00 back in derrick. Page 5/26 Report Printed: 6/15/2016 • Operations Summary (with Timelog Depths) it1i ,js ko: 2S-05 ConocaPhitilps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/20/2016 5/20/2016 2.50 SURFAC CEMENT PULD P PJSM,Cont to P/U 25 stands 5"drill 0.0 0.0 00:00 02:30 pipe via mouse hole and stand back in derrick.Picked up a total of 33 stands. 5/20/2016 5/20/2016 0.50 SURFAC CEMENT RURD P Clean and clear rig floor and remove 0.0 0.0 02:30 03:00 mouse hole. 5/20/2016 5/20/2016 2.50 SURFAC WHDBOP RURD P R/U to test BOPE w/5"TJ. Install 0.0 0.0 03:00 05:30 secondary valve on OA,and purge air from system. 5/20/2016 5/20/2016 4.00 SURFAC WHDBOP BOPE P Test BOPE w/5"test joint to 250/3500 0.0 0.0 05:30 09:30 psi for 5 min each.#1:Top pipe rams, CV 1,12,13, 14&manual kill valve. #2:Upper IBOP,HCR kill,CV 9,&11. #3:Lower IBOP,CV 5,8&10. #4: Dart,CV 4,6&7. #5:FOSV and CV 2. #6:HCR choke&4"kill line Demco valve, #7:Manual choke valve&HCR kill. #8:Annular preventer tested to 250/2500 psi.#9:Lower pipe rams. #10:Blind rams and CV 3. Accumulator test:System pressure= 3000 psi,Pressure after closing=1800 psi,200 psi attained after 40 seconds, full pressure attained after 175 seconds.Five bottle nitrogen avg= 1950 psi.Chuck Scheve of the AOGCC waived witness. 5/20/2016 5/20/2016 0.75 SURFAC WHDBOP RURD P R/U BOP testing equipment and drain 0.0 0.0 09:30 10:15 BOP stack. ' 5/20/2016 5/20/2016 1.75 SURFAC WHDBOP MPDA P PJSM,install MPD test cap and 0.0 0.0 10:15 12:00 pressure test RCD bearing and air valve to 1000 psi f/5 min. Remove test cap and install trip nipple. 5/20/2016 5/20/2016 1.00 SURFAC WHDBOP RURD P PJSM-Pull test plug.Set 10 1/16"ID 0.0 0.0 12:00 13:00 wear bushing.Rig down test equipment.Blow down choke,kill lines and top drive. 5/20/2016 5/20/2016 1.75 SURFAC CEMENT BHAH P PJSM-Make up BHA#2 as per SLB to 0.0 122.0 13:00 14:45 122'MD. 5/20/2016 5/20/2016 0.25 SURFAC CEMENT BHAH P Install nuclear source in LWD as per 122.0 122.0 14:45 15:00 SLB. 5/20/2016 5/20/2016 1.25 SURFAC CEMENT BHAH P Continue to pick up BHA#2 as per 122.0 778.0 15:00 16:15 SLB to 778'MD. 5/20/2016 5/20/2016 2.00 SURFAC CEMENT PULD P Single in hole with 5'DP to 2732'MD. 778.0 2,732.0 16:15 18:15 PU 110K SO 65K. Calc disp=16.16 bbls Act disp=15.98 bbls. 5/20/2016 5/20/2016 1.25 SURFAC CEMENT CIRC P Rig up test equipment.Break 2,732.0 2,732.0 18:15 19:30 circulation.Circulate and condition mud for casing test.Shallow test MWD.570 gpm,2490 psi 5/20/2016 5/20/2016 1.00 SURFAC CEMENT PRTS P Test 10 3/4"casing to 3500 psi/30 min 2,732.0 2,732.0 19:30 20:30 on chart.Test good.Rig down test equipment.Blow down kill line. 5/20/2016 5/20/2016 1.00 SURFAC CEMENT MPDA P Conduct MPD training meeting with rig 2,732.0 2,732.0 20:30 21:30 crew. 5/20/2016 5/20/2016 1.25 SURFAC CEMENT MPDA P PJSM-Pull trip nipple.Install RCD 2,732.0 2,732.0 21:30 22:45 bearing assy. Page 6/26 Report Printed: 6/15/2016 Operations Summary (with Timelog•pths) 2S-05 ConocoPhitlips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftK4) 5/20/2016 5/21/2016 1.25 SURFAC CEMENT MPDA P Flood MPD lines and choke skid. 2,732.0 2,732.0 22:45 00:00 Check for leaks and test to 1000 psi. Calibrate MPD computers.Practice MPD ramp up/ramp down procedure. 5/21/2016 5/21/2016 1.00 SURFAC CEMENT MPDA P MPD training with AM crew.Watch the 2,732.0 2,732.0 00:00 01:00 MI SWACO MPD training video with crews and train on the operation of the MI SWACO choke skid. 5/21/2016 5/21/2016 0.75 SURFAC CEMENT MPDA P Practice MPD ramp up/ramp down 2,732.0 2,732.0 01:00 01:45 procedure with crews as per MPD rep. 5/21/2016 5/21/2016 1.25 SURFAC CEMENT MPDA P PJSM,remove MPD bearing and 2,732.0 2,732.0 01:45 03:00 install trip nipple. 5/21/2016 5/21/2016 1.00 SURFAC CEMENT COCF P Wash and ream down f/2732'MD to 2,732.0 2,840.0 03:00 04:00 2840'MD @ 450 gpm=1025 psi,46% FO,P/U=115K,S/O=76K,ROT= 76K,Tq=5-10K.Tag TOC @ 2778' MD. 5/21/2016 5/21/2016 3.00 SURFAC CEMENT DRLG P Drill out float collar,shoe track,float 2,840.0 2,938.0 04:00 07:00 shoe and rat hole to 2938'MD.Pump @ 500 gpm=1500 psi,rotate @ 60/80 rpm's w/5-11K Tq.WOB 2-12K,46% FO,P/U=115K,S/O=76K,ROT=76K. 5/21/2016 5/21/2016 0.25 SURFAC CEMENT DDRL P Drill 20'of new hole f/2938'MD to 2,938.0 2,958.0 07:00 07:15 2958'MD.ADT=.20, Bit hrs=.20, Total Jars hrs=18.58,P/U= 115K, S/O=76K,ROT=76K.Pump @ 500 gpm=1285 psi,rotate @ 80 rpms w/ Tq 5-11K on,5-10K off.WOB=5-10K, FO=53%, ECD= 10.05 ppg,Max gas= 0 5/21/2016 5/21/2016 1.50 SURFAC CEMENT CIRC P Circulate and condition mud for FIT, 2,958.0 2,916.0 07:15 08:45 pump @ 500 gpm=1275 psi,50%FO. MW 9.6 ppg in/out.While CBU dressed up casing shoe,observed pipe torque up/stall out and overpull while pulling back into casing. 5/21/2016 5/21/2016 0.25 SURFAC CEMENT RURD P Rig up to perform FIT/LOT. 2,916.0 2,916.0 08:45 09:00 5/21/2016 5/21/2016 0.50 SURFAC CEMENT FIT P Perform LOT to 15.0 ppg EWM, 2,916.0 2,916.0 09:00 09:30 charted. 5/21/2016 5/21/2016 0.50 INTRM1 DRILL RURD P Rig down testing equipment and 2,916.0 2,916.0 09:30 10:00 confirm w/town on results. 5/21/2016 5/21/2016 0.25 INTRM1 DRILL SFTY P Hold PJSM on displacing well to 9.6 2,916.0 2,916.0 10:00 10:15 ppg LSND mud on the fly. Page 7/26 Report Printed: 6/15/2016 r �� ° � �- Operations Summary (with Timelog Depths) 2S-05 nitli Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time' End Time Our(hr) PhaseStart Depth Op Code Activity Code Time P-T-X Operation {W6} End Depth(ftKB) 5/21/2016 5/21/2016 1.50 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/2958'to 2,916.0 3,056.0 10:15 11:45 3056'MD 2645'TVD ADT-1.18 hrs.Bit hrs-1.38 Jar hrs- 18.58 ECD-10.17 ppg Footage- 98'WOB 5/7 k RPM 80 GPM 650 @ 1500 psi w/56%flow out PU wt 120 SO wt 85 ROT wt 97 Torque on/off btm.-8/6 k Max gas 96 units SPR's @ 3014'MD 2619'TVD w/9.6 ppg @ 1100 hrs. #1 30/40 SPM @ 120/180 psi #2 30/40 SPM @ 120/160 psi Note:Displace well to 9.6ppg LSND on the fly. 5/21/2016 5/21/2016 0.50 INTRM1 DRILL CIRC P PJSM;pull up to 3038'MD,break 3,056.0 3,056.0 11:45 12:15 connection&pump down RFID chips per WFT Rep to open reamer.Wash down to 3052 MD @ 650 gpm, 1450 psi,FO 57%,25 rpm,Tq 6K. Drop pump rate to 190gpm whilst RFID chips pass tool,then stage back up to 650 gpm,initial pressure 1450 psi dropping to 1230 psi indicating knives opened. Pull up to shoe&observe 5K over pull to verify reamer open. 5/21/2016 5/21/2016 5.75 INTRM1 DRILL DDRL P Drilled 11"hole w/RSS f/3056'to 3,056.0 3,514.0 12:15 18:00 3514'MD 2953'TVD ADT-4.88 hrs.Bit hrs-6.26 Jar hrs- 23.46 ECD-10.36 ppg Footage- 458' WOB 5/12 k RPM 170 GPM 780 @ 1825 psi w/59%flow out PU wt 130 SO wt 90 ROT wt 108 Torque on/off btm.-9/7 k Max gas 136 units Pump 25 bbls hi-vis/nut plug sweep @ 3288'MD.50%increase in cuttings. SPR's @ 3014'MD 2619'TVD w/9.6 ppg @ 1100 hrs. #1 30/40 SPM @ 120/180 psi #2 30/40 SPM @ 120/160 psi Page 8/26 Report Printed: 6/15/2016 •r' k • Operations Summary (with Timelog Depths) rpt 2S-05 con©cc tNtuu1}s Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) PhaseOp Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKE}) 5/21/2016 5/22/2016 6.00 INTRM1 DRILL DDRL P Drilled 11"hole w/RSS f/3514'to 3,514.0 4,041.0 18:00 00:00 4041'MD 3298'TVD ADT-4.50 hrs.Bit hrs-10.76 Jar hrs- 27.96 ECD-10.44 ppg Footage- 527' WOB 10-20 k RPM 170 GPM 780 @ 1975 psi w/58%flow out PUwt 136 SOwt91 ROT wt 110 Torque on/off btm.-5-15/6-7k Max gas 79 units Pump 25 bbls hi-vis/nut plug sweep @ 3573'MD.60%increase in cuttings. Pump 25 bbls hi-vis/nut plug sweep @ 3856'MD.80%increase in cuttings. SPR's @ 3942'MD 3235'TVD w/9.6 ppg @ 2245 hrs. #1 30/40 SPM @ 210/250 psi #2 30/40 SPM @ 200/250 psi 5/22/2016 5/22/2016 6.00 INTRM1 DRILL DDRL P Drilled 11"hole w/RSS f/4041'to 4,041.0 4,765.0 00:00 06:00 4765'MD 3778'TVD ADT-5.12 hrs.Bit hrs-15.88 Jar hrs- 33.08 ECD-10.60 ppg Footage- 724' WOB 10-15 k RPM 150 GPM 780 @ 2175 psi w/60%flow out PUwt145 SOwt100 ROT wt115 Torque on/off btm.-5-16k/4-12k Max gas 91 units Pump 25 bbls hi-vis/nut plug sweep @ 4223'MD.60%increase in cuttings. Pump 25 bbls hi-vis/nut plug sweep @ 4526'MD.30%increase in cuttings. SPR's @ 3942'MD 3235'TVD w/9.6 ppg @ 2245 hrs. #1 30/40 SPM @ 210/250 psi #2 30/40 SPM @ 200/250 psi Page 9/26 Report Printed: 6/15/2016 • • Operations Summary (with Timelog Depths) 2S-05 Conoc.oPhiiiiprs Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log StartTime End Time Our(hr) PhaseStart Depth Op Code Activity Code Time P-T-X t7pera�pn (ftKE} End Depth(ftKS) 5/22/2016 5/22/2016 6.00 INTRM1 DRILL DDRL P Drilled 11"hole w/RSS f/4765'to 4,765.0 5,301.0 06:00 12:00 5301'MD 4132'TVD ADT-4.55 hrs.Bit hrs-20.43 Jar hrs- 37.63 ECD-10.45 ppg Footage- 536' WOB 5-10 k RPM 150 GPM 780 @ 2300 psi w/60%flow out PU wt 147 SO wt 103 ROT wt 120 Torque on/off btm.-5-12k/11-12k Max gas 87 units Pump 25 bbls hi-vis/nut plug sweep @ 4805'MD.20%increase in cuttings. Pump 25 bbls hi-vis/nut plug sweep @ 5092'MD. 15%increase in cuttings. Observe cutting size decreasing down to—0.5"diameter SPR's @ 5064'MD 3974'TVD w/9.6 ppg @ 0919 hrs. #1 30/40 SPM @ 180/210 psi #2 30/40 SPM @ 200/240 psi 5355'40%increase overall,noticed size of cuttings getting smaller, 1-2"@ 6am,now.25-.5" cuttings @ 13:00hrs 5/22/2016 5/22/2016 6.00 INTRM1 DRILL DDRL P Drilled 11"hole w/RSS f/5301'to 5,301.0 5,820.0 12:00 18:00 5820'MD 4477'TVD ADT-4.89 hrs. Bit hrs-25.32 Jar hrs- 42.52 ECD-10.51 ppg Footage- 519' WOB 12-15k RPM 150 GPM 780 @ 2550 psi w/60%flow out PU wt 155K SO wt 110K ROT wt 127K Torque on/off btm.-11-12k/5-15k Max gas units 97 Pump 25 bbls hi-vis/nut plug sweep @ 5355'MD.40%increase in cuttings. Pump 25 bbls hi-vis/nut plug sweep @ 5630'MD 80%increase in cuttings. Perform 290bb1 dump/dilute @ 5794' MD. Observe cutting size decreasing down to—0.25"diameter SPR's @ 5522'MD 4279'TVD w/9.6 ppg @ 1415 hrs. #1 30/40 SPM @ 260/300 psi #2 30/40 SPM©250/300 psi Page 10/26 Report Printed: 6/15/2016 • Operations Summary (with Timelog Depths) i rw b y " 2S-05 ConoccThiiiips Rig: DOYON 141 Job: DRILLING ORIGINAL lime Log Start Depth Start Time End Tune Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKP,) End Depth(ttK6). 5/22/2016 5/23/2016 6.00 INTRM1 DRILL DDRL P Drilled 11"hole w/RSS f/5820'to 5,820.0 6,370.0 18:00 00:00 6370'MD 4863'TVD ADT-4.79 hrs.Bit hrs-30.11 Jar hrs- 47.31 ECD-10.56 ppg Footage- 550' WOB 9-13k RPM 150 GPM 780 @ 2625 psi w/60%flow out PUwt160K SOwt115K ROTwt 135K Torque on/off btm.-12k/5-11k Max gas units 152 Pump 25 bbls hi-vis/nut plug sweep @ 5916'MD.20%increase in cuttings. Pump 25 bbls hi-vis/nut plug sweep @ 6192'MD.50%increase in cuttings. SPR's @ 6274'MD 4792'TVD w/9.6 ppg @ 2245 hrs. #1 30/40 SPM @ 240/340 psi #2 30/40 SPM @ 260/360 psi 5/23/2016 5/23/2016 6.00 INTRM1 DRILL DDRL P Drilled 11"hole w/RSS f/6370'to 6,370.0 6,979.0 00:00 06:00 6979'MD 5308'TVD ADT-5.23 hrs.Bit hrs-35.34 Jar hrs- 52.54 ECD-10.68 ppg Footage- 609' WOB 10-15k RPM 150 GPM 780 @ 2800 psi w/60%flow out PUwt185K SOwt117K ROTwt 145K Torque on/off btm.-8-22k/9-18k Max gas units 128 Pump 25 bbls hi-vis/nut plug sweep @ 6565'MD.25%increase in cuttings. Pump 25 bbls hi-vis/nut plug sweep @ 6756'MD.5%increase in cuttings. Perform 290 bbl dump/dilute @ 6965' MD 5/23/2016 5/23/2016 6.50 INTRM1 DRILL DDRL P Drilled 11"hole w/RSS f/6979'to 6,979.0 7,579.0 06:00 12:30 7579'MD 5732'TVD ADT-5.25 hrs.Bit hrs-40.59 Jar hrs- 57.79 ECD-10.67 ppg Footage- 600' WOB 10-14k RPM 150 GPM 780 @ 2950 psi w/59%flow out PU wt 185K SO wt 122K ROT wt 150K Torque on/off btm. 14-16k/6-15k Max gas units 560 SPR's @ 7485'MD 5671'TVD w/9.8 ppg @ 1100 hrs. #1 30/40 SPM @ 180/260 psi #2 30/40 SPM @ 200/260 psi 5/23/2016 5/23/2016 1.00 INTRM1 DRILL CIRC P CBU.428 gpm, 100 rpm,5-15K tq. 7,579.0 7,579.0 12:30 13:30 Sim-ops/Change out liner and swab on pump#1 Page 11/26 Report Printed: 6/15/2016 • ,� .. eft Operations Summary (with Timelog Depths) 2S-05 t" vat ConocoPhitlips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr): Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/23/2016 5/23/2016 0.25 INTRM1 DRILL OWFF P Monitor well,rotate at 10 rpm.8-10K 7,579.0 7,579.0 13:30 13:45 tq.Static. 5/23/2016 5/23/2016 1.00 INTRM1 DRILL MPDA P PJSM-Remove trip nipple. Install RCD 7,579.0 7,579.0 13:45 14:45 bearing assy.Sim-ops/Clean possum belly and under shakers. 5/23/2016 5/23/2016 0.75 INTRM1 DRILL MPDA P Break circ.Stage pump up to 780 7,579.0 7,579.0 14:45 15:30 gpm,2950 psi, 140 rpm, 10-11K tq. Calibrate MPD as per rig engineer. 5/23/2016 5/23/2016 1.00 INTRM1 DRILL FIT P Perform open hole FIT on Cairn 7,579.0 7,579.0 15:30 16:30 formation at 5551'TVD.9.8 ppg MW. 596 psi=11.9 ppg EMW 5/23/2016 5/23/2016 1.50 INTRM1 DRILL DDRL P Drilled 11"hole w/RSS f/7579'to 7,579.0 7,673.0 16:30 18:00 7673'MD 5793'TVD ADT-1.23 hrs.Bit hrs-41.82 Jar hrs- 59.02 ECD-10.67 ppg Footage-94' WOB 10-15k RPM 150 GPM 780 @ 3100 psi w/83%flow out PU wt 190K SO wt 127K ROT wt 150K Torque on/off btm. 14-16k/6-15k Max gas units 173 Perform 100 bbl dump/dilute @ 5794' MD SPR's @ 7485'MD 5671'TVD w/9.8 ppg @ 1100 hrs. #1 30/40 SPM @ 180/260 psi #2 30/40 SPM @ 200/260 psi 5/23/2016 5/24/2016 6.00 INTRM1 DRILL DDRL P Drilled 11"hole w/RSS f/7673'to 7,673.0 7,954.0 18:00 00:00 7954'MD 5958'TVD ADT-4.78 hrs.Bit hrs-46.60 Jar hrs- 63.80 ECD-11.64 ppg Footage- 281' WOB 10-15k RPM 148 GPM 780 @ 3450 psi w/83%flow out PU wt 195K SO wt 120K ROT wt 148K Torque on/off btm. 10-22k/12-15k Max gas units 266 Raise mud weight to 10.5 ppg. SPR's @ 7954'MD 5957'TVD w/ 10.5 ppg @ 2330 hrs. #1 30/40 SPM @ 220/230 psi #2 30/40 SPM©240/340 psi 5/24/2016 5/24/2016 6.00 INTRM1 DRILL DDRL P DDrilled 11"hole w/RSS f/7954'- 7,954.0 8,340.0 00:00 06:00 8340'MD,6150'TVD,ADT 5.12,Bit 51.72,Jars 68.92,PU 200K,SO 120K,ROT 149K,Tq on/off 14K/10- 12K,ECD-11.63 ppg,FO 82%,WOB 12-20K,RPM 140,GPM 780,3450 PSI,Max gas 1912,Footage-386' Fire Drill CRT 78 sec @ 04:30 hrs. Page 12/26 Report Printed: 6/15/2016 Operations Summary (with Timelog Depths) R , f►='t� 2S-05 CcoPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS} End Depth(ftKS)' 5/24/2016 5/24/2016 2.25 INTRM1 DRILL DDRL P DDrilled 11"hole w/RSS f/8340'- 8,340.0 8,485.0 06:00 08:15 8485'MD,6208'TVD,ADT 1.72,Bit 53.44,Jars 70.64,PU 200K,SO 120K, ROT 149K,Tq on/off 14K/10- 12K, ECD-11.63 ppg,FO 82%,WOB 12-20K,RPM 140,GPM 780,3490 PSI,Max gas 974, Footage-145' 5/24/2016 5/24/2016 1.00 INTRM1 DRILL CIRC P Circulate&condition to 10.6 ppg MW 8,485.0 8,485.0 08:15 09:15 in&out for FIT @ drilling rate. 5/24/2016 5/24/2016 0.25 INTRM1 DRILL FIT P PJSM-perform open hole FIT with 8,485.0 8,485.0 09:15 09:30 10.5 ppg,Cairn depth 7314 MD,5551' TVD,hole depth 8484'MD,6188' TVD.Pressure up from 275 psi to 410 psi in 10 strokes.Shut in&observe pressure decrease from 380 psi to 285 psi in 10 minutes.Test showed an EMW at 7314'MD of 11.9 ppg. 5/24/2016 5/24/2016 0.75 INTRM1 DRILL CIRC P CBU @ 775 gpm,3525 psi,80 rpm, 8,485.0 8,485.0 09:30 10:15 Tq 10K.SIMOPS confer with town on FIT. SPR's @ 8479'MD,6211'TVD, 10.5+ ppg @ 10:00 hrs. #1 30/40 SPM @ 200/250 psi #2 30/40 SPM @ 210/260 psi 5/24/2016 5/24/2016 0.75 INTRM1 DRILL EQRP T Trouble shoot choke pressure switch. 8,485.0 8,485.0 10:15 11:00 Found stroke counter was intermittently malfunctioning. 5/24/2016 5/24/2016 1.00 INTRM1 DRILL DDRL P DDrilled 11"hole w/RSS f/8485'- 8,485.0 8,528.0 11:00 12:00 8528'MD,6225'TVD,ADT.49,Bit 53.93,Jars 71.13,PU 200K,SO 120K,ROT 149K,Tq on/off 14-15K/10 -11K,ECD 11.56 ppg,FO 82%,WOB 12-15K,RPM 140,GPM 780,3500 PSI,Max gas 836,Footage 43' 5/24/2016 5/24/2016 6.00 INTRM1 DRILL DDRL P DDrilled 11"hole w/RSS f/8528'- 8,528.0 8,791.0 12:00 18:00 8791'MD,6300'TVD,ADT 5.15,Bit 59.08,Jars 76.28,PU 225K,SO 125K,ROT 145K,Tq on/off 10-20K/13 -20K,ECD 11.52 ppg,FO 84%,WOB 10-15K,RPM 140,GPM 780,3375 PSI,Max gas 200,Footage 262' SPR's @ 8695'MD,6272'TVD, 10.5+ ppg @ 15:30 hrs. #1 30/40 SPM @ 240/320 psi #2 30/40 SPM @ 210/260 psi 5/24/2016 5/25/2016 6.00 INTRM1 DRILL DDRL P DDrilled 11"hole w/RSS f/8791'- 8,791.0 8,978.0 18:00 00:00 8978'MD,6336'TVD,ADT 5.12,Bit 64.20,Jars 81.40,PU 220K,SO 125K, ROT 145K,Tq on/off 14-22K/13 -20K,ECD 11.48 ppg,FO 83%,WOB 8-12K,RPM 140,GPM 780,3325 PSI, Max gas 1573,Footage 187' Page 13/26 Report Printed: 6/15/2016 w. i��' .. Iterations Summary (with Timelog Depths) igAti * 2S-05 ConacaPhifli, 'ii Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T X Operation MKS) End Depth(ftKD)' 5/25/2016 5/25/2016 1.50 INTRM1 DRILL DDRL P PJSM-DDrilled 11"hole w/RSS V 8,978.0 9,029.0 00:00 01:30 8978'-9029'MD,6335'TVD,ADT 1.46,Bit 65.66,Jars 82.86,PU 210K, SO 117K,ROT 145K,Tq on/off 14- 24K/12-18K,ECD 11.47 ppg,FO 83%,WOB 10-15K, RPM 140,GPM 780,3475 PSI,Max gas 1335, Footage 51' 5/25/2016 5/25/2016 3.50 INTRM1 CASING CIRC P CBU 3X©780 gpm,3475 psi, 140 9,029.0 9,029.0 01:30 05:00 rpm,Tq 14K, 10.5 ppg,PU 210K,SO 117K,ROT 145K. SPR's @ 9029'MD,6335'TVD, 10.5 ppg @ 5:00 hrs. #1 30/40 SPM @ 185/250 psi #2 30/40 SPM @ 200/288 psi 5/25/2016 5/25/2016 0.75 INTRM1 CASING CIRC P Pump RFID chips to shut under 9,029.0 9,029.0 05:00 05:45 reamer @ 670 gpm,2380 psi,FO 63%,slow to 200 gpm,590 psi,FO 12%.Pump 1750 strokes&shut down.work pipe for 10 min.Pump at 670 gpm,2780 psi,FO 67%.Observe 400 psi increase&increase in turbine speed indicating blocks closed. 5/25/2016 5/25/2016 1.25 INTRM1 CASING OWFF P Draw down back pressure to static. 9,029.0 9,029.0 05:45 07:00 Monitor well,slight flow to static. 5/25/2016 5/25/2016 0.25 INTRM1 CASING MPDA P Set MPD back pressure for stripping 9,029.0 9,029.0 07:00 07:15 out of the hole. Kick w/Tripping Drill CRT 80 sec @ 07:15 hrs. 5/25/2016 5/25/2016 5.25 INTRM1 CASING SMPD P PJSM-TOH f/9029'-2919'MD,hold 9,029.0 2,919.0 07:15 12:30 back pressure&trip speed as per schedule.Calculated fill 43.2,actual 57.4 bbls. 5/25/2016 5/25/2016 0.50 INTRM1 CASING CIRC P CBU,650 gpm, 1900 psi,40 rpm,Tq 3 2,919.0 2,919.0 12:30 13:00 -4K,FO 78%,Max Gas 74. 5/25/2016 5/25/2016 0.75 INTRM1 CASING OWFF P Monitor well,static.SIMOPS blow 2,919.0 2,919.0 13:00 13:45 down TD. 5/25/2016 5/25/2016 1.50 INTRM1 CASING MPDA P PJSM-blow down&rig down MPD 2,919.0 2,919.0 13:45 15:15 lines.Remove MPD bearing&install trip nipple.Cap 4"MPD return line. 5/25/2016 5/25/2016 1.75 INTRMI CASING TRIP P PJSM-TOH f/2919'-778'MD. 2,919.0 778.0 15:15 17:00 5/25/2016 5/25/2016 0.50 INTRM1 CASING BHAH P PJSM-lay down 18 joints of HWDP& 778.0 224.0 17:00 17:30 the jars 778'-224'MD. 5/25/2016 5/25/2016 0.25 INTRM1 CASING OWFF P Monitor well,static. 224.0 224.0 17:30 17:45 5/25/2016 5/25/2016 2.25 INTRM1 CASING BHAH P PJSM-lay down BHA as per SLB DD. 224.0 0.0 17:45 20:00 5/25/2016 5/25/2016 1.00 INTRM1 CASING BHAH P PJSM-clear&clean floor. 0.0 0.0 20:00 21:00 5/25/2016 5/25/2016 0.50 INTRM1 CASING WWWH P PJSM-rig up&flush stack. Rig down 0.0 0.0 21:00 21:30 stack washer&drain stack. 5/25/2016 5/25/2016 0.50 INTRM1 CASING RURD P PJSM-remove wear bushing. 0.0 0.0 21:30 22:00 5/25/2016 5/25/2016 1.25 INTRMI CASING BOPE P PJSM-C/O upper VBR's to 7-5/8" 0.0 0.0 22:00 23:15 solid body rams.SIMOPS rig up casing equipment. 5/25/2016 5/26/2016 0.75 INTRM1 CASING BOPE P PJSM-set test plug,rig up test 0.0 0.0 23:15 00:00 equipment,fill stack with H2O. Page 14/26 Report Printed: 6/15/2016 • • b Operations Summary (with Timelog Depths) 2S-05 CanocaPhiliips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code: Time P-T-X Operation MKS) End Depth MKS) 5/26/2016 5/26/2016 0.75 INTRM1 CASING BOPE P PJSM,Test top rams w/7-5/8"test 0.0 0.0 00:00 00:45 joint to 250/3500 psi,annular to 250/2500 psi on chart for 5 min each. 5/26/2016 5/26/2016 0.50 INTRM1 CASING BOPE P PJSM-R/D testing equipment and pull 0.0 0.0 00:45 01:15 test plug. 5/26/2016 5/26/2016 1.00 INTRM1 CASING RURD P PJSM-R/U to run 7-5/8"casing and 0.0 0.0 01:15 02:15 install stop collars(6)on 7-5/8"casing in pipe shed. 5/26/2016 5/26/2016 1.00 INTRM1 CASING PUTB P PJSM-M/U 7-5/8"casing shoe track 0.0 174.0 02:15 03:15 with TopCo float shoe and Weatherford float collar and landing collar with BakerLok on shoe track. Fill casing and test floats,good. 5/26/2016 5/26/2016 4.50 INTRM1 CASING PUTB P PJSM-RIH w/7-5/8",29.7#,L-80, Hyd 174.0 2,883.0 03:15 07:45 563 casing f/174'MD to 2883'MD© 2000 fph. 5/26/2016 5/26/2016 0.75 INTRM1 CASING CIRC P CBU @ 1.5-5.5 bpm, 100-180 psi,FO 2,883.0 2,883.0 07:45 08:30 24-36%,PU 100K,SO 95K.No losses. 5/26/2016 5/26/2016 4.25 INTRMI CASING PUTB P PJSM-RIH w/7-5/8",29.7#,L-80,Hyd 2,883.0 4,891.0 08:30 12:45 563 casing f/2883'MD to 4891'MD @ 1000-1500 fph.SO 95K,Calculated displacement 48.84,actual 21.3 bbls. 5/26/2016 5/26/2016 1.25 INTRMI CASING CIRC P CBU @ 1.5-5.5 bpm, ICP350 psi,FCP 4,891.0 4,891.0 12:45 14:00 300 psi,FO 16-35%,PU 149K,SO 108K. 5/26/2016 5/26/2016 5.00 INTRM1 CASING PUTB P PJSM-RIH w/7-5/8",29.7#,L-80,Hyd 4,891.0 6,568.0 14:00 19:00 563 casing f/4891'MD to 6568'MD @ 1000 fph.SO 125K. Lay down 2 joints that did not make up to mark. 5/26/2016 5/26/2016 2.75 INTRMI CASING CIRC P CBU @ 1-6 bpm,ICP500 psi,FCP 6,568.0 6,568.0 19:00 21:45 300 psi,FO 39%,PU 180K,SO 125K. 5/26/2016 5/27/2016 2.25 INTRM1 CASING PUTB P PJSM-RIH w/7-5/8",29.7#,L-80,Hyd 6,568.0 7,638.0 21:45 00:00 563 casing f/6568'MD to 7638'MD @ 1000 fph.SO 130K.Ran 187 joints,61 7.625"X9.38"hyrdoforms,&10 stop rings 5/27/2016 5/27/2016 0.75 INTRM1 CASING PUTB P PJSM-RIH w/7-5/8",29.7#,L-80, Hyd 7,638.0 7,843.0 00:00 00:45 563 casing f/7638'MD to 7843'MD @ 1000 fph. PU 215K,SO 130K. 5/27/2016 5/27/2016 2.00 INTRM1 CASING CIRC P CBU staging up f/1-5 bpm,ICP 400, 7,843.0 7,843.0 00:45 02:45 FCP 300 psi,FO 25-38%, 5/27/2016 5/27/2016 2.25 INTRM1 CASING PUTB P PJSM-RIH w/7-5/8",29.7#,L-80,Hyd 7,843.0 8,989.0 02:45 05:00 563 casing f/7843'MD to 8989'MD @ 1000 fph.Calculated displacement 17.32,actual 16.45 bbls. 5/27/2016 5/27/2016 0.50 INTRM1 CASING HOSO P PJSM-make up hanger&landing 8,989.0 9,019.4 05:00 05:30 joint.Set down hanger on load shoulder @ 9019.4'MD.PU 245K,SO 135K. 5/27/2016 5/27/2016 3.00 INTRM1 CEMENT CIRC P Circulate&condition mud system for 9,019.4 9,019.4 05:30 08:30 cement job.Stage up 1-6 bpm, ICP& FCP 300 psi, FO 21-35%, reciprocating 15'. Page 15/26 Report Printed: 6/15/2016 i • Operations Summary (with Timelog Depths) ) 2S-05 ft,ttt,ps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr)' Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKB) 5/27/2016 5/27/2016 0.25 INTRMI CEMENT RURD P PJSM-rig up cementing equipment. 9,019.4 9,019.4 08:30 08:45 5/27/2016 5/27/2016 0.75 INTRMI CEMENT CIRC P Continue circulating&conditioning 9,019.4 9,019.4 08:45 09:30 mud @ 6 bpm,500 psi,FO 35%,PU 245K,SO 135K. 5/27/2016 5/27/2016 3.50 INTRM1 CEMENT CMNT P PJSM-pump 5 bbls of H2O&PT lines 9,019.4 9,019.4 09:30 13:00 to 600/4000 psi.Pump 40 bbls of 12.5 ppg MPII at 4 bpm,280 psi.Drop bypass plug.Pump 151 bbls of 15.8 ppg Shark slurry cement at 5 bpm, 260 psi.Drop top plug.Pump 2 bbls of 15.8 ppg cement cap.Pump 10 bbls of H2O at 5 bpm,69 psi.Displace with 10.5 ppg mud at 6 bpm,300 psi.Slow to 3 bpm, 100 psi to allow bypass plug to go past stage collar.Continue pumping at 5bpm,200 psi,PU 275K, SO 143K.Bump plug with 3902 strokes,pressuring up to 1300 psi (500 psi over FCP)for 5 min.Check floats,bled back 2 bbls then stopped. CIP 12:38 hrs.Pressure up to 3200 psi to observe stage collar open. 5/27/2016 5/27/2016 1.00 INTRM1 CEMENT CIRC P CBU @ 7 bpm,500 psi,FO 46%. 9,019.4 9,019.4 13:00 14:00 Small amount of MPH returns were observed.SIMOPS PJSM for 2nd stage held. 5/27/2016 5/27/2016 2.00 INTRM1 CEMENT CMNT P Pump 40 bbls of 12.5 ppg MPII at 5 9,019.4 0.0 14:00 16:00 bpm,200 psi.Batch up&pump 53 bbls of 15.8 ppg cement at 5 bpm,260 psi. Drop closing plug.Pump 10 bbls of H2O at 5 bpm, 100 psi.Displace with 10.5 ppg mud at 6 bpm, ICP 250 psi,FCP 750 psi.Bump plug with 2850 strokes&pressure up to 1500 psi,holding for 5 min.Observed stage collar shift closed.CIP 16:00 hrs.Bled off pressure&monitor for 15 minutes. 5/27/2016 5/27/2016 0.25 INTRM1 CEMENT RURD P PJSM-lay down landing joint. 0.0 0.0 16:00 16:15 5/27/2016 5/27/2016 0.75 INTRM1 CEMENT WWSP P PJSM-rig up&install 7-5/8"X 10-3/4" 0.0 0.0 16:15 17:00 pack off,as per CIW Rep. 5/27/2016 5/27/2016 1.00 INTRM1 CEMENT WWSP P PJSM-rig up&test pack off to 5000 0.0 0.0 17:00 18:00 psi for 10 minutes,witnessed. 5/27/2016 5/27/2016 0.50 INTRM1 CEMENT RURD P PJSM-rig down&lay down CRT, 0.0 0.0 18:00 18:30 casing equipment,&cementing equipment. 5/27/2016 5/27/2016 0.50 INTRM1 CEMENT RURD P PJSM-rig up to lay down 5"DP. 0.0 0.0 18:30 19:00 5/27/2016 5/27/2016 1.00 INTRM1 CEMENT SLPC P PJSM-slip&cut 65'of drill line. 0.0 0.0 19:00 20:00 5/27/2016 5/27/2016 0.50 INTRM1 CEMENT SVRG P PJSM-service top drive&blocks. 0.0 0.0 20:00 20:30 5/27/2016 5/28/2016 3.50 INTRM1 CEMENT PULD P PJSM-lay down 72 stands of 5"DP 0.0 0.0 20:30 00:00 from derrick. 5/28/2016 5/28/2016 1.25 INTRMI CEMENT PULD P PJSM-lay down 20 stands of 5"DP. 0.0 0.0 00:00 01:15 Page 16/26 Report Printed: 6/15/2016 T 61KSSS 4,1a -, Aerations Summary (with Timelog 6epths) 2S-05 +Coneitlips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start.Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) Ends Depth MKS) 5/28/2016 5/28/2016 2.75 INTRM1 CEMENT RURD P PJSM-change over handling 0.0 0.0 01:15 04:00 equipment&saver sub from 5"to 4". SIMOPS load&tally 4"DP in pipe shed. 5/28/2016 5/28/2016 3.50 INTRM1 CEMENT FRZP P PJSM-rig up LRS&test lines to 4000 0.0 0.0 04:00 07:30 psi.Pump 130 bbls of H2O down 10- 3/4"X 7-5/8"annulus. Pump at.5 bpm &observe pressure break over at 550 psi with 2.5 bbls away.Continue pumping H2O at 2.5 bpm ICP 350 psi, FCP 500 psi.Swap to Isotherm& pump 89 bbls,at 1.5-2.25 bpm,ICP 550 psi,FCP 900 psi.Final shut in OA pressure 750 psi. SIMOPS ick up21 stands of 4" p HWDP&8 stands of 4"DP. Spill Drill CRT 70 sec @ 06:45 hrs. 5/28/2016 5/28/2016 3.25 INTRM1 CEMENT PULD P PJSM-pick up 40 stands of 4"DP, 0.0 0.0 07:30 10:45 racking back in derrick.SIMOPS load 10.5 ppg FloPro mud in pits. 5/28/2016 5/28/2016 0.25 INTRM1 CEMENT RURD P PJSM-remove mousehole&clear rig 0.0 0.0 10:45 11:00 floor. 5/28/2016 5/28/2016 1.00 INTRM1 CEMENT BOPE P PJSM-change upper rams from 0.0 0.0 11:00 12:00 7.625"solid body to 3.5"X 6"VBR's. SIMOPS load pipe shed with 4"DP. OA pressure 250 psi @ 12:00 hrs. 5/28/2016 5/28/2016 0.50 INTRMI CEMENT SVRG P PJSM-service rig. 0.0 0.0 12:00 12:30 5/28/2016 5/28/2016 1.00 INTRM1 WHDBOP RURD P PJSM-rig up to test BOPE. 0.0 0.0 12:30 13:30 5/28/2016 5/28/2016 4.00 INTRM1 WHDBOP BOPE P Test BOPE w/4.5"&3.5 test joints to 0.0 0.0 13:30 17:30 250/3500 psi for 5 min each.#1:Top pipe rams,CV 1,12,13, 14&manual kill valve.#2:Upper IBOP,HCR kill, CV 9,&11.#3: Lower IBOP,CV 5,8& 10. #4:Dart,CV 4,6&7. #5:FOSV and CV 2. #6:HCR choke&4"kill line Demco valve, #7:Manual choke valve&HCR kill. #8:Annular preventer tested to 250/2500 psi.#9: Lower pipe rams.#10: Blind rams and CV 3.#11:Top rams w/3.5"TJ.#12: Annular w/3.5"TJ.#13:Lower rams w/3.5"TJ. Accumulator test:System pressure= 2950 psi,Pressure after closing=1800 psi,200 psi attained after 42 seconds, full pressure attained after 189 seconds. Five bottle nitrogen avg= 1950 psi.Witnessed by AOGCC Rep Johnnie Hill 5/28/2016 5/28/2016 0.75 INTRMI WHDBOP RURD P PJSM-blow down&rig down test 0.0 0.0 17:30 18:15 equipment. Install 10"ID wear bushing. 5/28/2016 5/28/2016 0.50 INTRMI CEMENT BHAH P PJSM-mobilize BHA to rig floor. 0.0 0.0 18:15 18:45 5/28/2016 5/28/2016 0.75 INTRM1 CEMENT MPDA P Review MPD power point training for 0.0 0.0 18:45 19:30 Swaco system. 5/28/2016 5/28/2016 3.00 INTRM1 CEMENT BHAH P PJSM-pick up BHA 3 as per SLB DD 0.0 364.0 19:30 22:30 to 364'MD. Page 17/26 Report Printed: 6/15/2016 =56,14713ith.,,, Operations Summary (with Timelog•ths) 2S-05 401 ConocoPhiilips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/28/2016 5/28/2016 1.25 INTRM1 CEMENT PULD P PJSM-single in the hole with 48 joints 346.0 1,513.0 22:30 23:45 of 4"DP f/385'-1513'MD. 5/28/2016 5/29/2016 0.25 INTRM1 CEMENT DHEQ P PJSM-shallow hole test at 223 gpm, 1,513.0 1,513.0 23:45 00:00 1100 psi,FO 38%,PU 58K,SO 56K. OA pressure 480 psi @ 24:00 hrs. 5/29/2016 5/29/2016 0.25 INTRM1 CEMENT SLPC P PJSM-calibrate SLB block height. 1,513.0 1,513.0 00:00 00:15 5/29/2016 5/29/2016 3.75 INTRMI CEMENT PULD P PJSM-single in the hole f/1513'-6331' 1,513.0 6,331.0 00:15 04:00 MD.Calculated displacement 27, actual 33 bbls. Kick w/Tripping CRT 128 sec @ 00:30 hrs. 5/29/2016 5/29/2016 0.50 INTRMI CEMENT COCF P PJSM-wash&ream,cleaning out 6,331.0 6,464.0 04:00 04:30 cement to stage collar 6331'-6464' MD, 190 gpm, 1200 psi,FO 31%,60 rpm,Tq 7K,PU 120K,SO 85K,ROT 112K.Top of cement 6435'MD. 5/29/2016 5/29/2016 1.50 INTRM1 CEMENT DRLG P Drill out stage collar f/6464'-6466' 6,464.0 6,466.0 04:30 06:00 MD,at 200 gpm, 1425 psi,FO 34%, 80 rpm,Tq 7K,WOB 2-10K,reaming stage collar twice. 5/29/2016 5/29/2016 1.00 INTRM1 CEMENT CIRC P CBU at 220 gpm, 1550 psi,FO 35%, 6,466.0 6,510.0 06:00 07:00 60 rpm,Tq 7K. 5/29/2016 5/29/2016 0.25 INTRM1 CEMENT TRIP P PJSM-TOH f/6510'-6331'MD, 6,510.0 6,331.0 07:00 07:15 racking back 2 stands. 5/29/2016 5/29/2016 1.75 INTRM1 CEMENT PULD P PJSM-single in the hole f/6331'-8695' 6,331.0 8,695.0 07:15 09:00 MD.Calculated displacement 19.6, actual 21.9 bbls. 5/29/2016 5/29/2016 1.00 INTRM1 CEMENT CIRC P Circulate&condition mud f/8695'- 8,695.0 8,789.0 09:00 10:00 8789'MD,220 gpm, 1700 psi,FO 36%,60 rpm,Tq 9-11K,PU 168K,SO 86K,ROT 115K. 5/29/2016 5/29/2016 0.25 INTRM1 CEMENT RURD P PJSM-rig up to test casing. 8,789.0 8,789.0 10:00 10:15 5/29/2016 5/29/2016 0.75 INTRM1 CEMENT PRTS P PJSM-test 7.625"casing to 3500 psi 8,789.0 8,789.0 10:15 11:00 for 30 min,recorded on chart. Pressured up to 3525 psi,with 50 strokes(5 bbls).Shut in with 3500 psi &pressure decreased to 3450 psi in 30 min.Bled back 4.8 bbls. 5/29/2016 5/29/2016 0.25 INTRM1 CEMENT RURD P PJSM-rig down test equipment. 8,789.0 8,789.0 11:00 11:15 5/29/2016 5/29/2016 1.50 INTRMI CEMENT DRLG P Wash&ream down to landing collar 8,789.0 8,886.0 11:15 12:45 8789'-8885'MD.Drill out landing collar 8885'-8886'MD at 220 gpm, 1820 psi, FO 43%,60 rpm,Tq 11-15K.Tag cement at 8860'MD. OA pressure 490 psi at 12:00 hrs. 5/29/2016 5/29/2016 3.25 INTRM1 CEMENT DRLG P Drill out shoe track&rat hole f/8886'- 8,886.0 9,029.0 12:45 16:00 9029'MD, 198 gpm, 1450 psi,60 rpm, Tq 13-14K,WOB 2-5. SPR's @ 9014'MD,6339'TVD, 10.4 ppg @ 15:15 hrs. #1 20/30 SPM @ 560/755 psi #2 20/30 SPM @ 560/760 psi Page 18/26 Report Printed: 6/15/2016 • • Operations Summary (with Timelog Depths) � g- b 3 4 2S-05 ConocoPhillip>s Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (FMB) End Depth MKS) 5/29/2016 5/29/2016 0.50 INTRM1 CEMENT DDRL P PJSM-DDrilled 6-3/4"production 9,029.0 9,049.0 16:00 16:30 section f/9029'-9049'MD,6339'TVD, ADT.54,Bit.54,Jars.54,PU 180K, SO 77K,ROT 118K,Tq on/off 14K/12- 13K,ECD 11.3 ppg, FO 47%,WOB 5- 10K,RPM 80,GPM 200, 1450 PSI, Max gas 0,Footage 20' 5/29/2016 5/29/2016 1.25 INTRM1 CEMENT CIRC P Circulate&condition for FIT racking 9,049.0 8,978.0 16:30 17:45 back 1 stand f/9049-8978'MD, 198 gpm, 1450 psi,60 rpm,Tq 13-14K,FO 47%,WOB 4-5K. 5/29/2016 5/29/2016 0.50 INTRM1 CEMENT OWFF P Monitor well,slight flow to static. 8,978.0 8,978.0 17:45 18:15 5/29/2016 5/29/2016 0.75 INTRM1 CEMENT FIT P PJSM-rig up&perform FIT to an 8,978.0 8,978.0 18:15 19:00 EMW of 13.0 ppg at 6334'TVD,with 10.4 ppg LSND mud. Pump 1.2 bbls, pressuring up to 860 psi.Shut in& observe pressure for 10 minutes. Pressure decreased from 860 psi to 800 psi.Bled back 1 bbl.Rig down test equipment. 5/29/2016 5/29/2016 0.50 PROD1 DRILL MPDA P PJSM,pull trip nipple&install RCD 8,978.0 8,978.0 19:00 19:30 bearing on drill pipe.Observed element split. 5/29/2016 5/29/2016 0.50 PROD1 DRILL MPDA T PJSM-remove bearing&install back 8,978.0 8,978.0 19:30 20:00 up bearing. 5/29/2016 5/29/2016 0.75 PROD1 DRILL REAM P Down link to DH tools&ream to 8,978.0 9,049.0 20:00 20:45 bottom 8978'-9049'MD, 198 gpm, 1450 psi,60 rpm,Tq 13-14K,FO 47%. 5/29/2016 5/29/2016 1.00 PROD1 DRILL DISP P PJSM-displace well to 10.4 FloPro 9,049.0 9,049.0 20:45 21:45 mud system,260 gpm,2250 psi,60 rpm,Tq 12-13K. 5/29/2016 5/29/2016 2.00 PROD1 DRILL DDRL P PJSM-DDrilled 6-3/4"production 9,049.0 9,164.0 21:45 23:45 section f/9049'-9164'MD,6353'TVD, ADT 2.05,Bit 2.59,Jars 2.59, PU 165K,SO 85K,ROT 115K,Tq on/off 12-13K/9-10K,ECD 11.53 ppg,FO 45%,WOB 15-16K,RPM 80,GPM 260,2295 PSI,Max gas 0,Footage 115'. 5/29/2016 5/30/2016 0.25 PROD1 DRILL MPDA P Calibrate MPD chokes per MPD 9,164.0 9,164.0 23:45 00:00 Advisor. Kick w/Drilling CRT 77 sec @ 23:45 hrs. OA pressure 510 psi @ 24:00 hrs. 5/30/2016 5/30/2016 0.50 PROD1 DRILL MPDA P Calibrate MPD choke system as per 9,164.0 9,164.0 00:00 00:30 MPD Advisor. 5/30/2016 5/30/2016 5.50 PROD1 DRILL DDRL P PJSM-DDrilled 6-3/4"production 9,164.0 9,641.0 00:30 06:00 section f/9164'-9641'MD,6323'TVD, ADT 4.54,Bit 7.13,Jars 7.13, PU 160K,SO 73K,ROT 108K,Tq on/off 13K/11 K,ECD 11.66 ppg,FO 58%, WOB 10-15K,RPM 110-140,GPM 260,2380 PSI,Max gas 777, Footage 477'. Page 19/26 Report Printed: 6/15/2016 -44 leF444:. Operations Summary (with Timelog epths) 2S-05 Comicontitlips , Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Our hr PhaseStart Depth ( } Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/30/2016 5/30/2016 6.00 PROD1 DRILL DDRL P PJSM-DDrilled 6-3/4"production 9,641.0 10,190.0 06:00 12:00 section f/9641'-10190'MD,6318' TVD,ADT 4.74, Bit 11.87,Jars 11.87, PU 153K,SO 78K,ROT 111K,Tq on/off 13-14K/11.5K,ECD 11.71 ppg, FO 55%,WOB 7-10K,RPM 130,GPM 260,2400 PSI,Max gas 1322, Footage 549'. SPR's @ 10108'MD,6323'TVD, 10.4+ppg @ 10:54 hrs. #1 20/30 SPM @ 620/820 psi #2 20/30 SPM @ 600/800 psi OA 510 psi @ 12:00 hrs. 5/30/2016 5/30/2016 6.00 PROD1 DRILL DDRL P PJSM-DDrilled 6-3/4"production 10,190.0 10,675.0 12:00 18:00 section f/10190'-10675'MD,6330' TVD,ADT 4.86,Bit 16.73,Jars 16.73, PU 163K,SO 79K,ROT 112K,Tq on/off 13-141010-11K,ECD 11.73 ppg,FO 56%,WOB 10-14K,RPM 130,GPM 258,2525 PSI,Max gas 1206,Footage 485'. SPR's @ 10675'MD,6335'TVD, 10.4 ppg @ 18:00 hrs. #1 20/30 SPM @ 620/880 psi #2 20/30 SPM @ 620/880 psi 5/30/2016 5/31/2016 6.00 PROD1 DRILL DDRL P PJSM-DDrilled 6-3/4"production 10,675.0 11,147.0 18:00 00:00 section f/10675'-11147'MD,6323' TVD,ADT 4.21, Bit 20.94,Jars 20.94, PU 165K,SO 75K,ROT 111K,Tq on/off 14-15K/10-11K,ECD 11.89 ppg,FO 57%,WOB 7-12K,RPM 130, GPM 261,2650 PSI, Max gas 1157, Footage 472'. SPR's @ 11146'MD,6323'TVD, 10.4 ppg @ 23:45 hrs. #1 20/30 SPM @ 630/900 psi #2 20/30 SPM @ 630/900 psi OA 500 psi©24:00 hrs. 5/31/2016 5/31/2016 6.00 PROD1 DRILL DDRL P PJSM-DDrilled 6-3/4"production 11,147.0 11,887.0 00:00 06:00 section f/11147'-11887'MD,6327' TVD,ADT 5.13,Bit 26.07,Jars 26.07, PU 170K,SO 68K,ROT 106K,Tq on/off 14-15K/12-13K,ECD 11.95 ppg,FO 54%,WOB 10-15K, RPM 130, 2680 psi, Max Gas 1371.Total footage 740'. Fire Drill CRT 79 sec @ 05:30 hrs. 5/31/2016 5/31/2016 6.00 PROD1 DRILL DDRL P PJSM-DDrilled 6-3/4"production 11,887.0 12,340.0 06:00 12:00 section f/11887'-12340'MD,6310' TVD,ADT 4.10,Bit 30.08,Jars 30.08, PU 174K,SO 65K,ROT 108K,Tq on/off 15K/13K,ECD 11.95 ppg,FO 57%,WOB 10-15K,RPM 130,GPM 260,2675 PSI,Max gas 533, Footage 453'. SPR's @ 12279'MD,6313'TVD, 10.4 ppg @ 10:49 hrs. #1 20/30 SPM @ 700/970 psi #2 20/30 SPM @ 700/1000 psi OA 500 psi @ 12:00 hrs. Page 20/26 Report Printed: 6/15/2016 Operations Summary (with Timelog Depths) i•�s v, h � R" 2S-05 hitaps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Loi Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)' 5/31/2016 5/31/2016 6.25 PROD1 DRILL DDRL P PJSM-DDrilled 6-3/4"production 12,340.0 12,940.0 12:00 18:15 section f/12340'-12940'MD,6301' TVD,ADT 4.45,Bit 34.53,Jars 34.53, PU 177K,SO 67K,ROT 107K,Tq on/off 15-17K/12-13K, ECD 12.11 ppg,FO 57%,WOB 8-10K,RPM 130, GPM 272,3075 PSI, Max gas 900, Footage 600'. SPR's @ 12751'MD,6304'TVD, 10.4+ppg @ 16:00 hrs. #1 20/30 SPM @ 660/960 psi #2 20/30 SPM @ 660/960 psi 5/31/2016 5/31/2016 0.50 PROD1 DRILL SVRG P PJSM-Service rig,change out swivel 12,940.0 12,940.0 18:15 18:45 packing. 5/31/2016 6/1/2016 5.25 PROD1 DRILL DDRL P PJSM-DDrilled 6-3/4"production 12,940.0 13,470.0 18:45 00:00 section f/12940'-13470'MD,6296' TVD,ADT 3.83,Bit 38.36,Jars 38.36, PU 180K,SO 66K,ROT 110K,Tq on/off 16-18K/13-14K,ECD 12.12 ppg,FO 54%,WOB 9-12K,RPM 130, GPM 269,3100 PSI,Max gas 934, Footage 530'. SPR's©13410'MD,6299'TVD, 10.4+ppg @ 23:00 hrs. #1 20/30 SPM @ 720/1000 psi #2 20/30 SPM @ 710/990 psi OA 530 psi @ 24:00 hrs. 6/1/2016 6/1/2016 6.00 PROD1 DRILL DDRL P PJSM-DDrilled 6-3/4"production 13,470.0 14,055.0 00:00 06:00 section f/13470'-14055'MD,6267' TVD,ADT 4.43,Bit 42.79,Jars 42.79, PU 185K,SO 57K,ROT 110K,Tq on/off 17K/15K,ECD 12.26 ppg,FO 58%,WOB 12-15K,RPM 130,GPM 270,3280 PSI,Max gas 925,Footage 585'. Kick w/Drilling CRT 120 sec @ 05:30 hrs. 6/1/2016 6/1/2016 6.00 PROD1 DRILL DDRL P PJSM-DDrilled 6-3/4"production 14,055.0 14,607.0 06:00 12:00 section f/14055'-14607'MD,6273' TVD,ADT 4.43,Bit 47.22,Jars 47.22, PU 195K,SO OK, ROT 117K,Tq on/off 18K/16K, ECD 12.33 ppg,FO 55%,WOB 7-10K, RPM 130,GPM 270,3400 PSI,Max gas 1029, Footage 552'. SPR's @ 14515'MD,6272'TVD, 10.4+ppg @ 10:45 hrs. #1 20/30 SPM @ 820/1116 psi #2 20/30 SPM @ 800/1440 psi OA 485 psi @ 12:00 hrs. 6/1/2016 6/1/2016 5.50 PROD1 DRILL DDRL P PJSM-DDrilled 6-3/4"production 14,607.0 15,130.0 12:00 17:30 section f/14607'-15130'MD,6270' TVD,ADT 4.04,Bit 51.26,Jars 51.26, PU 226K,SO 53K,ROT 126K,Tq on/off 17-18K/15K,ECD 12.38 ppg, FO 56%,WOB 7-12K,RPM 130,GPM 270,3550 PSI,Max gas 1086, Footage 523'. 6/1/2016 6/1/2016 2.50 PROD1 CASING CIRC P CBU f/15130'-15069'MD,270 gpm, 15,130.0 15,069.0 17:30 20:00 3500 psi, 100 rpm,Tq 16K,FO 57%. SPR's @ 15130'MD,6270'TVD, 10.4+ppg @ 18:15 hrs. #1 20/30 SPM @ 780/1100 psi #2 20/30 SPM @ 780/1100 psi Page 21/26 Report Printed: 6/15/2016 • Operations Summary (with Timelog Depths) 2S-05 +Conocoehlflips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKl3) 6/1/2016 6/1/2016 1.25 PROD1 CASING OWFF P Monitor well pumping across the top of 15,069.0 15,069.0 20:00 21:15 the MPD head.Observed 1.5 bbls lost in 30 minutes. 6/1/2016 6/2/2016 2.75 PROD1 CASING BKRM P PJSM-BROOH f/15069'-13781'MD, 15,069.0 13,781.0 21:15 00:00 270 gpm,3350 psi, 130 rpm,Tq 16K, FO 55%, 1000 fph,calculated displacement 11.2,actual 25 bbls. OA 475 psi at 24:00 hrs. 6/2/2016 6/2/2016 5.50 PROD1 CASING BKRM P PJSM-BROOH f/13781'-11243'MD, 13,781.0 11,243.0 00:00 05:30 270 gpm,3350 psi, 130 rpm,Tq 16K, FO 55%, 1000 fph,calculated displacement 15.8,actual 11.6 bbls. 6/2/2016 6/2/2016 0.50 PROD1 CASING OWFF T Monitor well due to incorrect hole fill. 11,243.0 11,243.0 05:30 06:00 Shut in MPD chokes,observed pressure drop to-7 psi.Line up& circulate across the top through MPD head.Observe 1.5 bbls lost in 20 min. 6/2/2016 6/2/2016 1.25 PROD1 CASING CIRC T CBU at 270 gpm,2870 psi,90 rpm,Tq 11,243.0 11,243.0 06:00 07:15 12K.No gas observed at bottoms up. 6/2/2016 6/2/2016 1.25 PROD1 CASING OWFF T Shut in MPD chokes,observed 11,243.0 11,243.0 07:15 08:30 pressure drop to-7 psi.Line up& circulate across the top through MPD head.Observe-1.22 bbls,+1 bbl,then -.81 bbls for 30 min.Decision made to continue BROOH. 6/2/2016 6/2/2016 4.75 PROD1 CASING BKRM P PJSM-BROOH f/11243'-8977'MD, 11,243.0 8,977.0 08:30 13:15 270 gpm,2500 psi, 130 rpm,Tq 12K, FO 59%, 1000 fph,PU 155K,SO 75K, ROT 112,calculated displacement 8.1,actual 18.2 bbls. OA 475 psi @ 12:00 hrs. 6/2/2016 6/2/2016 2.00 PROD1 CASING CIRC P CBU at 270 gpm,2500 psi,FO 55%, 8,977.0 8,977.0 13:15 15:15 97 rpm,Tq 10K,till shaker cleaned up. 6/2/2016 6/2/2016 1.50 PROD1 CASING CIRC P Continue circulating at same 8,977.0 8,977.0 15:15 16:45 parameters&mix high vis spacer pill, prepping for displacement. 6/2/2016 6/2/2016 1.00 PROD1 CASING CIRC P PJSM-lay spacer in casing f/8977'- 8,977.0 8,505.0 16:45 17:45 8505'MD.Pump spacer to bit at 5 bpm, 1700 psi.Lay spacer at 1.5 bpm, 400 psi, 1500-1800 fph,30 rpm,Tq 11K. 6/2/2016 6/2/2016 1.25 PROD1 CASING DISP P PJSM-displace casing to 11.8 ppg 8,505.0 8,505.0 17:45 19:00 brine at 220 gpm, 1600 psi,60 rpm, Tq 10K,FO 52%. 6/2/2016 6/2/2016 1.50 PROD1 CASING CIRC P Circulate brine around to 11.8 ppg 8,505.0 8,505.0 19:00 20:30 in/out.220 gpm, 1700 psi,45 rpm,Tq 10K. 6/2/2016 6/2/2016 0.50 PROD1 CASING OWFF P Monitor well,SIMOPS blow down 8,505.0 8,505.0 20:30 21:00 MPD lines&drop 2.0"rabbit on stand 86. 6/2/2016 6/2/2016 1.25 PROD1 CASING MPDA P PJSM-remove RCD bearing&install 8,505.0 8,505.0 21:00 22:15 trip nipple.Rig down MPD lines&line up on flow line. SPR's @ 8505'MD,6239'TVD, 11.8 ppg @ 22:00 hrs. #1 20/30 SPM @ 385/650 psi #2 20/30 SPM @ 385/640 psi Page 22/26 Report Printed: 6/15/2016 5Ns" • !- Operations Summary (with Timelog Depths) is;* Y 1 , Yh� 2S-05 C ,ocitii Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X t Operation MMKS)', End Depth MKS), 6/2/2016 6/2/2016 0.75 PROD1 CASING SLPC P PJSM-cut&slip 59'of drill line. 8,505.0 8,505.0 22:15 23:00 SIMOPS change out flow show meter in flow line. 6/2/2016 6/2/2016 0.50 PROD1 CASING SVRG P PJSM-service rig 8,505.0 8,505.0 23:00 23:30 6/2/2016 6/3/2016 0.50 PROD1 CASING TRIP P PJSM-TOH f/8505'-8126 MD. 8,505.0 8,126.0 23:30 00:00 Kick w/Tripping Drill CRT 67 sec @ 11:45 hrs. OA 400 psi @ 24:00 hrs. 6/3/2016 6/3/2016 5.25 PROD1 CASING TRIP P PJSM-TOH f/8126-364'MD, 8,126.0 364.0 00:00 05:15 calculated fill 50.94,actual 64.35 bbls. 6/3/2016 6/3/2016 0.50 PROD1 CASING OWFF P Monitor well,static. 364.0 364.0 05:15 05:45 6/3/2016 6/3/2016 2.25 PROD1 CASING BHAH P PJSM-lay down HWDP,jars,& 364.0 0.0 05:45 08:00 remaining BHA per SLB DD. 6/3/2016 6/3/2016 0.50 PROD1 CASING BHAH P Clear&clean rig floor 0.0 0.0 08:00 08:30 6/3/2016 6/3/2016 1.75 COMPZN CASING RURD P PJSM-rig up casing tools to run liner. 0.0 0.0 08:30 10:15 6/3/2016 6/3/2016 8.25 COMPZN CASING PUTB P PJSM-run 4-1/2", 12.6#,L-80,Fiyd 0.0 6,235.0 10:15 18:30 563 f/0-6235'MD.Pick up Silver bullet float shoe,WFT float collar, WIV,&Baker Alfa Pressure Sleeve. Ran 9 frac sleeves,11 swell packers, 145 Hydroform centralizers,&12 WFT stop rings.Average MU torque 4000 ft/lbs.PU 100K,SO 72K. 0 remakes,0 rejects. OA 250 psi @ 12:00 hrs. 6/3/2016 6/3/2016 0.50 COMPZN CASING OTHR P PJSM-pick up ZXP 5.5"X 7.63"liner 6,235.0 6,286.0 18:30 19:00 top packer/hanger f/6235'-6286'MD& load Pal mix per Baker Rep. 6/3/2016 6/3/2016 0.25 COMPZN CASING RUNL P PJSM-swap out handling equipment 6,286.0 6,380.0 19:00 19:15 &TIH f/6286'-6380'MD,w/4"DP. 6/3/2016 6/3/2016 0.50 COMPZN CASING CIRC P Pump liner volume @ 3 bpm,350 psi, 6,380.0 6,380.0 19:15 19:45 FO 12%. Fire Drill CRT 167 sec @ 19:30 hrs. 6/3/2016 6/3/2016 1.75 COMPZN CASING RUNL P PJSM-TIH w/liner on DP f/6380'- 6,380.0 8,745.0 19:45 21:30 8745'MD,PU 135K,SO 80K. 6/3/2016 6/3/2016 0.25 COMPZN CASING CIRC P Fill drill pipe&PJSM for installing 8,745.0 8,745.0 21:30 21:45 MPD bearing. 6/3/2016 6/3/2016 0.75 COMPZN CASING MPDA P Remove trip nipple&install MPD 8,745.0 8,745.0 21:45 22:30 bearing.Hook up lines&flood system. 6/3/2016 6/3/2016 0.25 COMPZN CASING RUNL P PJSM-TIH w/liner on DP f/8745'- 8,745.0 8,998.0 22:30 22:45 8998'MD,PU 135K,SO 80K. 6/3/2016 6/3/2016 0.75 COMPZN CASING WAIT T Wait on vac trucks for displacement. 8,998.0 8,998.0 22:45 23:30 Dispatch scheduled wrong time for call out. 6/3/2016 6/4/2016 0.50 COMPZN CASING DISP P PJSM-displace 11.8 ppg brine to 10.4 8,998.0 8,998.0 23:30 00:00 ppg FloPro mud system.Pump 30 bbls hi-vis spacer&swap to mud at 3 bpm,575 psi. OA 400 psi @ 24:00 hrs. 6/4/2016 6/4/2016 2.00 COMPZN CASING DISP P PJSM-displace 11.8 ppg brine to 10.4 8,998.0 8,998.0 00:00 02:00 ppg FloPro mud system.Stage up pump to 195 gpm, 1000 psi,FO 34%. Page 23/26 Report Printed: 6/15/2016 • • Operations Summary (with Timelog Depths) *4147 NiitaVEVAA 2S-05 ConocoPhifiips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P T x Operation (ftKB)', End Depth(I KE)'; 6/4/2016 6/4/2016 0.25 COMPZN CASING OWFF P Monitor well pumping across the top 8,998.0 8,998.0 02:00 02:15 thru MPD,static.PU 145K,SO 84K, ROT 100K,TQ 6K. 6/4/2016 6/4/2016 8.25 COMPZN CASING RUNL P PJSM-TIH w/liner on DP f/8998'- 8,998.0 15,125.0 02:15 10:30 15125'MD,hold 30 psi w/MPD,fill every 10 stands,2000 fph.Calculated displacement 54.3,actual 39.5 bbls. 6/4/2016 6/4/2016 0.50 COMPZN CASING RUNL P Pick up single&tag bottom at 15130' 15,125.0 15,112.0 10:30 11:00 MD.Lay down single.Pick up to set depth at 15112'MD.PU 195K,SO 90K. 6/4/2016 6/4/2016 1.25 COMPZN CASING CIRC P Circulate string volume at 2.5 bpm, 15,112.0 15,112.0 11:00 12:15 1150 psi,FO 12%. OA 500 psi at 12:00 hrs. 6/4/2016 6/4/2016 2.75 COMPZN CASING PACK P PJSM-set liner hanger/packer.Drop 15,112.0 8,885.0 12:15 15:00 1.25"ball&pump down at 2 bpm,900 psi.Slow pump to 1 bpm,650 psi, 100 bbls away.Pump ball on seat pressuring up to 1200 psi,for 1 minute.Pressure up to 2000 psi for 5 minutes.Slack off&set 40K down weight to set hanger.Pressure up to 3500 psi to release HRD-E running tool,bleed off pressure.Pick up 7'to expose dog sub&confirm release. Set down 44K,observed shear at 65K. Pick up to neutral weight 135K,rotate 20 rpm,Tq 6K,set down 40K to confirm packer set.TOL 8835'MD. 6/4/2016 6/4/2016 1.00 COMPZN CASING PRTS P PJSM-pressure test liner top packer 8,885.0 8,885.0 15:00 16:00 to 3000 psi for 30 minutes,charted. Retest to 3000 psi for 10 minutes. 6/4/2016 6/4/2016 0.25 COMPZN WELLPR TRIP P Pick up to pull RS seals,PU 175K,SO 8,885.0 8,885.0 16:00 16:15 115K,ROT 143K. 6/4/2016 6/4/2016 1.00 COMPZN WELLPR DISP P PJSM-displace to 8.4 ppg clean sea 8,885.0 8,835.0 16:15 17:15 H2O at 5 bpm, 1100 psi.Pick up slowly out of tie back sleeve,to clean out. Increase rate to 10 bpm,3000 psi. 6/4/2016 6/4/2016 1.25 COMPZN WELLPR RURD P PJSM-clean solids control equipment 8,835.0 8,835.0 17:15 18:30 in the pits&change screens on shakers. 6/4/2016 6/4/2016 0.50 COMPZN WELLPR CIRC P CBU to clean IA 10 bpm,2225 psi,PU 8,835.0 8,835.0 18:30 19:00 175K,SO 115K. 6/4/2016 6/4/2016 0.75 COMPZN WELLPR OWFF P Monitor well,circulate across MPD 8,835.0 8,835.0 19:00 19:45 head to observe the well static. 6/4/2016 6/4/2016 1.00 COMPZN WELLPR MPDA P PJSM-blow down all MPD equipment 8,835.0 8,835.0 19:45 20:45 &lines.Remove RCD&install trip nipple. 6/4/2016 6/5/2016 3.25 COMPZN WELLPR PULD P PJSM-lay down 137 joints of 4"DP 8,835.0 4,466.0 20:45 00:00 while TOH f/8835'-4466'MD. Calculated fill 32,actual 36 bbls. Kick w/Tripping Drill CRT 78 sec @ 22:00 hrs. OA 480 psi @ 24:00 hrs 6/5/2016 6/5/2016 0.50 COMPZN WELLPR CIRC T CBU because sea water u-tubing,6 4,466.0 4,466.0 00:00 00:30 bpm,320 psi,FO 9%. Page 24/26 Report Printed: 6/15/2016 i • Operations Summary (with Timelog Depths) rpt„� . 2S-05 ConocoPhiiiips• Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Stall Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKS), 6/5/2016 6/5/2016 3.25 COMPZN WELLPR PULD P PJSM-TOH laying down 141 joints of 4,466.0 0.0 00:30 03:45 4"DP f/4466'-0'. Kick w/Tripping CRT 93 sec @ 03:15 hrs. 6/5/2016 6/5/2016 0.50 COMPZN WELLPR BHAH P PJSM-service break&lay down 0.0 0.0 03:45 04:15 Baker running tool. 6/5/2016 6/5/2016 0.50 COMPZN WELLPR RURD P PJSM-rig up mousehole&prep to lay 0.0 0.0 04:15 04:45 down 4"from derrick. 6/5/2016 6/5/2016 4.25 COMPZN WELLPR PULD P PJSM-lay down 192 joints of 4"DP 0.0 0.0 04:45 09:00 from derrick. 6/5/2016 6/5/2016 1.00 COMPZN RPCOMP WWWH P PJSM-remove wear bushing,flush 0.0 0.0 09:00 10:00 stack,&lay down stack washer. 6/5/2016 6/5/2016 2.50 COMPZN RPCOMP RURD P PJSM-mobilize casing&completion 0.0 0.0 10:00 12:30 equipment to rig floor.Rig up to run 3.5"upper completion. 6/5/2016 6/5/2016 1.00 COMPZN RPCOMP PUTB P PJSM-run 3.5",9.3#, L-80,EUE 8RD 0.0 126.0 12:30 13:30 Mod,R2 completion tubing as per detail f/0-126'MD.Pick up WLEG,No -Go Sub,D nipple w/RHC,Premier packer. 6/5/2016 6/5/2016 0.50 COMPZN RPCOMP PUTB P Make up gauge carrier per SLB f/ 126.0 152.0 13:30 14:00 126'-152'MD. 6/5/2016 6/5/2016 0.25 COMPZN RPCOMP PRTS P PJSM-pressure test guage carrier to 152.0 152.0 14:00 14:15 5000 psi for 15 minutes. 6/5/2016 6/6/2016 9.75 COMPZN RPCOMP PUTB P PJSM-run 3.5",9.3#, L-80,EUE 8RD 152.0 7,687.0 14:15 00:00 Mod, R2 completion tubing as per detail f/152'-7687'MD.Make up CMU,GLM w/SOV,&2 GLM's. Gauge carrier tested at surface to 5000 psi for 15 min.Ran 237 joints with I-wire tested every 1000'MD. OA 40 psi @ 24:00 hrs. 6/6/2016 6/6/2016 2.50 COMPZN RPCOMP PUTB P PJSM-run 3.5",9.3#,L-80, EUE 8RD 7,687.0 8,790.0 00:00 02:30 Mod,R2 completion tubing as per detail f/7687'-8790'MD.Ran 35 joints with I-wire tested every 1000'MD. Installed 288 total Cannon clamps,2 SS bands.Calculated displacement 30.2,actual 32.3 bbls. 6/6/2016 6/6/2016 0.50 COMPZN RPCOMP PUTB P Tag up on NoGo at 8840'MD,275'in 8,790.0 8,840.0 02:30 03:00 on joint 275.PU 105K,SO 70K 6/6/2016 6/6/2016 1.50 COMPZN RPCOMP HOSO P PJSM-lay down 3 joints#275-273. 8,840.0 8,846.0 03:00 04:30 Pick up 2 pup joints 8.12'&6.01',3.5" X 4.5"XO, 1 jt of 4.5"tubing,hanger, &landing joint. 6/6/2016 6/6/2016 1.00 COMPZN RPCOMP THGR P PJSM-test&terminate I-wire.Test 8,846.0 8,868.0 04:30 05:30 control line seals to 5000 psi for 10 minutes. Install clamp on hanger pup &tie off I-wire stub out.Land hanger to verify correct position. Pick up 5'for circulation. 6/6/2016 6/6/2016 0.75 COMPZN RPCOMP CRIH P Spot 20 bbls of corrosion inhibited 8,868.0 8,868.0 05:30 06:15 brine,chased with 77 bbls of 8.5 ppg filtered sea water,250 gpm,700 psi, FO13%. 6/6/2016 6/6/2016 1.00 COMPZN RPCOMP THGR P PJSM-land hanger&RILDS,8868'- 8,868.0 8,873.5 06:15 07:15 8873.49'MD. 6/6/2016 6/6/2016 0.25 COMPZN RPCOMP THGR P PJSM-test hanger seals to 5000 psi 8,873.5 8,873.5 07:15 07:30 for 10 minutes,witnessed. Page 25/26 Report Printed: 6/15/2016 • Operations Summary (with Timelog Depths) 14 2S-05 r_orxocoPhitlips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr). Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKS): 6/6/2016 6/6/2016 3.00 COMPZN RPCOMP PRTS P PJSM-drop 1.3"OD ball&rod, 8,873.5 8,873.5 07:30 10:30 allowing 15 min to fall.Test tubing to 4000 psi for 30 minutes. Bleed tubing to 2000 psi.Pressure test IA to 3500 psi for 30 minutes.Bleed off IA& tubing. Pressure up IA,observe SOV shear at 2700 psi.Rig down lines. 6/6/2016 6/6/2016 0.75 COMPZN WHDBOP MPSP P Install 4",type H BPV per CIW Rep& 8,873.5 8,873.5 10:30 11:15 test in the direction of flow to 2500 psi for 30 minutes. 6/6/2016 6/6/2016 0.50 COMPZN WHDBOP OWFF P Monitor well,static. 8,873.5 8,873.5 11:15 11:45 6/6/2016 6/6/2016 2.50 COMPZN WHDBOP NUND P PJSM-nipple down stack.Blow/rig 8,873.5 8,873.5 11:45 14:15 down BOPE&MPD lines. Nipple down BOPE&rack back on stump. 6/6/2016 6/6/2016 1.25 COMPZN WHDBOP NUND P PJSM-prep adapter for install,feed I- 8,873.5 8,873.5 14:15 15:30 wire thru adapter&make up adapter flange. 6/6/2016 6/6/2016 1.00 COMPZN WHDBOP PRTS P PJSM-test hanger seals,adapter void 8,873.5 8,873.5 15:30 16:30 &top body seals to 5000 psi for 15 minutes.Rig up&test SRL seal to 10,000 psi for 15 minutes,tests witnessed. 6/6/2016 6/6/2016 0.75 COMPZN WHDBOP NUND P PJSM-terminate I-wire per Cameo. 8,873.5 8,873.5 16:30 17:15 6/6/2016 6/6/2016 2.75 COMPZN WHDBOP NUND P PJSM-nipple up tree. 8,873.5 8,873.5 17:15 20:00 6/6/2016 6/6/2016 1.50 COMPZN WHDBOP PRTS P PJSM-rig up&test tree to 10,000 psi 8,873.5 8,873.5 20:00 21:30 for 15 minutes,witnessed. Rig down test equipment. 6/6/2016 6/6/2016 0.25 COMPZN WHDBOP MPSP P PJSM-remove BPV. 8,873.5 8,873.5 21:30 21:45 6/6/2016 6/7/2016 2.25 COMPZN WHDBOP FRZP P PJSM-freeze protect well with LRS. 8,873.5 8,873.5 21:45 00:00 Rig up&test lines to 3000 psi.Pump 95 bbls down IA at 1.5 bpm, ICP 410 psi,FCP 550 psi.Shut down&line up to U-tube with tubing.SIMOPS rig down LRS lines,prep for rig move. Rig release @ 24:00 hrs. Page 26/26 Report Printed: 6/15/2016 • i NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-05 2S-05 Definitive Survey Report 06 June, 2016 • • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference; Well 2S-05 Project: Kuparuk River Unit 7Vi Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference:,-v" 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Refereri '''/"'" True Wei!bore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 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 2S-05 Well Position +N/-S 0.00 usft Northing: 5,930,010.88 usfl Latitude: 70°13'11.806 N +E/-W 0.00 usft Easting: 481,191.79 usfl Longitude: 150°9'6.241 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-05 Magnetics Model Name :,Sample Date Declination Dip Angle Field Strength r) (°) (nT) i BGGM2016 6/1/2016 18.00 80.85 57,537 Design 2S-05 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Directien (ift) (usft) (usft) rf.. 27.50 0.00 0.00 15.00 Survey Date (u . (usft) Survey(Wetibore) Tool Name Description =- Survey Date 127.33 718.29 2S-05 Srvy 1 -SLB_GWD70(2S-05) GYD-GC-SS Gyrodata gyro single shots 5/16/2016 9:1 776.84 2,857.78 2S-05 Srvy 2-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/16/2016 9:1: 2,938.10 8,954.93 2S-05 Srvy 3-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/21/2016 10:4 9,009.78 9,009.78 2S-05 Srvy 4-SLB_INC+Filler(2S-05) INC+TREND Inclinometer+known azi trend 5/29/2016 3:3 9,103.15 15,062.69 2S-05 Srvy 5-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/29/2016 3:3, Survey Map Map Vertic MD Inc A26. TVD 'TVDSS +N/-S +E/-W Northing Easting OLS„'- (usft) (0) ,el-• (usft) (usft) (usft) ((lsft) (ft) (ft) (0/100`)' (ft) Survey Tool Nellie 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,930,010.88 481,191.79 0.00 0.00 UNDEFINED 127.33 0.94 313.77 127.33 -20.17 0.57 -0.59 5,930,011.45 481,191.20 0.94 0.39 GYD-GC-SS(1) 184.63 0.59 307.09 184.62 37.12 1.07 -1.17 5,930,011.95 481,190.63 0.63 0.73 GYD-GC-SS(1) 228.52 0.79 310.84 228.51 81.01 1.40 -1.58 5,930,012.29 481,190.22 0.47 0.95 GYD-GC-SS(1) 321.09 1.44 327.33 321.06 173.56 2.80 -2.69 5,930,013.69 481,189 11 0.78 2.01 GYD-GC-SS(1) 411.37 0.88 180.93 411.33 263.83 3.06 -3.31 5,930,013.95 481,188.49 2.47 2.10 GYD-GC-SS(1) 500.99 2.65 172.90 500.91 353.41 0.32 -3.06 5,930,011.20 481,188.73 1.99 -0.49 GYD-GC-SS(1) 583.33 2.51 173.94 583.16 435.66 -3.36 -2.64 5,930,007.52 481,189.14 0.18 -3.93 GYD-GC-SS(1) 626.53 2.32 175.81 626.32 478.82 -5.18 -2.48 5,930,005.71 481,189.30 0.48 -5.64 GYD-GC-SS(1) 718.29 6.11 164.66 717.82 570.32 -11.74 -1.05 5,929,999.14 481,190.71 4.21 -11.61 GYD-GC-SS(1) 6/6/2016 12:49:30PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nt-S +E!-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 776.84 5.77 164.05 776.06 628.56 -17.58 0.59 5,929,993.30 481,192.33 0.59 -16.83 MWD+IFR-AK-CAZ-SC(2) 870.48 7.51 165.97 869.06 721.56 -28.04 3.36 5,929,982.83 481,195.08 1.87 -26.21 MWD+IFR-AK-CAZ-SC(2) 964.29 9.91 166.14 961.78 814.28 -41.83 6.78 5,929,969.04 481,198.47 2.56 -38.65 MWD+IFR-AK-CAZ-SC(2) 1,056.46 13.75 166.94 1,051.98 904.48 -60.20 11.16 5,929,950.65 481,202.80 4.17 -55.26 MWD+IFR-AK-CAZ-SC(2) 1,148.49 16.50 170.20 1,140.82 993.32 -83.74 15.86 5,929,927.11 481,207.44 3.13 -76.78 MWD+IFR-AK-CAZ-SC(2) 1,243.13 19.42 172.42 1,230.84 1,083.34 -112.59 20.22 5,929,898.25 481,211.73 3.17 -103.52 MWD+IFR-AK-CAZ-SC(2) 1,337.56 20.49 172.52 1,319.59 1,172.09 -144.54 24.44 5,929,866.30 481,215.87 1.13 -133.28 MWD+IFR-AK-CAZ-SC(2) 1,430.53 22.32 173.46 1,406.15 1,258.65 -178.21 28.57 5,929,832.62 481,219.92 2.00 -164.74 MWD+IFR-AK-CAZ-SC(2) 1,523.41 25.57 172.76 1,491.02 1,343.52 -215.63 33.11 5,929,795.19 481,224.36 3.51 -199.71 MWD+IFR-AK-CAZ-SC(2) 1,616.92 28.71 169.85 1,574.23 1,426.73 -257.77 39.61 5,929,753.04 481,230.76 3.64 -238.73 MWD+IFR-AK-CAZ-SC(2) 1,710.88 33.53 167.54 1,654.65 1,507.15 -305.35 49.19 5,929,705.44 481,240.22 5.28 -282.22 MWD+IFR-AK-CAZ-SC(2) 1,804.43 34.46 159.17 1,732.25 1,584.75 -355.35 64.19 5,929,655.41 481,255.09 5.10 -326.63 MWD+IFR-AK-CAZ-SC(2) 1,897.26 33.95 151.23 1,809.06 1,661.56 -402.64 86.02 5,929,608.07 481,276.79 4.84 -366.66 MWD+IFR-AK-CAZ-SC(2) 1,990.29 33.62 147.98 1,886.39 1,738.89 -447.25 112.18 5,929,563.40 481,302.84 1.97 -402.98 MWD+IFR-AK-CAZ-SC(2) 2,082.45 32.65 138.89 1,963.61 1,816.11 -487.64 142.07 5,929,522.94 481,332.63 5.49 -434.25 MWD+IFR-AK-CAZ-SC(2) 2,177.13 34.51 133.21 2,042.51 1,895.01 -525.26 178.42 5,929,485.23 481,368.88 3.85 -461.18 MWD+IFR-AK-CAZ-SC(2) 2,268.36 39.66 131.78 2,115.26 1,967.76 -562.38 219.00 5,929,448.02 481,409.36 5.72 -486.53 MWD+IFR-AK-CAZ-SC(2) 2,360.68 42.71 132.42 2,184.73 2,037.23 -603.13 264.09 5,929,407.15 481,454.35 3.34 -514.23 MWD+IFR-AK-CAZ-SC(2) 2,453.72 46.16 134.18 2,251.16 2,103.66 -647.82 311.46 5,929,362.35 481,501.61 3.94 -545.13 MWD+I FR-AK-CAZ-SC(2) 2,546.91 48.47 135.46 2,314.34 2,166.84 -696.11 360.04 5,929,313.94 481,550.06 2.68 -579.21 MWD+IFR-AK-CAZ-SC(2) 2,639.00 48.84 135.77 2,375.17 2,227.67 -745.52 408.40 5,929,264.42 481,598.29 0.47 -614.42 MWD+IFR-AK-CAZ-SC(2) 2,733.79 48.82 136.29 2,437.57 2,290.07 -796.87 457.94 5,929,212.95 481,647.69 0.41 -651.20 MWD+IFR-AK-CAZ-SC(2) 2,828.56 48.75 136.55 2,500.01 2,352.51 -848.52 507.08 5,929,161.19 481,696.70 0.22 -688.36 MWD+IFR-AK-CAZ-SC(2) 2,857.78 49.18 136.92 2,519.20 2,371.70 -864.57 522.19 5,929,145.10 481,711.77 1.75 -699.95 MWD+IFR-AK-CAZ-SC(2) 2,927.20 48.06 134.59 2,565.09 2,417.59 -901.88 558.52 5,929,107.70 481,748.00 2.99 -726.60 MWD+I FR-AK-CAZ-SC(3) 103/Vx13112H xk 2,938.10 47.89 134.22 2,572.39 2,424.89 -907.55 564.30 5,929,102.02 481,753.77 2.99 -730.57 MWD+I FR-AK-CAZ-SC(3) 3,027.83 48.33 135.17 2,632.30 2,484.80 -954.53 611.78 5,929,054.92 481,801.13 0.93 -763.66 MWD+IFR-AK-CAZ-SC(3) 3,122.99 48.53 134.89 2,695.44 2,547.94 -1,004.90 662.10 5,929,004.44 481,851.32 0.30 -799.29 MWD+I FR-AK-CAZ-SC(3) 3,216.36 48.30 135.18 2,757.41 2,609.91 -1,054.31 711.45 5,928,954.91 481,900.54 0.34 -834.25 MWD+I F R-AK-CAZ-SC(3) 3,309.24 48.77 135.83 2,818.92 2,671.42 -1,103.96 760.23 5,928,905.14 481,949.19 0.73 -869.58 MWD+I FR-AK-CAZ-SC(3) 3,406.39 48.85 135.57 2,882.89 2,735.39 -1,156.28 811.29 5,928,852.70 482,000.12 0.22 -906.90 MWD+IFR-AK-CAZ-SC(3) 3,499.11 48.89 135.36 2,943.88 2,796.38 -1,206.06 860.27 5,928,802.80 482,048.97 0.18 -942.31 MWD+IFR-AK-CAZ-SC(3) 3,594.64 48.82 136.75 3,006.74 2,859.24 -1,257.86 910.19 5,928,750.88 482,098.75 1.10 -979.42 MWD+IFR-AK-CAZ-SC(3) 3,686.68 48.83 137.92 3,067.34 2,919.84 -1,308.80 957.14 5,928,699.83 482,145.57 0.96 -1,016.47 MWD+IFR-AK-CAZ-SC(3) 3,780.06 48.86 139.13 3,128.79 2,981.29 -1,361.47 1,003.70 5,928,647.04 482,192.00 0.98 -1,055.30 MWD+IFR-AK-CAZ-SC(3) 3,872.75 48.82 138.82 3,189.80 3,042.30 -1,414.12 1,049.51 5,928,594.29 482,237.67 0.26 -1,094.30 MWD+IFR-AK-CAZ-SC(3) 3,968.59 48.82 138.00 3,252.90 3,105.40 -1,468.07 1,097.39 5,928,540.23 482,285.41 0.64 -1,134.02 MWD+IFR-AK-CAZ-SC(3) 4,063.09 48.99 137.51 3,315.02 3,167.52 -1,520.79 1,145.27 5,928,487.39 482,333.15 0.43 -1,172.55 MWD+IFR-AK-CAZ-SC(3) 4,157.44 48.84 136.99 3,377.02 3,229.52 -1,573.01 1,193.54 5,928,435.06 482,381.29 0.44 -1,210.50 MWD+IFR-AK-CAZ-SC(3) 4,253.81 48.83 136.83 3,440.46 3,292.96 -1,625.99 1,243.10 5,928,381.96 482,430.71 0.13 -1,248.85 MWD+IFR-AK-CAZ-SC(3) 6/6/2016 12:49:30PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report company: NADConversion Local Co-ordinate Reference: Well 2S-05 r•-t: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) $ Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) 2S-05 North,Reference: True if�dr 2S-05 Survey Calculation Method: Minimum Curvature 2S-05 Database: OAKEDMP2 ttlrvey, Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +e-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft)', (usft) (usft) (ft) (ft) (°f100') (ft) Survey Tool Name 4,346.52 48.91 136.98 3,501.44 3,353.94 -1,676.98 1,290.81 5,928,330.85 482,478.29 0.15 -1,285.75 MWD+IFR-AK-CAZ-SC(3) 4,438.77 48.76 137.23 3,562.16 3,414.66 -1,727.86 1,338.08 5,928,279.86 482,525.43 0.26 -1,322.66 MWD+IFR-AK-CAZ-SC(3) 4,531.28 48.69 137.29 3,623.19 3,475.69 -1,778.92 1,385.27 5,928,228.69 482,572.48 0.09 -1,359.77 MWD+IFR-AK-CAZ-SC(3) 4,622.32 48.67 137.83 3,683.30 3,535.80 -1,829.38 1,431.41 5,928,178.12 482,618.49 0.45 -1,396.57 MWD+IFR-AK-CAZ-SC(3) 4,715.87 48.64 138.15 3,745.09 3,597.59 -1,881.57 1,478.41 5,928,125.82 482,665.36 0.26 -1,434.81 MWD+IFR-AK-CAZ-SC(3) 4,808.83 48.75 138.60 3,806.45 3,658.95 -1,933.77 1,524.80 5,928,073.51 482,711.61 0.38 -1,473.23 MWD+IFR-AK-CAZ-SC(3) 4,900.02 48.73 138.33 3,866.59 3,719.09 -1,985.08 1,570.25 5,928,022.09 482,756.93 0.22 -1,511.03 MWD+IFR-AK-CAZ-SC(3) 4,993.01 48.88 137.38 3,927.84 3,780.34 -2,036.96 1,617.20 5,927,970.10 482,803.75 0.79 -1,548.99 MWD+IFR-AK-CAZ-SC(3) 5,083.39 48.74 137.07 3,987.36 3,839.86 -2,086.88 1,663.39 5,927,920.07 482,849.81 0.30 -1,585.26 MWD+IFR-AK-CAZ-SC(3) 5,178.67 48.20 136.87 4,050.53 3,903.03 -2,139.02 1,712.06 5,927,867.81 482,898.35 0.59 -1,623.02 MWD+IFR-AK-CAZ-SC(3) 5,272.80 48.20 135.64 4,113.27 3,965.77 -2,189.71 1,760.58 5,927,817.00 482,946.74 0.97 -1,659.43 MWD+IFR-AK-CAZ-SC(3) 5,364.75 48.31 134.73 4,174.50 4,027.00 -2,238.38 1,808.94 5,927,768.22 482,994.96 0.75 -1,693.92 MWD+IFR-AK-CAZ-SC(3) 5,455.15 48.19 134.73 4,234.69 4,087.19 -2,285.85 1,856.85 5,927,720.64 483,042.75 0.13 -1,727.37 MWD+IFR-AK-CAZ-SC(3) 5,550.87 48.42 134.31 4,298.36 4,150.86 -2,335.96 1,907.81 5,927,670.41 483,093.58 0.41 -1,762.59 MWD+IFR-AK-CAZ-SC(3) 5,643.72 48.15 134.33 4,360.15 4,212.65 -2,384.38 1,957.40 5,927,621.86 483,143.05 0.29 -1,796.53 MWD+IFR-AK-CAZ-SC(3) 5,738.55 48.23 134.40 4,423.36 4,275.86 -2,433.81 2,007.93 5,927,572.32 483,193.45 0.10 -1,831.19 MWD+IFR-AK-CAZ-SC(3) 5,830.05 48.13 134.35 4,484.38 4,336.88 -2,481.49 2,056.67 5,927,524.52 483,242.07 0.12 -1,864.63 MWD+IFR-AK-CAZ-SC(3) 5,926.59 48.29 134.00 4,548.71 4,401.21 -2,531.65 2,108.29 5,927,474.23 483,293.56 0.32 -1,899.72 MWD+IFR-AK-CAZ-SC(3) 6,018.86 45.64 130.31 4,611.69 4,464.19 -2,576.93 2,158.24 5,927,428.83 483,343.39 4.10 -1,930.53 MWD+IFR-AK-CAZ-SC(3) 6,110.09 43.36 127.63 4,676.76 4,529.26 -2,617.16 2,207.92 5,927,388.49 483,392.97 3.24 -1,956.53 MWD+IFR-AK-CAZ-SC(3) 6,202.20 42.96 123.24 4,743.96 4,596.46 -2,653.68 2,259.23 5,927,351.84 483,444.17 3.29 -1,978.53 MWD+IFR-AK-CAZ-SC(3) 6,297.34 42.78 119.28 4,813.70 4,666.20 -2,687.26 2,314.53 5,927,318.13 483,499.39 2.84 -1,996.65 MWD+IFR-AK-CAZ-SC(3) 6,392.09 42.87 115.56 4,883.21 4,735.71 -2,716.91 2,371.69 5,927,288.34 483,556.46 2.67 -2,010.49 MWD+IFR-AK-CAZ-SC(3) 6,484.85 42.93 112.23 4,951.17 4,803.67 -2,742.47 2,429.40 5,927,262.63 483,614.11 2.44 -2,020.25 MWD+IFR-AK-CAZ-SC(3) 6,577.50 42.86 110.46 5,019.04 4,871.54 -2,765.43 2,488.13 5,927,239.54 483,672.78 1.30 -2,027.22 MWD+IFR-AK-CAZ-SC(3) 6,671.65 43.46 106.99 5,087.73 4,940.23 -2,786.09 2,549.11 5,927,218.73 483,733.70 2.60 -2,031.39 MWD+IFR-AK-CAZ-SC(3) 6,764.87 44.31 102.69 5,154.93 5,007.43 -2,802.61 2,611.55 5,927,202.05 483,796.09 3.32 -2,031.19 MWD+IFR-AK-CAZ-SC(3) 6,859.39 44.50 98.05 5,222.48 5,074.98 -2,814.50 2,676.57 5,927,190.00 483,861.07 3.44 -2,025.85 MWD+IFR-AK-CAZ-SC(3) 6,951.24 44.03 92.71 5,288.28 5,140.78 -2,820.52 2,740.35 5,927,183.82 483,924.83 4.09 -2,015.16 MWD+IFR-AK-CAZ-SC(3) 7,044.08 43.50 88.11 5,355.34 5,207.84 -2,820.99 2,804.53 5,927,183.19 483,989.00 3.47 -1,999.01 MWD+IFR-AK-CAZ-SC(3) 7,137.61 43.41 83.52 5,423.25 5,275.75 -2,816.30 2,868.65 5,927,187.72 484,053.13 3.38 -1,977.88 MWD+IFR-AK-CAZ-SC(3) 7,231.09 43.88 77.70 5,490.92 5,343.42 -2,805.77 2,932.25 5,927,198.09 484,116.75 4.33 -1,951.25 MWD+IFR-AK-CAZ-SC(3) 7,323.71 44.26 74.04 5,557.48 5,409.98 -2,790.05 2,994.70 5,927,213.66 484,179.23 2.78 -1,919.89 MWD+IFR-AK-CAZ-SC(3) 7,416.14 46.22 70.37 5,622.57 5,475.07 -2,769.96 3,057.15 5,927,233.58 484,241.73 3.53 -1,884.33 MWD+IFR-AK-CAZ-SC(3) 7,508.02 48.15 65.55 5,685.03 5,537.53 -2,744.64 3,119.57 5,927,258.74 484,304.20 4.38 -1,843.72 MWD+IFR-AK-CAZ-SC(3) 7,602.13 50.06 61.54 5,746.66 5,599.16 -2,712.93 3,183.22 5,927,290.29 484,367.92 3.81 -1,796.62 MWD+IFR-AK-CAZ-SC(3) 7,694.43 51.60 57.39 5,804.97 5,657.47 -2,676.57 3,244.81 5,927,326.50 484,429.60 3.86 -1,745.55 MWD+IFR-AK-CAZ-SC(3) 7,788.55 54.02 52.38 5,861.88 5,714.38 -2,633.42 3,306.08 5,927,369.49 484,490.96 4.96 -1,688.02 MWD+IFR-AK-CAZ-SC(3) 7,883.74 55.21 46.86 5,917.03 5,769.53 -2,583.16 3,365.14 5,927,419.60 484,550.14 4.89 -1,624.18 MWD+IFR-AK-CAZ-SC(3) 7,976.43 56.45 42.50 5,969.11 5,821.61 -2,528.64 3,419.02 5,927,473.98 484,604.16 4.11 -1,557.57 MWD+IFR-AK-CAZ-SC(3) 6/6/2016 12:49:30PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report rrmpany ° NADConversion Local Co-ordinate Reference: Well 2S-05 p[ Kuparuk River Unit TVD Reference:, 2S-05 actual @ 147.50usft(D141) Site; Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Wayt 4 , 2S-05 North Reference: True Wel ii 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 Database: OAKEDMP2 *�rvey Map Map Vertical MD„ Inc Azi Typ 1YDSSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°} (usft) :{waft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 8,069.08 58.67 38.60 6,018.81 5,871.31 -2,469.22 3,469.81 5,927,533.26 484,655.09 4.28 -1,487.03 MWD+IFR-AK-CAZ-SC(3) 8,162.58 60.41 37.13 6,066.21 5,918.71 -2,405.60 3,519.27 5,927,596.76 484,704.71 2.30 -1,412.77 MWD+IFR-AK-CAZ-SC(3) 8,255.11 62.56 36.26 6,110.38 5,962.88 -2,340.40 3,567.85 5,927,661.83 484,753.44 2.47 -1,337.23 MWD+IFR-AK-CAZ-SC(3) 8,347.41 63.52 35.71 6,152.23 6,004.73 -2,273.83 3,616.18 5,927,728.27 484,801.94 1.17 -1,260.42 MWD+IFR-AK-CAZ-SC(3) 8,441.19 67.25 35.14 6,191.28 6,043.78 -2,204.37 3,665.59 5,927,797.60 484,851.51 4.02 -1,180.53 MWD+IFR-AK-CAZ-SC(3) 8,532.78 70.78 33.75 6,224.08 6,076.58 -2,133.85 3,713.94 5,927,867.99 484,900.03 4.11 -1,099.91 MWD+IFR-AK-CAZ-SC(3) 8,626.05 73.21 30.53 6,252.92 6,105.42 -2,058.75 3,761.10 5,927,942.97 484,947.38 4.19 -1,015.16 MWD+IFR-AK-CAZ-SC(3) 8,719.40 75.72 26.83 6,277.92 6,130.42 -1,979.86 3,804.24 5,928,021.74 484,990.70 4.67 -927.79 MWD+IFR-AK-CAZ-SC(3) 8,811.42 77.02 21.10 6,299.62 6,152.12 -1,898.18 3,840.53 5,928,103.33 485,027.20 6.21 -839.49 MWD+IFR-AK-CAZ-SC(3) 8,907.00 80.12 16.70 6,318.57 6,171.07 -1,809.57 3,870.85 5,928,191.85 485,057.73 5.56 -746.06 MWD+IFR-AK-CAZ-SC(3) 8,954.93 81.25 15.33 6,326.33 6,178.83 -1,764.11 3,883.90 5,928,237.27 485,070.89 3.68 -698.77 MWD+IFR-AK-CAZ-SC(3) 9,009.78 82.75 14.58 6,333.96 6,186.46 -1,711.64 3,897.91 5,928,289.71 485,085.04 3.05 -644.46 INC+TREND(4) 9,019.40 82.92 14.45 6,335.16 6,187.66 -1,702.40 3,900.30 5,928,298.94 485,087.45 2.23 -634.91 MWD+IFR-AK-CAZ-SC(5) 7-5/8"x 9-718-11" 9,103.15 84.43 13.34 6,344.39 6,196.89 -1,621.59 3,920.29 5,928,379.68 485,107.64 2.23 -551.69 MWD+IFR-AK-CAZ-SC(5) 9,198.02 86.80 13.34 6,351.64 6,204.14 -1,529.56 3,942.12 5,928,471.65 485,129.69 2.50 -457.15 MWD+IFR-AK-CAZ-SC(5) 9,292.14 89.51 12.97 6,354.67 6,207.17 -1,437.97 3,963.52 5,928,563.18 485,151.32 2.91 -363.13 MWD+IFR-AK-CAZ-SC(5) 9,386.99 92.19 11.86 6,353.26 6,205.76 -1,345.35 3,983.91 5,928,655.74 485,171.94 3.06 -268.40 MWD+IFR-AK-CAZ-SC(5) 9,482.45 94.16 12.36 6,347.98 6,200.48 -1,252.17 4,003.91 5,928,748.86 485,192.17 2.13 -173.21 MWD+IFR-AK-CAZ-SC(5) 9,577.25 94.08 12.63 6,341.17 6,193.67 -1,159.85 4,024.36 5,928,841.12 485,212.85 0.30 -78.75 MWD+IFR-AK-CAZ-SC(5) 9,671.27 94.15 12.31 6,334.42 6,186.92 -1,068.29 4,044.61 5,928,932.62 485,233.33 0.35 14.94 MWD+IFR-AK-CAZ-SC(5) 9,764.90 93.05 12.77 6,328.54 6,181.04 -977.07 4,064.90 5,929,023.78 485,253.84 1.27 108.29 MWD+IFR-AK-CAZ-SC(5) 9,859.15 91.57 13.40 6,324.74 6,177.24 -885.35 4,086.22 5,929,115.44 485,275.39 1.71 202.41 MWD+IFR-AK-CAZ-SC(5) 9,954.56 89.97 13.89 6,323.46 6,175.96 -792.64 4,108.73 5,929,208.08 485,298.12 1.75 297.78 MWD+IFR-AK-CAZ-SC(5) 10,048.88 91.45 13.42 6,322.29 6,174.79 -701.00 4,130.99 5,929,299.66 485,320.61 1.65 392.07 MWD+IFR-AK-CAZ-SC(5) 10,142.59 91.06 13.39 6,320.24 6,172.74 -609.86 4,152.71 5,929,390.73 485,342.55 0.42 485.72 MWD+IFR-AK-CAZ-SC(5) 10,235.80 90.25 13.36 6,319.17 6,171.67 -519.19 4,174.27 5,929,481.34 485,364.34 0.87 578.88 MWD+IFR-AK-CAZ-SC(5) 10,329.80 87.43 13.78 6,321.08 6,173.58 -427.84 4,196.32 5,929,572.63 485,386.61 3.03 672.83 MWD+IFR-AK-CAZ-SC(5) 10,425.15 87.83 15.10 6,325.02 6,177.52 -335.58 4,220.08 5,929,664.82 485,410.60 1.45 768.09 MWD+IFR-AK-CAZ-SC(5) 10,519.50 87.44 16.54 6,328.91 6,181.41 -244.89 4,245.77 5,929,755.44 485,436.52 1.58 862.34 MWD+IFR-AK-CAZ-SC(5) 10,614.16 89.57 15.95 6,331.38 6,183.88 -154.04 4,272.24 5,929,846.21 485,463.21 2.33 956.94 MWD+IFR-AK-CAZ-SC(5) 10,706.07 93.05 13.90 6,329.28 6,181.78 -65.28 4,295.91 5,929,934.91 485,487.09 4.39 1,048.81 MWD+IFR-AK-CAZ-SC(5) 10,801.34 92.62 13.47 6,324.57 6,177.07 27.18 4,318.42 5,930,027.29 485,509.83 0.64 1,143.94 MWD+IFR-AK-CAZ-SC(5) 10,896.98 90.08 13.50 6,322.32 6,174.82 120.15 4,340.71 5,930,120.20 485,532.36 2.66 1,239.51 MWD+IFR-AK-CAZ-SC(5) 10,992.81 89.69 13.26 6,322.51 6,175.01 213.37 4,362.89 5,930,213.36 485,554.76 0.48 1,335.30 MWD+IFR-AK-CAZ-SC(5) 11,087.14 90.06 13.54 6,322.71 6,175.21 305.14 4,384.75 5,930,305.06 485,576.85 0.49 1,429.60 MWD+IFR-AK-CAZ-SC(5) 11,179.92 89.99 15.04 6,322.67 6,175.17 395.04 4,407.65 5,930,394.90 485,599.97 1.62 1,522.37 MWD+IFR-AK-CAZ-SC(5) 11,275.69 89.79 15.72 6,322.86 6,175.36 487.38 4,433.05 5,930,487.17 485,625.60 0.74 1,618.13 MWD+IFR-AK-CAZ-SC(5) 11,369.67 89.03 16.82 6,323.83 6,176.33 577.59 4,459.38 5,930,577.30 485,652.15 1.42 1,712.08 MWD+IFR-AK-CAZ-SC(5) 11,464.04 89.00 17.36 6,325.45 6,177.95 667.78 4,487.10 5,930,667.41 485,680.10 0.57 1,806.38 MWD+IFR-AK-CAZ-SC(5) 11,558.57 89.62 17.13 6,326.59 6,179.09 758.05 4,515.13 5,930,757.61 485,708.34 0.70 1,900.83 MWD+IFR-AK-CAZ-SC(5) 6/6/2016 12:49:30PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,652.44 89.72 16.31 6,327.13 6,179.63 847.95 4,542.13 5,930,847.43 485,735.57 0.88 1,994.65 MWD+IFR-AK-CAZ-SC(5) 11,746.61 89.82 15.34 6,327.50 6,180.00 938.55 4,567.81 5,930,937.95 485,761.47 1.04 2,088.81 MWD+IFR-AK-CAZ-SC(5) 11,841.21 89.72 15.27 6,327.88 6,180.38 1,029.80 4,592.78 5,931,029.13 485,786.67 0.13 2,183.41 MWD+IFR-AK-CAZ-SC(5) 11,936.02 89.12 15.59 6,328.84 6,181.34 1,121.18 4,618.01 5,931,120.44 485,812.12 0.72 2,278.21 MWD+IFR-AK-CAZ-SC(5) 12,029.65 91.09 16.71 6,328.67 6,181.17 1,211.11 4,644.05 5,931,210.30 485,838.38 2.42 2,371.81 MWD+IFR-AK-CAZ-SC(5) 12,124.46 94.11 16.35 6,324.37 6,176.87 1,301.90 4,670.99 5,931,301.01 485,865.55 3.21 2,466.48 MWD+IFR-AK-CAZ-SC(5) 12,218.48 93.60 16.58 6,318.05 6,170.55 1,391.86 4,697.58 5,931,390.89 485,892.36 0.59 2,560.26 MWD+IFR-AK-CAZ-SC(5) 12,312.22 92.64 17.68 6,312.95 6,165.45 1,481.31 4,725.15 5,931,480.26 485,920.14 1.56 2,653.79 MWD+IFR-AK-CAZ-SC(5) 12,406.15 92.16 17.30 6,309.02 6,161.52 1,570.82 4,753.35 5,931,569.69 485,948.57 0.65 2,747.55 MWD+IFR-AK-CAZ-SC(5) 12,501.16 91.02 17.06 6,306.38 6,158.88 1,661.55 4,781.41 5,931,660.35 485,976.84 1.23 2,842.45 MWD+IFR-AK-CAZ-SC(5) 12,595.09 90.23 16.47 6,305.35 6,157.85 1,751.48 4,808.50 5,931,750.20 486,004.16 1.05 2,936.33 MWD+IFR-AK-CAZ-SC(5) 12,690.77 90.58 14.85 6,304.68 6,157.18 1,843.60 4,834.32 5,931,842.25 486,030.21 1.73 3,032.00 MWD+IFR-AK-CAZ-SC(5) 12,785.05 90.78 14.55 6,303.56 6,156.06 1,934.79 4,858.25 5,931,933.37 486,054.36 0.38 3,126.27 MWD+IFR-AK-CAZ-SC(5) 12,879.58 90.68 14.63 6,302.35 6,154.85 2,026.27 4,882.06 5,932,024.77 486,078.39 0.14 3,220.79 MWD+IFR-AK-CAZ-SC(5) 12,974.80 90.75 13.79 6,301.17 6,153.67 2,118.56 4,905.43 5,932,117.00 486,101.99 0.89 3,315.99 MWD+IFR-AK-CAZ-SC(5) 13,070.05 89.99 14.31 6,300.55 6,153.05 2,210.96 4,928.55 5,932,209.33 486,125.34 0.97 3,411.23 MWD+IFR-AK-CAZ-SC(5) 13,165.27 90.23 13.80 6,300.37 6,152.87 2,303.33 4,951.67 5,932,301.64 486,148.70 0.59 3,506.43 MWD+IFR-AK-CAZ-SC(5) 13,258.35 89.98 14.06 6,300.20 6,152.70 2,393.67 4,974.08 5,932,391.91 486,171.33 0.39 3,599.50 MWD+IFR-AK-CAZ-SC(5) 13,351.13 91.17 13.66 6,299.27 6,151.77 2,483.75 4,996.31 5,932,481.92 486,193.77 1.35 3,692.25 MWD+IFR-AK-CAZ-SC(5) 13,441.41 90.75 12.96 6,297.75 6,150.25 2,571.59 5,017.09 5,932,569.70 486,214.77 0.90 3,782.48 MWD+IFR-AK-CAZ-SC(5) 13,533.55 90.82 13.19 6,296.49 6,148.99 2,661.33 5,037.93 5,932,659.38 486,235.83 0.26 3,874.56 MWD+IFR-AK-CAZ-SC(5) 13,625.59 91.64 13.55 6,294.52 6,147.02 2,750.85 5,059.21 5,932,748.84 486,257.33 0.97 3,966.54 MWD+IFR-AK-CAZ-SC(5) 13,718.74 92.88 13.76 6,290.84 6,143.34 2,841.30 5,081.18 5,932,839.23 486,279.53 1.35 4,059.59 MWD+IFR-AK-CAZ-SC(5) 13,809.28 94.25 14.09 6,285.21 6,137.71 2,929.01 5,102.93 5,932,926.87 486,301.49 1.56 4,149.94 MWD+IFR-AK-CAZ-SC(5) 13,902.16 94.18 14.96 6,278.39 6,130.89 3,018.67 5,126.16 5,933,016.47 486,324.94 0.94 4,242.56 MWD+IFR-AK-CAZ-SC(5) 13,993.83 94.01 15.34 6,271.84 6,124.34 3,106.93 5,150.05 5,933,104.66 486,349.06 0.45 4,334.00 MWD+IFR-AK-CAZ-SC(5) 14,087.12 92.84 15.80 6,266.27 6,118.77 3,196.64 5,175.05 5,933,194.29 486,374.27 1.35 4,427.11 MWD+IFR-AK-CAZ-SC(5) 14,181.07 87.82 15.80 6,265.73 6,118.23 3,287.01 5,200.62 5,933,284.59 486,400.07 5.34 4,521.02 MWD+IFR-AK-CAZ-SC(5) 14,270.89 88.38 15.71 6,268.70 6,121.20 3,373.40 5,225.00 5,933,370.92 486,424.66 0.63 4,610.79 MWD+IFR-AK-CAZ-SC(5) 14,361.91 89.21 15.46 6,270.62 6,123.12 3,461.06 5,249.45 5,933,458.50 486,449.32 0.95 4,701.78 MWD+IFR-AK-CAZ-SC(5) 14,454.23 89.27 14.97 6,271.84 6,124.34 3,550.13 5,273.67 5,933,547.51 486,473.77 0.53 4,794.09 MWD+IFR-AK-CAZ-SC(5) 14,546.71 88.90 13.46 6,273.32 6,125.82 3,639.77 5,296.38 5,933,637.07 486,496.69 1.68 4,886.55 MWD+IFR-AK-CAZ-SC(5) 14,638.08 89.27 13.36 6,274.78 6,127.28 3,728.63 5,317.57 5,933,725.88 486,518.10 0.42 4,977.87 MWD+IFR-AK-CAZ-SC(5) 14,730.50 89.96 14.64 6,275.40 6,127.90 3,818.30 5,339.92 5,933,815.49 486,540.68 1.57 5,070.27 MWD+IFR-AK-CAZ-SC(5) 14,820.41 90.95 14.68 6,274.69 6,127.19 3,905.28 5,362.68 5,933,902.40 486,563.65 1.10 5,160.18 MWD+IFR-AK-CAZ-SC(5) 14,912.70 91.13 15.47 6,273.01 6,125.51 3,994.38 5,386.68 5,933,991.43 486,587.87 0.88 5,252.45 MWD+IFR-AK-CAZ-SC(5) 15,003.54 90.34 15.63 6,271.85 6,124.35 4,081.89 5,411.03 5,934,078.87 486,612.43 0.89 5,343.28 MWD+IFR-AK-CAZ-SC(5) 15,062.69 90.34 15.00 6,271.49 6,123.99 4,138.94 5,426.65 5,934,135.87 486,628.19 1.07 5,402.43 MWD+IFR-AK-CAZ-SC(5) 15,112.00 90.34 15.00 6,271.20 6,123.70 4,186.57 5,439.41 5,934,183.46 486,641.07 0.00 5,451.73 4112""z 6-314" 6/6/2016 12:49:30PM Page 6 COMPASS 5000.1 Build 74 411 Schlumberger • Definitive Survey Report ------, Company: NADConversion Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit ND Reference: 2S-05 actual @ 147 50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +14/-S +EJ-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1513000 90.34 15.00 6,271 10 6,123 60 4,203 95 5,444 07 5,934,200 83 486,645 78 0.00 5,469 73 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and or well position objectives have been achieved. LJ Ye5 LI No I have checked to the best of ray ability that the following data is correct: LI Surface Coordinates A Declination & Convergence El GRS Survey Corrections 0 Survey-Tool Codes Vincent Logazdhrswalltqp Virctel Dszra .4thiumincTgan, oe.Scinkorberim SLB E)E, 0 sara elnail.wmarkAsliaraerk.e..1.6 Date NI t.M.Ni 171a..2A CM JakeVoss :N..r.A..V Mt,..101_,.....nik*irr..4,44.......,c4,,,,,, ,V Chent.Representative: Date: 06-Jun-2016 6/6/2016 12:49:30PM Page 7 COMPASS 5000.1 Build 74 1 „,, •0 Cement Detail Report • 2S-05 Cortrafltps Adxkro String: Surface Casing Cement Job: DRILLING ORIGINAL, 5/13/2016 15:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 5/18/2016 21:25 5/19/2016 00:00 2S-05 Comment Pump 65 bbl nut plug mud marker pill. Pump 5 bbls water.Test lines to 3500 psi. Pump 20 bbls 8.35 ppg CW-100.Pump 75 bbls 10.5 ppg MPII w/red dye at 4 bpm, 130 psi. Drop bottom plug. Pump 421 bbls of 11 ppg lead cement at 6 bpm,450 psi.At 390 bbls pumped packed off at hanger. Line up and take returns to cellar box. Pumped 57 bbls of tail 15.8 ppg cement @ 2 bpm,shut down and drop top plug. Kicked top plug out with 3 bbls of tail cement followed by 10 bbls of H2O. Displaced cement w/rig pumps @ 2-5 bpm w/175 to 100 psi pump pressure. Pump rate had to be adjusted due to Vac trucks sucking out the cellar. Slowed pumps back to 3 bpm and bumped the plug @ 2580 strokes. FCP=1000 psi. Pressured up to 1500 psi for 5 min then bled off and checked floats,good. CIP @ 2:30 am.203 bbls returns to surface Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 28.5 2,927.2 Yes 203.0 Yes Yes 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) 2 5 4 1,000.0 1,500.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cemented 10-3/4”surface casing,pumped 20 bbls 8.35 ppg CW-100, 75 bbls 10.5 ppg MPII , 421 bbls of 11 ppg lead cement and 57 bbls of tail 15.8 ppg cement. Plug bumped and floats held.203 bbls returns to surface Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 28.5 2,427.0 1,236 LiteCRETE 421.0 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 6.80 11.00 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D185 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,427.0 2,927.0 238 Class G 57.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 0.00 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 Page 1/1 Report Printed: 6/27/2016 ,, Milling Cement Detail Report 2S-05 conoccehillips i. String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 5/13/2016 15:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 5/27/2016 10:15 5/27/2016 16:00 2S-05 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 7,314.0 9,029.0 Yes Yes Yes Cement Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 5 5 259.0 800.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 5 bbls of H2O&PT lines to 600/4000 psi. Pump 40 bbls of 12.5 ppg MPII at 4 bpm,280 psi. Drop bypass plug. Pump 151 bbls of 15.8 ppg Shark slurry cement at 5 bpm,260 psi.Drop top plug. Pump 2 bbls of 15.8 ppg cement cap. Pump 10 bbls of H2O at 5 bpm,69 psi. Displace with 10.5 ppg mud at 6 bpm, 300 psi.Slow to 3 bpm, 100 psi to allow bypass plug to go past stage collar.Continue pumping at 5bpm,200 psi, PU 275K,SO 143K. Bump plug with 3902 strokes, pressuring up to 1300 psi(500 psi over FCP)for 5 min.Check floats, bled back 2 bbls then stopped.CIP 12:38 hrs. Pressure up to 3200 psi to observe stage collar open. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 7,314.0 9,029.0 730 G 151.0 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 15.80 241.6 4.75 Additives Additive Type Concentration Conc Unit label ' Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.6 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D146 0.8 %BWOC Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 5,844.0 6,464.0 Yes Yes No Cement Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 2 5 5 311.0 570.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 40 bbls of 12.5 ppg MPII at 5 bpm,200 psi.Batch up&pump 53 bbls of 15.8 ppg cement at 5 bpm,260 psi. Drop closing plug. Pump 10 bbls of H2O at 5 bpm, 100 psi. Displace with 10.5 ppg mud at 6 bpm, ICP 250 psi, FCP 750 psi. Bump plug with 2850 strokes&pressure up to 1500 psi, holding for 5 min. Observed stage collar shift closed.CIP 16:00 hrs.Bled off pressure&monitor for 15 minutes. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 5,844.0 6,464.0 256 G 53.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.'s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.10 15.80 241.6 4.75 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant 0065 0.6 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D146 0.8 %BWOC Page 1/1 Report Printed: 6/27/2016 RECeVED21 60 39 JUN162W0 2727 OGCC Transmittal#: 16JUN16-SP01 SchlumbergerDrilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery �" �201� F.t K ENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-05 Date Dispatched: 16-Jun-16 Job#: 16AKA0099 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: Tom.Osterkamp(a)conocophillips.com AlaskaPTSPrintCenter(&slb.com Tom Osterkamp Attn:Stephanie Pacillo 907-263-4795 o_ei.teat1 1 Received By: 1 ,A.,2,adze.L,</) • • 21 6039 27277 FINAL NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-05 2S-05 Definitive Survey Report 06 June, 2016 NAD 27 • • • _ Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 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 2S-05 Well Position +N/-S 0.00 usft Northing: 5,930,010.88 usfi Latitude: 70°13'11.806 N +E/-W 0.00 usft Easting: 481,191.79 usfl Longitude: 150°9'6.241 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore 2S-05 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 6/1/2016 18.00 80.85 57,537 Design 2S-05 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 27.50 0.00 0.00 15.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 127.33 718.29 2S-05 Srvy 1 -SLB_GWD70(2S-05) GYD-GC-SS Gyrodata gyro single shots 5/16/2016 9:11 776.84 2,857.78 2S-05 Srvy 2-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/16/2016 9:1: 2,938.10 8,954.93 2S-05 Srvy 3-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/21/2016 10:4 9,009.78 9,009.78 2S-05 Srvy 4-SLB_INC+Filler(2S-05) INC+TREND Inclinometer+known azi trend 5/29/2016 3:3 9,103.15 15,062.69 2S-05 Srvy 5-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/29/2016 3:3, 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) (0/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,930,010.88 481,191.79 0.00 0.00 UNDEFINED 127.33 0.94 313.77 127.33 -20.17 0.57 -0.59 5,930,011.45 481,191.20 0.94 0.39 GYD-GC-SS(1) 184.63 0.59 307.09 184.62 37.12 1.07 -1.17 5,930,011.95 481,190.63 0.63 0.73 GYD-GC-SS(1) 228.52 0.79 310.84 228.51 81.01 1.40 -1.58 5,930,012.29 481,190.22 0.47 0.95 GYD-GC-SS(1) 321.09 1.44 327.33 321.06 173.56 2.80 -2.69 5,930,013.69 481,189.11 0.78 2.01 GYD-GC-SS(1) 411.37 0.88 180.93 411.33 263.83 3.06 -3.31 5,930,013.95 481,188.49 2.47 2.10 GYD-GC-SS(1) 500.99 2.65 172.90 500.91 353.41 0.32 -3.06 5,930,011.20 481,188.73 1.99 -0.49 GYD-GC-SS(1) 583.33 2.51 173.94 583.16 435.66 -3.36 -2.64 5,930,007.52 481,189.14 0.18 -3.93 GYD-GC-SS(1) 626.53 2.32 175.81 626.32 478.82 -5.18 -2.48 5,930,005.71 481,189.30 0.48 -5.64 GYD-GC-SS(1) 718.29 6.11 164.66 717.82 570.32 -11.74 -1.05 5,929,999.14 481,190.71 4.21 -11.61 GYD-GC-SS(1) 6/6/2016 12:49:30PM Page 2 COMPASS 5000.1 Build 74 I • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 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 776.84 5.77 164.05 776.06 628.56 -17.58 0.59 5,929,993.30 481,192.33 0.59 -16.83 MWD+IFR-AK-CAZ-SC(2) 870.48 7.51 165.97 869.06 721.56 -28.04 3.36 5,929,982.83 481,195.08 1.87 -26.21 MWD+IFR-AK-CAZ-SC(2) 964.29 9.91 166.14 961.78 814.28 -41.83 6.78 5,929,969.04 481,198.47 2.56 -38.65 MWD+IFR-AK-CAZ-SC(2) 1,056.46 13.75 166.94 1,051.98 904.48 -60.20 11.16 5,929,950.65 481,202.80 4.17 -55.26 MWD+IFR-AK-CAZ-SC(2) 1,148.49 16.50 170.20 1,140.82 993.32 -83.74 15.86 5,929,927.11 481,207.44 3.13 -76.78 MWD+IFR-AK-CAZ-SC(2) 1,243.13 19.42 172.42 1,230.84 1,083.34 -112.59 20.22 5,929,898.25 481,211.73 3.17 -103.52 MW D+I FR-AK-CAZ-SC(2) 1,337.56 20.49 172.52 1,319.59 1,172.09 -144.54 24.44 5,929,866.30 481,215.87 1.13 -133.28 MW D+I FR-AK-CAZ-SC(2) 1,430.53 22.32 173.46 1,406.15 1,258.65 -178.21 28.57 5,929,832.62 481,219.92 2.00 -164.74 MWD+IFR-AK-CAZ-SC(2) 1,523.41 25.57 172.76 1,491.02 1,343.52 -215.63 33.11 5,929,795.19 481,224.36 3.51 -199.71 MW D+I FR-AK-CAZ-SC(2) 1,616.92 28.71 169.85 1,574.23 1,426.73 -257.77 39.61 5,929,753.04 481,230.76 3.64 -238.73 MWD+IFR-AK-CAZ-SC(2) 1,710.88 33.53 167.54 1,654.65 1,507.15 -305.35 49.19 5,929,705.44 481,240.22 5.28 -282.22 MWD+IFR-AK-CAZ-SC(2) 1,804.43 34.46 159.17 1,732.25 1,584.75 -355.35 64.19 5,929,655.41 481,255.09 5.10 -326.63 MWD+IFR-AK-CAZ-SC(2) 1,897.26 33.95 151.23 1,809.06 1,661.56 -402.64 86.02 5,929,608.07 481,276.79 4.84 -366.66 MWD+IFR-AK-CAZ-SC(2) 1,990.29 33.62 147.98 1,886.39 1,738.89 -447.25 112.18 5,929,563.40 481,302.84 1.97 -402.98 MWD+IFR-AK-CAZ-SC(2) 2,082.45 32.65 138.89 1,963.61 1,816.11 -487.64 142.07 5,929,522.94 481,332.63 5.49 -434.25 MWD+IFR-AK-CAZ-SC(2) 2,177.13 34.51 133.21 2,042.51 1,895.01 -525.26 178.42 5,929,485.23 481,368.88 3.85 -461.18 MW D+I FR-AK-CAZ-SC(2) 2,268.36 39.66 131.78 2,115.26 1,967.76 -562.38 219.00 5,929,448.02 481,409.36 5.72 -486.53 MWD+IFR-AK-CAZ-SC(2) 2,360.68 42.71 132.42 2,184.73 2,037.23 -603.13 264.09 5,929,407.15 481,454.35 3.34 -514.23 MWD+IFR-AK-CAZ-SC(2) 2,453.72 46.16 134.18 2,251.16 2,103.66 -647.82 311.46 5,929,362.35 481,501.61 3.94 -545.13 MWD+IFR-AK-CAZ-SC(2) 2,546.91 48.47 135.46 2,314.34 2,166.84 -696.11 360.04 5,929,313.94 481,550.06 2.68 -579.21 MW D+I FR-AK-CAZ-SC(2) 2,639.00 48.84 135.77 2,375.17 2,227.67 -745.52 408.40 5,929,264.42 481,598.29 0.47 -614.42 MWD+IFR-AK-CAZ-SC(2) 2,733.79 48.82 136.29 2,437.57 2,290.07 -796.87 457.94 5,929,212.95 481,647.69 0.41 -651.20 MWD+IFR-AK-CAZ-SC(2) 2,828.56 48.75 136.55 2,500.01 2,352.51 -848.52 507.08 5,929,161.19 481,696.70 0.22 -688.36 MWD+IFR-AK-CAZ-SC(2) 2,857.78 49.18 136.92 2,519.20 2,371.70 -864.57 522.19 5,929,145.10 481,711.77 1.75 -699.95 MWD+IFR-AK-CAZ-SC(2) 2,927.20 48.06 134.59 2,565.09 2,417.59 -901.88 558.52 5,929,107.70 481,748.00 2.99 -726.60 'NOT an Actual Survey 3) 14 3/4"x 13-1/2" 2,938.10 47.89 134.22 2,572.39 2,424.89 -907.55 564.30 5,929,102.02 481,753.77 2.99 -730.57 MWD+IFR-AK-CAZ-SC(3) 3,027.83 48.33 135.17 2,632.30 2,484.80 -954.53 611.78 5,929,054.92 481,801.13 0.93 -763.66 MWD+IFR-AK-CAZ-SC(3) 3,122.99 48.53 134.89 2,695.44 2,547.94 -1,004.90 662.10 5,929,004.44 481,851.32 0.30 -799.29 MWD+IFR-AK-CAZ-SC(3) 3,216.36 48.30 135.18 2,757.41 2,609.91 -1,054.31 711.45 5,928,954.91 481,900.54 0.34 -834.25 MW D+I FR-AK-CAZ-SC(3) 3,309.24 48.77 135.83 2,818.92 2,671.42 -1,103.96 760.23 5,928,905.14 481,949.19 0.73 -869.58 MWD+IFR-AK-CAZ-SC(3) 3,406.39 48.85 135.57 2,882.89 2,735.39 -1,156.28 811.29 5,928,852.70 482,000.12 0.22 -906.90 MWD+IFR-AK-CAZ-SC(3) 3,499.11 48.89 135.36 2,943.88 2,796.38 -1,206.06 860.27 5,928,802.80 482,048.97 0.18 -942.31 MWD+IFR-AK-CAZ-SC(3) 3,594.64 48.82 136.75 3,006.74 2,859.24 -1,257.86 910.19 5,928,750.88 482,098.75 1.10 -979.42 MWD+IFR-AK-CAZ-SC(3) 3,686.68 48.83 137.92 3,067.34 2,919.84 -1,308.80 957.14 5,928,699.83 482,145.57 0.96 -1,016.47 MWD+IFR-AK-CAZ-SC(3) 3,780.06 48.86 139.13 3,128.79 2,981.29 -1,361.47 1,003.70 5,928,647.04 482,192.00 0.98 -1,055.30 MWD+IFR-AK-CAZ-SC(3) 3,872.75 48.82 138.82 3,189.80 3,042.30 -1,414.12 1,049.51 5,928,594.29 482,237.67 0.26 -1,094.30 MWD+IFR-AK-CAZ-SC(3) 3,968.59 48.82 138.00 3,252.90 3,105.40 -1,468.07 1,097.39 5,928,540.23 482,285.41 0.64 -1,134.02 MWD+IFR-AK-CAZ-SC(3) 4,063.09 48.99 137.51 3,315.02 3,167.52 -1,520.79 1,145.27 5,928,487.39 482,333.15 0.43 -1,172.55 MWD+1FR-AK-CAZ-SC(3) 4,157.44 48.84 136.99 3,377.02 3,229.52 -1,573.01 1,193.54 5,928,435.06 482,381.29 0.44 -1,210.50 MWD+IFR-AK-CAZ-SC(3) 4,253.81 48.83 136.83 3,440.46 3,292.96 -1,625.99 1,243.10 5,928,381.96 482,430.71 0.13 -1,248.85 MWD+IFR-AK-CAZ-SC(3) 6/6/2016 12:49:30PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 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 4,346.52 48.91 136.98 3,501.44 3,353.94 -1,676.98 1,290.81 5,928,330.85 482,478.29 0.15 -1,285.75 MWD+IFR-AK-CAZ-SC(3) 4,438.77 48.76 137.23 3,562.16 3,414.66 -1,727.86 1,338.08 5,928,279.86 482,525.43 0.26 -1,322.66 MWD+I FR-AK-CAZ-SC(3) 4,531.28 48.69 137.29 3,623.19 3,475.69 -1,778.92 1,385.27 5,928,228.69 482,572.48 0.09 -1,359.77 MW D+I FR-AK-CAZ-SC(3) 4,622.32 48.67 137.83 3,683.30 3,535.80 -1,829.38 1,431.41 5,928,178.12 482,618.49 0.45 -1,396.57 MW D+I FR-AK-CAZ-SC(3) 4,715.87 48.64 138.15 3,745.09 3,597.59 -1,881.57 1,478.41 5,928,125.82 482,665.36 0.26 -1,434.81 MW D+I FR-AK-CAZ-SC(3) 4,808.83 48.75 138.60 3,806.45 3,658.95 -1,933.77 1,524.80 5,928,073.51 482,711.61 0.38 -1,473.23 MW D+I FR-AK-CAZ-SC(3) 4,900.02 48.73 138.33 3,866.59 3,719.09 -1,985.08 1,570.25 5,928,022.09 482,756.93 0.22 -1,511.03 MWD+I FR-AK-CAZ-SC(3) 4,993.01 48.88 137.38 3,927.84 3,780.34 -2,036.96 1,617.20 5,927,970.10 482,803.75 0.79 -1,548.99 MWD+I FR-AK-CAZ-SC(3) 5,083.39 48.74 137.07 3,987.36 3,839.86 -2,086.88 1,663.39 5,927,920.07 482,849.81 0.30 -1,585.26 MWD+IFR-AK-CAZ-SC(3) 5,178.67 48.20 136.87 4,050.53 3,903.03 -2,139.02 1,712.06 5,927,867.81 482,898.35 0.59 -1,623.02 MWD+IFR-AK-CAZ-SC(3) 5,272.80 48.20 135.64 4,113.27 3,965.77 -2,189.71 1,760.58 5,927,817.00 482,946.74 0.97 -1,659.43 MWD+IFR-AK-CAZ-SC(3) 5,364.75 48.31 134.73 4,174.50 4,027.00 -2,238.38 1,808.94 5,927,768.22 482,994.96 0.75 -1,693.92 MWD+IFR-AK-CAZ-SC(3) 5,455.15 48.19 134.73 4,234.69 4,087.19 -2,285.85 1,856.85 5,927,720.64 483,042.75 0.13 -1,727.37 MWD+IFR-AK-CAZ-SC(3) 5,550.87 48.42 134.31 4,298.36 4,150.86 -2,335.96 1,907.81 5,927,670.41 483,093.58 0.41 -1,762.59 MWD+IFR-AK-CAZ-SC(3) 5,643.72 48.15 134.33 4,360.15 4,212.65 -2,384.38 1,957.40 5,927,621.86 483,143.05 0.29 -1,796.53 MWD+1FR-AK-CAZ-SC(3) 5,738.55 48.23 134.40 4,423.36 4,275.86 -2,433.81 2,007.93 5,927,572.32 483,193.45 0.10 -1,831.19 MWD+1FR-AK-CAZ-SC(3) 5,830.05 48.13 134.35 4,484.38 4,336.88 -2,481.49 2,056.67 5,927,524.52 483,242.07 0.12 -1,864.63 MWD+I FR-AK-CAZ-SC(3) 5,926.59 48.29 134.00 4,548.71 4,401.21 -2,531.65 2,108.29 5,927,474.23 483,293.56 0.32 -1,899.72 MWD+IFR-AK-CAZ-SC(3) 6,018.86 45.64 130.31 4,611.69 4,464.19 -2,576.93 2,158.24 5,927,428.83 483,343.39 4.10 -1,930.53 MWD+I F R-AK-CAZ-SC(3) 6,110.09 43.36 127.63 4,676.76 4,529.26 -2,617.16 2,207.92 5,927,388.49 483,392.97 3.24 -1,956.53 MWD+I FR-AK-CAZ-SC(3) 6,202.20 42.96 123.24 4,743.96 4,596.46 -2,653.68 2,259.23 5,927,351.84 483,444.17 3.29 -1,978.53 MW D+I FR-AK-CAZ-SC(3) 6,297.34 42.78 119.28 4,813.70 4,666.20 -2,687.26 2,314.53 5,927,318.13 483,499.39 2.84 -1,996.65 MW D+I FR-AK-CAZ-SC(3) 6,392.09 42.87 115.56 4,883.21 4,735.71 -2,716.91 2,371.69 5,927,288.34 483,556.46 2.67 -2,010.49 MW D+I FR-AK-CAZ-SC(3) 6,484.85 42.93 112.23 4,951.17 4,803.67 -2,742.47 2,429.40 5,927,262.63 483,614.11 2.44 -2,020.25 MW D+I FR-AK-CAZ-SC(3) 6,577.50 42.86 110.46 5,019.04 4,871.54 -2,765.43 2,488.13 5,927,239.54 483,672.78 1.30 -2,027.22 MWD+1FR-AK-CAZ-SC(3) 6,671.65 43.46 106.99 5,087.73 4,940.23 -2,786.09 2,549.11 5,927,218.73 483,733.70 2.60 -2,031.39 MW D+I FR-AK-CAZ-SC(3) 6,764.87 44.31 102.69 5,154.93 5,007.43 -2,802.61 2,611.55 5,927,202.05 483,796.09 3.32 -2,031.19 MW D+I FR-AK-CAZ-SC(3) 6,859.39 44.50 98.05 5,222.48 5,074.98 -2,814.50 2,676.57 5,927,190.00 483,861.07 3.44 -2,025.85 MWD+IFR-AK-CAZ-SC(3) 6,951.24 44.03 92.71 5,288.28 5,140.78 -2,820.52 2,740.35 5,927,183.82 483,924.83 4.09 -2,015.16 MWD+IFR-AK-CAZ-SC(3) 7,044.08 43.50 88.11 5,355.34 5,207.84 -2,820.99 2,804.53 5,927,183.19 483,989.00 3.47 -1,999.01 MWD+IFR-AK-CAZ-SC(3) 7,137.61 43.41 83.52 5,423.25 5,275.75 -2,816.30 2,868.65 5,927,187.72 484,053.13 3.38 -1,977.88 MWD+IFR-AK-CAZ-SC(3) 7,231.09 43.88 77.70 5,490.92 5,343.42 -2,805.77 2,932.25 5,927,198.09 484,116.75 4.33 -1,951.25 MWD+IFR-AK-CAZ-SC(3) 7,323.71 44.26 74.04 5,557.48 5,409.98 -2,790.05 2,994.70 5,927,213.66 484,179.23 2.78 -1,919.89 MWD+IFR-AK-CAZ-SC(3) 7,416.14 46.22 70.37 5,622.57 5,475.07 -2,769.96 3,057.15 5,927,233.58 484,241.73 3.53 -1,884.33 MWD+IFR-AK-CAZ-SC(3) 7,508.02 48.15 65.55 5,685.03 5,537.53 -2,744.64 3,119.57 5,927,258.74 484,304.20 4.38 -1,843.72 MWD+IFR-AK-CAZ-SC(3) 7,602.13 50.06 61.54 5,746.66 5,599.16 -2,712.93 3,183.22 5,927,290.29 484,367.92 3.81 -1,796.62 MWD+IFR-AK-CAZ-SC(3) 7,694.43 51.60 57.39 5,804.97 5,657.47 -2,676.57 3,244.81 5,927,326.50 484,429.60 3.86 -1,745.55 MW D+I FR-AK-CAZ-SC(3) 7,788.55 54.02 52.38 5,861.88 5,714.38 -2,633.42 3,306.08 5,927,369.49 484,490.96 4.96 -1,688.02 MWD+IFR-AK-CAZ-SC(3) 7,883.74 55.21 46.86 5,917.03 5,769.53 -2,583.16 3,365.14 5,927,419.60 484,550.14 4.89 -1,624.18 MWD+IFR-AK-CAZ-SC(3) 7,976.43 56.45 42.50 5,969.11 5,821.61 -2,528.64 3,419.02 5,927,473.98 484,604.16 4.11 -1,557.57 MWD+IFR-AK-CAZ-SC(3) 6/6/2016 12:49:30PM Page 4 COMPASS 5000.1 Build 74 • • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 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) (°/100') (ft) Survey Tool Name 8,069.08 58.67 38.60 6,018.81 5,871.31 -2,469.22 3,469.81 5,927,533.26 484,655.09 4.28 -1,487.03 MWD+IFR-AK-CAZ-SC(3) 8,162.58 60.41 37.13 6,066.21 5,918.71 -2,405.60 3,519.27 5,927,596.76 484,704.71 2.30 -1,412.77 MWD+IFR-AK-CAZ-SC(3) 8,255.11 62.56 36.26 6,110.38 5,962.88 -2,340.40 3,567.85 5,927,661.83 484,753.44 2.47 -1,337.23 MWD+IFR-AK-CAZ-SC(3) 8,347.41 63.52 35.71 6,152.23 6,004.73 -2,273.83 3,616.18 5,927,728.27 484,801.94 1.17 -1,260.42 MWD+IFR-AK-CAZ-SC(3) 8,441.19 67.25 35.14 6,191.28 6,043.78 -2,204.37 3,665.59 5,927,797.60 484,851.51 4.02 -1,180.53 MWD+IFR-AK-CAZ-SC(3) 8,532.78 70.78 33.75 6,224.08 6,076.58 -2,133.85 3,713.94 5,927,867.99 484,900.03 4.11 -1,099.91 MWD+IFR-AK-CAZ-SC(3) 8,626.05 73.21 30.53 6,252.92 6,105.42 -2,058.75 3,761.10 5,927,942.97 484,947.38 4.19 -1,015.16 MWD+IFR-AK-CAZ-SC(3) 8,719.40 75.72 26.83 6,277.92 6,130.42 -1,979.86 3,804.24 5,928,021.74 484,990.70 4.67 -927.79 MWD+IFR-AK-CAZ-SC(3) 8,811.42 77.02 21.10 6,299.62 6,152.12 -1,898.18 3,840.53 5,928,103.33 485,027.20 6.21 -839.49 MWD+IFR-AK-CAZ-SC(3) 8,907.00 80.12 16.70 6,318.57 6,171.07 -1,809.57 3,870.85 5,928,191.85 485,057.73 5.56 -746.06 MWD+IFR-AK-CAZ-SC(3) 8,954.93 81.25 15.33 6,326.33 6,178.83 -1,764.11 3,883.90 5,928,237.27 485,070.89 3.68 -698.77 MWD+IFR-AK-CAZ-SC(3) 9,009.78 82.75 14.58 6,333.96 6,186.46 -1,711.64 3,897.91 5,928,289.71 485,085.04 3.05 -644.46 INC+TREND(4) 9,019.40 82.92 14.45 6,335.16 6,187.66 -1,702.40 3,900.30 5,928,298.94 485,087.45 2.23 -634.91 NOT an Actual Survey 5) 7.5/R"Y 9-71R-11" 9,103.15 84.43 13.34 6,344.39 6,196.89 -1,621.59 3,920.29 5,928,379.68 485,107.64 2.23 -551.69 MWD+IFR-AK-CAZ-SC(5) 9,198.02 86.80 13.34 6,351.64 6,204.14 -1,529.56 3,942.12 5,928,471.65 485,129.69 2.50 -457.15 MWD+IFR-AK-CAZ-SC(5) 9,292.14 89.51 12.97 6,354.67 6,207.17 -1,437.97 3,963.52 5,928,563.18 485,151.32 2.91 -363.13 MWD+IFR-AK-CAZ-SC(5) 9,386.99 92.19 11.86 6,353.26 6,205.76 -1,345.35 3,983.91 5,928,655.74 485,171.94 3.06 -268.40 MWD+IFR-AK-CAZ-SC(5) 9,482.45 94.16 12.36 6,347.98 6,200.48 -1,252.17 4,003.91 5,928,748.86 485,192.17 2.13 -173.21 MWD+IFR-AK-CAZ-SC(5) 9,577.25 94.08 12.63 6,341.17 6,193.67 -1,159.85 4,024.36 5,928,841.12 485,212.85 0.30 -78.75 MWD+IFR-AK-CAZ-SC(5) 9,671.27 94.15 12.31 6,334.42 6,186.92 -1,068.29 4,044.61 5,928,932.62 485,233.33 0.35 14.94 MWD+IFR-AK-CAZ-SC(5) 9,764.90 93.05 12.77 6,328.54 6,181.04 -977.07 4,064.90 5,929,023.78 485,253.84 1.27 108.29 MWD+IFR-AK-CAZ-SC(5) 9,859.15 91.57 13.40 6,324.74 6,177.24 -885.35 4,086.22 5,929,115.44 485,275.39 1.71 202.41 MWD+IFR-AK-CAZ-SC(5) 9,954.56 89.97 13.89 6,323.46 6,175.96 -792.64 4,108.73 5,929,208.08 485,298.12 1.75 297.78 MWD+IFR-AK-CAZ-SC(5) 10,048.88 91.45 13.42 6,322.29 6,174.79 -701.00 4,130.99 5,929,299.66 485,320.61 1.65 392.07 MWD+IFR-AK-CAZ-SC(5) 10,142.59 91.06 13.39 6,320.24 6,172.74 -609.86 4,152.71 5,929,390.73 485,342.55 0.42 485.72 MWD+IFR-AK-CAZ-SC(5) 10,235.80 90.25 13.36 6,319.17 6,171.67 -519.19 4,174.27 5,929,481.34 485,364.34 0.87 578.88 MWD+IFR-AK-CAZ-SC(5) 10,329.80 87.43 13.78 6,321.08 6,173.58 -427.84 4,196.32 5,929,572.63 485,386.61 3.03 672.83 MWD+IFR-AK-CAZ-SC(5) 10,425.15 87.83 15.10 6,325.02 6,177.52 -335.58 4,220.08 5,929,664.82 485,410.60 1.45 768.09 MWD+IFR-AK-CAZ-SC(5) 10,519.50 87.44 16.54 6,328.91 6,181.41 -244.89 4,245.77 5,929,755.44 485,436.52 1.58 862.34 MWD+IFR-AK-CAZ-SC(5) 10,614.16 89.57 15.95 6,331.38 6,183.88 -154.04 4,272.24 5,929,846.21 485,463.21 2.33 956.94 MWD+IFR-AK-CAZ-SC(5) 10,706.07 93.05 13.90 6,329.28 6,181.78 -65.28 4,295.91 5,929,934.91 485,487.09 4.39 1,048.81 MWD+IFR-AK-CAZ-SC(5) 10,801.34 92.62 13.47 6,324.57 6,177.07 27.18 4,318.42 5,930,027.29 485,509.83 0.64 1,143.94 MWD+IFR-AK-CAZ-SC(5) 10,896.98 90.08 13.50 6,322.32 6,174.82 120.15 4,340.71 5,930,120.20 485,532.36 2.66 1,239.51 MWD+IFR-AK-CAZ-SC(5) 10,992.81 89.69 13.26 6,322.51 6,175.01 213.37 4,362.89 5,930,213.36 485,554.76 0.48 1,335.30 MWD+IFR-AK-CAZ-SC(5) 11,087.14 90.06 13.54 6,322.71 6,175.21 305.14 4,384.75 5,930,305.06 485,576.85 0.49 1,429.60 MWD+IFR-AK-CAZ-SC(5) 11,179.92 89.99 15.04 6,322.67 6,175.17 395.04 4,407.65 5,930,394.90 485,599.97 1.62 1,522.37 MWD+IFR-AK-CAZ-SC(5) 11,275.69 89.79 15.72 6,322.86 6,175.36 487.38 4,433.05 5,930,487.17 485,625.60 0.74 1,618.13 MWD+IFR-AK-CAZ-SC(5) 11,369.67 89.03 16.82 6,323.83 6,176.33 577.59 4,459.38 5,930,577.30 485,652.15 1.42 1,712.08 MWD+IFR-AK-CAZ-SC(5) 11,464.04 89.00 17.36 6,325.45 6,177.95 667.78 4,487.10 5,930,667.41 485,680.10 0.57 1,806.38 MWD+IFR-AK-CAZ-SC(5) 11,558.57 89.62 17.13 6,326.59 6,179.09 758.05 4,515.13 5,930,757.61 485,708.34 0.70 1,900.83 MWD+IFR-AK-CAZ-SC(5) 6/6/2016 12:49:30PM Page 5 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 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) (0/100.) (ft) Survey Tool Name 11,652.44 89.72 16.31 6,327.13 6,179.63 847.95 4,542.13 5,930,847.43 485,735.57 0.88 1,994.65 MWD+IFR-AK-CAZ-SC(5) 11,746.61 89.82 15.34 6,327.50 6,180.00 938.55 4,567.81 5,930,937.95 485,761.47 1.04 2,088.81 MWD+IFR-AK-CAZ-SC(5) 11,841.21 89.72 15.27 6,327.88 6,180.38 1,029.80 4,592.78 5,931,029.13 485,786.67 0.13 2,183.41 MW D+I FR-AK-CAZ-SC(5) 11,936.02 89.12 15.59 6,328.84 6,181.34 1,121.18 4,618.01 5,931,120.44 485 812.12 0.72 W +F - 2,278.21 M D I R AK-CAZ SC(5) 12,029.65 91.09 16.71 6,328.67 6,181.17 1,211.11 4,644.05 5,931,210.30 485,838.38 2.42 2,371.81 MWD+IFR-AK-CAZ-SC(5) 12,124.46 94.11 16.35 6,324.37 6,176.87 1,301.90 4,670.99 5,931,301.01 485,865.55 3.21 2,466.48 MW D+I FR-AK-CAZ-SC(5) 12,218.48 93.60 16.58 6,318.05 6,170.55 1,391.86 4,697.58 5,931,390.89 485,892.36 0.59 2,560.26 MWD+IFR-AK-CAZ-SC(5) 12,312.22 92.64 17.68 6,312.95 6,165.45 1,481.31 4,725.15 5,931,480.26 485,920.14 1.56 2,653.79 MWD+IFR-AK-CAZ-SC(5) 12,406.15 92.16 17.30 6,309.02 6,161.52 1,570.82 4,753.35 5,931,569.69 485,948.57 0.65 2,747.55 MWD+IFR-AK-CAZ-SC(5) 12,501.16 91.02 17.06 6,306.38 6,158.88 1,661.55 4,781.41 5,931,660.35 485,976.84 1.23 2,842.45 MW D+I FR-AK-CAZ-SC(5) 12,595.09 90.23 16.47 6,305.35 6,157.85 1,751.48 4,808.50 5,931,750.20 486,004.16 1.05 2,936.33 MW D+I FR-AK-CAZ-SC(5) 12,690.77 90.58 14.85 6,304.68 6,157.18 1,843.60 4,834.32 5,931,842.25 486,030.21 1.73 3,032.00 MWD+IFR-AK-CAZ-SC(5) 12,785.05 90.78 14.55 6,303.56 6,156.06 1,934.79 4,858.25 5,931,933.37 486,054.36 0.38 3,126.27 MWD+IFR-AK-CAZ-SC(5) 12,879.58 90.68 14.63 6,302.35 6,154.85 2,026.27 4,882.06 5,932,024.77 486,078.39 0.14 3,220.79 MWD+IFR-AK-CAZ-SC(5) 12,974.80 90.75 13.79 6,301.17 6,153.67 2,118.56 4,905.43 5,932,117.00 486,101.99 0.89 3,315.99 MWD+IFR-AK-CAZ-SC(5) 13,070.05 89.99 14.31 6,300.55 6,153.05 2,210.96 4,928.55 5,932,209.33 486,125.34 0.97 3,411.23 MWD+IFR-AK-CAZ-SC(5) 13,165.27 90.23 13.80 6,300.37 6,152.87 2,303.33 4,951.67 5,932,301.64 486,148.70 0.59 3,506.43 MW D+I FR-AK-CAZ-SC(5) 13,258.35 89.98 14.06 6,300.20 6,152.70 2,393.67 4,974.08 5,932,391.91 486,171.33 0.39 3,599.50 MW D+I FR-AK-CAZ-SC(5) 13,351.13 91.17 13.66 6,299.27 6,151.77 2,483.75 4,996.31 5,932,481.92 486,193.77 1.35 3,692.25 MWD+IFR-AK-CAZ-SC(5) 13,441.41 90.75 12.96 6,297.75 6,150.25 2,571.59 5,017.09 5,932,569.70 486,214.77 0.90 3,782.48 MWD+IFR-AK-CAZ-SC(5) 13,533.55 90.82 13.19 6,296.49 6,148.99 2,661.33 5,037.93 5,932,659.38 486,235.83 0.26 3,874.56 MW D+I FR-AK-CAZ-SC(5) 13,625.59 91.64 13.55 6,294.52 6,147.02 2,750.85 5,059.21 5,932,748.84 486,257.33 0.97 3,966.54 MWD+IFR-AK-CAZ-SC(5) 13,718.74 92.88 13.76 6,290.84 6,143.34 2,841.30 5,081.18 5,932,839.23 486,279.53 1.35 4,059.59 MWD+IFR-AK-CAZ-SC(5) 13,809.28 94.25 14.09 6,285.21 6,137.71 2,929.01 5,102.93 5,932,926.87 486,301.49 1.56 4,149.94 MWD+IFR-AK-CAZ-SC(5) 13,902.16 94.18 14.96 6,278.39 6,130.89 3,018.67 5,126.16 5,933,016.47 486,324.94 0.94 4,242.56 MWD+IFR-AK-CAZ-SC(5) 13,993.83 94.01 15.34 6,271.84 6,124.34 3,106.93 5,150.05 5,933,104.66 486,349.06 0.45 4,334.00 MWD+IFR-AK-CAZ-SC(5) 14,087.12 92.84 15.80 6,266.27 6,118.77 3,196.64 5,175.05 5,933,194.29 486,374.27 1.35 4,427.11 MWD+IFR-AK-CAZSC(5) 14,181.07 87.82 15.80 6,265.73 6,118.23 3,287.01 5,200.62 5,933,284.59 486,400.07 5.34 4,521.02 MWD+IFR-AK-CAZ-SC(5) 14,270.89 88.38 15.71 6,268.70 6,121.20 3,373.40 5,225.00 5,933,370.92 486,424.66 0.63 4,610.79 MWD+IFR-AK-CAZ-SC(5) 14,361.91 89.21 15.46 6,270.62 6,123.12 3,461.06 5,249.45 5,933,458.50 486,449.32 0.95 4,701.78 MWD+IFR-AK-CAZ-SC(5) 14,454.23 89.27 14.97 6,271.84 6,124.34 3,550.13 5,273.67 5,933,547.51 486,473.77 0.53 4,794.09 MWD+IFR-AK-CAZ-SC(5) 14,546.71 88.90 13.46 6,273.32 6,125.82 3,639.77 5,296.38 5,933,637.07 486,496.69 1.68 4,886.55 MWD+IFR-AK-CAZ-SC(5) 14,638.08 89.27 13.36 6,274.78 6,127.28 3,728.63 5,317.57 5,933,725.88 486,518.10 0.42 4,977.87 MWD+IFR-AK-CAZ-SC(5) 14,730.50 89.96 14.64 6,275.40 6,127.90 3,818.30 5,339.92 5,933,815.49 486,540.68 1.57 5,070.27 MWD+IFR-AK-CAZ-SC(5) 14,820.41 90.95 14.68 6,274.69 6,127.19 3,905.28 5,362.68 5,933,902.40 486,563.65 1.10 5,160.18 MWD+IFR-AK-CAZ-SC(5) 14,912.70 91.13 15.47 6,273.01 6,125.51 3,994.38 5,386.68 5,933,991.43 486,587.87 0.88 5,252.45 MWD+I FR-AK-CAZ-SC(5) 15,003.54 90.34 15.63 6,271.85 6,124.35 4,081.89 5,411.03 5,934,078.87 486,612.43 0.89 5,343.28 MWD+1FR-AK-CAZ-SC(5) 15,062.69 90.34 15.00 6,271.49 6,123.99 4,138.94 5,426.65 5,934,135.87 486,628.19 1.07 5,402.43 MWD+IFR-AK-CAZ-SC(5) 15,112.00 90.34 15.00 6,271.20 6,123.70 4,186.57 5,439.41 5,934,183.46 486,641.07 0.00 5,451.73 NOT an Actual Sway 4 1/2"x 6-314" 6/6/2016 12:49:30PM Page 6 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 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 15,130.00 90.34 15.00 6,271.10 6,123.60 4,203.95 5,444.07 5,934,200.83 486,645.78 0.00 5,469.73 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. L Yes L No I have checked to the best of my ability that the following data is correct: O Surface Coordinates FA Declination & Convergence EJ GRS Survey Corrections Digitate,'%vet be Yircers un ▪ Survey Tool Codes Vincent Ott cn-ltircerc Odra o-Schlumbrgr., owSnlumberger, SLB DE: OSdra uca 0E06125ue-cane Jake Voss °g"n'" °b" ' Client Representative: " "4 �131116at.ilatk°"`"'°m`t""°. ah]OtGIDLOE?3�1i16.BVC Date 06-Jun-2016 6/6/2016 12:49:30PM Page 7 COMPASS 5000.1 Build 74 r 0 216039 27177 FINAL .. ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-05 2S-05 Definitive Survey Report 06 June, 2016 NAD 83 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 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 2S-05 Well Position +N/-S 0.00 usft Northing: 5,929,760.47 usfi Latitude: 70° 13'10.686 N +E/-W 0.00 usft Easting: 1,621,225.11 usfi Longitude: 150°9'17.391 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore 2S-05 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2016 6/1/2016 18.00 80.85 57,537 Design 2S-05 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 15.00 Survey Program Date 6/6/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 127.33 718.29 2S-05 Srvy 1 -SLB_GWD70(2S-05) GYD-GC-SS Gyrodata gyro single shots 5/16/2016 9:11 776.84 2,857.78 2S-05 Srvy 2-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/16/2016 9:1: 1,1 2,938.10 8,954.93 2S-05 Srvy 3-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/21/2016 10:4 9,009.78 9,009.78 2S-05 Srvy 4-SLB_INC+Filler(2S-05) INC+TREND Inclinometer+known azi trend 5/29/2016 3:3 9,103.15 15,062.69 2S-05 Srvy 5-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/29/2016 3:3. 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 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,760.47 1,621,225.11 0.00 0.00 UNDEFINED 127.33 0.94 313.77 127.33 -20.17 0.57 -0.59 5,929,761.04 1,621,224.52 0.94 0.39 GYD-GC-SS(1) 184.63 0.59 307.09 184.62 37.12 1.07 -1.17 5,929,761.54 1,621,223.94 0.63 0.73 GYD-GC-SS(1) 228.52 0.79 310.84 228.51 81.01 1.40 -1.58 5,929,761.88 1,621,223.54 0.47 0.95 GYD-GC-SS(1) 321.09 1.44 327.33 321.06 173.56 2.80 -2.69 5,929,763.28 1,621,222.43 0.78 2.01 GYD-GC-SS(1) 411.37 0.88 180.93 411.33 263.83 3.06 -3.31 5,929,763.54 1,621,221.81 2.47 2.10 GYD-GC-SS(1) 500.99 2.65 172.90 500.91 353.41 0.32 -3.06 5,929,760.79 1,621,222.04 1.99 -0.49 GYD-GC-SS(1) 583.33 2.51 173.94 583.16 435.66 -3.36 -2.64 5,929,757.11 1,621,222.46 0.18 -3.93 GYD-GC-SS(1) 626.53 2.32 175.81 626.32 478.82 -5.18 -2.48 5,929,755.30 1,621,222.62 0.48 -5.64 GYD-GC-SS(1) 718.29 6.11 164.66 717.82 570.32 -11.74 -1.05 5,929,748.73 1,621,224.03 4.21 -11.61 GYD-GC-SS(1) 6/6/2016 11:21:35AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 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) (°/100') (ft) Survey Tool Name 776.84 5.77 164.05 776.06 628.56 -17.58 0.59 5,929,742.89 1,621,225.65 0.59 -16.83 MWD+IFR-AK-CAZ-SC(2) 870.48 7.51 165.97 869.06 721.56 -28.04 3.36 5,929,732.42 1,621,228.40 1.87 -26.21 MWD+IFR-AK-CAZ-SC(2) 964.29 9.91 166.14 961.78 814.28 -41.83 6.78 5,929,718.63 1,621,231.78 2.56 -38.65 MWD+IFR-AK-CAZ-SC(2) 1,056.46 13.75 166.94 1,051.98 904.48 -60.20 11.16 5,929,700.24 1,621,236.11 4.17 -55.26 MWD+IFR-AK-CAZ-SC(2) 1,148.49 16.50 170.20 1,140.82 993.32 -83.74 15.86 5,929,676.70 1,621,240.75 3.13 -76.78 MWD+IFR-AK-CAZ-SC(2) 1,243.13 19.42 172.42 1,230.84 1,083.34 -112.59 20.22 5,929,647.84 1,621,245.04 3.17 -103.52 MWD+IFR-AK-CAZ-SC(2) 1,337.56 20.49 172.52 1,319.59 1,172.09 -144.54 24.44 5,929,615.89 1,621,249.18 1.13 -133.28 MWD+IFR-AK-CAZ-SC(2) 1,430.53 22.32 173.46 1,406.15 1,258.65 -178.21 28.57 5,929,582.20 1,621,253.23 2.00 -164.74 MWD+IFR-AK-CAZ-SC(2) 1,523.41 25.57 172.76 1,491.02 1,343.52 -215.63 33.11 5,929,544.78 1,621,257.67 3.51 -199.71 MWD+IFR-AK-CAZ-SC(2) 1,616.92 28.71 169.85 1,574.23 1,426.73 -257.77 39.61 5,929,502.63 1,621,264.06 3.64 -238.73 MWD+IFR-AK-CAZ-SC(2) 1,710.88 33.53 167.54 1,654.65 1,507.15 -305.35 49.19 5,929,455.02 1,621,273.52 5.28 -282.22 MWD+IFR-AK-CAZ-SC(2) 1,804.43 34.46 159.17 1,732.25 1,584.75 -355.35 64.19 5,929,405.00 1,621,288.39 5.10 -326.63 MWD+IFR-AK-CAZ-SC(2) 1,897.26 33.95 151.23 1,809.06 1,661.56 -402.64 86.02 5,929,357.65 1,621,310.09 4.84 -366.66 MWD+IFR-AK-CAZ-SC(2) 1,990.29 33.62 147.98 1,886.39 1,738.89 -447.25 112.18 5,929,312.98 1,621,336.13 1.97 -402.98 MWD+IFR-AK-CAZ-SC(2) 2,082.45 32.65 138.89 1,963.61 1,816.11 -487.64 142.07 5,929,272.52 1,621,365.92 5.49 -434.25 MWD+IFR-AK-CAZ-SC(2) 2,177.13 34.51 133.21 2,042.51 1,895.01 -525.26 178.42 5,929,234.81 1,621,402.18 3.85 -461.18 MWD+IFR-AK-CAZ-SC(2) 2,268.36 39.66 131.78 2,115.26 1,967.76 -562.38 219.00 5,929,197.59 1,621,442.65 5.72 -486.53 MWD+IFR-AK-CAZ-SC(2) 2,360.68 42.71 132.42 2,184.73 2,037.23 -603.13 264.09 5,929,156.73 1,621,487.64 3.34 -514.23 MWD+IFR-AK-CAZ-SC(2) 2,453.72 46.16 134.18 2,251.16 2,103.66 -647.82 311.46 5,929,111.92 1,621,534.89 3.94 -545.13 MWD+IFR-AK-CAZ-SC(2) 2,546.91 48.47 135.46 2,314.34 2,166.84 -696.11 360.04 5,929,063.51 1,621,583.34 2.68 -579.21 MWD+IFR-AK-CAZ-SC(2) 2,639.00 48.84 135.77 2,375.17 2,227.67 -745.52 408.40 5,929,013.99 1,621,631.57 0.47 -614.42 MWD+IFR-AK-CAZ-SC(2) 2,733.79 48.82 136.29 2,437.57 2,290.07 -796.87 457.94 5,928,962.51 1,621,680.97 0.41 -651.20 MWD+IFR-AK-CAZ-SC(2) 2,828.56 48.75 136.55 2,500.01 2,352.51 -848.52 507.08 5,928,910.75 1,621,729.98 0.22 -688.36 MWD+IFR-AK-CAZ-SC(2) 2,857.78 49.18 136.92 2,519.20 2,371.70 -864.57 522.19 5,928,894.66 1,621,745.04 1.75 -699.95 MWD+IFR-AK-CAZ-SC(2) 2,927.20 48.06 134.59 2,565.09 2,417.59 -901.88 558.52 5,928,857.26 1,621,781.28 2.99 -726.60 NOT an Actual Survey) 10 3/4"x 13-1/2" 2,938.10 47.89 134.22 2,572.39 2,424.89 -907.55 564.30 5,928,851.58 1,621,787.05 2.99 -730.57 MWD+IFR-AK-CAZ-SC(3) 3,027.83 48.33 135.17 2,632.30 2,484.80 -954.53 611.78 5,928,804.48 1,621,834.40 0.93 -763.66 MWD+IFR-AK-CAZ-SC(3) 3,122.99 48.53 134.89 2,695.44 2,547.94 -1,004.90 662.10 5,928,753.99 1,621,884.58 0.30 -799.29 MWD+IFR-AK-CAZ-SC(3) 3,216.36 48.30 135.18 2,757.41 2,609.91 -1,054.31 711.45 5,928,704.46 1,621,933.81 0.34 -834.25 MWD+IFR-AK-CAZ-SC(3) 3,309.24 48.77 135.83 2,818.92 2,671.42 -1,103.96 760.23 5,928,654.69 1,621,982.45 0.73 -869.58 MWD+IFR-AK-CAZ-SC(3) 3,406.39 48.85 135.57 2,882.89 2,735.39 -1,156.28 811.29 5,928,602.25 1,622,033.37 0.22 -906.90 MWD+IFR-AK-CAZ-SC(3) 3,499.11 48.89 135.36 2,943.88 2,796.38 -1,206.06 860.27 5,928,552.34 1,622,082.22 0.18 -942.31 MWD+IFR-AK-CAZ-SC(3) 3,594.64 48.82 136.75 3,006.74 2,859.24 -1,257.86 910.19 5,928,500.43 1,622,132.01 1.10 -979.42 MWD+IFR-AK-CAZ-SC(3) 3,686.68 48.83 137.92 3,067.34 2,919.84 -1,308.80 957.14 5,928,449.37 1,622,178.82 0.96 -1,016.47 MWD+IFR-AK-CAZ-SC(3) 3,780.06 48.86 139.13 3,128.79 2,981.29 -1,361.47 1,003.70 5,928,396.58 1,622,225.25 0.98 -1,055.30 MWD+IFR-AK-CAZ-SC(3) 3,872.75 48.82 138.82 3,189.80 3,042.30 -1,414.12 1,049.51 5,928,343.83 1,622,270.91 0.26 -1,094.30 MW D+I FR-AK-CAZ-SC(3) 3,968.59 48.82 138.00 3,252.90 3,105.40 -1,468.07 1,097.39 5,928,289.76 1,622,318.65 0.64 -1,134.02 MWD+IFR-AK-CAZ-SC(3) 4,063.09 48.99 137.51 3,315.02 3,167.52 -1,520.79 1,145.27 5,928,236.92 1,622,366.39 0.43 -1,172.55 MWD+1FR-AK-CAZ-SC(3) 4,157.44 48.84 136.99 3,377.02 3,229.52 -1,573.01 1,193.54 5,928,184.59 1,622,414.53 0.44 -1,210.50 MWD+IFR-AK-CAZ-SC(3) 4,253.81 48.83 136.83 3,440.46 3,292.96 -1,625.99 1,243.10 5,928,131.48 1,622,463.95 0.13 -1,248.85 MWD+IFR-AK-CAZ-SC(3) 6/6/2016 11:21:35AM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 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 4,346.52 48.91 136.98 3,501.44 3,353.94 -1,676.98 1,290.81 5,928,080.38 1,622,511.52 0.15 -1,285.75 MWD+IFR-AK-CAZ-SC(3) 4,438.77 48.76 137.23 3,562.16 3,414.66 -1,727.86 1,338.08 5,928,029.38 1,622,558.66 0.26 -1,322.66 MWD+1FR-AK-CAZ-SC(3) 4,531.28 48.69 137.29 3,623.19 3,475.69 -1,778.92 1,385.27 5,927,978.21 1,622,605.71 0.09 -1,359.77 MWD+IFR-AK-CAZ-SC(3) 4,622.32 48.67 137.83 3,683.30 3,535.80 -1,829.38 1,431.41 5,927,927.64 1,622,651.72 0.45 -1,396.57 MWD+IFR-AK-CAZ-SC(3) 4,715.87 48.64 138.15 3,745.09 3,597.59 -1,881.57 1,478.41 5,927,875.34 1,622,698.58 0.26 -1,434.81 MWD+IFR-AK-CAZ-SC(3) 4,808.83 48.75 138.60 3,806.45 3,658.95 -1,933.77 1,524.80 5,927,823.02 1,622,744.83 0.38 -1,473.23 MWD+IFR-AK-CAZ-SC(3) 4,900.02 48.73 138.33 3,866.59 3,719.09 -1,985.08 1,570.25 5,927,771.60 1,622,790.15 0.22 -1,511.03 MWD+IFR-AK-CAZ-SC(3) 4,993.01 48.88 137.38 3,927.84 3,780.34 -2,036.96 1,617.20 5,927,719.61 1,622,836.97 0.79 -1,548.99 MWD+IFR-AK-CAZ-SC(3) 5,083.39 48.74 137.07 3,987.36 3,839.86 -2,086.88 1,663.39 5,927,669.57 1,622,883.02 0.30 -1,585.26 MWD+1FR-AK-CAZ-SC(3) 5,178.67 48.20 136.87 4,050.53 3,903.03 -2,139.02 1,712.06 5,927,617.31 1,622,931.56 0.59 -1,623.02 MW D+I FR-AK-CAZ-SC(3) 5,272.80 48.20 135.64 4,113.27 3,965.77 -2,189.71 1,760.58 5,927,566.50 1,622,979.94 0.97 -1,659.43 MWD+IFR-AK-CAZ-SC(3) 5,364.75 48.31 134.73 4,174.50 4,027.00 -2,238.38 1,808.94 5,927,517.72 1,623,028.17 0.75 -1,693.92 MW D+I FR-AK-CAZ-SC(3) 5,455.15 48.19 134.73 4,234.69 4,087.19 -2,285.85 1,856.85 5,927,470.14 1,623,075.96 0.13 -1,727.37 MWD+1FR-AK-CAZ-SC(3) 5,550.87 48.42 134.31 4,298.36 4,150.86 -2,335.96 1,907.81 5,927,419.90 1,623,126.78 0.41 -1,762.59 MWD+IFR-AK-CAZ-SC(3) 5,643.72 48.15 134.33 4,360.15 4,212.65 -2,384.38 1,957.40 5,927,371.35 1,623,176.24 0.29 -1,796.53 MW D+I FR-AK-CAZ-SC(3) 5,738.55 48.23 134.40 4,423.36 4,275.86 -2,433.81 2,007.93 5,927,321.81 1,623,226.64 0.10 -1,831.19 MW D+I FR-AK-CAZ-SC(3) 5,830.05 48.13 134.35 4,484.38 4,336.88 -2,481.49 2,056.67 5,927,274.00 1,623,275.26 0.12 -1,864.63 MWD+IFR-AK-CAZ-SC(3) 5,926.59 48.29 134.00 4,548.71 4,401.21 -2,531.65 2,108.29 5,927,223.72 1,623,326.75 0.32 -1,899.72 MW D+I FR-AK-CAZ-SC(3) 6,018.86 45.64 130.31 4,611.69 4,464.19 -2,576.93 2,158.24 5,927,178.31 1,623,376.57 4.10 -1,930.53 MWD+IFR-AK-CAZ-SC(3) 6,110.09 43.36 127.63 4,676.76 4,529.26 -2,617.16 2,207.92 5,927,137.96 1,623,426.15 3.24 -1,956.53 MW D+I FR-AK-CAZ-SC(3) 6,202.20 42.96 123.24 4,743.96 4,596.46 -2,653.68 2,259.23 5,927,101.32 1,623,477.36 3.29 -1,978.53 MWD+1FR-AK-CAZ-SC(3) 6,297.34 42.78 119.28 4,813.70 4,666.20 -2,687.26 2,314.53 5,927,067.60 1,623,532.57 2.84 -1,996.65 MWD+1FR-AK-CAZ-SC(3) 6,392.09 42.87 115.56 4,883.21 4,735.71 -2,716.91 2,371.69 5,927,037.81 1,623,589.64 2.67 -2,010.49 MWD+IFR-AK-CAZ-SC(3) 6,484.85 42.93 112.23 4,951.17 4,803.67 -2,742.47 2,429.40 5,927,012.10 1,623,647.29 2.44 -2,020.25 MWD+IFR-AK-CAZ-SC(3) 6,577.50 42.86 110.46 5,019.04 4,871.54 -2,765.43 2,488.13 5,926,989.00 1,623,705.95 1.30 -2,027.22 MWD+IFR-AK-CAZ-SC(3) 6,671.65 43.46 106.99 5,087.73 4,940.23 -2,786.09 2,549.11 5,926,968.19 1,623,766.87 2.60 -2,031.39 MWD+IFR-AK-CAZ-SC(3) 6,764.87 44.31 102.69 5,154.93 5,007.43 -2,802.61 2,611.55 5,926,951.51 1,623,829.26 3.32 -2,031.19 MWD+IFR-AK-CAZ-SC(3) 6,859.39 44.50 98.05 5,222.48 5,074.98 -2,814.50 2,676.57 5,926,939.45 1,623,894.25 3.44 -2,025.85 MWD+IFR-AK-CAZ-SC(3) 6,951.24 44.03 92.71 5,288.28 5,140.78 -2,820.52 2,740.35 5,926,933.27 1,623,958.01 4.09 -2,015.16 MWD+IFR-AK-CAZ-SC(3) 7,044.08 43.50 88.11 5,355.34 5,207.84 -2,820.99 2,804.53 5,926,932.63 1,624,022.18 3.47 -1,999.01 MWD+IFR-AK-CAZ-SC(3) 7,137.61 43.41 83.52 5,423.25 5,275.75 -2,816.30 2,868.65 5,926,937.16 1,624,086.31 3.38 -1,977.88 MWD+IFR-AK-CAZ-SC(3) 7,231.09 43.88 77.70 5,490.92 5,343.42 -2,805.77 2,932.25 5,926,947.53 1,624,149.92 4.33 -1,951.25 MWD+IFR-AK-CAZ-SC(3) 7,323.71 44.26 74.04 5,557.48 5,409.98 -2,790.05 2,994.70 5,926,963.10 1,624,212.40 2.78 -1,919.89 MWD+IFR-AK-CAZ-SC(3) • 7,416.14 46.22 70.37 5,622.57 5,475.07 -2,769.96 3,057.15 5,926,983.02 1,624,274.90 3.53 -1,884.33 MWD+IFR-AK-CAZ-SC(3) 7,508.02 48.15 65.55 5,685.03 5,537.53 -2,744.64 3,119.57 5,927,008.17 1,624,337.38 4.38 -1,843.72 MWD+IFR-AK-CAZ-SC(3) 7,602.13 50.06 61.54 5,746.66 5,599.16 -2,712.93 3,183.22 5,927,039.72 1,624,401.10 3.81 -1,796.62 MWD+I FR-AK-CAZ-SC(3) 7,694.43 51.60 57.39 5,804.97 5,657.47 -2,676.57 3,244.81 5,927,075.92 1,624,462.78 3.86 -1,745.55 MWD+IFR-AK-CAZ-SC(3) 7,788.55 54.02 52.38 5,861.88 5,714.38 -2,633.42 3,306.08 5,927,118.91 1,624,524.15 4.96 -1,688.02 MWD+IFR-AK-CAZ-SC(3) 7,883.74 55.21 46.86 5,917.03 5,769.53 -2,583.16 3,365.14 5,927,169.02 1,624,583.33 4.89 -1,624.18 MWD+1FR-AK-CAZ-SC(3) 7,976.43 56.45 42.50 5,969.11 5,821.61 -2,528.64 3,419.02 5,927,223.40 1,624,637.35 4.11 -1,557.57 MWD+IFR-AK-CAZ-SC(3) 6/6/2016 11:21:35AM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 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 8,069.08 58.67 38.60 6,018.81 5,871.31 -2,469.22 3,469.81 5,927,282.68 1,624,688.29 4.28 -1,487.03 MWD+IFR-AK-CAZ-SC(3) 8,162.58 60.41 37.13 6,066.21 5,918.71 -2,405.60 3,519.27 5,927,346.17 1,624,737.90 2.30 -1,412.77 MWD+IFR-AK-CAZ-SC(3) 8,255.11 62.56 36.26 6,110.38 5,962.88 -2,340.40 3,567.85 5,927,411.23 1,624,786.64 2.47 -1,337.23 MWD+IFR-AK-CAZ-SC(3) 8,347.41 63.52 35.71 6,152.23 6,004.73 -2,273.83 3,616.18 5,927,477.67 1,624,835.14 1.17 -1,260.42 MWD+IFR-AK-CAZ-SC(3) 8,441.19 67.25 35.14 6,191.28 6,043.78 -2,204.37 3,665.59 5,927,547.01 1,624,884.72 4.02 -1,180.53 MWD+IFR-AK-CAZ-SC(3) 8,532.78 70.78 33.75 6,224.08 6,076.58 -2,133.85 3,713.94 5,927,617.39 1,624,933.24 4.11 -1,099.91 MWD+IFR-AK-CAZ-SC(3) 8,626.05 73.21 30.53 6,252.92 6,105.42 -2,058.75 3,761.10 5,927,692.36 1,624,980.59 4.19 -1,015.16 MWD+IFR-AK-CAZ-SC(3) 8,719.40 75.72 26.83 6,277.92 6,130.42 -1,979.86 3,804.24 5,927,771.14 1,625,023.92 4.67 -927.79 MWD+IFR-AK-CAZ-SC(3) 8,811.42 77.02 21.10 6,299.62 6,152.12 -1,898.18 3,840.53 5,927,852.72 1,625,060.42 6.21 -839.49 MWD+IFR-AK-CAZ-SC(3) 8,907.00 80.12 16.70 6,318.57 6,171.07 -1,809.57 3,870.85 5,927,941.24 1,625,090.96 5.56 -746.06 MWD+IFR-AK-CAZ-SC(3) 8,954.93 81.25 15.33 6,326.33 6,178.83 -1,764.11 3,883.90 5,927,986.67 1,625,104.12 3.68 -698.77 MWD+IFR-AK-CAZ-SC(3) 9,009.78 82.75 14.58 6,333.96 6,186.46 -1,711.64 3,897.91 5,928,039.10 1,625,118.27 3.05 -644.46 INC+TREND(4) 9,019.40 82.92 14.45 6,335.16 6,187.66 -1,702.40 3,900.30 5,928,048.33 1,625,120.68 2.23 -634.91 r NOT an Actual Survey 7-5/8"x 9-7/8-11" 9,103.15 84.43 13.34 6,344.39 6,196.89 -1,621.59 3,920.29 5,928,129.07 1,625,140.88 2.23 -551.69 MWD+IFR-AK-CAZ-SC(5) 9,198.02 86.80 13.34 6,351.64 6,204.14 -1,529.56 3,942.12 5,928,221.04 1,625,162.93 2.50 -457.15 MWD+IFR-AK-CAZ-SC(5) 9,292.14 89.51 12.97 6,354.67 6,207.17 -1,437.97 3,963.52 5,928,312.57 1,625,184.57 2.91 -363.13 MWD+IFR-AK-CAZ-SC(5) 9,386.99 92.19 11.86 6,353.26 6,205.76 -1,345.35 3,983.91 5,928,405.12 1,625,205.19 3.06 -268.40 MWD+IFR-AK-CAZ-SC(5) 9,482.45 94.16 12.36 6,347.98 6,200.48 -1,252.17 4,003.91 5,928,498.25 1,625,225.42 2.13 -173.21 MWD+IFR-AK-CAZ-SC(5) 9,577.25 94.08 12.63 6,341.17 6,193.67 -1,159.85 4,024.36 5,928,590.50 1,625,246.11 0.30 -78.75 MWD+IFR-AK-CAZ-SC(5) 9,671.27 94.15 12.31 6,334.42 6,186.92 -1,068.29 4,044.61 5,928,682.01 1,625,266.59 0.35 14.94 MWD+IFR-AK-CAZ-SC(5) 9,764.90 93.05 12.77 6,328.54 6,181.04 -977.07 4,064.90 5,928,773.16 1,625,287.11 1.27 108.29 MWD+IFR-AK-CAZ-SC(5) 9,859.15 91.57 13.40 6,324.74 6,177.24 -885.35 4,086.22 5,928,864.82 1,625,308.66 1.71 202.41 MWD+IFR-AK-CAZ-SC(5) 9,954.56 89.97 13.89 6,323.46 6,175.96 -792.64 4,108.73 5,928,957.46 1,625,331.40 1.75 297.78 MWD+IFR-AK-CAZ-SC(5) 10,048.88 91.45 13.42 6,322.29 6,174.79 -701.00 4,130.99 5,929,049.04 1,625,353.89 1.65 392.07 MWD+IFR-AK-CAZ-SC(5) 10,142.59 91.06 13.39 6,320.24 6,172.74 -609.86 4,152.71 5,929,140.11 1,625,375.84 0.42 485.72 MWD+IFR-AK-CAZ-SC(5) 10,235.80 90.25 13.36 6,319.17 6,171.67 -519.19 4,174.27 5,929,230.72 1,625,397.63 0.87 578.88 MWD+IFR-AK-CAZ-SC(5) 10,329.80 87.43 13.78 6,321.08 6,173.58 -427.84 4,196.32 5,929,322.00 1,625,419.91 3.03 672.83 MWD+IFR-AK-CAZ-SC(5) 10,425.15 87.83 15.10 6,325.02 6,177.52 -335.58 4,220.08 5,929,414.19 1,625,443.90 1.45 768.09 MWD+IFR-AK-CAZ-SC(5) 10,519.50 87.44 16.54 6,328.91 6,181.41 -244.89 4,245.77 5,929,504.81 1,625,469.82 1.58 862.34 MWD+IFR-AK-CAZ-SC(5) 10,614.16 89.57 15.95 6,331.38 6,183.88 -154.04 4,272.24 5,929,595.58 1,625,496.52 2.33 956.94 MWD+IFR-AK-CAZ-SC(5) 10,706.07 93.05 13.90 6,329.28 6,181.78 -65.28 4,295.91 5,929,684.28 1,625,520.41 4.39 1,048.81 MWD+IFR-AK-CAZ-SC(5) 10,801.34 92.62 13.47 6,324.57 6,177.07 27.18 4,318.42 5,929,776.66 1,625,543.15 0.64 1,143.94 MWD+IFR-AK-CAZ-SC(5) 10,896.98 90.08 13.50 6,322.32 6,174.82 120.15 4,340.71 5,929,869.57 1,625,565.68 2.66 1,239.51 MWD+IFR-AK-CAZ-SC(5) 10,992.81 89.69 13.26 6,322.51 6,175.01 213.37 4,362.89 5,929,962.73 1,625,588.09 0.48 1,335.30 MWD+IFR-AK-CAZ-SC(5) 11,087.14 90.06 13.54 6,322.71 6,175.21 305.14 4,384.75 5,930,054.43 1,625,610.18 0.49 1,429.60 MWD+IFR-AK-CAZ-SC(5) 11,179.92 89.99 15.04 6,322.67 6,175.17 395.04 4,407.65 5,930,144.26 1,625,633.31 1.62 1,522.37 MWD+IFR-AK-CAZ-SC(5) 11,275.69 89.79 15.72 6,322.86 6,175.36 487.38 4,433.05 5,930,236.53 1,625,658.94 0.74 1,618.13 MWD+IFR-AK-CAZ-SC(5) 11,369.67 89.03 16.82 6,323.83 6,176.33 577.59 4,459.38 5,930,326.66 1,625,685.49 1.42 1,712.08 MWD+IFR-AK-CAZ-SC(5) 11,464.04 89.00 17.36 6,325.45 6,177.95 667.78 4,487.10 5,930,416.77 1,625,713.45 0.57 1,806.38 MWD+IFR-AK-CAZ-SC(5) 11,558.57 89.62 17.13 6,326.59 6,179.09 758.05 4,515.13 5,930,506.97 1,625,741.70 0.70 1,900.83 MWD+IFR-AK-CAZ-SC(5) 6/6/2016 11:21:35AM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(D141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 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) (°l100') (ft) Survey Tool Name 11,652.44 89.72 16.31 6,327.13 6,179.63 847.95 4,542.13 5,930,596.79 1,625,768.93 0.88 1,994.65 MWD+IFR-AK-CAZ-SC(5) 11,746.61 89.82 15.34 6,327.50 6,180.00 938.55 4,567.81 5,930,687.31 1,625,794.84 1.04 2,088.81 MWD+IFR-AK-CAZ-SC(5) 11,841.21 89.72 15.27 6,327.88 6,180.38 1,029.80 4,592.78 5,930,778.48 1,625,820.04 0.13 2,183.41 MWD+IFR-AK-CAZ-SC(5) 11,936.02 89.12 15.59 6,328.84 6,181.34 1,121.18 4,618.01 5,930,869.80 1,625,845.49 0.72 2,278.21 MWD+IFR-AK-CAZ-SC(5) 12,029.65 91.09 16.71 6,328.67 6,181.17 1,211.11 4,644.05 5,930,959.65 1,625,871.76 2.42 2,371.81 MWD+IFR-AK-CAZ-SC(5) 12,124.46 94.11 16.35 6,324.37 6,176.87 1,301.90 4,670.99 5,931,050.36 1,625,898.93 3.21 2,466.48 MWD+IFR-AK-CAZ-SC(5) 12,218.48 93.60 16.58 6,318.05 6,170.55 1,391.86 4,697.58 5,931,140.24 1,625,925.74 0.59 2,560.26 MWD+IFR-AK-CAZ-SC(5) 12,312.22 92.64 17.68 6,312.95 6,165.45 1,481.31 4,725.15 5,931,229.61 1,625,953.54 1.56 2,653.79 MWD+IFR-AK-CAZ-SC(5) 12,406.15 92.16 17.30 6,309.02 6,161.52 1,570.82 4,753.35 5,931,319.04 1,625,981.97 0.65 2,747.55 MWD+IFR-AK-CAZ-SC(5) 12,501.16 91.02 17.06 6,306.38 6,158.88 1,661.55 4,781.41 5,931,409.69 1,626,010.25 1.23 2,842.45 MWD+IFR-AK-CAZ-SC(5) 12,595.09 90.23 16.47 6,305.35 6,157.85 1,751.48 4,808.50 5,931,499.54 1,626,037.56 1.05 2,936.33 MWD+IFR-AK-CAZ-SC(5) 12,690.77 90.58 14.85 6,304.68 6,157.18 1,843.60 4,834.32 5,931,591.59 1,626,063.62 1.73 3,032.00 MWD+IFR-AK-CAZ-SC(5) 12,785.05 90.78 14.55 6,303.56 6,156.06 1,934.79 4,858.25 5,931,682.71 1,626,087.77 0.38 3,126.27 MWD+IFR-AK-CAZ-SC(5) 12,879.58 90.68 14.63 6,302.35 6,154.85 2,026.27 4,882.06 5,931,774.11 1,626,111.81 0.14 3,220.79 MWD+IFR-AK-CAZ-SC(5) 12,974.80 90.75 13.79 6,301.17 6,153.67 2,118.56 4,905.43 5,931,866.34 1,626,135.42 0.89 3,315.99 MWD+IFR-AK-CAZ-SC(5) 13,070.05 89.99 14.31 6,300.55 6,153.05 2,210.96 4,928.55 5,931,958.67 1,626,158.77 0.97 3,411.23 MWD+IFR-AK-CAZ-SC(5) 13,165.27 90.23 13.80 6,300.37 6,152.87 2,303.33 4,951.67 5,932,050.97 1,626,182.13 0.59 3,506.43 MWD+IFR-AK-CAZ-SC(5) 13,258.35 89.98 14.06 6,300.20 6,152.70 2,393.67 4,974.08 5,932,141.25 1,626,204.77 0.39 3,599.50 MWD+IFR-AK-CAZ-SC(5) 13,351.13 91.17 13.66 6,299.27 6,151.77 2,483.75 4,996.31 5,932,231.26 1,626,227.22 1.35 3,692.25 MWD+IFR-AK-CAZ-SC(5) 13,441.41 90.75 12.96 6,297.75 6,150.25 2,571.59 5,017.09 5,932,319.04 1,626,248.22 0.90 3,782.48 MWD+IFR-AK-CAZ-SC(5) 13,533.55 90.82 13.19 6,296.49 6,148.99 2,661.33 5,037.93 5,932,408.72 1,626,269.29 0.26 3,874.56 MWD+IFR-AK-CAZ-SC(5) 13,625.59 91.64 13.55 6,294.52 6,147.02 2,750.85 5,059.21 5,932,498.18 1,626,290.79 0.97 3,966.54 MWD+IFR-AK-CAZ-SC(5) 13,718.74 92.88 13.76 6,290.84 6,143.34 2,841.30 5,081.18 5,932,588.56 1,626,312.99 1.35 4,059.59 MWD+IFR-AK-CAZ-SC(5) 13,809.28 94.25 14.09 6,285.21 6,137.71 2,929.01 5,102.93 5,932,676.20 1,626,334.96 1.56 4,149.94 MWD+IFR-AK-CAZ-SC(5) 13,902.16 94.18 14.96 6,278.39 6,130.89 3,018.67 5,126.16 5,932,765.80 1,626,358.41 0.94 4,242.56 MWD+IFR-AK-CAZ-SC(5) 13,993.83 94.01 15.34 6,271.84 6,124.34 3,106.93 5,150.05 5,932,853.99 1,626,382.53 0.45 4,334.00 MWD+IFR-AK-CAZ-SC(5) 14,087.12 92.84 15.80 6,266.27 6,118.77 3,196.64 5,175.05 5,932,943.62 1,626,407.75 1.35 4,427.11 MWD+IFR-AK-CAZ-SC(5) 14,181.07 87.82 15.80 6,265.73 6,118.23 3,287.01 5,200.62 5,933,033.91 1,626,433.55 5.34 4,521.02 MWD+IFR-AK-CAZ-SC(5) 14,270.89 88.38 15.71 6,268.70 6,121.20 3,373.40 5,225.00 5,933,120.24 1,626,458.15 0.63 4,610.79 MWD+IFR-AK-CAZ-SC(5) 14,361.91 89.21 15.46 6,270.62 6,123.12 3,461.06 5,249.45 5,933,207.82 1,626,482.81 0.95 4,701.78 MWD+IFR-AK-CAZ-SC(5) 14,454.23 89.27 14.97 6,271.84 6,124.34 3,550.13 5,273.67 5,933,296.83 1,626,507.26 0.53 4,794.09 MWD+IFR-AK-CAZ-SC(5) 14,546.71 88.90 13.46 6,273.32 6,125.82 3,639.77 5,296.38 5,933,386.39 1,626,530.20 1.68 4,886.55 MWD+IFR-AK-CAZ-SC(5) 14,638.08 89.27 13.36 6,274.78 6,127.28 3,728.63 5,317.57 5,933,475.20 1,626,551.61 0.42 4,977.87 MWD+IFR-AK-CAZ-SC(5) 14,730.50 89.96 14.64 6,275.40 6,127.90 3,818.30 5,339.92 5,933,564.80 1,626,574.19 1.57 5,070.27 MWD+IFR-AK-CAZ-SC(5) 14,820.41 90.95 14.68 6,274.69 6,127.19 3,905.28 5,362.68 5,933,651.72 1,626,597.16 1.10 5,160.18 MWD+IFR-AK-CAZ-SC(5) 14,912.70 91.13 15.47 6,273.01 6,125.51 3,994.38 5,386.68 5,933,740.74 1,626,621.39 0.88 5,252.45 MWD+IFR-AK-CAZ-SC(5) 15,003.54 90.34 15.63 6,271.85 6,124.35 4,081.89 5,411.03 5,933,828.18 1,626,645.96 0.89 5,343.28 MWD+IFR-AK-CAZ-SC(5) 15,062.69 90.34 15.00 6,271.49 6,123.99 4,138.94 5,426.65 5,933,885.18 1,626,661.72 1.07 5,402.43 MWD+IFR-AK-CAZ-SC(5) 15,112.00 90.34 15.00 6,271.20 6,123.70 4,186.57 5,439.41 5,933,932.77 1,626,674.60 0.00 5,451.73 NOT an Actual Survey 4 1/2"x 6-3/4" 6/6/2016 11:21:35AM Page 6 COMPASS 5000.1 Build 74 i r Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-05 Project: Kuparuk River Unit TVD Reference: 2S-05 actual @ 147.50usft(D141) Site: Kuparuk 2S Pad MD Reference: 2S-05 actual @ 147.50usft(0141) Well: 2S-05 North Reference: True Wellbore: 2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05 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) (°/100') (ft) Survey Tool Name 15,130.00 90.34 15.00 6,271.10 6,123.60 4,203.95 5,444.07 5,933,950.15 1,626,679.31 0.00 5,469.73 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and%or well position objectives have been achieved. L Yes L No I have checked to the best of my ability that the following data is correct: 0 Surface Coordinates 0 Declination & Convergence Q GRS Survey Corrections Li SurveyTool Codes Vincent Dtg.mly vs net by Yircerr Clara CN:cn-vircerc Cara. o-Schla.,b..y..., a.-Schlwrberger, SLB DE: Osara emailwvarwi tlhmrnc-Ug Cm:ni6.06.041:58:.9 COW Jake Voss �g"�" '°"' Client Representative: `rc�`c U1.I"" "`�"" `�""� aih 7Cis.a<.f6 t311�159egU Date: 06-Iun-2016 6/6/2016 11:21:35AM Page 7 COMPASS 5000.1 Build 74 ,oF ry • i g*•e \ y/j�B THE STATE Alaska Oil and Gas ti ► of LAsKA Conservation Commission 1- Sir£'=== 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 SFA ;SSP Fax: 907.276.7542 www.aogcc.alaska.gov Adam Klem Completions Engineer Conoco Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tabasco Oil Pool, KRU 2S-05 Permit to Drill Number: 216-039 Sundry Number: 316-309 Dear Ms. Klem: 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, il-41-444\ Cathy . Foerster Chair DATED this /U' day of June, 2016. RBDMS `'JUN 1 3 2016 RECEIVED STATE OF ALASKA • JUN 0 Q2 010 ALASKA OIL AND GAS CONSERVATION COMMISSION S 6.7/o �� APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0' Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. . Exploratory ❑ Development 0 1 216-039 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service P.O. Box 100360,Anchorage,Alaska 99510 50-103-20739-00-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2S-05 I Will planned perforations require a spacing exception? Yes ❑ No ❑✓ , 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL 25604, 25589, 25603 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ftffective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,4x2'eF+a/s5 4' 6,Mfc'est. Cage 4,400 AyCasing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 127.5' 127.5' Surface 2,887' 10-3/4" 2,927' 2,565' Intermediate 8,979' 7-5/8" 9,019' 6,335' Production Liner 6,269'est. 4-1/2" 1g434P-est dimes/ 6,120'est. Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See attached schematic See attached schematic 3.5" L-80 8,869'est. Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): LEM Installation,no SSSV 8,769'est.MD,6,280'est,TVD 12.Attachments: Proposal Summary 0 Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 2 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 21-Jun-16 Commencing Operations: OIL ❑✓ ` WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Adam Klem @ 907-263-4529 Email Adam.Klem@conocophillips.com Printed Name Adam m Title: Completions Engineer/ 6-3/4 Signature Phone 907-263-4529 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: . k4 -309 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No 111--.- RBDMS 1'' JUN 1 3 2016 Spacing Exception Required? Yes ❑ No 11 Subsequent Form Required: /Q— 40 APPROVED BY Approved by: COMMISSIONER THErCOMMISSION Date: �6"/ 47 r��/9 6 �� (9)�(��" Submit Form and For 10-403 Revised 11/2015 �[RtU1IctP\ nAvII for 12 months from fftFhh�e date of approval. Attachments in Duplicate / • • ` ch11c. 2S-05 ConocoPhillips Grassroots Horizontal A-Sand Producer Final et CAMERON Last Edited: 4-'/:"tree,top joint is 4-W12.6#IBTM KI em 6/9/16 c I 16"Conductor to-107' �,, 13.5" Surface Hole F 2 J ' y Base Permafrost:1,396'MD/1,375'TVD Ar• c mak,. Base West Sak:2,840 MD/2,506'ND ,,1 J 3-'/a"x 1-1A"Camco MMG GLM Surface Casing 10-3/4"45.5#L-80 Hydril 563 2,927'MD/2,565'TVD(48° INC) a. 9-7/8" x 11" Intermediate Hole 0.o O Tubing: i 3-1/2" 9.3#L-80 EUE 8RD-MOD ai a; o GL GLM w/SOV Z N J 411 2'Stage TOC= 500'MD above C-37 Formation at 5,844' 11111111 Weatherford Stage Collar:6,465'MD C-37:6,344'MD/4,849'TVD ,.1'Stage TOC: Top of Bermuda/Cairn formation) Growler(Iceberg):6,544'MD/4,994'TVD i Baker 2.812"CMU Sliding Sleeve Cairn:7,314'MD 15,551 TVD Bermuda:7,469'MD/5,659'TVD 0\1\\ 3-'/"2.75"D Nipple 3-%"x 7-5/8",Premier Packer HRZ:8,046'MD/6,007'TVD • Kalubik:8,300'MD 16,132'TVD SLB DHG i ®�9 5.75"x4'/:"Swell Packer Kunaruk C: 8.785 MD/6.296'ND f C: Kuparuk A4:8,856'MD/6,312'TVD-10.2 ppg • a i "? '' Mai"ano.e"k. g1 • 7-5/8"x 5-%"Baker ZXP . ID k Packer/Flex Lock Liner ■ II ■ ll 1111 ■ • ■ wW�a nines rR Hanger r r TD:15,130'MDI 6,258'ND intermediate Casing 6-3/4" Production Hole 7-5/8"29.7#L-80 Hyd563 Casing Production Liner: 9,019'MD/6,335'TVD(83° INC) 4-1/2"11.6#L-80 Hydril 563 15,118'MD/6,258'ND 0 • 2S-05 ConocoPhillips Grassroots Horizontal A-Sand Producer Proposed Wellbore Schematic(wp10) i ( CAMERON Last Edited: 4-xtreetop joint is a-'._'12 6#IBTI,I M arusha ck 6/1/16 : G A 616"Conductor to-107' 13.5" Surf a Hole a ;.; (4 B e Permafrost:1,396'MD/1,375'TVD : Base West Sak:2.840 MD 1 2.506'ND a — -- 3-' "x 1-'2"Camco MMG GLM 1F Surface Casing 10-3/4"45.5#L-80 Hydril 563 2.927'MD!2,565'TVD(,:' I\lo 9-7/8" x 11" Intermediate Hole a c Tho• s: 0 3-1/2" 9.3# -80- 8RD-MOD ai c G,, ',y GLM wt SOV z Jlif Sta.e TOC= 500'MD above C-37 Formation at 5,844' r 11111111 eatherford Stage Collar:6,465'MD C.37:6,344'MD/4,849'ND Iminms2 Stage TOC: Top of Bermuda/Cairn formation) Growler(Iceberg):6,544'MD/4,994'ND aka 2812"CMU Siding Sleeve Cairn:7,314'MD/5,551'ND Bermuda:7,469'MD(5,659'TVD _ C:3 3-':,"2.75"XN Nipple 3',^x 7-518",Premier Palter H RZ:8,046'MD/6,007'TVD .c z Kalubik:8,300'MD/6,132'ND 1 1PY SLB DHG 5.75"X4!"Swell Packer Kuparu k C: 8,785 MD/6,296'TVD 1- `.a. , � ?'s Kuparuk A4:8,856'MD/6,312'ND-102 ppg a. J — a ...... i 'I�I,� • l m 7 8"x 5-',"Baker ZXP a=;' +�- 1 I 1 t --,- 1 ,�(. ,` �.: I ackel/Rex Lock liner ---- ---ill � eme,e I y Hanger Y TD:15,130'M D/6,258'TVD Intermediate Casing 6-3/4" Production .1,,-1aii. 7-5/8"29.7#L-80 Hyd563 Casing Production Liner: 9.019'MD/6,335'TVD(83° INC) 41/2"11.6#L-80 Hydril 563 1430-PD/6,258'TVD • . Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). TO THEASKA OIL AND GAS CONSERVATION COI/LION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K.Wharton Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the 2S-05 Well ) under the Provisions of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Paul K.Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K.Wharton, and I have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283(1) CPAI prepared the attached Notice of Operations("Notice"). 4. On or about June 2, 2016, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 2nd day of June, 2016. Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 2nd day of June, 2016, by Paul K.Wharton. Not ryPublic, Sttae of Alaska My Commission Expires: STATE OF ALASKA , NOTARY PUBLIC �.. REBECCA SWENSEN � = -T My Commission Expires • 2:42018 • ConocoPhillips Alaska, Inc. Paul K. Wharton Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Fax (907)263-4966 Paul.K.Wharton@conocophillips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2S-05 Well Kuparuk River Unit, Alaska ADL 25603, KRU Tract 90; ADL 25604, KRU Tract 89; and ADL 255589, KRU Tract 75 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2S-05 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about June 2, 2016. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well on leases ADL 25603, KRU Tract 90; ADL 25604, KRU Tract 89; and ADL 25589, KRU Tract 75 as depicted on Exhibit 1 as follows: Surface Location: 3037' FNL, 1378' FEL, Section 17, T1ON, RO8E, UM Target Location: 4649' FNL, 2737' FEL, Section 16, T1ON, RO8E, UM Bottomhole Location: 4126' FNL, 1195' FEL, Section 9, T1ON, RO8E, UM Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, 6' 14- Paul Wharton Staff Landman cc: Adam Klem Rebecca Swensen 2S-05 Hydraulic Fracturing Notice Lett* • June 2, 2016 Page 2 Exhibit 1 ConocoPhillips 2S-0- Alas •a; Inc. Lease Plat ADL.025590 ADL025589 . 76f '/2 mile radius from Well 10N R8E 88 ADL02 4 i�-) AD1025603 — ADL 25605 2S-05 Kuparuk River Unit '9L392952 ........ cDS 1'= •2S-05 Open Interval ACL32$0? —2S-05 Trajectory ❑1+2 Mi Trajectory Radius Unit Tract Number --Ku pa ruk PA - _ ['CPA]Lease 2S-05 Hydraulic Fracturing Notice Lett* • June 2, 2016 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, Manager, NS Development Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. Robert Kinnear Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. Glenn Fredrick ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Gilbert Wong Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director • • Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: 2S-05 Landowners 1,,,-- 02 9,n16 ConocoPhillips 2S-05 Alaska,Inc. Lease Plat N 4 6 5 A 0 0.15 0.3 0-45 0.6 Flies Au-ut5Nsu ADL025590 , ADL025569 i, 76 1�, /71 /118 /'� 30 1 2504 25-007 2K-19AL1 1 1 10 2s-02 2 17 '..„,46.441111 15 2513P81 ' � T I X25603 rldol, 1 k i A 0 , �' 17 ,i., ADL 2S-05 21-10-8 i 19 20 / 21 22 23 / 2S-03P61 2�1. Kuparuk River/ ltnit I / zs-10 • Frac Points —25-05 Open Interval2s/a3 �, :7 X92952 —2S-05 Trajectory 23 28 01/2 Mi.Frac point Radius ADLo2•.17 01/2 Mi.Trajectory Radius —Well Within Trajectory Radius ()Unit Tract Number --Kuparuk PA 0 CPAI Lease �2 33 34 i .37, • • Table 1: Wells within .5 miles WELL NAME STATUS WELL TYPE 2K-19AL1 ACTIVE PROD 2S-01 ACTIVE PROD 2S-02 ACTIVE PROD 2S-03 ACTIVE PROD 2S-03PB1 PA EXPEND 2S-04 ACTIVE PROD 2S-04PB1 PA EXPEND 2S-07 ACTIVE PROD 2S-08 ACTIVE PROD 2S-10 ACTIVE PROD 2S-11 ACTIVE PROD 2S-13 PROP SVC 2S-13L1 PROP SVC 2S-13PB1 PA EXPEND KRU 21-10-8 PA PROD • • SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) r There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), "That portions of the aquifers on the North Slope described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field". • • SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. • • SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. • • SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10-3/4" casing cement pump report on 5/18/2016 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg Lead Deep Crete cement and 15.8 ppg tail cement. Full returns were seen throughout the job. The plug bumped at 1,500 psi and the floats were checked and they held. The 7-5/8" casing cement report on 5/27/2016 shows that the job was pumped as designed, indicating competent cementing operations. The first stage was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 570 psi and the floats were checked and they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. • • SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 5/20/2016 the 10 & 3/4" casing was pressure tested to 3500 psi. On 5/29/2016 the 7 & 5/8" casing was pressure tested to 4000 psi. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 3,600 Annulus pressure during frac 3,600 Annulus PRV setpoint during frac 3,700 7 5/8" Annulus pressure test 4,000 3 1/2" Tubing pressure Test 5,000 Nitrogen PRV 7,505 Highest pump trip 7,305 • • SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & 3/4" 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8" 29.7 L-80 6,890 psi 4,790 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi Table 2: Pressure Ratings • • Stimulation Surface Rig-Up F Bleed/Tattle Tale Tank 1I1 ),‘1 121 ;9 j r a` a, IIF fl/f 10111 irk m 1100011 12 BIF `a dH to •1 a2 r 11a. ►� Y I N K1 durnd Pop-Off Tank Pop-Off Tank 1 1 Pump Truck �ry �Z> cp. F J V GI _ Frac Pump NI 04 Frac Nov Frac Pump 47.1 Frac Pump 2 Frac Pump NJ 04 oil Frac Pump • • 10K Frac Tree Note. Dimensional information retliecied on this drawing are estimated measurements only. 63 OTIS 1111111111 , i 'III :I ': Ila 4"1002 A,- 4"1002 de4-1/16"10,0000 '4''' _. nj 4-1/16' 10,000# isr a : ■ III( ' ' E ()Ill �II3 1)111 •• 4" 1502- 4-111 b 502-4-111b 10,000 1 cu ffydraulis !:t3.94' r, n meemA.... 4-1f16' 10,UOO4 r.,''....',,, .15 1 4-1116' 10,000# ConocoPhillips ;;CAMERON Drill Site 2S-10K Frac Tree _. STEPHEN u.12-30-15 # 116200-C-2 • • Wellhead with 10K Frac Tree _ ,....,._ mi ll 6 5 0115 , *me thrnensetytal intotmattan reffectesi ail the;drawing arr miimitoti rnanurement onts.. 41-111Ljla . r 4-1002 ....0 .2' 4"1002 4-1,41o* 10,U(Xnt Ark .... ,....„. 4-1/16* 10000l '1 4 Nib, I 1111111 1 , 4' _i • - 4 .2 • en _ 1016 iiir ' 1 Illi ill, 124.08" 7 - -" 4-1/1 b"i(I,UOUR 1 x?' 1502 4-1/1n- 11 _.,..,r. C-.,( )"), . 1 tycludttlir pmmilm== 184,45" 4-1/1&" 10.0004 ., .. t 4-1/1610,Otr..ro 1 110.k A.1-14111` 11731' In.u. ' am me lig t min i 11- s.000X 41.--0 t ..— -.17-41.11 i roi 0. .--1/1n"5.00011 10.19' 11. 5 H. ir I 11111 — Ia 1111•11 Er, - tr.. 1..._ 2-1/16' 5.0001 .11.7S" 1 14.425" , . . !--4, - ---------- ' 1 - 14.8I /...",.." or Conductor __ up of Conductor to BUIL ttf hanger 16" 1110," ConocoPhillips ":°At) 41,1';CAMERON Drift Site 25-Producers w/10K nee STEPHEN _12-30-15 # 1162040-D • • SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone, the Kuparuk A sand interval, is approximately 115' TVT at the heel, with the top of the Kuparuk A at 6,164' TVDSS (8,930' MD) and 115' TVT at the toe of the well, with the top Kuparuk A estimated at 6,090' TVDSS. The Kuparuk A interval is composed of multiple packages of very fine grained, quartz rich sandstone, separated by laterally continuous shale interbeds. The estimated fracture pressure for the Kuparuk A is 13.1 ppg. The overlying confining zone has an overall thickness of 334' TVT (867' MD) and consists of HRZ and Kalubik mudstones. Top HRZ was encountered at 5,820' TVDSS (7,980' MD). The estimated fracture pressure for the overlying confining layer is 16 ppg. The underlying confining zone consists of the Miluveach interval, a marine shale, approximately 500' thick. The estimated fracture pressure for the Miluveach is 15.5 ppg. The top of the Miluveach is located at approximately 6,263' TVDSS at the heel (the Miluveach interval was not penetrated in the 2S-05 wellbore). • S SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 2S-03: The 7-5/8" casing cement report on 2/11/2016 shows that the job was pumped as designed, indicating competent cementing operations. The first stage was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1,103 psi and the floats were checked and they held. 2S-07: The 7 & 5/8 casing cement pump report on 8/6/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.3 ppg cement, displaced with 10.6 ppg mud. The plug bumped at 1,251 psi and the floats were checked and they held. 2S-02: The 7 & 5/8 casing cement pump report on 7/1/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 10.4 ppg LSND. The plug bumped at 1,505psi and the floats were checked and they held. 2S-10: The 7 & 5/8 casing cement pump report on 9/2/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 10.5 ppg mud. The plug bumped at 1,450 psi and the floats were checked and they held. 2S-01: The 7-5/8" casing cement report on 1/3/2016 shows that the job was pumped as designed, indicating competent cementing operations. The first stage was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1,100 psi and the floats were checked and they held. KRU 21-10-8: KRU 21-10-8 was plugged and abandoned as per state regulations on 4/28/1989. 0 S fat 27 a\ 2\ � _ 5 \\\ \\_ /�01 (\ \c. � % � �O.( � 0. � ( 2§I 00 00I- - ; � [ in \ 00 \q � � ■ E .1 n — \ 2 § r. ) To s ) © o § 0 ) lq ƒ ) _ ;� -06- ) 0 _- _ - ) ;re) a _� \$ . /\ �� IN b § §� ) / 0 0.) cu \ h h _ .> . f f |i QJ )CC ) ) \ \ 4- 0 �} I ! I !` J ] ! I . R en To 00 1t . ui . , § V f � _ t "U }k \ / k b \ U £ \\a.g } j \ 0 \ tei a2 ° s k� -en - 01 § IN ,$ 171 _ . g § 2 2 -Cuol . } % r a « r, R 0 0 2 2 2 an Lo 2 0tt in§ , 01 , CA § • • oul V o a• C W Q N Q N Y N H I, H 01 I-N .0 a o 2 0 2 0 2 0 V m c a NNN .a „ n ON n ° Nn O a^ p oO aO 2 tD c u-,”" u x `a coa a p 0 m n £m m m m 7 G Htri tfi (D V E xm v. H V V � p n K o m m m m `a ti is `a c Cal Cal u o ao a. o e a 2 o l a a II ooN o_ 2 n. 2 m m • m ob co o Ca N:@, 71V W N Cal W m O VCo V O V V m 0 O 0 r o .. oo c c a . c o 0 0 Y w` `a `a > v v v h -2,-; n CU L' voi voi o .- z H CC LL O CCS CU c m L a m o o O Q 111 C £ a ▪ E v u u c a P g (j O Fa D co E• a £N VO 12 N N W O 4-, O of V V V N O CUL C U dg co IN o U— F v N Ws N. G t41:' N N 6 6 t0 T m O— (0 b H O iS S Gip t7 S o sad : o g m o0 00 't .3 Lel V n n n Q 0 Z Z Z H 2 1412 Zo Ni O O2 N N N N O v) 3 N • • SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion based on seismic, well, and other subsurface information currently available that there are 13 mapped faults that transect the Kuparuk A interval and enter the confining zone within one half mile radius of the wellbore trajectory for 2S-05. The north-south trending faults between 2S-05 and 2S-07 terminate in the Cairn interval, which consists of sands, silts, and shales in this area with an estimated fracture pressure of>12 ppg. Three faults intersect the 2S-05 wellbore and terminate within the confining layer (Fault #1, #2, and #3). Faults #4 and #5 terminate at the C-35. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of—16ppg. No losses were observed at any of the fault crossings during drilling of the 2S-05 lateral section. Fracture gradients within the confining zone (Kalubik and HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining layer is discussed in Section 9. 2S-05 Faults MD SSTVD Throw Fault#1 (A4/A4) 10562 6182 2 (DTS) Fault#2(A4/A4) 10570 6182 2 (DTS) Fault#3(A4/A4) 10585 6183 4(DTS) Fault#4(A4/A4) 11958 6181 21 (DTS) Fault#5 (A4/A4) 13684 6146 8 (DTS) Two mapped faults within the half mile radius intersect the offset 2S-07 wellbore in the Kuparuk A sands. They also intersect the 2S-05 wellbore and correspond to faults #4 and #5. Both faults terminate in the C-35. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of—16ppg. No losses were observed at any faults during drilling of the 2S-07 lateral section. The 2S-05 lateral is greater than 1500' from the 2S-07 wellbore. 2S-07 Fault MD SSTVD Throw Fault#1(A4/A4) 11350 6167 29 (DTS) Fault#2(A4/A4) 13022 6142 5 (DTS) Two mapped faults within the half mile radius intersect the offset 2S-02 wellbore in the Kuparuk A sands. Fault#2 intersects the 2S-05 wellbore and corresponds to Fault#4 in 2S- 05. Both faults terminate in the C-35. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of—16ppg. No losses were observed at the fault during the drilling of the 2S-02 lateral section. The 2S-05 lateral is greater than 1500' west of the 2S-02 wellbore. 2S-02 Fault MD SSTVD Throw Fault#1(A4/A4) 16225 6227 27(DTS) Fault#2(A4/A4) 17488 6214 25 (DTS) • • The effective fracture length is estimated to be 420'. All of the fractures will be longitudinal, running parallel to the 2S-05 wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. • • Plat 2: Fault Analysis y,- 4:du116 6 ConocoPhillips ^`-'f Alaska,Inc. Fa.*l:,Analysis N 0 0.'. 22 C. 2.4 A4IDLOs5 ADL0255BG B ❑ 1a KIR Wi ' Unit 1/ i T .il 1? j i to . , to 4,, t ft N 1 �~"— _ ..:::2 iU ill 1 23 to l7 ,i/ y i 22 j, � I 1 ^ 3P81 '/ / 1 2S-®1 i • Frac Points Faults Within Con ring Zone 1' --2S-05 Trajectory -10 1/i 0112 Mi.Frac Point radius ,Ig / 25 ADLO25O7 27, p 1,2 Mi.Trajectory Radius / —W'eils Within Frac Point Radius 23103 —Kuparuk PA �-••• El CPAII Lease • • SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 2S-05 was completed in 2016 as horizontal producer in the Kuparuk A sand formation. The well will be completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 1st stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (A Sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 18 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 15,650 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 500 bbl breakdown stage (35# linear gel) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 25 BPM as quick as possible, pressure permitting. Increase annulus pressure to 3,500 psi. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. 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From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday,June 09, 2016 2:05 PM To: Klem, Adam <Adam.Klem@conocophillips.com> Subject: [EXTERNAL]KRU 2S-05 (PTD 216-039): Fracture Stimulate Sundry Application Good afternoon Adam, Please provide a final wellbore schematic for KRU 2S-05. This may be sent to me via email. 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 1150. Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, June 09, 2016 2:05 PM To: Adam.Klem@conocophillips.com Subject: KRU 2S-05 (PTD 216-039): Fracture Stimulate Sundry Application Good afternoon Adam, Please provide a final wellbore schematic for KRU 2S-05. This may be sent to me via email. 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 11, Pro 2/6, - 0.3 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday, May 12, 2016 2:07 PM To: 'Hallford, Kelsey' Subject: KRU 2S-05 (PTD 216-039 (REVISED)) - Rig Swap Kelsey, This email notification will suffice. I will make a note to the approved PTD. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Hallford, Kelsey [mailto:Kelsey.Hallford@conocodhillips.com] Sent: Thursday, May 12, 2016 8:35 AM To: Loepp,Victoria T(DOA) Cc: Bearden,3 Daniel; Voss,Jake Subject: PTD 216-039(REVISED) - Rig Swap Victoria, Doyon 142 is the rig named in the PTD for drilling KRU 25-05,however we are now making the necessary changes to have Doyon 141 drill this well. • Current schedule has Doyon 141 moving to the 2S pad this weekend. Other than notification,does a revised PTD need to be submitted to the state declaring this change? Kelsey Hallford GKA Drilling Engineer ConocoPhillips,Alaska 907-265-1577 work 907-440-0004 cell 1 ti OF rji • \ iyy�sA THE STATE Alaska Oil and Gas �,:s�a� OfA LAsKA Conservation Commission s };E - 333 West Seventh Avenue !, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Off' ALAS�P Fax: 907.276.7542 www.aogcc.alaska.gov G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-05 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-039 (revised) Surface Location: 3037' FNL, 1378' FEL, Sec. 17, T1ON, R8E, UM Bottomhole Location: 4126' FNL, 1195' FEL, Sec. 9, T1ON, R8E, 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 March 15, 2016. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, P)ze_4 &_ Cathy P Foerster Chair DATED this Gip day of April, 2016. RECEIVED STATE OF ALASKA 2016 ALI A OIL AND GAS CONSERVATION COMMSJN REVISED PERMIT TO DRILL 20 AAC 25.005 AUG GC la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ 1 c.Specify if well is proposed for: Drill ❑✓ . Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑✓ . Service- Winj ❑ Single Zone 0 Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 KRU 2S-05 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 15,138 TVD: , 6,289 - ,- -'Kuparuk 1 r field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3037'FNL, 1378'FEL, Sec 17, T10N,R008E,UM ' ADL 25603,25604,25589• Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4604'FNL,2725'FEL,Sec 16,T10N,R008E,UM 2677,2678,2675 5/6/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4126'FNL, 1195'FEL, Sec 9,T10N,R008E,UM 7632 . 3036.88'from ADL025590 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 159 4 15.Distance to Nearest Well Open Surface: x- 481192 y- 5930011 Zone- 4 ' GL Elevation above MSL(ft): 120 to Same Pool: KRU 2S-03:525.11' 16.Deviated wells: Kickoff depth: 400 feet 1'143 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: Q 1 9,0 degrees Downhole: 3373. Surface: 2737 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) 24" 16" 62.5# H-40 Welded 79' 39' 39' 118' 118' pre-driven,cement to surface 13.5" 10.75" 45.5# L-80 Hydril 563 2,913' 39' 39' 2952' 2586' 1238 sx DeepCRETE,270sx 15.8 Class G 9.875" 7.625" 29.7# L-80 Hydril 563 9,143° 39' 39' 9182' 6359' /6/U,'sx Class G,205 sx Class G 6.75" 4.5" 12.6# L-80 Hydril 564 6,106' 9032' 6348' 15138' 6,269' N/A 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 Q Time v.Depth Plot ❑ Shallow Hazard Analysis ii Diverter Sketch ❑✓ Seabed Report ❑ Drilling Fluid Program ❑ 20 AACLI 25.050 requirements 21. Verbal Approval: Commission Representative: Date f A i�, ` 22.I hereby certify that the foregoing is true and the procedure approved herein will not Jacob Voss JJJ265-6935 �{ be deviated from without prior written approval. Contact ,r A; jake.vosscop.com/ Email Printed Name G.L.Alvord Title Alaska Drilling Manager Signature A ,e. a o(__ Phone 265-6120 Date 4-112-1( 2.714 Commission Use Only Permit to Drill API Number: Permit Approval t� See cover letter for other Number: a (P o39 <e, .64. 50- J 03- t2,0 235 —Q�---do Date: ( 1 Y 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: V Other: , p fie S t f , 3 5-"op p 5 4-9 Samples req'd: Yes❑ No Mud log req'd:Yes❑ No L' /1-11.n 1/t,a P re-vY el-fit`7rs1"fa 2500 p5-19 HZS measures: Yes( No❑,�/ Directional svy req'd:Yes 2.--No❑ Spacirrexception req'd: Yes❑ No L>/� Inclination-only svy req'd:Yes❑ No 2( Post initial injection MIT req'd:Yes❑ No❑ S17 / [/_, APPROVED BY / Approved by:4171211( ' v COMMISSIONER THE COMMISSION Date:_^2.4— /," ?"' 1I'`1 `� AA Submit Form and Form 10-401(Revised 11/2015) This permit is valid fo/i RtiS/�i tNa4pOt�approval(20 C 25,0 (g)) Attachments in Duplicate • • Application for Permit to Drill,Well 2S-05 Saved: 12-Apr-16 Post Office Box 100360 Anchorage,Alaska 99510-0360 Phone(907)265-6935 ConocoPhillips '' „R 11 Email: lake.vossaconocophillips.com April 11,2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Revise Permit to Drill Well 2S-05, A Kuparuk A4 Sand Producer Dear Commissioner: ConocoPhillips Alaska, Inc.hereby applies for a revised permit to drill an onshore grassroots producer well from the 2S pad. The expected spud date for this well is May 6th', 2015. It is planned to use rig Doyon 142.'''Revisions include, deeper intermediate setting point and subsequent changes due to updated pore pressure measurements. 2S-05 is planned to be a horizontal well in the Kuparuk A4 sand.The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-2,952' MD/2,856' TVD. The intermediate section will be drilled with 9-7/8"x 11"bit/Under Reamer and run 7-5/8"casing to 9,182'MD/6,359'TVD. The production hole will be drilled with 6-3/4"bit and run 4- 1/2"slotted liner to+/- 15,138'MD/6,269'TVD.The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment,diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Jake Voss at 265-6935 (jake.voss(&conocophillips.com)or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager • • Application for Permit to Drill Document Kuparuk Well 2S-05 con« ni ps Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-05 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 identhving the properly 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 3037'FNL, 1378'FEL, Sec 17, T 1ON,R008E,UM NGS Coordinates RKB Elevation 159'AMSL Northings: 5,930,010.88' Eastings: 481,191.79' Pad Elevation 120'AMSL Location at Top of 4604' FNL,2725 FEL, Sec 16,T1ON,R008E,UM Productive Interval (Kuparuk A4 Sand) NGS Coordinates Measured Depth, RKB: 9,138' Northings: 5,928,434,.90 Eastings: 485,125.06 Total Vertical Depth, RKB: 6,359' Total Vertical Depth, SS: 6,200' Location at Total Depth 4126'FNL, 1195'FEL, Sec 9,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 15,138' Northings: 5,934,189.84'Eastings:486,652.27' Total Vertical Depth, RKB: 6,269' Total Vertical Depth, SS: 6,109' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally devi,i t.the application for a Permit to Drill(Form 10-401)must (1)include a plat.drown to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of proposed well: Please see Attachment: Directional Plan 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. 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(HOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 142. • • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the 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 maximum potential surface pressure (MPSP)wTile drilling 2S-05 is calculated using an estimated maximum reservoirpressure of 3 373psi (10.2 based on 2 - S 03 development well agas gradient of ppg, p )� 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,359' TVD (WP09): A Sand Estimated. BHP =3,373 psi A Sand estimated depth(WP09) = 6,359' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column =636 psi (6,360' TVD * 0.10 psi/ft) MPSP =BHP—gas column =2,737 psi (3,373 psi—636psi) (B)data on potential gas=ones: The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation_ones,and zones that have a propensity for differential sticking; See attached 2S-05 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the 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 25.0300; A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and 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 Cement Program Casing and Cementing Program Csg/Tbg OD Hole Weight Length Top MD/TVD Btm MD/TVD (in) �) (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 79 Surf 118/118 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,913 Surf 2,952/2,586 1,238 sx DeepCRETE Lead 11.0 ppg, 270sx Class G Tail Slurry 15.8 ppg Stage 1: 869 sx Class G+GASBLOK at 9-7/8 Hydril 15.8 ppg w/TOC at 7,324 MD 7-5/8 X 29.7 L-80 9,143 Surf 9,182/6,359 Stage 2: 205 sx Class G+GASBLOK at 11 563 15.8 ppg w/TOC at 5,812 MD 4 1/2 6-3/4 11.6 L-80 IBTM 6,106 9,032/6,348 15,138/6,269 Uncemented Liner with Frac Sleeves • • 2S-05 wp09 Cementing Schematic 16" Conductor to 118' 10-3/4"45.5# L-80 HYD563 2,952' MD/2,586'TVD @ 48°inc. 9-7/8"x 11" Hole Top of 2nd Stage Cement 5,812' MD C-37 6,312' MD/4,780' TVD Top of 1st Stage Cement(top Cairn) 7,324' MD/5,513' TVD Kalubik 7-5/8"29.7#L-80 HYD563 Casing 8,359' MD/6,116'TVD 9,182 MD/6,359'TVD @ 85° Kuparuk A4 9,039' MD/6,345'TVD 6-3/4" Hole 4-1/2" Liner 11.6# L80 IBT k 15,138' MD/6,269' TVD s s 10-3/4" Surface casing run to 2,952' MD/2,586' TVD Cement from 2952' MD to 2452'(500' of tail)with Class G @ 15.8 ppg,and from 2452'to surface with 11 ppg DeepCrete.Assume 250%excess annular volume in permafrost and 50%excess below the permafrost(1400' MD),zero excess in 16"conductor. Lead slurry from 2,452' MD to surface with Arctic Lite Crete @ 11 ppg Conductor (115'—0')X 1.339 ft3/ft X 1.0(0% excess) = 154 ft3 Permafrost to Conductor (1,400'—115') X 0.3637 ft3/ft X 3.5 (250%excess) = 1,636 ft3 Top of Tail to Permafrost (2,452— 1,400')X 0.3637 ft3/ft X 1.5 (50% excess) =574 ft3 Total Volume= 154+ 1,636+574=2,364 ft3=> 1,238sx of 11Pp9 DeepCrete Crete 1.91 ft3/sk Tail slurry from 2,952' MD to 2,452' MD with 15.8 ppg Class G Shoe to Top of Tail (2,952—2,452')X 0.3637 ft3/ft X 1.50 (50%excess) =273 ft3 Shoe Joint (80')X 0.5400 ft3/ft X 1.0 (0%excess) =43 ft3 Total Volume=273+43=316 ft3=>270 sx of 15.8 ppg Class G @ 1.17 ft3/sk 7-5/8"Intermediate casing run to 9,182' MD/6,359' TVD 1st stage slurry designed to be at the top of Bermuda/Cairn Formation at 7,324' MD. Top of 2nd stage slurry is designed to be at 5,812' MD,which is 500' above the C-37.Assume 40%excess annular volume. 1st Stage slurry from 9,400' MD to 7,324' MD with 15.8ppg Class G+additives Shoe to Top of Cement (9.182—7,324')X 0.3428 ft3/ft X 1.40(40%excess) =892 ft3 Shoe Joint (80')X 0.2578 ft3/ft X 1.0 (0%excess) =21 ft3 Total Volume=892+21 =913 ft3=>780 sx of 15.8 ppg Class G+GasBLOK @ 1.17 ft3/sk 2"d Stage slurry from 6,312' MD to 5,812' MD with 15.8ppg Class G +additives Stage Collar to Top of Cement (6,312—5,812)X 0.3428 ft3/ft X 1.40 (40%excess) =240 ft3 Total Volume=240 ft3=>205sx of 15.8 ppg Class G+GasBLOK @ 1.17 ft3/sk • . Diverter System Information Requirements of 20 AAC 25.005(c)(7) .in application fur a Permit to Drill num lie 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 MC 25.035(h)(2); Please reference diverter schematic on file for Doyon 142. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application fur a Telma to Drill must he 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; Mud Program Summary Surface Intermediate Production 9-7/8"x 11" 13-1/2" Hole Hole 6-3/4" Hole 10-3/4" Casing 7-5/8"Casing 4-1/2" Liner Spud LSND FlowPro Mud System (WBM) (WBM) (WBM) Density 9.3- 10 9.6—10.5 10.3—11.0 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. • • Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) an application for a Permit to 1)i-ifl, - 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 to attachment for proposed well schematic • • 1. Move in/rig up Doyon Rig 142. Install Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-2,952' MD/2,586' TVD as per directional plan (wp09). Survey with MWD, Gamma,Resistivity,Gyro. / 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. Notify AOGCC if this occurs. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3500 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 13 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Open 9-5/8"x 11"Under Reamer and directionally drill to the top of the HRZ 9. Install RCD bearing at this time for use of MPD if necessary. 10. Directionally drill to intermediate TD of 9,182' MD/6,359' TVD,wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean,minimum of 3 bottoms up. 11. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. 12. Lay down intermediate BHA and rack back 5"DP 13. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD at 9,182' MD. 14. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 7,324' MD(top of Cairn formation),top of second stage to be 5,812'MD(500' above C37). 15. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 16. Lay down 5"DP. 17. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,and neutron density) / 18. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes and chart. 19. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 14.5 ppg EMW leak off,recording results. 20. Swap mud over to 10.2 ppg FlowPro mud system 21. Directionally drill 6-3/4"hole geosteering through the Kuparuk A4 sand to TD 15,138' MD as per directional plan(wp09). 22. Circulate hole clean and POOH. 23. Lay down production BHA. 24. PU and run 4-1/2", 11.6#liner. The top of liner will be placed at-9,032 MD,allowing for 150' of overlap in the 7-5/8"casing. 25. Set liner hanger. Slackoff and set liner top packer. 26. Monitor well for flow for 15 minutes • • 27. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 28. Flow check well for 30 minutes and POOH 29. Run 3-1/2"upper completion. 30. Nipple down BOPE,nipple up tree and test. 31. Freeze protect well with diesel and install BPV. 32. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items.except for an item already on file with the commission and identified in the application: (1 4)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 authorisation 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 (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary • • 2S-05 ConocoPhillips Grassroots Horizontal A-Sand Producer Proposed Wellbore Schematic(wp09) �\ l CAMERON Last Edited: 4-W tree,top joint is 4-%'126#IBTM Voss 4/11/16 16"Conductor to-118' f C; 13.5" Surface Hole GL Base Permafrost 1,398'MD 11,374'TVD Base West Sak:2,875 MD/2,535'TVD J ah, 3'/:"x1'/2"CamcoMMGGLM Surface Casing 10-3/4"45.5#L-80 Hydril 563 2,952'MD/2,585.5'TVD(48" INC) 9-7/8" x 11" Intermediate•tei „ Tubing: i 3-1/2" 9.3#L-80 EUE 8RD-MOD m at CI a. ,J GLM w/SOV z C4 8 f— 2nd Stage TOC= 500'MD above C-37 Formation at 5,81 .4_____—.--- Weatherford Stage Collar:6,312'MD C37:6,312 MD 14,780'TVD 1st Stage TOC: Top of BermudalCaim formation) Growler(Iceberg):6,618 MD/5,000'TVD Baker2812"CMUS5ding Sleeve Cairn:7,324'MD 15,513'TVD Bermuda:7,460'MD 15,606'ND J VVAAkAA1 3h"275"XN Nipple 3=/:"x 7-511r,Premier Palter HRZ:8,178'MD 16,033'TVD Kalubik:8,359'MD 16,116'TVD SLB DHG I API 5.75"x 444"Swel Packer . Kuparuk C: 8,858 MD 16,314'TVD Li � Kuparuk A4:9,039'MD!6,345 TVD^102 ppg --a,roaara -- Shoe 1 75/8" /5ek eP III U E �. �...._ U U t: anb Packer/Flex LacocLin Lock Liner : Hanger "ID:15,138'MD/6,270'TVD Jntermediate Casing 6-3/4" Production Hole 7-5/8"29.7#L-80 Hyd563 Casing Production Liner: 9,182'MD/6,359'TVD(85° INC) 4-1/2"11.6#L-80 Hydril 563 15,138'MD/6,269'TVD • • AegF�� z • s h R < . A\ O P ,n r D N m N mFl w IIS o -0 < , No m I— O I o -D > z o a-, m m 9 D o O :A O_ m$ 1 , S p F ,6 < 1'= F M D O ❑ o � o ° EIN 00 o ❑ — o ❑ y —< — O R�J.- F 7 /111411111'I; I 0 ® Li -< ;. I'''j F _' N D al ` NO [2.1. Irl.. = \\,,, ,c,, ,....._ _ _ GO�� o �� IA IG�A a v r g , o � 07) _. ® a D Z ID co --< 1 E-,0 NJ -< 1 r, N RRRRr y ® e o 0 11: _, D o Z m \ T T T T T T / • 2S-05wp09[Nurse] Permit Pack 1 Plan Summary - Top W Sak(W Sak D) Growler-AA Top Cairn-op Bermuda Lower Kalubik(K-1 mkr) C-37 (TopC4) -5 ._. tap T-3 Sand 1 .. Upperl(alubik(base paruk C To A5 W K-1E Mfrker,, I ' . ifs:. -......:::.1.111 - - rn - 'Base rmafr?st(?).. - -- ... ". ...�.... ....____ I, I I Base ermtda C-35 p HRZ(K-2 mkr) po qse W Sak C-80 C-6040 A4 -..i.. _..... ......;-.. .. 0 �� i i i 1 f 1 i 0 44 4 , 0 13500 7000 1 10500 14000 1 / ,0„ i, 10-3/4"x 13-1/2' Measurl7-5/8"x 9-7/8"by 111 I4-1/2"x 6-3/41 0-_0° Geodetic Datum: North American Datum 1983 IV" Depth Reference: 39+120©159.00usft(Doyon142) Vie0°♦ I10-3/4"x 13-1/2'' Rig: Doyon142 -......-._..,. ..._.. ... ...... �k* O O - o ad O 60 6000 I7-5/8"x 9-7/8"by 11f I4-1/2"x 6-3/41 - o _-....___ '1000° 0 a m I I I I I I I 1 I r i , i t+r I S/ g I X/ I i I 0 1500 3000 4500 6000 0 7590 °9000 c 10500 x'2000 12s-06w06lsw o II o 125-03Pa1I 400 - 590 Horizontal Departure it 'zs-o<Pet 330 OO� 0 _,.12s-o3 590 - 770 /r�0 Q�• 770 - 960 s-mnoa la ( 60 - c _ rt \,,„:,-„ .. ..._... --.... I2s.aal---0i,01f1, - m 60 iqd�mWl 1, Iv , 1140 �._�'.a'ri�i,r�lj,Q�' ri �►•r": Z 1940 - 1330 119 , ' ` 300 •` .11064. '';4:6;4:-..- tre80 1 1330 - 1510 c'E ♦_e1 N 'III 1 iIr ' ,- Zg-03P61 - -_ . 1510 - 1700 rn �_ . 2s as) ,j• �L��i {Y�i 1700 - 2260 c - 'f 11 .k \ �2S-04 ss s�jj;/ ...zjzs-ot 2260 21330 U 30 II r \ 25-07 a I - � 2830 - 3390 o - 1. �. A. ` ,- 4 I' ><os-0l 3390 - 3950 4 1S-04PB1 270 �� \\� s 4 ulWlll 3950 - 4510 2S-03Wp091[Bamopo] _ j 4510 - 5070 o 2S-06wp06 Salmon); `. i 7-f solo - 5640 0 I 1 1 I 1 1 I I I I I I I I I I I I I 1 ) IL 8',.. 5640 - 6200 6200 - 7320 0 1500 3000 4500 6000 7500 9000 10500 240 120 7320 - 8430 SURVEY PROGRAM8430 - 9550 Surface Location 9 r'. 9550 - 10670 Depth From Depth To Survey/Plan Tool Pad Elevation: 120.00 10670 - 117so� 39.00 1000.00 25-05wp09[Nurse](Plan 2S-05 GYD-GC-SS210 - - 160 1000.00 2000.00 2S-05wp09[Nurse](Plan 2S-05) MWD 1..: 11790 12900 1000.00 2951.53 2S-05wp09[Nurse](Plan 2S-05yaIWD+IFR-AK-CAZ-SC 180 12900 14020 2951.53 4451.53 2S-05wp09[Nurse](Plan 2S-05 MWD CASING DETAILS 14020 - 15138 2951.53 9181.86 2S-05wp09[Nurse](Plan 2S-05 WD+IFR-AK-CAZ-SC 9181.86 10681.86 2S-05wp09[Nurse](Plan 2S-05) MWD ND MD Name M W 9181.86 15138.02 2S-05wp09[Nurse](Plan 2S-05)MD+IFR-AK-CAZ-SC 2585.00 2951.53 10-3/4"x 13-1/2" Magnetic Model: BGGM2015 T 6359.00 9181.86 7-5/8"x 9-7/8"by 11" Magnetic Model Date: 25-May-16 A 6269.00 15138.02 4-1/2"x 6-3/4" Magnetic Declination: 18.19' To convert a Magnetic Direction to a True Direction,Add 18.19°East SECTION DETAILS -2 =3;�)T-3 Sand Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.00 0.00 0.00 39.00 -25.56 -117.09 0.00 0.00 0.00 2 400.00 0.00 0.00 400.00 -25.56 -117.09 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,170°TF,for 200.09' K-15 Marker 3 600.09 3.00 170.00 600.00 -30.72 -116.18 1.50 170.00 -4.75 Start 2.5°/100'DLS,0°TF,for 743.21' 4 1343.31 21.58 170.00 1323.00 -185.85 -88.83 2.50 0.00 -147.52 Hold for 107.54' 5 1450.85 21.58 170.00 1423.00 -224.61 -81.96 0.00 0.00 -183.37 Start 3°/100'DLS,-50.88°TF,for 1070.92' -1373.0 6 2521.77 48.39 136.50 2299.60 -722.30 236.18 3.00 -50.88 -581.57 Hold for 3484.46' Base permafrost(? 7 8006.22 48.39 136.50 4613.56 -2612.19 2029.32 0.00 0.00-1942.96 Start 3.5°/100'DLS,-116.04°TF,for 3129.74' 8 9135.97 85.00 14.72 6355.00 -1635.94 3808.86 3.50 -116.04 -539.40 2S-Nurse 1.Heel Hold for 45.89' -1859.0 9 9181.86 85.00 14.72 8359.00 -1591.72 3820.47 0.00 0.00 -493.68 Adjust TF to 0°,for 20' 10 9201.86 85.00 14.72 6360.74 -1572.45 3825.53 0.00 0.00 -473.76 Start 2°/100'DLS,0°TF,for 301.95' Top W Sak(W Sak 7) 11 9503.82 91.04 14.72 6371.17 -1280.71 3902.15 2.00 0.00 -172.13 Hold for 5634.2' 12 15138.02 91.04 14.72 6269.00 4167.78 5333.17 0.00 0.00 5461.08 25-Nurse 2.Toe TD:15138.02'MD,6269'TVD -2535.0 Base W Sak -2959.0 C-80 -4342.0 C-50 -46 .0 -47 7 -499. y��G(rowle��rrj-AAA § cBLkaa 6g22 C-35 (jl$5zz p�,2c ar�krj� 67 &fliVg E 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 ollision avoidance plan as set out in the audit pack.I a prove it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified otherwise,all taraets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: Vinent Osara Nate Beck Ifeanyi Ifesie • • 16:40,Apr004 2016 Easting(4500 uswin) Kuparuk 2M Pad Kuparuk 2H Pad �) 2M-24 H 2H_.. - ._ g ,.. r-2: / 1 2M-26 2H-1 A-13 'H-1 2H-0 38wp09 2H- 4A' i•-liblL11-`�1 M-31 / -30 2M-17 2M-2 2H-14 2H-10 2H-01 2H-0' - 2. 9 2M-02 2 09A 2K-03 ��% 1 2M-: 2M-1 2K-04 2K-05 2K-01 _ K�L1 (1_ +u%^ Ovi/p6002 ( 2 Tim rlinewp10 1N1'... 1'81�,SASK 15 B1wp1r 2M-33 2M-32L1PB 04 1\ M-08 2M-09 a Kuparuk 2K Pad 2K-, - 2S-14wp09.2 1 i •Ir�]4 2M-32L1P:2 4 �` 2w12JtL3pp1 ��./ � - 2M-35 2M 08AL2_ .14 jai), 23S-1131_ 25-111409[Great White] r 13AL' 2K-26 S— 2S-09wp06[Tiger] 2M-08A_wp05 c El 2L-03 2S-04 i 2S-07 4 s ° - '.: ''.- 2K-19 > -11 ' 2K-11 ' 21ff. ii- -23 0 - .n - 2 "" 'K-22. 7:v c= 2 -05wp09[Nu. ] 2K-2 iL o — Pad 2S-o -21 :K-22 2K-24 zK z. PB2L306PB1 ! tKuParuk2S idealei, Kuparuk 2L Pa 2L-3 9 2K-22AL1-01 • 6 Isv 2K-22AL1 2K-201 2L-3:: K U 21 0-8 _ 22L-310 2L- • 1 2L-311 2L- 4 #1 L-3 1g _ L 2L- 2L- 16wp(3b. 1 2S-03PB1 2S-01 L-3 L- 2L-31 2L-320 2S-12 1t1�1 Cookiec er wp03 2L-322A 25-10 2L- 2L 1 0-09 Sigxill p03 Lantern wp03 2N-322 C — 2@PIi065A g 12wp05 \ 2 -30 - i2A14 = 2L-3 8 Prelim: Kuparuk Cairn Pad i i i I ' 2L 2LJ 7/vp � Xaus ffi2 3I10,1P,E12 - 06 Quaicorax�] ' I I 1 I 1 i [ i 1 I ' I i i ' I ' I i 1 1 I Ir ' 1 ' I i 1 1 i ' 1 ' I i i Easting(4500 usft/in) • • 2S-05wp09[Nurse] Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 4500— 2S°5w Ogpv, Sed 4-1/2"x 6-3/4"- 2S-Nurse 2.Toe 3000- 3_ ti 0 500— in L t Z 0— A10 L �Q 7 10-3/4"x 13-1/ `� c$P 3 -1500— 2S-Nurse 1.1ieel h � -3000— 0 -3000 -1500 0 1500 3000 4500 6000 7500 9000 West(-)/East(+) (1500 usft/in) • • 2S-05wp09[Nurse] Section View top T-3 Sand K-15 Marker 0— T, Base permafrost(?) 1000 Top W Sak(W Sak D) c^1500— o <'C00 Base W Sak Lo 0 ---C-80 -c3000— 10-3/4"x 13-1/ -'U Q- C-40 a. 4 C-50 , q8 p0" C 37 Top HRZ (K-2 mkr) 3 Growler-AA Lower Kalubik K-1 mkr) .. - - Q-1--- Top Cairn ( 4500— = -- -?9 -1a miuda_-' -- ",, ---.- ... 1 2 0 $ase Bermuda A5 Upper Kalubik(base HRZ �0 A4 7S1 A4 Q ca - o-a o 6000 � s�, _ - g g 4-1/'x 6-3/4' 7-5/8"x 9-7/8" by 11" o 0 0 00 o cco Z N 7500— Kuparuk C (Top C4) 0 O - - I I I I I -4500 -3000 -1500 1500 3000 4500 6000 7500 Vertical Section at 15.00° (1500 usft/in) • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-05 Plan: 2S-05 Plan: 2S-05wp09[Nurse] Report Permit Pack 05 April, 2016 • Schlumberger • Comments apply to Report the line before it. Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit ND Reference: 39+120 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp09[Nurse] Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan:2S-05 Well Position +N/-S 0.00 usft Northing: usft Latitude: +EI-W 0.00 usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore Plan:2S-05 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2015 5/25/2016 18.19 80.86 57,481 Design 2S-05wp09[Nurse] Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) 39.00 0.00 0.00 15.00 Survey Tool Program Date 4/4/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.00 1,000.00 25-05wp09[Nurse](Plan:2S-05) GYD-GC-SS Gyrodata gyro single shots 1,000.00 2,000.00 2S-05wp09[Nurse](Plan:2S-05) MWD MWD-Standard 1,000.00 2,951.53 2S-05wp09[Nurse](Plan:2S-05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,951.53 4,451.53 25-05wp09[Nurse](Plan:2S-05) MWD MWD-Standard 2,951.53 9,181.86 2S-05wp09[Nurse](Plan:2S-05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,181.86 10,681.86 2S-05wp09[Nurse](Plan:2S-05) MWD MWD-Standard 9,181.86 15,138.02 2S-05wp09[Nurse](Plan:2S-05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (0) (usft) 39.00 0.00 0.00 39.00 -120.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -59.00 0.00 0.00 0.04 200.00 0.00 0.00 200.00 41.00 0.00 0.00 0.19 279.00 0.00 0.00 279.00 120.00 0.00 0.00 0.33 top T-3 Sand 300.00 0.00 0.00 300.00 141.00 0.00 0.00 0.33 4/5/2016 10:13:06AM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: 39+120 @ 159.O0usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp09[Nurse] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (°) (usft) 374.00 0.00 0.00 374.00 215.00 0.00 0.00 0.48 K-15 Marker 400.00 0.00 0.00 400.00 241.00 0.00 0.00 0.48 KOP:Start 1.5°/100'DLS,170°TF,for 200.09' 500.00 1.50 170.00 499.99 340.99 1.50 170.00 0.56 600.00 3.00 170.00 599.91 440.91 1.50 0.00 0.60 600.09 3.00 170.00 600.00 441.00 1.50 0.00 0.60 Start 2.5°/100'DLS,0°TF,for 743.21' 700.00 5.50 170.00 699.63 540.63 2.50 0.00 0.68 800.00 8.00 170.00 798.93 639.93 2.50 0.00 0.78 900.00 10.50 170.00 897.62 738.62 2.50 0.00 0.91 1,000.00 13.00 170.00 995.51 836.51 2.50 0.00 1.06 1,100.00 15.50 170.00 1,092.43 933.43 2.50 0.00 1.16 1,200.00 18.00 170.00 1,188.18 1,029.18 2.50 0.00 1.32 1,300.00 20.50 170.00 1,282.58 1,123.58 2.50 0.00 1.64 1,343.31 21.58 170.00 1,323.00 1,164.00 2.50 0.00 1.82 Hold for 107.54' 1,397.08 21.58 170.00 1,373.00 1,214.00 0.00 0.00 2.08 Base permafrost(?) 1,400.00 21.58 170.00 1,375.72 1,216.72 0.00 0.00 2.08 1,450.85 21.58 170.00 1,423.00 1,264.00 0.00 0.00 2.32 Start 3°/100'DLS,-50.88°TF,for 1070.92' 1,500.00 22.54 167.01 1,468.56 1,309.56 3.00 -50.89 2.56 1,600.00 24.64 161.65 1,560.21 1,401.21 3.00 -48.12 3.07 1,700.00 26.90 157.11 1,650.26 1,491.26 3.00 -43.20 3.64 1,800.00 29.28 153.24 1,738.49 1,579.49 3.00 -39.11 4.29 1,900.00 31.76 149.91 1,824.63 1,665.63 3.00 -35.69 5.01 1,940.66 32.79 148.69 1,859.00 1,700.00 3.00 -32.83 5.80 Top W Sak(W Sak D) 2,000.00 34.32 147.03 1,908.45 1,749.45 3.00 -31.80 5.80 2,100.00 36.93 144.50 1,989.73 1,830.73 3.00 -30.41 3.04 2,200.00 39.60 142.27 2,068.25 1,909.25 3.00 -28.36 3.40 2,300.00 42.30 140.27 2,143.77 1,984.77 3.00 -26.60 3.80 2,400.00 45.03 138.47 2,216.11 2,057.11 3.00 -25.09 4.22 2,500.00 47.78 136.84 2,285.06 2,126.06 3.00 -23.79 4.66 2,521.77 48.39 136.50 2,299.61 2,140.61 3.00 -22.66 4.76 Hold for 3484.46' 2,600.00 48.39 136.50 2,351.56 2,192.56 0.00 -22.44 5.15 2,700.00 48.39 136.50 2,417.97 2,258.97 0.00 0.00 5.64 2,800.00 48.39 136.50 2,484.37 2,325.37 0.00 0.00 6.14 2,876.23 48.39 136.50 2,535.00 2,376.00 0.00 0.00 6.64 Base W Sak 2,900.00 48.39 136.50 2,550.78 2,391.78 0.00 0.00 6.64 2,951.53 48.39 136.50 2,585.00 2,426.00 0.00 0.00 7.12 10-3/4"x13-112" 4/5/2016 10:13:06AM Page 3 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: 39+120 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp09[Nurse] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 3,000.00 48.39 136.50 2,617.19 2,458.19 0.00 0.00 7.12 3,100.00 48.39 136.50 2,683.60 2,524.60 0.00 0.00 7.73 3,200.00 48.39 136.50 2,750.01 2,591.01 0.00 0.00 8.49 3,300.00 48.39 136.50 2,816.42 2,657.42 0.00 0.00 9.37 3,400.00 48.39 136.50 2,882.83 2,723.83 0.00 0.00 10.32 3,500.00 48.39 136.50 2,949.23 2,790.23 0.00 0.00 11.35 3,514.71 48.39 136.50 2,959.00 2,800.00 0.00 0.00 12.42 C-80 3,600.00 48.39 136.50 3,015.64 2,856.64 0.00 0.00 12.42 3,700.00 48.39 136.50 3,082.05 2,923.05 0.00 0.00 13.52 3,800.00 48.39 136.50 3,148.46 2,989.46 0.00 0.00 14.66 3,900.00 48.39 136.50 3,214.87 3,055.87 0.00 0.00 15.81 4,000.00 48.39 136.50 3,281.28 3,122.28 0.00 0.00 16.99 4,100.00 48.39 136.50 3,347.68 3,188.68 0.00 0.00 18.17 4,200.00 48.39 136.50 3,414.09 3,255.09 0.00 0.00 19.37 4,300.00 48.39 136.50 3,480.50 3,321.50 0.00 0.00 20.58 4,400.00 48.39 136.50 3,546.91 3,387.91 0.00 0.00 21.80 4,500.00 48.39 136.50 3,613.32 3,454.32 0.00 0.00 11.80 4,600.00 48.39 136.50 3,679.73 3,520.73 0.00 0.00 12.23 4,700.00 48.39 136.50 3,746.14 3,587.14 0.00 0.00 12.67 4,800.00 48.39 136.50 3,812.54 3,653.54 0.00 0.00 13.11 4,900.00 48.39 136.50 3,878.95 3,719.95 0.00 0.00 13.56 5,000.00 48.39 136.50 3,945.36 3,786.36 0.00 0.00 14.02 5,100.00 48.39 136.50 4,011.77 3,852.77 0.00 0.00 14.48 5,200.00 48.39 136.50 4,078.18 3,919.18 0.00 0.00 14.94 5,300.00 48.39 136.50 4,144.59 3,985.59 0.00 0.00 15.41 5,400.00 48.39 136.50 4,211.00 4,052.00 0.00 0.00 15.88 5,500.00 48.39 136.50 4,277.40 4,118.40 0.00 0.00 16.35 5,597.27 48.39 136.50 4,342.00 4,183.00 0.00 0.00 16.83 C-50 5,600.00 48.39 136.50 4,343.81 4,184.81 0.00 0.00 16.83 5,700.00 48.39 136.50 4,410.22 4,251.22 0.00 0.00 17.31 5,800.00 48.39 136.50 4,476.63 4,317.63 0.00 0.00 17.79 5,900.00 48.39 136.50 4,543.04 4,384.04 0.00 0.00 18.28 5,993.30 48.39 136.50 4,605.00 4,446.00 0.00 0.00 18.76 C-40 6,000.00 48.39 136.50 4,609.45 4,450.45 0.00 0.00 18.76 6,006.22 48.39 136.50 4,613.58 4,454.58 0.00 0.00 18.79 Start 3.5°/100'DLS,-116.04°TF,for 3129.74' 6,100.00 47.02 132.47 4,676.70 4,517.70 3.50 -116.04 19.01 6,200.00 45.72 127.98 4,745.72 4,586.72 3.50 -113.32 19.00 6,247.43 45.17 125.78 4,779.00 4,620.00 3.50 -110.22 18.88 C-37 6,300.00 44.60 123.30 4,816.25 4,657.25 3.50 -108.68 18.88 6,400.00 43.69 118.45 4,888.03 4,729.03 3.50 -106.92 18.62 4/5/2016 10:13:06AM Page 4 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: 39+120 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp09[Nurse] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 6,500.00 42.98 113.45 4,960.79 4,801.79 3.50 -103.44 18.23 6,552.10 42.70 110.80 4,999.00 4,840.00 3.50 -99.80 17.69 Growler-AA 6,600.00 42.50 108.34 5,034.26 4,875.26 3.50 -97.86 17.69 6,700.00 42.24 103.16 5,108.16 4,949.16 3.50 -96.05 17.02 6,800.00 42.23 97.96 5,182.23 5,023.23 3.50 -92.22 16.22 2S W16-Toe 6,900.00 42.44 92.77 5,256.17 5,097.17 3.50 -88.36 15.33 7,000.00 42.89 87.64 5,329.72 5,170.72 3.50 -84.53 14.36 7,100.00 43.56 82.63 5,402.61 5,243.61 3.50 -80.76 13.35 7,200.00 44.45 77.75 5,474.55 5,315.55 3.50 -77.10 12.33 7,252.70 45.00 75.25 5,512.00 5,353.00 3.50 -73.60 11.34 Top Cairn 7,300.00 45.54 73.05 5,545.29 5,386.29 3.50 -71.82 11.34 7,325.77 45.85 71.86 5,563.29 5,404.29 3.50 -70.27 10.42 2S W16-Heel 7,386.06 46.62 69.15 5,605.00 5,446.00 3.50 -69.44 10.42 Top Bermuda 7,400.00 46.81 68.53 5,614.56 5,455.56 3.50 -67.56 10.42 7,495.36 48.18 64.40 5,679.00 5,520.00 3.50 -67.13 9.60 Base Bermuda 7,500.00 48.25 64.20 5,682.09 5,523.09 3.50 -64.35 9.60 7,565.09 49.27 61.50 5,725.00 5,566.00 3.50 -64.21 8.91 C-35 7,600.00 49.85 60.08 5,747.65 5,588.65 3.50 -62.43 8.91 7,700.00 51.59 56.15 5,810.97 5,651.97 3.50 -61.51 8.39 7,800.00 53.45 52.42 5,871.84 5,712.84 3.50 -59.02 8.06 7,900.00 55.42 48.86 5,930.01 5,771.01 3.50 -56.75 7.92 8,000.00 57.49 45.47 5,985.28 5,826.28 3.50 -54.68 7.98 8,089.28 59.41 42.58 6,032.00 5,873.00 3.50 -52.81 8.20 Top HRZ(K-2 mkr) 8,100.00 59.65 42.24 6,037.44 5,878.44 3.50 -51.30 8.20 8,200.00 61.88 39.15 6,086.29 5,927.29 3.50 -51.12 8.57 8,262.38 63.31 37.29 6,115.00 5,956.00 3.50 -49.61 9.06 Upper Kalubik(base HRZ) 8,300.00 64.18 36.19 6,131.64 5,972.64 3.50 -48.76 9.06 8,400.00 66.54 33.35 6,173.34 6,014.34 3.50 -48.27 9.64 8,500.00 68.94 30.60 6,211.23 6,052.23 3.50 -47.08 10.29 8,590.17 71.15 28.20 6,242.00 6,083.00 3.50 -46.04 10.99 Lower Kalubik(K-1 mkr) 8,600.00 71.39 27.94 6,245.16 6,086.16 3.50 -45.22 10.99 8,700.00 73.88 25.36 6,275.00 6,116.00 3.50 -45.14 11.73 8,800.00 76.39 22.84 6,300.66 6,141.66 3.50 -44.37 12.49 8,900.00 78.94 20.38 6,322.02 6,163.02 3.50 -43.72 13.27 8,955.52 80.36 19.03 6,332.00 6,173.00 3.50 -43.20 14.07 Kuparuk C(Top C4) 4/5/2016 10:13:06AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: 39+120 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp09[Nurse] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (°) (usft) 9,000.00 81.50 17.96 6,339.02 6,180.02 3.50 -42.95 14.07 9,020.84 82.03 17.46 6,342.00 6,183.00 3.50 -42.79 14.87 A5 9,100.00 84.07 15.57 6,351.58 6,192.58 3.50 -42.71 14.87 9,135.95 85.00 14.72 6,355.00 6,196.00 3.50 -42.49 15.16 2S-Nurse 1.Heel-2S-Nurse 1.Heel_Cirlce 9,135.97 85.00 14.72 6,355.00 6,196.00 0.00 0.00 15.16 Hold for 45.89' 9,181.84 85.00 14.72 6,359.00 6,200.00 0.00 0.00 15.31 A4 9,181.86 85.00 14.72 6,359.00 6,200.00 0.00 0.00 15.31 Adjust TF to 0°,for 20'-7-5/8"x 9-7/8"by 11" 9,200.00 85.00 14.72 6,360.58 6,201.58 0.00 0.00 15.32 9,201.84 85.00 14.72 6,360.74 6,201.74 0.00 0.00 15.32 9,201.86 85.00 14.72 6,360.74 6,201.74 0.00 0.00 15.32 Start 2°/100'DLS,0°TF,for 301.95' 9,300.00 86.96 14.72 6,367.62 6,208.62 2.00 -0.01 15.30 9,400.00 88.96 14.72 6,371.18 6,212.18 2.00 -0.01 15.41 9,500.00 90.96 14.72 6,371.24 6,212.24 2.00 -0.01 15.66 9,503.80 91.04 14.72 6,371.17 6,212.17 2.00 -0.01 15.67 9,503.82 91.04 14.72 6,371.17 6,212.17 0.00 0.00 15.67 Hold for 5634.2' 9,600.00 91.04 14.72 6,369.43 6,210.43 0.00 0.00 16.04 9,700.00 91.04 14.72 6,367.62 6,208.62 0.00 0.00 16.55 9,800.00 91.04 14.72 6,365.80 6,206.80 0.00 0.00 17.16 9,900.00 91.04 14.72 6,363.99 6,204.99 0.00 0.00 17.88 10,000.00 91.04 14.72 6,362.18 6,203.18 0.00 0.00 18.69 10,100.00 91.04 14.72 6,360.36 6,201.36 0.00 0.00 19.57 10,200.00 91.04 14.72 6,358.55 6,199.55 0.00 0.00 20.52 10,300.00 91.04 14.72 6,356.73 6,197.73 0.00 0.00 21.53 10,400.00 91.04 14.72 6,354.92 6,195.92 0.00 0.00 22.59 10,500.00 91.04 14.72 6,353.11 6,194.11 0.00 0.00 23.69 10,600.00 91.04 14.72 6,351.29 6,192.29 0.00 0.00 24.83 10,700.00 91.04 14.72 6,349.48 6,190.48 0.00 0.00 17.23 10,800.00 91.04 14.72 6,347.67 6,188.67 0.00 0.00 17.50 10,900.00 91.04 14.72 6,345.85 6,186.85 0.00 0.00 17.79 11,000.00 91.04 14.72 6,344.04 6,185.04 0.00 0.00 18.09 11,100.00 91.04 14.72 6,342.23 6,183.23 0.00 0.00 18.41 11,200.00 91.04 14.72 6,340.41 6,181.41 0.00 0.00 18.73 11,300.00 91.04 14.72 6,338.60 6,179.60 0.00 0.00 19.07 11,400.00 91.04 14.72 6,336.79 6,177.79 0.00 0.00 19.42 11,500.00 91.04 14.72 6,334.97 6,175.97 0.00 0.00 19.78 11,600.00 91.04 14.72 6,333.16 6,174.16 0.00 0.00 20.16 11,700.00 91.04 14.72 6,331.35 6,172.35 0.00 0.00 20.54 11,800.00 91.04 14.72 6,329.53 6,170.53 0.00 0.00 20.93 4/5/2016 10:13:06AM Page 6 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit ND Reference: 39+120 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp09[Nurse] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (0) (usft) (usft) (°/100usft) (0) (usft) 11,900.00 91.04 14.72 6,327.72 6,168.72 0.00 0.00 21.33 12,000.00 91.04 14.72 6,325.91 6,166.91 0.00 0.00 21.73 12,100.00 91.04 14.72 6,324.09 6,165.09 0.00 0.00 22.15 12,200.00 91.04 14.72 6,322.28 6,163.28 0.00 0.00 22.57 12,300.00 91.04 14.72 6,320.47 6,161.47 0.00 0.00 23.00 12,400.00 91.04 14.72 6,318.65 6,159.65 0.00 0.00 23.43 12,500.00 91.04 14.72 6,316.84 6,157.84 0.00 0.00 23.88 12,600.00 91.04 14.72 6,315.03 6,156.03 0.00 0.00 24.32 12,700.00 91.04 14.72 6,313.21 6,154.21 0.00 0.00 24.78 12,800.00 91.04 14.72 6,311.40 6,152.40 0.00 0.00 25.23 12,900.00 91.04 14.72 6,309.58 6,150.58 0.00 0.00 25.70 13,000.00 91.04 14.72 6,307.77 6,148.77 0.00 0.00 26.16 13,100.00 91.04 14.72 6,305.96 6,146.96 0.00 0.00 26.64 13,200.00 91.04 14.72 6,304.14 6,145.14 0.00 0.00 27.11 13,300.00 91.04 14.72 6,302.33 6,143.33 0.00 0.00 27.59 13,400.00 91.04 14.72 6,300.52 6,141.52 0.00 0.00 28.07 13,500.00 91.04 14.72 6,298.70 6,139.70 0.00 0.00 28.56 13,600.00 91.04 14.72 6,296.89 6,137.89 0.00 0.00 29.05 13,700.00 91.04 14.72 6,295.08 6,136.08 0.00 0.00 29.55 13,800.00 91.04 14.72 6,293.26 6,134.26 0.00 0.00 30.04 13,900.00 91.04 14.72 6,291.45 6,132.45 0.00 0.00 30.54 14,000.00 91.04 14.72 6,289.64 6,130.64 0.00 0.00 31.04 14,100.00 91.04 14.72 6,287.82 6,128.82 0.00 0.00 31.55 14,200.00 91.04 14.72 6,286.01 6,127.01 0.00 0.00 32.06 14,300.00 91.04 14.72 6,284.20 6,125.20 0.00 0.00 32.57 14,400.00 91.04 14.72 6,282.38 6,123.38 0.00 0.00 33.08 14,500.00 91.04 14.72 6,280.57 6,121.57 0.00 0.00 33.59 14,600.00 91.04 14.72 6,278.76 6,119.76 0.00 0.00 34.11 14,700.00 91.04 14.72 6,276.94 6,117.94 0.00 0.00 34.63 14,800.00 91.04 14.72 6,275.13 6,116.13 0.00 0.00 35.15 14,900.00 91.04 14.72 6,273.32 6,114.32 0.00 0.00 35.67 15,000.00 91.04 14.72 6,271.50 6,112.50 0.00 0.00 36.19 15,100.00 91.04 14.72 6,269.69 6,110.69 0.00 0.00 36.72 2K-Pad T5 15,138.00 91.04 14.72 6,269.00 6,110.00 0.00 0.00 36.92 TD:15138.02'MD,6269'ND-2S-Nurse 2.Toe-2S-Nurse 2.Toe_Circle 4/5/2016 10:13:06AM Page 7 COMPASS 5000.1 Build 74 • Schlurnberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: 39+120 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp09[Nurse] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 2,951.53 2,585.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 9,181.86 6,359.00 7-5/8"x 9-7/8"by 11" 7-5/8 11 15,138.02 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 1,397.08 1,373.00 Base permafrost(?) 3,514.71 2,959.00 C-80 7,386.06 5,605.00 Top Bermuda 2,876.23 2,535.00 Base W Sak 8,590.17 6,242.00 Lower Kalubik(K-1 mkr) 6,552.10 4,999.00 Growler-AA 5,993.30 4,605.00 C-40 279.00 279.00 top T-3 Sand 0.00 5,597.27 4,342.00 C-50 8,262.38 6,115.00 Upper Kalubik(base HRZ) 7,565.09 5,725.00 C-35 9,020.84 6,342.00 A5 9,181.84 6,359.00 A4 6,247.43 4,779.00 C-37 8,089.28 6,032.00 Top HRZ(K-2 mkr) 7,495.36 5,679.00 Base Bermuda 8,955.52 6,332.00 Kuparuk C(Top C4) 1,940.66 1,859.00 Top W Sak(W Sak D) 374.00 374.00 K-15 Marker 7,252.70 5,512.00 Top Cairn Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 400.00 400.00 0.00 0.00 KOP:Start 1.5°/100'DLS, 170°TF,for 200.09' 600.09 600.00 -5.16 0.91 Start 2.5°/100'DLS,0°TF,for 743.21' 1,343.31 1,323.00 -160.29 28.26 Hold for 107.54' 1,450.85 1,423.00 -199.25 35.13 Start 3°/100'DLS,-50.88°TF,for 1070.92' 2,521.77 2,299.61 -696.73 353.27 Hold for 3484.46' 6,006.22 4,613.58 -2,586.58 2,146.44 Start 3.5°/100'DLS,-116.04°TF,for 3129.74' 9,135.97 6,355.00 -1,610.30 3,925.98 Hold for 45.89' 9,181.86 6,359.00 -1,566.08 3,937.59 Adjust TF to 0°,for 20' 9,201.86 6,360.74 -1,546.81 3,942.65 Start 2°/100'DLS,0°TF,for 301.95' 9,503.82 6,371.17 -1,255.07 4,019.27 Hold for 5634.2' 15,138.00 6,269.00 4,193.42 5,450.19 TD: 15138.02'MD,6269'TVD Checked By: Approved By: Date: 4/5/2016 10:13:06AM Page 8 COMPASS 5000.1 Build 74 • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-05 Plan: 2S-05 2S-05wp09[Nurse] Clearance Summary Anticollision Report Permit Pack 04 April, 2016 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2S Pad-Plan:2S-05-Plan:2S-05-2S-05wp09[Nurse] Well Coordinates: Datum Height: 39+120 @ 159.O0usft(Doyon142) Scan Range: 0.00 to 15,138.02 usft.Measured Depth. Scan Radius is 1,709.90 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 • • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-05-2S-05wp09[Nurse] Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2S Pad-Plan:2S-05-Plan:2S-05-2S-05wp09[Nurse] Scan Range: 0.00 to 15,138.02 usft.Measured Depth. Scan Radius is 1,709.90 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 2S Pad 2S-01-2S-01-2S-01 349.36 117.14 349.36 110.93 350.00 18.864 Centre Distance Pass-Major Risk 2S-01-2S-01-2S-01 399.35 117.42 399.35 110.38 400.00 16.678 Clearance Factor Pass-Major Risk 2S-02-2S-02-2S-02 261.50 89.23 261.50 82.39 250.00 13.043 Centre Distance Pass-Major Risk 25-02-2S-02-2S-02 361.46 89.86 361.46 81.60 350.00 10.887 Clearance Factor Pass-Major Risk 2S-03-2S-03-2S-03 324.31 57.75 324.31 51.99 325.00 10.020 Centre Distance Pass-Major Risk 2S-03-2S-03-2S-03 399.23 58.27 399.23 51.21 400.00 8.254 Clearance Factor Pass-Major Risk 2S-03-2S-03PB1-2S-03PB1 324.31 57.75 324.31 51.99 325.00 10.020 Centre Distance Pass-Major Risk 2S-03-2S-03PB1-2S-03PB1 399.23 58.27 399.23 51.21 400.00 8.254 Clearance Factor Pass-Major Risk 2S-03-2S-03PB1-2S-03wp09.1[Bamboo] 349.50 59.91 349.50 53.70 350.00 9.650 Centre Distance Pass-Major Risk 2S-03-2S-03PB1-2S-03wp09.1[Bamboo] 449.44 60.64 449.44 52.77 450.00 7.707 Clearance Factor Pass-Major Risk 2S-04-2S-04-2S-04 511.40 26.47 511.40 17.75 500.00 3.036 Centre Distance Pass-Major Risk 2S-04-2S-04-2S-04 710.46 28.07 710.46 16.91 700.00 2.515 Clearance Factor Pass-Major Risk 2S-04-2S-04PB1-2S-04PB1 511.40 26.47 511.40 17.75 500.00 3.036 Centre Distance Pass-Major Risk 2S-04-2S-04PB1-2S-04PB1 710.46 28.07 710.46 16.91 700.00 2.515 Clearance Factor Pass-Major Risk 2S-07-2S-07-2S-07 39.00 59.67 39.00 58.44 27.50 48.521 Centre Distance Pass-Major Risk 2S-07-2S-07-2S-07 910.85 62.85 910.85 43.22 900.00 3.201 Clearance Factor Pass-Major Risk 2S-08-2S-08-2S-08 286.49 88.79 286.49 83.74 275.00 17.556 Centre Distance Pass-Major Risk 2S-08-2S-08-2S-08 361.46 89.37 361.46 83.05 350.00 14.158 Clearance Factor Pass-Major Risk 2S-10-25-10-2S-10 833.50 141.74 833.50 128.94 825.00 11.067 Centre Distance Pass-Major Risk 2S-10-2S-10-2S-10 881.73 142.19 881.73 128.67 875.00 10.516 Clearance Factor Pass-Major Risk 2S-11-2S-11-2S-11 399.29 178.81 399.29 171.81 400.00 25.561 Centre Distance Pass-Major Risk 2S-11-2S-11-2S-11 499.49 179.79 499.49 171.25 500.00 21.053 Clearance Factor Pass-Major Risk 2S-11- 2S-11-2S-11wp09[Great White] 374.50 180.28 374.50 173.64 375.00 27.130 Centre Distance Pass-Major Risk 2S-11- 25-11-2S-11wp09[Great White] 524.72 181.32 524.72 172.65 525.00 20.921 Clearance Factor Pass-Major Risk Plan:2S-06-Plan:2S-06-2S-06wp06[Salmon] 510.98 30.11 510.98 21.30 500.00 3.416 Centre Distance Pass-Major Risk Plan:2S-06-Plan:2S-06-2S-06wp06[Salmon] 585.73 30.55 585.73 20.63 575.00 3.077 Clearance Factor Pass-Major Risk Plan:2S-09-Plan:2S-09-25-09wp06[Tiger] 461.07 120.17 461.07 112.17 450.00 15.034 Centre Distance Pass-Major Risk Plan:2S-09-Plan:2S-09-25-09wp06[Tiger] 911.32 123.33 911.32 109.03 900.00 8.621 Clearance Factor Pass-Major Risk 04 April,2016- 16:12 Page 2 of 5 COMPASS • • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-05-2S-05wp09[Nurse] Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2S Pad-Plan:2S-05-Plan:2S-05-2S-05wp09[Nurse] Scan Range: 0.00 to 15,138.02 usft.Measured Depth. Scan Radius is 1,709.90 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:2S-12-Plan:2S-12-2S-12wp07[Bull] 361.00 210.19 361.00 203.80 350.00 32.904 Centre Distance Pass-Major Risk Plan:2S-12-Plan:25-12-2S-12wp07[Bull] 436.07 210.69 436.07 203.08 425.00 27.691 Clearance Factor Pass-Major Risk Plan:2S-315-Plan:2S-315-2S-315wp02 400.00 240.40 400.00 233.31 400.00 33.908 Centre Distance Pass-Major Risk Plan:2S-315-Plan:2S-315-2S-315wp02 450.11 240.70 450.11 232.87 450.00 30.774 Clearance Factor Pass-Major Risk Survey tool proaram From To Survey/Plan Survey Tool (usft) (usft) 39.00 1,000.00 2S-05wp09[Nurse] GYD-GC-SS 1,000.00 2,000.00 2S-05wp09[Nurse] MWD 1,000.00 2,951.53 2S-05wp09[Nurse] MWD+IFR-AK-CAZ-SC 2,951.53 4,451.53 2S-05wp09[Nurse] MWD 2,951.53 9,181.86 2S-05wp09[Nurse] MWD+IFR-AK-CAZ-SC 9,181.86 10,681.86 2S-05wp09[Nurse] MWD 9,181.86 15,138.02 2S-05wp09[Nurse] 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. 04 April,2016- 16:12 Page 3 of 5 COMPASS II • 16:19, April 04 201! Ladder View 2S-05wp09[Nurse]] The Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors 0 0 2 E E r4 ui 2. F m F ,O .. n m 3 c i } a ? 'T q o '9 0 9 r IWJCN H �rn CO CO CO r t 300— 111 �II i it . I �I i, Il lid I 01111111 �II , npil ii,1 p10j111III , jl1 1 , 2 I illieir III0OI t11 f a - ........mn4IIIC IIII L,i,,, 'I II I I I w IIIA;/II lir I II u ll,l, 'IA l I� � II, � / I . mnn 41111III t ' 150— milli 'I I AIII� IIII I LA '',' ''II I I i 1- / gIIlilII�l1A. !w ,nmq IlI11 I'111 III VIII/ I I _ ,A 0 U ,'°1 11IIIlllIt 101 IIIII.II'I ........................ 111oIlIl IIII 0111 l:,t AlIr1111" ....61.011111 0 \, 1 I 1 I 1 I 1 I 1 1 I I I I I 1 1 1 I I I I I 1 1 1 1 Equivelant Magnetic Distance v 1500 3000 4500 6000 7500 9000 10500 Displayed interval could be less than entire well:Measured Depth 39.00 To 15138.02 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 1000.00 25-05wp09[Nurse] (Plan: 2S-05) GYD-GC-SS 2585.G1r951.53 10-3/4"x 13-1/2" 1000.00 2000.00 25-05wp09[Nurse] (Plan: 2S-05) MWD 6359.®181786/8"x 9-7/8" by 11" 1000.00 2951.53 25-05wp09[Nursel (Plan: 2S-05) MWD+IFR-AK-CAZ-SC 6269:M138.02 4-1/2"x 6-3/4" 2951.53 4451.53 25-05wp09[Nurse] (Plan: 2S-05) MWD 2951.53 9181.86 25-05wp09[Nurse] (Plan: 2S-05) MWD+IFR-AK-CAZ-SC 9181.8610681.86 25-05wp09[Nurse] (Plan: 2S-05) MWD 9181.8615138.02 25-05wp09[Nurse] (Plan: 2S-05) MWD+IFR-AK-CAZ-SC I 7. a o E I E I m 3 0= fdlU1 N y Ml N N 60 "i1.dI' . N . ,. '41``1.401110111111111r1i fly ,/// C 11 111 111 / , m MMO 1 , L 1111 ®,I0 --11,1111111 • u,�l Olp \s I 1 I1 1 1 I 1 I I I I I I I I I I I 1 1 1 1 I 1 I I I 1 0 '‘ 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth Equivelant Magnetic Distance • Sy 4UU 2S-05wp09[Nurse] •MD Inc Azi TVD Dleg TFace Target 400 590 39.00 0.00 0.00 39.00 0.00 0.00 39.00 To 15138.02 400.00 0.00 0.00 400.00 0.00 0.00 590 770 600.09 3.00 170.00 600.00 1.50 170.00 770 960 1343.31 21.58 170.00 1323.00 2.50 0.00 16:19,April 04 2016 1450.85 21.58 170.00 1423.00 0.00 0.00 960 - 1140 2521.77 48.39 136.50 2299.60 3.00 -50.88 CASING DETAILS 6006.22 48.39 136.50 4613.56 0.00 0.00 1140 1330 9135.97 85.00 14.72 6355.00 3.50 -116.04 2S-Nurse 1.Heel TVD MD Name 9181.86 85.00 14.72 6359.00 0.00 0.00 1330 1510 2585.00 2951.53 10-3/4" x 13-1/2" 9201.86 85.00 14.72 6360.74 0.00 0.00 6359.00 9181.88-5/8•• x 9-7/8•• by 11" 1510 1700 6269.00 15138.02 4-1/2" x 6-3/4" 9503.82 91.04 14.72 6371.17 2.00 0.00 15138.02 91.04 14.72 6269.00 0.00 0.00 2S-Nurse 2.Toe 1700 2260 ea��x 2260 2830 _05,09[x9699] ,01,9:2S-O.N. 2830 3390 o9[x�99, [9199: --- o9[x�99, ,2199: 2S-0...1.x-11K-GE-x 3390 _. 3950 = 6 o9 a*•6,9, [9199:2s-9.,uro 9181.88 15100.02 25- 9609[x00699, 10199:25-088.009x-nx-uz-0C 3950 4510 4510 -- 5070 5070 5640 5640 6200 6200 7320 0/360 7320 - 8430 2S-06wp06 [Salmon] a \ 1 &lai w , 8430 9550 ou'w4 i r oi=4-4y 9550 10670 -30/330, af► �1lrs ,,. 4 30 2S-10 - �hr�'1� $ j Vr 2S-01 10670 11790 � j �►, , +,�/ 11790 12900 �l ��� 180" -- .`'4n' 0' -� .4-%•32' �4.1O 4000.• 6dl' � V'O�1A -, " 'dom.. 12900 14020 2S-08---- iT�;1i� .Q ♦t /�� 165 dra .�•�4 •� .,� �;�®p® �acg1+� 14020 15138 40 r.�Q� ;`ro. 15 +►► i. lj M.d®to► ;,4:,�p:h Q deffiozpriv,„:".;;•ur.,,i;,..L, 60/36691. es ® 9 y► -- a 1•� 1� N- �s �`P 2S-04 � �1� ®'1 `9.. -_•��./. 1 �a .r. � ►�% �i■i.�'� tia 60 2S-04PB1 e���- �� %'�� /V i,pr [til,,;.:7 e • i:. W 4 `leA®<-''ro.':rw�t►W f451,..,,,T .--11-„,,,,....fel•,... ....fp-v., ',pt..", ..0.„ \ .......4,,,,donew.,-2...100 _ ...vie;e..Z k 4,, ..,_...... -1-1,/,V Fte.;'.. 11.,;:1.0., , 4...»`...-- • wool-0MM - 2S-12wp07 [Bull] i�1 ii44 �I�~ :S '0' `,�IM� `z 11fe+`,1►�7q, '►ai���, . .r ,, � 1iv� Jam &- :73 1 ♦.�eN • t1•• q7 C 1'♦��1.,,41 iij e Otti.0v.: ,�4, , ,•9s1 fF' Ia.... " �' ,, 90/270 ao �� � �Wig.44■ alka'„,; t ` ,,p ti�� ,71 �-90 dikt, . Rp �� •e, `'' i �-- {� 2S-03 , .,7170..../) 1 t.'i•:fol, 60 ' " / / 2S 03PB1 2S-11 1►•��� �+ ' Fay.! 90 - / -4-i4. :-; / 2 -07 • 2S-09wp06 [figerl '2'�"�� 120 i /j= % ► ' , 120 135 %/ C_ ,...4 iiiiimmifflir 150 / '7' ��, 7y� *444. ��'. 1 165 hfr /0 i '' , �j. �✓�,�. 180 /���� �,� � ��i�,�� 195 / OA .SCG►='�S 150/210 Xfor 210 ,it.. '150 �,11�♦r_ 2S-02 -180/180 411 • 16:26,April 04 2016 Easting(2500 usft/in) I , , , , I , , , 1I , 1 1 , 1ii , , Iiir I1 , I , ! Ur I II , J , Ii ] 1 I I , , , IJ , IIIII 111111111111111 „ ii I III II II , „ I , , , , Ii (NOT a Spider) ;§-111Up09[Great White] - 2S-09wp06[Tiger] 2S-04 2S-07 _ 2S-05wp09[Nurse] Kuparuk 2S Pad `�ifir .,„,.......i„.„0,,,,..4� 2s-o2 -_ . c \41141111 l' 4 ' , o _.5 a _ _. ., _ -N _csi _ _ ,,, O C— C a f „IvO _ • z _ 7 2S-03PB1 2S-01 - _ 2S-315 .02 2S-12wp07[B'i]2S-08 2S-10 - 2S-06wp06[Salmon] pg 25-0 wp09.1[Bamboo] - iiiiiii1 1111iilliiIiIiiii 1 1 iiiiiiiiiiiiilliiiiiiiiIiiiIiiilliiiiIiiiI iiIiiiiiiiiiiIiIiiiiiii 1 I 1 1 iiii Easting(2500 usft/in) AC Flipbook • • Casing Details Survey Rogram TVD MD Name Depth From Depth To Survey/Plan Tool -,- 2S-05wp09[Nurse] 2585.P15 295+-53 +0314"xt3-th" 39.00 +000.00 25-o5wpo9[Nurse](PWn:2505) GYDLC-55 39 400 635900 gt8t.86 y.5/8"x¢7/8"by tt 25-15 Nurse Plan:25a MWD 6269.00 t5t38.o2 qqn 6-3/q" 100000 x000uo SwPo9[ ]( 5) +000.00 2951.53 2So5wp09[Nurse](Plan:25-05) MWD.IFR-AK-CAZ-SC 295+53 945+53 25o5wpoq[Nurse]Man:2505) MWD --"""-." O0 295153 9+88.86 2So5wpog[Nurse](Plan:x505) MWD.IFR-AK- SC-X 400 590 39• To o 1000 f00 9+8+.86 +15688.86 25-o5wpog[[Nurx](Plan:2505) MWD g+8+.86 25+38.15x 25-DSwPoq[Nurse](Plan:2505) MWD.IFRAK-CAZ-5C 2S-o6wpo6 [Salmon] 590 770 MD Azi 02:.3.0640 25--03wpo9.1[Bamboo] 770 960 39.00 0.00 400.00 0.00 90 ° 96o 1140 -30 / 33 25--153 04SO4Q25- OjPB1 1,40 ,330 ,450.85 170.00 -� it4►'ra�►. 2521.77 136.50 �A% - 15101700 5 77 ��, ,,Ira- (1�l 6006.22 136.50 -60 / 300 I, �`'i 4, !';�. ,A��ito 60 1700 2260 9135.97 14.72 1-1 25-07 !/4.lIP►.,4 .4 �� 2260 2830 9181.86 14.72 , t�2 ®1 �:rr.►i!�i�4, ' ti p � 4171,001# ,:. 2830 3390 201.86 1 2 1 ••►"-' '' � ���/�I� �+, f a' �+`SPI 9 4.7 .\ .#.462.4,fir®.O, t 9503.82 14.72 ►1�r����, 1, 3390 3950 ��Ad� ~�, 2 al��VS\\\� 395015138.02 14.7 � � Ad __ 50 -9° / 27°� ,I,ilf/ '� ,, �rwrit25--o4PB1 L �. 0 4 , ,� �jl 9 4510 5070 , 5070 5640 25--152 25-08 30 5640 6200 6200 7320 -120 / 240 120 7320 8430 6 0 8430 9550 9550 10670 10670 11790 -150 / 210 --. .. 150 90 . 11790 12900 -180 /180 12900 14020 14020 15138 16:33,April 04 2016 0 • Casing Details Surve Pro y gram - MD Name Depth From Depth To Survey/Plan Tool 39 400 2S-05wpo9[Nurse] 6585.00 918153 "x6-2/x 13 II" 39'00 000.00 25-o5wpo9[Nurse](Plan:2505) GYDLCSS 6585.o. 2+8+.86 li/8"x47/8"by++" loop oo i5-o5wpo9[Nurse](Plan:2S o5) MWD 6262.00 +5138.ox q-+/i"xb-3/9" iS-0 Nurse Plan: 1000.00 295+.53 Swpo9[ ]( iS.o 5) MWD+IFR- AK-CAZ-X �000 0o To 2000 00 95+53 995+5 S 3 ioSwPog(Nurse(Plan:i5o5) MWD 695+.53 9181.86 2S-o5p09[Nurse((Plan:2S-o5) MWD+IFR AK-CAZ-SC 400 590 2+8+.86 to681.86 25-o5wpo9[Nurse](Plan:2S o5) MWD 9282.86 15238.o2 25-o5wpog[Nurse](Plan:2S o5) MWD+IFR-AK CAZ-SC 25-0 590 77o MD Azi 2S-o4PB1 4 0 / 360 77o 960 39.0o 0.0o 400.00 0.00 ljrrnMl9 96o 1140 -30 /33•�/"440031*�' ■li o 600.09 170.00 ������ ��i� ��/��i�� 1140 1330 1343.31 170.00 -"=®�:�� �ffaef�Mi _oy��� ,Arpm�, 1330 1510 1450.85 170.00 �b�:(�r kk, �.� F• ♦ 1510 1700 2521.77 136.50 - �� �;;;�! 6006.22 136.50"0 /300 x '� 6o 1700 2260 9135.97 14.72 � � ,t�. 2S-07.,0:-0.-...--":"7" , �� ' 2260 2830 9181.86 14.72 . 4.���►� �; „. v y,, 9201.86 14.72 /�`c ti` 30 2830 3390 9503.82 14.72 �� 3390 3950 15138.02 14.72 Alk 0 10 OV 395 45 -90 270 --__ 3.1go I161 ,- 4510 5070 /Ptsfr 5070 5640 30 5640 6200 6200 7320 -P 0 / 240 � 120 7320 8430 6o 8430 9550 9550 10670 / \ 10670 11790 -150 / 210 150 90 11790 12900 -180 /180 12900 14020 14020 15138 16:34,April 04 2016 • • Casing Details Survey Program ND MD Name Depth From Depth To Survey/Plan Tool 25-05wp09[Nurse] 2585•-00 2951.53 a3/q"x131/z" 635900 9181.866269.-0-0 15138.02 ]5/8"x 9)/8"by 0• 1000.00 44/2"s63/4" 390-0 aoo.00 25-oSwPo9[Nurse](Plan:2S o5)-0-0-0. 25-o5wpo9[Nurze](PUn:25 o5) GYDLC-SS 39 400 MWD 1000.00 2x951.5533 25.o5wpo9[Nurse](Plan:2S-05) MWDHFRAK-CAZ-SC 295153 4451.53 x5-o5wp09[Nurse](Plan:25-05) MWD 2000.00 To 15138 02 2951.53 9181.86 2,05w009(Nurse](Plan:25425) MWD"IFRAK-AZX 400 590 981.86 10681.86 25-o5wpo9[Nurse Plan:2545) MWD 9181.86 15138.a2 x5-o5wPo9[Nurse](PWn:xSoS) MWDelFR-AK-CAZ-SC 590 77o MD Azi 0 / 360 770 960 39.00 0.00 400.00 0.00 -30 •/ 33• 90 0 960 1140 600.09 170.00 1140 1330 1343.31 170.00 1330 1510 1450.85 170.00 `v 2521.77 136.50 6 o = 15101700 6006.22 136.5660 /300 6o 1700 2260 9135.97 14.72 2260 2830 9181.86 14.72 9201.86 14.72 316283o 3390 9503.82 14.72 3390 3950 15138.02 14.72 -90 / 270 90 3950 4510 \ 4510 5070 5070 564o 30 564o 62oo 6200 7320 -120 / 240 120 732o 843o 6 0 8430 9550 9550 10670 10670 11790 -150 / 210 150 go `, 11790 12900 -180 / 180 12900 14020 14020 _ 15138 X635,April 04 2016 ! ! ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-05 Plan: 2S-05 Plan: 2S-05wp09[Nurse] Report - Errors To calculate actual errors: 04 April, 2016 • • Schlumberger Comments apply g pp Y Report- Errors the line before it. Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Site Kuparuk 2S Pad Project: Kuparuk River Unit TVD Reference: 39+120 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp09[Nurse] Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan:2S-05 Well Position +N/-S usft Northing: usfl Latitude: +E/-W usft Easting: usfl Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore Plan:2S-05 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 5/25/2016 18.19 80.86 57,481 Design 2S-05wp09[Nurse] Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.00 15.00 Survey Tool Program Date 4/4/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.00 1,000.00 2S-05wp09[Nurse](Plan:2S-05) GYD-GC-SS Gyrodata gyro single shots 1,000.00 2,000.00 2S-05wp09[Nurse](Plan:2S-05) MWD MWD-Standard 1,000.00 2,951.53 2S-05wp09[Nurse](Plan:2S-05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,951.53 4,451.53 2S-05wp09[Nurse](Plan:2S-05) MWD MWD-Standard 2,951.53 9,181.86 2S-05wp09[Nurse](Plan:2S-05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,181.86 10,681.86 2S-05wp09[Nurse](Plan:2S-05) MWD MWD-Standard 9,181.86 15,138.02 2S-05wp09[Nurse](Plan:2S-05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 39.00 0.00 0.00 0.00 -120.00 0.00 0.00 0.00 100.00 1.15 0.00 0.00 -59.00 1.15 0.04 0.04 200.00 1.15 0.00 0.00 41.00 1.15 0.19 0.19 279.00 1.15 0.00 0.00 120.00 1.15 0.33 0.33 top T-3 Sand 300.00 1.15 0.00 0.00 141.00 1.15 0.33 0.33 414/2016 4:14:45PM Page 2 COMPASS 5000.1 Build 74 • Schlurnberger S . Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Site Kuparuk 2S Pad Project: Kuparuk River Unit TVD Reference: 39+120 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp09[Nurse] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 374.00 1.15 0.00 0.00 215.00 1.15 0.48 0.48 K-15 Marker 400.00 1.15 0.00 0.00 241.00 1.15 0.48 0.48 KOP:Start 1.5°/100'DLS,170°TF,for 200.09' 500.00 1.15 1.50 45.00 340.99 1.15 0.56 0.56 600.00 1.15 3.00 80.17 440.91 1.15 0.60 0.60 600.09 1.15 3.00 80.17 441.00 1.15 0.60 0.60 Start 2.5°/100'DLS,0°TF,for 743.21' 700.00 1.16 5.50 80.29 540.63 1.15 0.68 0.68 800.00 1.16 8.00 80.73 639.93 1.15 0.78 0.77 900.00 1.17 10.50 168.69 738.62 1.15 0.91 0.88 1,000.00 1.18 13.00 169.63 836.51 1.15 1.06 1.00 1,100.00 1.19 15.50 169.99 933.43 1.14 1.16 1.07 1,200.00 1.20 18.00 170.45 1,029.18 1.13 1.32 1.08 1,300.00 1.22 20.50 170.49 1,123.58 1.13 1.64 1.12 1,343.31 1.22 21.58 170.49 1,164.00 1.12 1.82 1.14 Hold for 107.54' 1,397.08 1.23 21.58 170.48 1,214.00 1.13 2.08 1.18 Base permafrost(?) 1,400.00 1.23 21.58 170.48 1,216.72 1.13 2.08 1.18 1,450.85 1.23 21.58 170.48 1,264.00 1.13 2.32 1.23 Start 3°/100'DLS,-50.88°TF,for 1070.92' 1,500.00 1.24 22.54 170.36 1,309.56 1.14 2.56 1.27 1,600.00 1.26 24.64 169.30 1,401.21 1.15 3.07 1.40 1,700.00 1.30 26.90 167.57 1,491.26 1.17 3.64 1.58 1,800.00 1.37 29.28 165.51 1,579.49 1.19 4.29 1.78 1,900.00 1.45 31.76 163.32 1,665.63 1.23 5.01 2.00 1,940.66 1.57 32.80 161.13 1,700.00 1.27 5.80 2.23 Top W Sak(W Sak D) 2,000.00 1.57 34.32 161.13 1,749.45 1.27 5.80 2.23 2,100.00 1.45 36.93 162.24 1,830.73 1.18 3.04 1.71 2,200.00 1.52 39.60 159.99 1,909.24 1.21 3.40 1.82 2,300.00 1.60 42.30 157.86 1,984.77 1.25 3.80 1.94 2,400.00 1.69 45.03 155.86 2,057.11 1.29 4.22 2.05 2,500.00 1.80 47.78 153.99 2,126.06 1.35 4.66 2.16 2,521.77 1.82 48.39 153.64 2,140.60 1.36 4.76 2.18 Hold for 3484.46' 2,600.00 1.83 48.39 152.31 2,192.55 1.42 5.15 2.28 2,700.00 1.83 48.39 150.92 2,258.96 1.52 5.64 2.42 2,800.00 1.84 48.39 149.77 2,325.37 1.61 6.14 2.55 2,876.24 1.85 48.39 148.81 2,376.00 1.71 6.64 2.69 Base W Sak 2,900.00 1.85 48.39 148.81 2,391.78 1.71 6.64 2.69 2,951.53 1.88 48.39 147.96 2,426.00 1.73 7.12 2.76 10-3/4"x 13-1/2" 4/4/2016 4:14:45PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger S . Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Site Kuparuk 2S Pad Project: Kuparuk River Unit TVD Reference: 39+120 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp09[Nurse] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 3,000.00 1.88 48.39 147.96 2,458.19 1.73 7.12 2.76 3,100.00 1.89 48.39 146.66 2,524.60 1.76 7.73 2.79 3,200.00 1.90 48.39 145.30 2,591.00 1.82 8.49 2.85 3,300.00 1.91 48.39 144.05 2,657.41 1.90 9.37 2.94 3,400.00 1.92 48.39 143.00 2,723.82 2.00 10.32 3.05 3,500.00 1.93 48.39 142.12 2,790.23 2.11 11.35 3.18 3,514.72 1.94 48.39 141.41 2,800.00 2.24 12.42 3.33 C-80 3,600.00 1.94 48.39 141.41 2,856.64 2.24 12.42 3.33 3,700.00 1.95 48.39 140.83 2,923.04 2.38 13.52 3.50 3,800.00 1.96 48.39 140.35 2,989.45 2.54 14.66 3.68 3,900.00 1.97 48.39 139.96 3,055.86 2.70 15.81 3.88 4,000.00 1.98 48.39 139.63 3,122.27 2.87 16.99 4.08 4,100.00 1.99 48.39 139.35 3,188.68 3.04 18.17 4.30 4,200.00 2.01 48.39 139.12 3,255.08 3.22 19.37 4.52 4,300.00 2.02 48.39 138.92 3,321.49 3.40 20.58 4.75 4,400.00 2.03 48.39 138.75 3,387.90 3.59 21.80 4.99 4,500.00 2.04 48.39 142.25 3,454.31 2.57 11.80 3.68 4,600.00 2.05 48.39 142.01 3,520.72 2.66 12.23 3.79 4,700.00 2.07 48.39 141.78 3,587.12 2.75 12.67 3.90 4,800.00 2.08 48.39 141.58 3,653.53 2.84 13.11 4.01 4,900.00 2.09 48.39 141.39 3,719.94 2.94 13.56 4.13 5,000.00 2.11 48.39 141.21 3,786.35 3.03 14.02 4.25 5,100.00 2.12 48.39 141.05 3,852.76 3.13 14.48 4.37 5,200.00 2.13 48.39 140.91 3,919.17 3.23 14.94 4.49 5,300.00 2.15 48.39 140.77 3,985.57 3.33 15.41 4.61 5,400.00 2.16 48.39 140.64 4,051.98 3.43 15.88 4.74 5,500.00 2.17 48.39 140.53 4,118.39 3.54 16.35 4.87 5,597.29 2.19 48.39 140.42 4,183.00 3.64 16.83 5.00 C-50 5,600.00 2.19 48.39 140.42 4,184.80 3.64 16.83 5.00 5,700.00 2.20 48.39 140.32 4,251.21 3.75 17.31 5.13 5,800.00 2.22 48.39 140.23 4,317.61 3.85 17.79 5.27 5,900.00 2.23 48.39 140.14 4,384.02 3.96 18.28 5.40 5,993.33 2.25 48.39 140.06 4,446.00 4.07 18.76 5.54 C-40 6,000.00 2.25 48.39 140.06 4,450.43 4.07 18.76 5.54 6,006.22 2.25 48.39 140.06 4,454.56 4.07 18.79 5.54 Start 3.5°/100'DLS,-116.04°TF,for 3129.74' 6,100.00 2.62 47.02 139.99 4,517.69 4.17 19.01 5.92 6,200.00 3.30 45.72 139.89 4,586.71 4.27 19.00 6.46 6,247.45 4.12 45.16 139.74 4,620.00 4.37 18.88 7.16 C-37 6,300.00 4.12 44.60 139.74 4,657.24 4.37 18.88 7.16 6,400.00 5.03 43.69 139.52 4,729.02 4.47 18.62 7.98 4/4/2016 4:14:45PM Page 4 COMPASS 5000.1 Build 74 • Schlurnberger S . Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Site Kuparuk 2S Pad Project: Kuparuk River Unit TVD Reference: 39+120 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 25-05wp09[Nurse] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (0) (usft) (usft) (usft) (usft) 6,500.00 5.97 42.98 139.24 4,801.78 4.56 18.23 8.89 6,552.12 6.93 42.70 138.89 4,840.00 4.65 17.69 9.85 Growler-AA 6,600.00 6.93 42.50 138.89 4,875.24 4.65 17.69 9.85 6,700.00 7.90 42.24 138.49 4,949.15 4.74 17.02 10.82 6,800.00 8.86 42.23 138.03 5,023.21 4.83 16.22 11.76 2S W16-Toe 6,900.00 9.82 42.44 137.53 5,097.16 4.92 15.33 12.62 7,000.00 10.76 42.89 136.98 5,170.71 5.00 14.36 13.38 7,100.00 11.69 43.56 136.39 5,243.59 5.09 13.35 14.01 7,200.00 12.59 44.45 135.77 5,315.54 5.18 12.33 14.50 7,252.72 13.46 45.00 135.12 5,353.00 5.27 11.34 14.85 Top Cairn 7,300.00 13.46 45.54 135.12 5,386.28 5.27 11.34 14.85 7,325.80 14.30 45.85 134.46 5,404.29 5.36 10.42 15.05 2S W16-Heel 7,386.08 14.30 46.62 134.46 5,446.00 5.36 10.42 15.05 Top Bermuda 7,400.00 14.30 46.81 134.46 5,455.54 5.36 10.42 15.05 7,495.38 15.10 48.18 133.78 5,520.00 5.46 9.60 15.10 Base Bermuda 7,500.00 15.10 48.25 133.78 5,523.08 5.46 9.60 15.10 7,565.11 15.87 49.27 133.10 5,566.00 5.56 8.91 15.03 C-35 7,600.00 15.87 49.85 133.10 5,588.63 5.56 8.91 15.03 7,700.00 16.59 51.58 132.43 5,651.96 5.66 8.39 14.83 7,800.00 17.27 53.45 131.77 5,712.83 5.76 8.06 14.53 7,900.00 17.89 55.42 131.12 5,771.00 5.87 7.92 14.14 8,000.00 18.47 57.49 130.51 5,826.27 5.99 7.98 13.66 8,089.30 19.00 59.41 129.93 5,873.00 6.10 8.20 13.13 Top HRZ(K-2 mkr) 8,100.00 19.00 59.65 129.93 5,878.43 6.10 8.20 13.13 8,200.00 19.46 61.88 129.39 5,927.28 6.23 8.57 12.55 8,262.40 19.88 63.31 128.90 5,956.00 6.35 9.06 11.93 Upper Kalubik(base HRZ) 8,300.00 19.88 64.18 128.90 5,972.64 6.35 9.06 11.93 8,400.00 20.23 66.54 128.48 6,014.34 6.49 9.64 11.30 8,500.00 20.52 68.94 128.12 6,052.22 6.62 10.29 10.67 8,590.19 20.75 71.15 127.85 6,083.00 6.76 10.99 10.06 Lower Kalubik(K-1 mkr) 8,600.00 20.75 71.39 127.85 6,086.15 6.76 10.99 10.06 8,700.00 20.92 73.88 127.68 6,116.00 6.91 11.73 9.49 8,800.00 21.02 76.39 127.61 6,141.65 7.06 12.49 8.97 8,900.00 21.07 78.94 127.68 6,163.02 7.21 13.27 8.53 8,955.54 21.05 80.36 127.90 6,173.00 7.36 14.07 8.19 Kuparuk C(Top C4) 4/4/2016 4:14:45PM Page 5 COMPASS 5000.1 Build 74 Schlurnberger Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Site Kuparuk 2S Pad Project: Kuparuk River Unit TVD Reference: 39+120 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp09[Nurse] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (0) (usft) (usft) (usft) (usft) 9,000.00 21.05 81.50 127.90 6,180.01 7.36 14.07 8.19 9,020.86 20.98 82.03 128.29 6,183.00 7.52 14.87 7.95 A5 9,100.00 20.98 84.07 128.29 6,192.57 7.52 14.87 7.95 9,135.97 20.94 85.00 128.48 6,196.00 7.58 15.16 7.90 Hold for 45.89'-2S-Nurse 1.Heel-2S-Nurse 1.Heel_Cirlce 9,181.86 21.17 85.00 127.08 6,200.00 7.58 15.25 7.93 Adjust TF to 0°,for 20'-A4-7-5/8"x 9-7/8"by 11" 9,200.00 21.17 85.00 126.67 6,201.58 7.58 15.23 7.94 9,201.86 21.17 85.00 126.63 6,201.74 7.58 15.23 7.94 Start 2°/100'DLS,0°TF,for 301.95' 9,300.00 21.24 86.96 124.37 6,208.62 7.60 15.24 7.77 9,400.00 21.29 88.96 121.99 6,212.18 7.63 15.39 7.68 9,500.00 21.31 90.96 119.42 6,212.24 7.68 15.68 7.66 9,503.82 21.32 91.04 119.31 6,212.17 7.69 15.69 7.66 Hold for 5634.2' 9,600.00 21.32 91.04 116.52 6,210.43 7.75 16.10 7.73 9,700.00 21.32 91.04 113.06 6,208.62 7.84 16.64 7.81 9,800.00 21.32 91.04 108.58 6,206.80 7.94 17.28 7.91 9,900.00 21.33 91.04 102.30 6,204.99 8.05 18.03 8.03 10,000.00 21.33 91.04 92.97 6,203.18 8.18 18.86 8.16 10,100.00 21.33 91.04 79.96 6,201.36 8.33 19.76 8.31 10,200.00 21.33 91.04 66.27 6,199.55 8.49 20.73 8.46 10,300.00 21.34 91.04 55.92 6,197.74 8.66 21.76 8.64 10,400.00 21.34 91.04 49.12 6,195.92 8.84 22.83 8.82 10,500.00 21.34 91.04 44.59 6,194.11 9.04 23.95 9.01 10,600.00 21.34 91.04 41.40 6,192.29 9.24 25.10 9.22 10,700.00 21.35 91.04 118.30 6,190.48 8.07 17.22 8.05 10,800.00 21.35 91.04 117.60 6,188.67 8.13 17.50 8.11 10,900.00 21.35 91.04 116.84 6,186.85 8.20 17.79 8.18 11,000.00 21.36 91.04 115.99 6,185.04 8.27 18.10 8.25 11,100.00 21.36 91.04 115.01 6,183.23 8.34 18.42 8.32 11,200.00 21.36 91.04 113.82 6,181.41 8.42 18.75 8.40 11,300.00 21.36 91.04 112.34 6,179.60 8.50 19.09 8.47 11,400.00 21.37 91.04 110.35 6,177.79 8.58 19.45 8.56 11,500.00 21.37 91.04 107.46 6,175.97 8.66 19.81 8.64 11,600.00 21.37 91.04 102.80 6,174.16 8.75 20.19 8.73 11,700.00 21.38 91.04 94.34 6,172.35 8.84 20.57 8.82 11,800.00 21.38 91.04 78.73 6,170.53 8.94 20.96 8.92 11,900.00 21.38 91.04 60.09 6,168.72 9.03 21.36 9.01 12,000.00 21.39 91.04 48.36 6,166.91 9.13 21.77 9.11 12,100.00 21.39 91.04 42.18 6,165.09 9.23 22.19 9.21 12,200.00 21.39 91.04 38.61 6,163.28 9.34 22.62 9.32 12,300.00 21.40 91.04 36.30 6,161.47 9.44 23.05 9.42 12,400.00 21.40 91.04 34.67 6,159.65 9.55 23.48 9.53 4/4/2016 4:14:45PM Page 6 COMPASS 5000.1 Build 74 • • Schlurnberger Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Site Kuparuk 2S Pad Project: Kuparuk River Unit TVD Reference: 39+120 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp09[Nurse] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 12,500.00 21.40 91.04 33.44 6,157.84 9.66 23.93 9.64 12,600.00 21.41 91.04 32.48 6,156.03 9.77 24.38 9.75 12,700.00 21.41 91.04 31.69 6,154.21 9.89 24.83 9.87 12,800.00 21.41 91.04 31.03 6,152.40 10.00 25.29 9.98 12,900.00 21.42 91.04 30.46 6,150.59 10.12 25.76 10.10 13,000.00 21.42 91.04 29.96 6,148.77 10.24 26.22 10.22 13,100.00 21.42 91.04 29.52 6,146.96 10.36 26.70 10.34 13,200.00 21.43 91.04 29.12 6,145.15 10.48 27.18 10.47 13,300.00 21.43 91.04 28.76 6,143.33 10.61 27.66 10.59 13,400.00 21.43 91.04 28.42 6,141.52 10.73 28.14 10.72 13,500.00 21.44 91.04 28.12 6,139.70 10.86 28.63 10.84 13,600.00 21.44 91.04 27.83 6,137.89 10.99 29.12 10.97 13,700.00 21.44 91.04 27.56 6,136.08 11.12 29.62 11.10 13,800.00 21.45 91.04 27.31 6,134.26 11.25 30.11 11.24 13,900.00 21.45 91.04 27.07 6,132.45 11.39 30.62 11.37 14,000.00 21.45 91.04 26.85 6,130.64 11.52 31.12 11.50 14,100.00 21.46 91.04 26.63 6,128.82 11.66 31.62 11.64 14,200.00 21.46 91.04 26.43 6,127.01 11.79 32.13 11.78 14,300.00 21.47 91.04 26.24 6,125.20 11.93 32.64 11.92 14,400.00 21.47 91.04 26.05 6,123.38 12.07 33.16 12.05 14,500.00 21.47 91.04 25.87 6,121.57 12.21 33.67 12.19 14,600.00 21.48 91.04 25.70 6,119.76 12.35 34.19 12.34 14,700.00 21.48 91.04 25.54 6,117.94 12.49 34.71 12.48 14,800.00 21.49 91.04 25.38 6,116.13 12.63 35.23 12.62 14,900.00 21.49 91.04 25.23 6,114.32 12.78 35.75 12.76 15,000.00 21.49 91.04 25.08 6,112.50 12.92 36.28 12.91 15,100.00 21.50 91.04 24.94 6,110.69 13.07 36.80 13.06 2K-Pad T5 15,138.02 21.50 91.04 24.88 6,110.00 13.12 37.00 13.11 TD:15138.02'MD,6269'TVD-4-1/2"x 6-3/4"-2S-Nurse 2.Toe-2S-Nurse 2.Toe Circle 4/4/2016 4:14:45PM Page 7 COMPASS 5000.1 Build 74 Schlumberger Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Site Kuparuk 2S Pad Project: Kuparuk River Unit TVD Reference: 39+120 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: 39+120 @ 159.00usft(Doyon142) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp09[Nurse] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') C') 2,951.53 2,585.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 9,181.86 6,359.00 7-5/8"x 9-7/8"by 11" 7-5/8 11 15,138.02 6,269.00 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 1,397.08 1,373.00 Base permafrost(?) 3,514.72 2,959.00 C-80 7,386.08 5,605.00 Top Bermuda 2,876.24 2,535.00 Base W Sak 8,590.19 6,242.00 Lower Kalubik(K-1 mkr) 6,552.12 4,999.00 Growler-AA 5,993.33 4,605.00 C-40 279.00 279.00 top T-3 Sand 0.00 5,597.29 4,342.00 C-50 8,262.40 6,115.00 Upper Kalubik(base HRZ) 7,565.11 5,725.00 C-35 9,020.86 6,342.00 A5 9,181.86 6,359.00 A4 6,247.45 4,779.00 C-37 8,089.30 6,032.00 Top HRZ(K-2 mkr) 7,495.38 5,679.00 Base Bermuda 8,955.54 6,332.00 Kuparuk C(Top C4) 1,940.66 1,859.00 Top W Sak(W Sak D) 374.00 374.00 K-15 Marker 7,252.72 5,512.00 Top Cairn Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (usft) (usft) (usft) (usft) Comment 400.00 400.00 -25.56 -117.09 KOP:Start 1.5°/100'DLS, 170°TF,for 200.09' 600.09 600.00 -30.72 -116.18 Start 2.5°/100'DLS,0°TF,for 743.21' 1,343.31 1,323.00 -185.85 -88.83 Hold for 107.54' 1,450.85 1,423.00 -224.81 -81.96 Start 3°/100'DLS,-50.88°TF,for 1070.92' 2,521.77 2,299.60 -722.30 236.18 Hold for 3484.46' 6,006.22 4,613.56 -2,612.19 2,029.32 Start 3.5°/100'DLS,-116.04°TF,for 3129.74' 9,135.97 6,355.00 -1,635.94 3,808.86 Hold for 45.89' 9,181.86 6,359.00 -1,591.72 3,820.47 Adjust TF to 0°,for 20' 9,201.86 6,360.74 -1,572.45 3,825.53 Start 2°/100'DLS,0°TF,for 301.95' 9,503.82 6,371.17 -1,280.71 3,902.15 Hold for 5634.2' 15,138.02 6,269.00 4,167.78 5,333.17 TD: 15138.02'MD,6269'TVD Checked By: Approved By: Date: 4/4/2016 4:14:45PM Page 8 COMPASS 5000.1 Build 74 Pool Report • 0 15:39,April 06 2016 WELLBORE TARGET DETAILS(MAP CO-ORDINATES) 2S-05wp09[Nurse] Name 2S-Nurse 1 Heel 635D5.00 Circle(Radius:1000) 2S-Nurse 2.1oe 8289.00 circle(Radius:100.00) Quarter Mile View 2S-Nurse 1ae Cake 00 Circle(Rados 1320.00) 2S-Nurse 2.Toe Cirde 8260 8 8355255 00 Cycle(Radius:1320.00) I 211 6000 • • • • • • ?S�4 • • 281,1 2:• ZS�SWp,,• �N��e) • 4000 • '' 1 c • • fiat- a . „. • . . . . . : . • , . . • 1 •••. . . . . . . . . . .•• 0 : : • .•• ...._ 1 . • . • „ , . 1 ,, 1 c\I000 •• .•• . .••. . . • . . . . . . + . . , . .•• . • 28-x2 4ir 1 ?S'O4p �� i O O • • • • I �r 3 !q'! • • • ,,../ i„, ,igkr 6 .•• -2000 _r , 4000 _ ---- I • 1 • • • ZS • • ZS.1 p• / ::.03P81 • •• 2. ••: -6000 -4000 -2000 0 2000 4000 6000 8000 10000 West(-1/East(+1 (2000 usft/in) • • 2S-05wp09[Nurse] 3-D View ini 2S-05wp09[Nurs/ lie = 2S 0 !IP \ 2 3 \.411111111""4 f lit ° 2504P ifil' , AO'. , "' / /fa AL 4. • • 2S-05wp09[Nurse] 3-D View 1 mi .. 2S-0SwpO9[Nurs. ,..-.-... * EU V .z. � • '� yam ... z . f' ......001010i • 4 • • 2S-05wp09[Nurse] 3-D View ma 2S-05wp091Nurs= ............................................... *'- re" . s°` 0 • 2S-05wp09[Nurse] 3-D View qy 1 t I • • 25-05wp09 Surface Location Efj CPAI oo dinate Converter h'. _ [ r< From: ------- .. _ —To: { Datum: ;NAD83 -.1 Region lalaska z Datum: INAD27 i� Region: Falaska TT ( _ C Latitude/Longitude _!Decimal Degrees + C Latitude/Longitude �jD ecimal D egr ees C UTM Zone: (--___ r South C UTM Zone: True r_ South C State Plane Zone: j4 ,i Units: us-ft is State Plane Zone: [4.----,--1 Units: us-ft C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: - X: 11621225.11 X: [401191.791850198 Y: 15929760.47 Y: I 5930010.8806618 i Transform Quit I Help 25-05wp09 Intermediate Casing n CPA:Coordinate Converter" . il`a I r:, '1 I From: _To: Datum: [NAD833 Region: Ialaska 21.1 Datum: NAD27 Region: alaska -` Latitude/Longitude �p al Degrees J C Latitude/Longitude 1Decimal Degrees UTM Zone: I_ South C UTM Zone: 1True ; South State Plane Zone: 4 Units: us ft +; 4 State Plane Zone: 4..^ Units: us-fk rl C Legal Description(NAD27 only) r Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: 11625158.31 X: [485125.060294498 if Y: 5928184.52 Y: i 5928434.90882599 Transform Quit 1 Help 1 iiiii • 0 1 - 25-05wp09 TD In CPAI Coo-d i nate Converter''. - 4'0,45444.44404144c1 kt' 4-.', ''', From:-- To: Datum: INAD83---"C Region: lalaska ±..1 Datum: !NAD27 ,:.! Region: --ai-a-s17.-----..-A _ Latitude/Longitude 167cirnal Degrees , C Latitude/Longitude !Decimal Degrees • UT M Zone: 1- (--- South C UTM Zone: !True E South '• State Plane Zone: r4 ,, Units: i,;:ii---;] , State Plane Zone: 4 ,l Units: Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: 11626685.40 X: 1 486652.265095153 ----1 4 Y: 15933939.60 Y: ! 5934189.83561528 Transform Quit J Help ,„ , • • 25-05wp09 Surface Location i CPN: Coo dinate Converter ( i i 1 From: To: Datum: 1NAD83 �1 Region: lalaska Datum: 1NAD27- Region: jalaska _; " Latitude/Longitude Decimal Degrees _:.! C Latitude/Longitude Decimal Degrees 1 r UTM Zone: 1 E South ir UTM Zone: 'True _ r South State Plane Zone: jq-----'– Units: [s•fts j'• �'"' State Plane Zone: fq�_���� Units: us ft ( Legal Description(NAD27 only] i* Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11621225.11 Township: 010 N Range: 008 E Y: 15929760.47 — Meridian: Iu Section:117 J FN L , 13037.0634 FE LJ 1378.4825 Transform Quit I Help 1 25-05wp09 Intermediate Casing In CPA: Coordinate Converter ' p From: Datum: 1NAp83 H Region: lalaska Datum: NAD27 Region: alaska (-- Latitude/Longitude iDecimal Degrees C Latitude/Longitude !Decimal Degrees .... Zone:one: r__..__._._- r_.. South r UTM Zone: ' True r South State Plane Zone: 14 H Units: us•ft '1 t'"'' State Plane Zone: 4 , Units: us-ft C Legal Description(NAD27 only) i+ Legal Description(NAD27 only) Starting Coordinates: — Legal Description X: 11625158.31 Township: p70 N ;, Range: 008 'E H Y: 15928184.52 Meridian: lu T Section:1-76 jFNL + 14604.4200 IT :. 12725.5790 Transform 11 Quit ] Help • • 1 25-05wp09 TD r E_ CPN =:oo=dinate Conver � � a ��s From: To: Datum: 1NAD$3 Region: ralaska Datum: 1NAD27 Region: alaskaj r._. Latitude/Longitude Decimal Degrees C-.. Latitude/Longitude 'Decimal Degrees +j UTM Zone: ] South UTM Zone: r----- ITrue 1 South 1 " State Plane Zone: 14 , Units: jus-ft i`- State Plane Zone: 14 Units: us-ft . ! � C Legal Description(NAD27 on1.1) (Z. Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 16266$5.40 Township: 1010 I:4,1 Range: [00$ [E `r: 15933939.60 Meridian: U .,1 Section:19 FNL 4126.0644 mi—_---:-] in 95.4120 Transform li Quit I Help As - built REV DATE BY CK APP DESCRIPTION REV DATE BY .. APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS 2 11/14/15 SZ MEH Add Well 13 per K150013ACS NOTES. 17 2 5 4 1 11 0 17 116 • n 02 DS2A' 4 1. BASIS OF LOCATION AND ELEVATION IS DS2S tilMig �� =n 2G 21 .22 23 +� a J _ ,� . MONUMENTATION PER LOUNSBURY & ASSOC. I 3 37 22 2. 2 25 �' f'� za 27 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, 24 �,, . ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES �`; - '� ' y.', ARE NAD 27. �?,, / .� 1 6 1. T11N f K' w w Ili ION 3. ELEVATIONS ARE B.P.M.S.L. . ./.3.‘'01•11, �?/� 3 2 �c 4 3 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED e4 e z `"` SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, . ' .,08 9 +0 11 s r . 9 30 UMIAT MERIDIAN. ) r // 10 016 15 14 13 19 17 16 15 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS _ V L15-28, L15-29, L15-32, L15-35, 11-13-2015 22 FIELD BOOK L15-75. 19 0 2+ 23 2a 19 2 22 PROJECT LOCATION 6. ALL DISTANCES SHOWN ARE TRUE. 2, 2 27 2.2 30 29 29 n 7. CONDUCTOR 15 WAS ORIGINALLY SET AS CONDUCTOR 13. 11 32 3+ x ,, Si 32 33 33 N VICINITY MAP NTS / .... 30' T`9 DS2S --\ r 14 12 • 10 . •8 • 6 54 3 21 10 3. • 15. 11• 9 LEGEND O AS—BUILT CONDUCTOR LOCATION \ 17+16 • EXISTING CONDUCTOR LOCATIONS ` 20 21 GRAPHIC SCALE 0 100 200 400 IidLOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS 0 & ASSOCIATES, INC. 1 inch = 200 ft. SURVEYORS ENGINEERS PLANNERS AREA:2S MODULE: XXXX UNIT: D2 ConocoPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA—D2SX-6219D24 I 1 OF 2 I 2 • IREV DATE DY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS 2 11/14/15 SZ MEM Add Well 13 Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. 0.G. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70' 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70' 13' 11.873" 150' 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70' 13' 11.806" 150' 09' 06.242" 2243' 1378' 111.8' 120.0' I 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70' 13' 11.684" 150° 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70' 13' 11.622" 150' 09' 08.804" 2224' 1467' 111.1' 120.0' 9 5,929,986.08 481,074.22 70' 13' 11.559" 150° 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5,929,979.72 481,044.13 70' 13' 11.496" 150' 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70' 13' 11.436" 150' 09' 11.362" 2205' 1555' 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150' 09' 12.212" 2199' 1584' 110.9' 120.0' 13 5,929,948.70 480,898.09 70' 13' 11.187" 150' 09' 14.767" 2180' 1672' 110.5' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 2186' 1643' 110.5' 120.0' 15 5,929,961.45 480,956.55 70' 13' 11.314" 150' 09' 13.070" 2192' 1614' 110.6' 120.0' CONDUCTOR AS BUILT THIS SURVEY SEE NOTE 7 SHEET 1 REGARDING CONDUCTOR 15. Rif • 'A.'./•7766/44 0)0 /��B® SURVEYOR'S CERTIFICATE EJ 4 /\ • O I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND ci � �`'� y ••• '• -1 LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF C� /• ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY �" 'JEREMIAH F. CORNELL,' c�� DONE BY ME OR UNDER MY DIRECT SUPERVISION AND • �'. ? �,,® THATAS ALLNOVEDIMENSIONMS, AND OTHER DETAILS ARE CORRECT LS-1266.3 ♦��FPF :r i, y .•°'• A OFBER 13 2015. Op •ir r1 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS I AREA:25 MODULE: XXXX UNIT: D2 bS2S cc:© r( ©CO hillhps, WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION ICADD FILE NO. DRAWING NO. PART. I LK6219d24 5 28/15 CEA-D2SX 6219D24x�M� re 2 0F__2a NMI • 2S-05 Drilling Hazards Summary 13-1/2"Hole/10-3/4"Casing Interval Event I Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision Low Run Gyro as needed for magnetic interference.Third well on pad,so no real anti-collision risk,only with future plans. Gravel/Sand Sloughing Low Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections. Hole Swabbing/Tight Hole on Trips Moderate Circulate hole clean prior to trip. Proper hole fill(use of trip sheets), Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement.Use proper pump rate. 9-7/8"x 11"Hole/7-5/8"Casing Interval Event I Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to eliminate swab. High ECD and swabbing with higher Low Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology,add LCM. Use GKA LC decision tree. Keep ECD below known frac gradient of—12.5 ppg in Tam formations crossed in intermediate. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight,PWD monitor ECD. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. 6-3/4"Hole/4-1/2"Liner Interval Event I Risk Level I Mitigation Strategy High ECD and swabbing with higher Moderate Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology,add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. • TRANSMITTAL LETTER CHECKLIST WELL NAME: k tk. 02 5 r c75 CPA/(cseci PTD: ) 4 �c3� Development —Service Exploratory Stratigraphic Test _Non-Conventional FIELD: 4r. 1 IVB✓ POOL: KycAhAk,RIV61 kl2cAt4, 2\40 s 1 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 MC 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 MC 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 MC 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 Well Lo in also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 MC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 0 40 El m o a) o N 0 6 Ui a 0 c6 a Q a , ' , ;ci I o ., C p Z E, 2 u vi . 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O' r ° a 2' € m, m a)', o, o 'U Lz; a -) m ' ' co 0, 0, aa U, � ¢� a 0,, o 0,, UU� U� a� .= < - 0 coc..) �', 2', a ❑, cO0) 0 - a Cr O• .- N M V l0 CO O O) O -- N M V CO CO O) O N M CD h n0 O _' E h. c' N Co) Tr R) CO I . O 0) O N N N N N N N N N N 0) K1 CM M M C0 M CM M M S` O C 0 ON ON R ON U O_ OCI c0 r U) 1- W W co t6 E V V O.E ❑ cp CL N a U O J w c J o CO U w ola < eela W O. 5 . 0. a a or Tg� • 9 y7y � THE STATE Alaska Oil and Gas ti�►`i'`��� of LASI�:A Conservation Commission __ ° A 5 £-= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF AL AS Fax: 907.276.7542 www.aogcc.alaska.gov G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-05 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-039 Surface Location: 3037' FNL, 1378' FEL, Sec. 17, T1ON, R8E, UM Bottomhole Location: 4126' FNL, 1195' FEL, Sec. 9, TION, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development 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. 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. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, atiaa-t-f. r/L— Cathy . Foerster Chair DATED this JSay of March, 2016. STATE OF ALASKA RECEIVED 41111A OIL AND GAS CONSERVATION COMIN PERMIT TO DRILL 20 AAC 25.005 1 a.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ lc.Sp IPS?s roposed for: Drill •0 Lateral ❑ Stratigraphic Test ❑ Development-Oil El- Service- Winj ❑ Single Zone CM Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry El Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket LI. Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska, Inc.- Bond No. 59-52-180, KRU 2S-05 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 15,324 • TVD: . 6,270 Kuparuk River Field t 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3037'FNL, 1378'FEL, Sec 17, T1ON,R008E,UM ' ADL 25603,25604,25589 „ Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4599'FNL,2724'FEL,Sec 16,T1ON,R008E,UM 2677,2678,2675 3/29/201/11 Total Depth: 9.Acres in Property: • 14.Distance to Nearest Property: 4126'FNL, 1195'FEL, Sec 9,T1ON,R008E,UM 7632 3036.88'from ADL025590 -1 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 159 1 15.Distance to Nearest Well Open Surface: x- 481192 y- 5930011 Zone- 4 • GL Elevation above MSL(ft): 120 , to Same Pool: KRU 2S-03:525.11' 16.Deviated wells: Kickoff depth: . 400 feet 17.Maximum Potential Pressures in psig(see 20 AAC-"25.035)`� Maximum Hole Angle: . 90 degrees Downhole: 306 383(a Surface: 3Yts5 3aQp 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD d (including stage data) 24" 16" 62.5# H-40 Welded 79' 39.5' 39.5' 118' 118' 1• `J pre-driven,cement to surface 13.5" 10.75" 45.5# L-80 Hydril 563 2913' 39.5' 39.5' 2952' 2585.5' .;,,,1.3241x DeepCRETE,195sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 8804' 39.5' 39.5' / 8843' 6277.5' 791 sx GasBLOK,205 sx GasBLOK 6.75" 4.5" 12.6# L-80 Hydril 564 6631' 8,693' 62/38' 15324' 6269.5' N/A 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(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 ND(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch Q Seabed Report El Drilling Fluid Program ❑ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 3/(/I(D ft/22. I hereby certify that the foregoing is true and the procedure approved herein will not Jaco Voss @ 265-6935 be deviated from without prior written approval. Contact jake.voss@cop.com Email Printed Name G.L.Alvord Title Alaska Drilling Manager Signature �,J (_do( Phone 265-6120 Date 3'1 12_4, ,I _ Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 116- 035 50- 10.1",Q0?37"39 -pa-O0 Date: 3 ^ \fj ^ \Le 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: 1711 Other: 5CP t C5¢ fD 3 57' PS/ Samples req'd: Yes L No Mud log req'd:Yes❑ No Wi 4 onv/Gt pre-t VC`i Tri- 7- * f Z SGC P HzS measures: Yes No Directional svy req'd:Yes dr No❑ Spacing exception req'd: Yes IIINo12( Inclination-only svy req'd:Yes No Post initial injection MIT req'd:Yes No Ir . APPROVED BY Approved by� 7 --- COMMISSIONER THE COMMISSION Date: 3-/3-/�j vrc- /i s/!� Fa .s/./IC- O j Gni Submit Form ane Form 10-401( evised 11/2015) y'•`moi I' 0 24 months fro a dale of approval(20 AAC 25.005(91) Attachments in Duplicate • Application for Permit to Drill,Well 2S-05 MAR 0 1 2016 Saved: 1-Mar-16 Post Office Box 100360 AOGCC Anchorage,Alaska 99510-0360 o '1 oPhil s Phone(907)265-6935 Email: lake.vossAconocophillips.com February 29, 2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2S-05,A Kuparuk A4 Sand Producer Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a permit to drill an onshore grassroots producer well from the 2S pad. The expected spud date for this well is March 29th,2015. It is planned to use rig Doyon 25. 2S-05 is planned to be a horizontal well in the Kuparuk A4 sand. The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-2,952' MD/2,856' TVD. The intermediate section will be drilled with 9-7/8"x 11"bit/Under Reamer and run 7-5/8"casing to 8,843'MD/6,278'TVD.The production hole will be drilled with 6-3/4"bit and run 4- 1/2"slotted liner to+/- 15,324'MD/6,270'TVD. The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Jake Voss at 265-6935 (j ake.voss@conocophillips.com)or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager • • Application for Permit to Drill Document Kuparuk Well 2S-05 conocoPhillips Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-05 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must he 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 3037' FNL, 1378'FEL, Sec 17, T ION,R008E,UM NGS Coordinates RKB Elevation 159.5'AMSL Northings: 5,930,010.88' Eastings: 481,191.79' Pad Elevation 120'AMSL Location at Top of 4599' FNL,2724 FEL, Sec 16,TION,R008E,UM Productive Interval (Kuparuk A4 Sand) NGS Coordinates Measured Depth, RKB: 9,374' Northings: 5,928,439.96'Eastings: 485,126.40' Total Vertical Depth, RKB: 6,359' Total Vertical Depth, SS: 6,200' Location at Total Depth 4126'FNL, 1195' FEL, Sec 9,TION,R008E,UM NGS Coordinates Measured Depth, RKB: 15,324' Northings: 5,934,189.84'Eastings: 486,652.27' Total Vertical Depth, RKB: 6,270' Total Vertical Depth, SS: 6,110' and (D)other information required by 20 AAC 25.050(1): Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10--I01)must (I)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: Directional Plan And (2),for all wells within 200 feet of-the proposed wellbore (.I)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. 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 cornrnission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 25. • • 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 maximum potential surface pressure (MPSP)while drilling 2S-05 is calculated using an estimated maximum reservoir pressure of 3,834 psi (11.6 ppg, based on 2S-02 development well), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,360' TVD (WP08.2): A Sand Estimated. BHP = 3,836 psi • A Sand estimated depth(WP09) = 6,360' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column =636 psi • (6,360' TVD * 0.10 psi/ft) MPSP =BHP—gas column =3,200 psi (3,836 psi—636psi) (B)data on potential gas cones: The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo pressured strata,lost circulation cones,and cones that have a propensity for differential sticking; See attached 2S-05 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must he 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 25.0300: A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and 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 Cement Program Casing and Cementing Program Csg/Tbg OD Hole Weight Length Top MD/TVD Btm MD/TVD (in) ��) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 78 Surf 118/118 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,913 Surf 2,952/2,586 1,238 sx DeepCRETE Lead 11.0 ppg, 194 sx DeepCRETE Tail Slurry 12.0 ppg Stage 1: 641 sx Class G+GASBLOK at 9-7/8 Hydril 15.8 ppg w/TOC at 7,324 MD 7-5/8 X 29.7 L-80 8,804 Surf 8,843/6,278 Stage 2: 205 sx Class G+GASBLOK at 11 563 15.8 ppg w/TOC at 5,812 MD 4 1/2 6-3/4 11.6 L-80 IBTM 6,631 8,693/6,238 15,324/6,270 Uncemented Liner with Frac Sleeves • • 2S-05 wp08.2 Cementing Schematic AJ 16" Conductor to 118' 10-3/4"45.5#L-80 HYD563 A ihh, 2,952' MD/2,586'TVD @ 59° inc. 9-7/8"x 11" Hole Top of 2nd Stage Cement 5,812' MD 7 C-37 6,312' MD/4,780'TVD Top of 1st Stage Cement(top Cairn) 7,324' MD/5,513'TVD Aar Kalubik 7-5/8" 29.7#L-80 HYD563 Casing 8,359' MD/6,116'TVD M8,843 MD/6,278'TVD @ 76° Kuparuk A4 A 9,374' MD/6,360'TVD 6-3/4" Hole 4-1/2" Liner 11.6#L80 IBT k 15,324' MD/6,270'TVD • • 10-3/4" Surface casing run to 3,295' MD/2,660'TVD Cement from 2952' MD to 2452'(500' of tail)with DeepCrete. @ 12 ppg, and from 2452'to surface with 11 ppg DeepCrete. Assume 250%excess annular volume in permafrost and 50%excess below the permafrost(1400' MD),zero excess in 16"conductor. Lead slurry from 2,452' MD to surface with Arctic Lite Crete @ 11 ppg Conductor (115'—0')X 1.339 ft3/ft X 1.0(0% excess) = 154 ft3 Permafrost to Conductor (1,400'—115') X 0.3637 ft3/ft X 3.5 (250%excess) = 1,636 ft3 Top of Tail to Permafrost (2,452— 1,400')X 0.3637 ft3/ft X 1.5 (50%excess) =574 ft3 Total Volume= 154+ 1,636+574=2,364 ft3=> 1,238sx of 11 ppg DeepCrete @ 1.91 ft3/sk Tail slurry from 2,952' MD to 2,452' MD with 12 ppg DeepCrete Shoe to Top of Tail (2,952—2,452')X 0.3637 ft3/ft X 1.50(50%excess) =273 ft3 Shoe Joint (80')X 0.5400 ft3/ft X 1.0 (0%excess) =43 ft3 Total Volume=273+43=316 ft3=> 194 sx of 12 ppg DeepCrete @ 1.63 ft3/sk 7-5/8"Intermediate casing run to 8,843' MD/6,278' TVD 1st stage slurry designed to be at the top of Bermuda/Cairn Formation at 7,324' MD. Top of 2°d stage slurry is designed to be at 5,812' MD,which is 500' above the C-37. Assume 40%excess annular volume. 1st Stage slurry from 8,843' MD to 7,324' MD with 15.8ppg Class G+additives Shoe to Top of Cement (8,843'—7,324')X 0.3428 ft3/ft X 1.40(40%excess) = 729 ft3 Shoe Joint (80')X 0.2578 ft3/ft X 1.0(0%excess) =21 ft3 Total Volume=729+21 =750 ft3=>641 sx of 15.8 ppg Class G+GasBLOK @ 1.17 ft3/sk 2"d Stage slurry from 6,312' MD to 5,812' MD with 15.8ppg Class G+additives Stage Collar to Top of Cement (6,312—5,812)X 0.3428 ft3/ft X 1.40 (40%excess) =240 ft3 Total Volume=240 ft3=>205sx of 15.8 ppg Class G +GasBLOK @ 1.17 ft3/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the 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 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please reference diverter schematic on file for Doyon 25. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must he 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; Mud Program Summary Surface Intermediate Production 9-7/8"x 11" 13-1/2" Hole Hole 6-3/4" Hole 10-3/4" Casing 7-5/8"Casing 4-1/2" Liner Spud LSND FlowPro Mud System (WBM) (WBM) (WBM) Density 9.3- 10 9.6—10.5 10.3—11.5 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 25 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A- Application is not for an exploratory or stratigraphic test well. • • Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A- Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill innst 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 to attachment for proposed well schematic • le 1. Move in/rig up Doyon Rig 25. Install Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-2,952' MD/2,586' TVD as per directional plan (wp8.2). Survey with MWD, Gamma,Resistivity,Gyro. 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. Notify AOGCC if this occurs. 5. Remove diverter system, install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annularpreventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. V 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3500 psi for 30 minutes. /3,D p�y ATL 7. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 1 . ppg,maximum of 16 ppg EMW leak off,recording results. 8. Open 9-5/8"x 11"Under Reamer and directionally drill to the top of the HRZ NOTE:There is potential trip for logging the Cairn interval(currently being evaluated).Procedure would be POOH,RIH with RDT Log for formation evaluation,POOH and RIH to resume drilling. 9. Install RCD bearing at this time for use of MPD if necessary. 10. Directionally drill to intermediate TD of 8,843' MD/6,278' TVD,wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean,minimum of 3 bottoms up. 11. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. 12. Lay down intermediate BHA and rack back 5"DP 13. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD at 8,843'MD. 14. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 7,324' MD(top of Cairn formation),top of second stage to be 5,812' MD(500' above C37). 15. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 16. Lay down 5"DP. 17. PU 4"DP,6-3/4"bit,and Under Reamer assembly 18. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. G h A,--4-- 19. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 14.5 ppg EMW leak off,recording results. 20. Perform selective shale under ream procedure,POOH 21. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,and neutron density) 22. Swap mud over to 10.3 ppg FlowPro mud system,using MPD to hold near constant BHP of---11.8 ppg on the heel (for shale stability). 23. Directionally drill 6-3/4"hole geosteering through the Kuparuk A4 sand to TD-15,324' MD as per directional plan(wp8.2). 24. Circulate hole clean and POOH. • • 25. Lay down production BHA. 26. PU and run 4-1/2", 11.6#liner. The top of liner will be placed at 8,696' MD,allowing for 150' of overlap in the 7-5/8"casing. 27. Set liner hanger. Slackoff and set liner top packer. 28. Monitor well for flow for 15 minutes 29. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 30. Flow check well for 30 minutes and POOH 31. Run 3-1/2"upper completion. 32. Nipple down BOPE,nipple up tree and test. 33. Freeze protect well with diesel and install BPV. 34. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music he 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 authori_ation 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 / (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary S • 2S-05 ConocoPhillips Grassroots Horizontal A-Sand Producer Proposed Wellbore Schematic(wp08.2) \I / CAMERON Last Edited: \\ 4W tree,top joint is 4:4'12.6#IBTM Voss 2/24/15 L6"Conductor to–118' s` ai 13.5" Surface Hole 0 01 Base West Sak:1,398'MD!1,374'ND Gr J , 3-1/2"x 1'/z"Camco MMG GLM — ! Surface Casing 10-3/4"45.5#L-80 Hydril 563 2,952'MD/2,585.5'TVD(59" INC) 9-7/8"x 11" Intermediate Hole i Tubing: "p 3-1/2" 9.3#L-80 EUE 8RD-MOD o r".a a GLM v/SOV 4 a 2"tl Stage TOC= 500'MD above C-37 Formation at 5,81 x I I I I I I I( Weatherford Stage collar:6,312 MD C37:6,312 MD!4,780'ND st Growler(Iceberg):6,61MD/5,000'ND ',� I 8'1 Stage TOC: Top of Bermuda/Caim formation) Baker 2.81T CMU Sliding Sleeve Cairn:7,324'MD!5,513"ND \\1\11\\1 — ; f� 3-/:"x 7-518",Premier Packer Bermuda:7,460'MD 15,606'ND f ®�� 3-r"2.75"D Nipple i \ :1 HtiZ:8,178'MD K,033'ND Kalubik:8,359'MD/6,116'ND r'�' SLB DHG . 6"x 4'h"SwellPacker — Kuparuk C:9,135'MD 16,333'TVD I`' Kuparuk A4:9,374'MD!6,360'ND–11.3 ppg r ��—� if anoe I 7-5/8"x 5-W'Baker ZXP L I,(� Packer/Flex Lock Lina _ N I q HangerII.--.. ■ �..._._.. IIII III III ...._ w a°re TD:15,324'MD 16,270'TVD Intermediate Casing Production Liner: 6-3/4" Production Hole 7-5/8"29.7#L-80 Hyd563 Casing 4-1/2"11.6#L-80 Hydril 563 with Torque Rings 8,843'MD/6,278'TVD(76° INC) 15,324'MD/6,270'TVD 0 ! =�o ggF i A 1-'17- g C Z CI Z i N U ( r r N n D N s (n N rn C In IIS o n VI o z r O 0 o > Z mo g q vv a 0 J� O M O • O N T 4 O ❑ . Z CN o 0 D \ me _. ■ o0 ms I : --r0ONIN I ® 0 ■ ® o •, 1111111.11111 N D , ksVN‘l® 0ir, :„.. n: n `44) 1.-• 6 - II -4-1ri lb, �IiN1 DR �` ,, v r g >- � v _� _ 1 ® a N T 2 V LIED P.) E • o m ID C/) # , Jt 1:13 c - 0 € I 2:3 — N D I Y o_ Z A T T T T T T-7,1 m c 2S-05wp08.2[Nurse] 6.810 Plan Summary Top W Sak(W Sak Growler-AA CaimTop HRZ(K-2 mkr) • Base Befmuda Upper Kalubik(base HRZ) (?),, C-39 C-351Lower Kalubik(K-1 m1,15-5 56ase permafrost 1 I . , Top Belmada .._.._ .,-... \t vk ,�< 3 . i e- to)Z T-3 Sad .� C-40 S ____ A5 Base W Sak __ A4 1 -K-1nr r Kuparuk C(Top C4) - C-865q _--- / ,' " � �7-5/8"x>:'�/8"6y 111' � 0 , I 1 1 I I I , I I I I I ` I it 4 (/'�� 0 1 100 7000 10500 140001 I \ " _ 10-3/4"x 13-1/2 Measured Depth I4-1/2"x 6-3/4'14Aired'', o- 0" Geodetic Datum: -40�-- ®�, Depth Reference: Plan:39.5+120 @ 159.50usft(Doyon25) • Rig: Doyon25 ,,••• i01'' 110-3/4"x 13-1/21' o C3 V ,. ce 0900 OOO h o0o 7-5/8"x 9 7/8"by 11f 14-1/2"x 6-3/a'I e , i o_ to - O r o0 (Lc) 0 My 0 a 11 .. } illy i i I I O �/ I I []`y r, �i I I I 1jf:7 I 0 1500 3000 4500 6000 0 7 ,t °90100 0 10500 312000 13 I2sasm,oe Isaim""II 0 400 - 590 Horizontal Departure . ZEZ7.1590 - 770 330 se� 0 _ �., rr ,. z .z la. 770 - 980 I i a� /0. 4��'�" 960 - 1140 �rs �m 1111II�II 6e►?ir 4,# \ 4►ya+ o II 1 1111 I. -- -_ - yE, el :� 1140 - 1330 m 60 hiI 1 • 60at 1700 - 22so2260 2830CO \�`�Ng-25.03 ;whirr V �5 NO' 2830 - 3390 0 30 .,NI]IIIIII _______- __ e 0 - t 2�S-r PB1 vo -.o az a, lII4iIVII 2S-06Wpr°[Salmon] 3390 3950 3950 4510 c i . - :11� 45� - 550670 2S-03wp09 [Bamboo] - 50 0 40 5640 - 6200 6� 6200 - 7340 0 1500 3000 4500 6000 7500 9000 10500 240 126 7340 - eaeo SURVEY PROGRAM eaeo - 9620 Surface Location 9620 - 1076 Depth From Depth To Survey/Plan Tool Pad Elevation: 12000 10760 - 11so� 39.50 1000.00 2S-05wp08.2 . Nurse (Plan:2S-05) GYD-GC-SS210 - 160 1000.00 2000.00 2S-05wp08.2 Nurse (Plan-2S-05) MWD 1 i' 11900 1304 1000.00 2952.30 2S-05wp08.2 Nurse (Plan 2S-0B)WD+IFR-AK-CAZ-SC 180 13040 1418 2952.30 4452.30 2S-05wp08.2 Nurse (Plan 2S-05) MWD CASING DETAILS 14180 - 15324 2952.30 8843.41 2S-05wp08.2 Nurse (Plan 2S-0B ND+IFR-AK-CAZ-SC 8843.41 10343.41 25-05wp08.2 Nurse (Plan 2S-05) MWD TVD MD Name 8843.41 15324.15 25-05wp08.2 Nurse (Plan 25-05 ND+IFR-AK-CAZ-SC 2585.50 2952.30 10-3/4"x 13-1/2" Magnetic Model: BGGM2015 T 6277.50 8843.41 7-5/8"x 9-7/8"by 11" Magnetic Model Date: 10-Jul-16 - 6269.50 15324.15 41/2"x 6-3/4" Magnetic Declination: 18.12° To convert a Magnetic Direction to a True Direction,Add 18.12°East SECTION DETAILS 37AY 374 T-3 Sand Sec MD Inc Azi TVD +N/-S +E/-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 2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,170°TF,for 200.09' K-15 Marker 3 600.09 3 0 170.00 600.00 -5.18 0.91 1.50 170.00 -4.75 Start 2.5°/100'DLS,0°TF,for 915.3' 4 1515.40 25.88 170.00 1480.50 -228.49 40.29 2.50 0.00 -210.28 Hold for 111.15' 5 1626.55 25.88 170.00 1580.50 -278.27 48.71 0.00 0.00 -254.25 Start 3°/100'DLS,-53.75°TF,for 998.71' - 1373.5 6 2625.26 49.42 137.97 2372.75 -784.30 347.30 3.00 -53.75 -667.69 Hold for 3384.3' Base permafrost(? 7 6009.58 49.42 137.97 4574.36 -2693.60 2068.08 0.00 0.00-2066.56 Start 3.5°/100'DLS,-116.88°TF,for 2833.85' 8 8843.41 76.40 22.92 6277.50 -2056.97 3773.70 3.50 -116.88-1010.18 Hold for 20' - 1859.5 9 8863.41 76.40 22.92 6282.20 -2039.07 3781.27 0.00 0.00 -990.92 Start 3.5°/100'DLS,-44.03°TF,for 168.97' 10 9030.38 80.63 18.81 6315.45 -1886.22 3839.48 3.50 -44.03 -828.22 Hold for 93.33' Top W Sak ON Sak r) 11 9123.72 80.83 18.81 6330.84 -1799.05 3869.16 0.00 0.00 -736.34 Start 3°/100'DLS,-43.18°TF,for 198.74' 12 9322.46 85.00 14.72 6355.50 -1610.32 3925.97 3.00 -43.18 -539.34 2S-Nurse 1.Heel Start 2°7100'DLS,0°TF,for 298.47' -2535.5 13 9620.93 90.97 14.72 6365.99 -1321.95 4001.70 2.00 0.00 -241.19 Hold for 5703.22' Base W Sak 14 15324.15 90.97 14.72 8269.50 4193.42 5450.19 0.00 0.00 5461.15 2S-Nurse 2.Toe TD:15324.15'MD,6269.5'TVD -2959.5 C-80 4342.5 Permit Pack 46C-50 -47 -x99-p 7 Growler-rrAA �� E l4�9s�rj9FIHilaa gg C-35 p,2K ry�y in §F11, ",, kr) P 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 ollision 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. Prepared by: Checked by: Accepted by: Approved by: Vinent Osara Nate Beck Ifeanyi Ifesie • S 11:03,February 192016 Easting(4000 usft/in) ii , iIiiiiIiiiiIiiiiIii iIiiiiIiiiiIiiiiIy�nh�il , i iiIiiiI , I il , i , rliiiVokli 41-h4_'Fbi I , rr. 30 2M-17 2M-22H-14 2H-10 2H-0i 2 9 2 09A 1 2M-02 M-0 2M-1. 2K-04 2K-03 _ 2K-0� 2 -0 L1-01 _ (sp. 20002 tilt 2 -Timb ule2K2K- 1 WIF AMU 15 1 ! -71 rliroP61wp10 2M-33 2 -04 K-0. Kuparuk 2K Pad _ 2M-32L1PB1 M-08 2M-09 '',''r8AP:, 0140 2S-14wp09.2[ ,Ni34 2M-32L1PB 4L1 2 MI.12T1 � % 2K-26 2M-35 2M-��8AL2_wp04 ��� ���� -13 ��� I.1� 22K-15L71 — 1$-'11311 28-11wp08[Great White] - 2'4''' K-13AL2 2S-09wp06[Tiger] 2M-08A_wp05 2K-23 2L-03 - 2S-04 2S-07 2S-05wp08.2 e K!" 2K-17 _ 2K- 22A 4-25L1-( 0 2K-28'1 0— K-21A ? o Kuparuk 2S Pad 2S-o. 2 21 K-22 2K- 4A g co-5 - IIIP2L-306PB1 1 2S-13 1 r�� _ T K-22AL1-01 o e6 2L-31= -�I1" (kWIF Gulper p02 2K-22AL1 S —� 2L-3e'_ K' 21-1e-8 \`\moi 2L-310 i �"`�\ -2L-311 - 2L- -S l 2L-3 I T\=� 2L-3 6wp0g�`23' Rig:2S-03 2S-01 L-3 • 2L-31 ' 2S-3 5w 02 Cookiecut-r wp01 2L-320 2S-12w.e921gi 2L-3 2S-10 2L-3 e - -c1 9 oc_na,.,na rc.r Sigxillwp0l Lantern wp02 2N-322 2N 01(wp Prelim: Kuparuk Cairn PaCP29.2[Bamboo] 2U 12wp05 2 302 N-322P62�2�ppgg gg ) 2L-32.w Prelim: Kuparuk Cairn Pad 2N-3 1A 2L- '$S-i'wpuoltnyooausl[ ] 2�N3a24PB1 2 16wp06 Sq ualicorax I • , 1 , 1 , I , , I I 1 , , , l I I , 1 1 I I I l I I , I , I , f I I l I , , , I 1 , , I I I , I I , , I , I , I , , I , , r , I , , , I I I , , , I , , I , I , l , , I , , l , l , l Easting(4000 ustn) 2S-05wp08.2[Nurse] Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 4500- 2S OSwpOPe -.2[Nurse] 4-1/2"x 6-3/4" 2S-Nurse 2.Toe 3000- U) g1500- 0 7-5/8"x 9-7/8"by 11" z 0- 100 re- c°n o� 1500- 10-3/4"x 13-1/2" , (§) 00 �� 2S-Nurse 1.Heel Ao 6 -3000- 000 I -3000 -1500 0 1500 3000 4500 6000 7500 9000 West(-)/East(+) (1500 usft/in) S 410 2S-05wp08.2[Nurse] Section View top T-3 Sand K-15 Marker Base permafrost(?) 1000— /00Q , Top W Sak(W Sak D) "(Jo-'___._ 2000— 2000 F Base W Sak �, 0 0 10-3/4"x 13-1/ "490 --- C-80 3000 o. 0 900 C-50 To 1:9.,C-40 f C-37 >4000— t,SO0p Growler-AA a) irn a cn cb ped 'uof JHRZ) 5000 T(38a ase o 000' Lower40 m E u C (1fopk64) 00 IV - r r � 6000— co _,z03.___,.:-0)_6 o 7-5/8'x 9-7/8"by 11j o 1,0 2 i 0 3C®0 4034-1/2"x 6- 4 6000 °Vertical Section at 15.00° (1000 usft/in) ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-05 Plan: 2S-05 Plan: 2S-05wp08.2[Nurse] Report Permit Pack 19 February, 2016 411 ewew Comments apply to • Schlumberger • the line before it. Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse] Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan:2S-05 Well Position +N/-S 0.00 usft Northing: usft Latitude: +EI-W 0.00 usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore Plan:2S-05 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2015 7/10/2016 18.12 80.86 57,480 Design 2S-05wp08.2[Nurse] Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.50 0.00 0.00 15.00 Survey Tool Program Date 2/19/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 1,000.00 25-05wp08.2[Nurse](Plan:2S-05) GYD-GC-SS Gyrodata gyro single shots 1,000.00 2,000.00 2S-05wp08.2[Nurse](Plan:2S-05) MWD MWD-Standard 1,000.00 2,952.30 2S-05wp08.2[Nurse](Plan:2S-05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,952.30 4,452.30 25-05wp08.2[Nurse](Plan:2S-05) MWD MWD-Standard 2,952.30 8,843.41 2S-05wp08.2[Nurse](Plan:2S-05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,843.41 10,343.41 2S-05wp08.2[Nurse](Plan:2S-05) MWD MWD-Standard 8,843.41 15,324.15 2S-05wp08.2[Nurse](Plan:2S-05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (°) (usft) 39.50 0.00 0.00 39.50 -120.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -59.50 0.00 0.00 0.04 200.00 0.00 0.00 200.00 40.50 0.00 0.00 0.19 279.50 0.00 0.00 279.50 120.00 0.00 0.00 0.33 top T-3 Sand 300.00 0.00 0.00 300.00 140.50 0.00 0.00 0.33 2/19/2016 10:52:06AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger III Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit ND Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse) Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (0) (usft) (usft) (°/100usft) (0) (usft) 374.50 0.00 0.00 374.50 215.00 0.00 0.00 0.48 K-15 Marker 400.00 0.00 0.00 400.00 240.50 0.00 0.00 0.48 KOP:Start 1.5°/100'DLS,170°TF,for 200.09' 500.00 1.50 170.00 499.99 340.49 1.50 170.00 0.56 600.00 3.00 170.00 599.91 440.41 1.50 0.00 0.60 600.09 3.00 170.00 600.00 440.50 1.50 0.00 0.60 Start 2.5°/100'DLS,0°TF,for 915.3' 700.00 5.50 170.00 699.63 540.13 2.50 0.00 0.68 800.00 8.00 170.00 798.93 639.43 2.50 0.00 0.78 900.00 10.50 170.00 897.62 738.12 2.50 0.00 0.91 1,000.00 13.00 170.00 995.51 836.01 2.50 0.00 1.06 1,100.00 15.50 170.00 1,092.43 932.93 2.50 0.00 1.16 1,200.00 18.00 170.00 1,188.18 1,028.68 2.50 0.00 1.32 1,300.00 20.50 170.00 1,282.58 1,123.08 2.50 0.00 1.64 1,397.88 22.95 170.00 1,373.50 1,214.00 2.50 0.00 2.08 Base permafrost(?) 1,400.00 23.00 170.00 1,375.46 1,215.96 2.50 0.00 2.08 1,500.00 25.50 170.00 1,466.63 1,307.13 2.50 0.00 2.64 1,515.40 25.88 170.00 1,480.50 1,321.00 2.50 0.00 2.73 Hold for 111.15' 1,600.00 25.88 170.00 1,556.62 1,397.12 0.00 0.00 3.25 1,626.55 25.88 170.00 1,580.50 1,421.00 0.00 0.00 3.42 Start 3°/100'DLS,-53.75°TF,for 998.71' 1,700.00 27.24 166.12 1,646.20 1,486.70 3.00 -53.75 3.87 1,800.00 29.24 161.39 1,734.31 1,574.81 3.00 -50.28 4.49 1,900.00 31.39 157.24 1,820.64 1,661.14 3.00 -46.11 5.17 1,945.78 32.41 155.50 1,859.50 1,700.00 3.00 -42.53 5.91 Top W Sak(W Sak D) 2,000.00 33.66 153.58 1,904.96 1,745.46 3.00 -41.06 5.91 2,100.00 36.02 150.34 1,987.04 1,827.54 3.00 -39.44 3.04 2,200.00 38.46 147.45 2,066.65 1,907.15 3.00 -36.78 3.37 2,300.00 40.96 144.86 2,143.58 1,984.08 3.00 -34.48 3.73 2,400.00 43.51 142.52 2,217.62 2,058.12 3.00 -32.48 4.11 2,500.00 46.11 140.39 2,288.56 2,129.06 3.00 -30.75 4.52 2,600.00 48.75 138.44 2,356.20 2,196.70 3.00 -29.24 4.96 2,625.26 49.42 137.97 2,372.75 2,213.25 3.00 -27.92 5.07 Hold for 3384.3' 2,700.00 49.42 137.97 2,421.37 2,261.87 0.00 0.00 5.44 2,800.00 49.42 137.97 2,486.42 2,326.92 0.00 0.00 5.94 2,875.44 49.42 137.97 2,535.50 2,376.00 0.00 0.00 6.44 Base W Sak 2,900.00 49.42 137.97 2,551.48 2,391.98 0.00 0.00 6.44 2,952.30 49.42 137.97 2,585.50 2,426.00 0.00 0.00 6.93 10-3/4"x 13-1/2" 2/19/2016 10:52:06AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 3,000.00 49.42 137.97 2,616.53 2,457.03 0.00 0.00 6.93 3,100.00 49.42 137.97 2,681.58 2,522.08 0.00 0.00 7.57 3,200.00 49.42 137.97 2,746.64 2,587.14 0.00 0.00 8.35 3,300.00 49.42 137.97 2,811.69 2,652.19 0.00 0.00 9.26 3,400.00 49.42 137.97 2,876.74 2,717.24 0.00 0.00 10.24 3,500.00 49.42 137.97 2,941.80 2,782.30 0.00 0.00 11.29 3,527.21 49.42 137.97 2,959.50 2,800.00 0.00 0.00 12.39 C-80 3,600.00 49.42 137.97 3,006.85 2,847.35 0.00 0.00 12.39 3,700.00 49.42 137.97 3,071.90 2,912.40 0.00 0.00 13.52 3,800.00 49.42 137.97 3,136.96 2,977.46 0.00 0.00 14.68 3,900.00 49.42 137.97 3,202.01 3,042.51 0.00 0.00 15.86 4,000.00 49.42 137.97 3,267.07 3,107.57 0.00 0.00 17.05 4,100.00 49.42 137.97 3,332.12 3,172.62 0.00 0.00 18.26 4,200.00 49.42 137.97 3,397.17 3,237.67 0.00 0.00 19.48 4,300.00 49.42 137.97 3,462.23 3,302.73 0.00 0.00 20.71 4,400.00 49.42 137.97 3,527.28 3,367.78 0.00 0.00 21.95 4,500.00 49.42 137.97 3,592.33 3,432.83 0.00 0.00 11.74 4,600.00 49.42 137.97 3,657.39 3,497.89 0.00 0.00 12.18 4,700.00 49.42 137.97 3,722.44 3,562.94 0.00 0.00 12.63 4,800.00 49.42 137.97 3,787.49 3,627.99 0.00 0.00 13.09 4,900.00 49.42 137.97 3,852.55 3,693.05 0.00 0.00 13.55 5,000.00 49.42 137.97 3,917.60 3,758.10 0.00 0.00 14.01 5,100.00 49.42 137.97 3,982.66 3,823.16 0.00 0.00 14.48 5,200.00 49.42 137.97 4,047.71 3,888.21 0.00 0.00 14.95 5,300.00 49.42 137.97 4,112.76 3,953.26 0.00 0.00 15.42 5,400.00 49.42 137.97 4,177.82 4,018.32 0.00 0.00 15.90 5,500.00 49.42 137.97 4,242.87 4,083.37 0.00 0.00 16.38 5,600.00 49.42 137.97 4,307.92 4,148.42 0.00 0.00 16.87 5,653.15 49.42 137.97 4,342.50 4,183.00 0.00 0.00 17.35 C-50 5,700.00 49.42 137.97 4,372.98 4,213.48 0.00 0.00 17.35 5,800.00 49.42 137.97 4,438.03 4,278.53 0.00 0.00 17.84 5,900.00 49.42 137.97 4,503.08 4,343.58 0.00 0.00 18.33 6,000.00 49.42 137.97 4,568.14 4,408.64 0.00 0.00 18.83 6,009.56 49.42 137.97 4,574.36 4,414.86 0.00 0.00 18.87 Start 3.5°/100'DLS,-116.88°TF,for 2833.85' 6,057.07 48.68 136.00 4,605.50 4,446.00 3.50 -116.88 19.08 C-40 6,100.00 48.05 134.18 4,634.02 4,474.52 3.50 -115.59 19.08 6,200.00 46.69 129.79 4,701.77 4,542.27 3.50 -114.38 19.08 6,300.00 45.50 125.22 4,771.13 4,611.63 3.50 -111.41 18.96 6,311.92 45.37 124.67 4,779.50 4,620.00 3.50 -108.23 18.72 C-37 6,400.00 44.50 120.48 4,841.86 4,682.36 3.50 -107.84 18.72 2/19/2016 10:52:06AM Page 4 COMPASS 5000.1 Build 74 0 Schlumberger 111 Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit ND Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 6,500.00 43.71 115.58 4,913.69 4,754.19 3.50 -104.88 18.34 6,600.00 43.13 110.56 4,986.36 4,826.86 3.50 -101.36 17.83 6,618.00 43.04 109.64 4,999.50 4,840.00 3.50 -97.71 17.18 Growler-AA 6,700.00 42.77 105.44 5,059.58 4,900.08 3.50 -97.04 17.18 6,800.00 42.64 100.29 5,133.08 4,973.58 3.50 -93.97 16.40 2S W16-Toe 6,900.00 42.75 95.13 5,206.60 5,047.10 3.50 -90.18 15.52 7,000.00 43.08 90.01 5,279.86 5,120.36 3.50 -86.38 14.56 7,100.00 43.64 84.98 5,352.59 5,193.09 3.50 -82.63 13.54 7,200.00 44.42 80.06 5,424.51 5,265.01 3.50 -78.97 12.51 7,300.00 45.40 75.30 5,495.35 5,335.85 3.50 -75.44 11.51 7,324.48 45.67 74.16 5,512.50 5,353.00 3.50 -72.07 10.55 Top Cairn 7,400.00 46.57 70.72 5,564.85 5,405.35 3.50 -71.27 10.55 7,459.55 47.35 68.07 5,605.50 5,446.00 3.50 -68.88 9.70 Top Bermuda 7,500.00 47.92 66.32 5,632.76 5,473.26 3.50 -67.07 9.70 7,516.59 48.15 65.60 5,643.85 5,484.35 3.50 -65.89 8.98 2S W16-Heel 7,570.44 48.96 63.33 5,679.50 5,520.00 3.50 -65.41 8.98 Base Bermuda 7,600.00 49.42 62.11 5,698.82 5,539.32 3.50 -63.91 8.98 7,641.30 50.09 60.43 5,725.50 5,566.00 3.50 -63.11 8.42 C-35 7,700.00 51.08 58.09 5,762.77 5,603.27 3.50 -62.02 8.42 7,800.00 52.86 54.27 5,824.39 5,664.89 3.50 -60.54 8.05 7,900.00 54.76 50.63 5,883.45 5,723.95 3.50 -58.19 7.88 8,000.00 56.77 47.16 5,939.72 5,780.22 3.50 -56.04 7.92 8,100.00 58.86 43.85 5,992.99 5,833.49 3.50 -54.08 8.13 8,178.33 60.56 41.36 6,032.50 5,873.00 3.50 -52.32 8.50 Top HRZ(K-2 mkr) 8,200.00 61.04 40.68 6,043.07 5,883.57 3.50 -51.06 8.50 8,300.00 63.29 37.65 6,089.76 5,930.26 3.50 -50.73 8.99 8,358.63 64.64 35.93 6,115.50 5,956.00 3.50 -49.32 9.57 Upper Kalubik(base HRZ) 8,400.00 65.60 34.74 6,132.90 5,973.40 3.50 -48.56 9.57 8,500.00 67.97 31.93 6,172.33 6,012.83 3.50 -48.06 10.23 8,600.00 70.38 29.21 6,207.88 6,048.38 3.50 -46.95 10.94 8,700.00 72.83 26.58 6,239.44 6,079.94 3.50 -45.99 11.68 8,710.42 73.09 26.31 6,242.50 6,083.00 3.50 -45.15 12.45 Lower Kalubik(K-1 mkr) 8,800.00 75.31 24.01 6,266.89 6,107.39 3.50 -45.08 12.45 8,843.41 76.40 22.92 6,277.50 6,118.00 3.50 -44.45 12.67 Hold for 20'-7-5/8"x 9-7/8"by 11" 2/19/2016 10:52:06AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit ND Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 8,863.41 76.40 22.92 6,282.20 6,122.70 0.00 -44.18 12.66 Start 3.5°/100'DLS,-44.03°TF,for 166.97' 8,900.00 77.32 22.01 6,290.52 6,131.02 3.50 -44.03 12.76 9,000.00 79.86 19.55 6,310.30 6,150.80 3.50 -43.82 13.14 9,030.38 80.63 18.81 6,315.45 6,155.95 3.50 -43.33 13.27 Hold for 93.33' 9,100.00 80.63 18.81 6,326.78 6,167.28 0.00 0.00 13.42 9,123.72 80.63 18.81 6,330.64 6,171.14 0.00 0.00 13.47 Start.3°/100'DLS,-43.18°TF,for 198.74' 9,135.28 80.89 18.57 6,332.50 6,173.00 3.00 -43.18 13.86 Kuparuk C(Top C4) 9,200.00 82.30 17.23 6,341.96 6,182.46 3.00 -43.15 13.86 9,204.06 82.39 17.14 6,342.50 6,183.00 3.00 -42.95 14.51 A5 9,300.00 84.50 15.17 6,353.45 6,193.95 3.00 -42.94 14.51 9,322.46 85.00 14.72 6,355.50 6,196.00 3.00 -42.71 14.67 Start 2°/100'DLS,0°TF,for 298.47'-2S-Nurse 1.Heel-2S-Nurse 1.Heel_Cirlce 9,373.57 86.02 14.72 6,359.50 6,200.00 2.00 0.00 15.09 A4 9,400.00 86.55 14.72 6,361.21 6,201.71 2.00 0.00 15.09 9,500.00 88.55 14.72 6,365.49 6,205.99 2.00 0.00 15.67 9,600.00 90.55 14.72 6,366.27 6,206.77 2.00 0.00 16.36 9,620.93 90.97 14.72 6,365.99 6,206.49 2.00 0.00 16.51 Hold for 5703.22' 9,700.00 90.97 14.72 6,364.65 6,205.15 0.00 0.00 17.14 9,800.00 90.97 14.72 6,362.96 6,203.46 0.00 0.00 18.01 9,900.00 90.97 14.72 6,361.27 6,201.77 0.00 0.00 18.96 10,000.00 90.97 14.72 6,359.58 6,200.08 0.00 0.00 19.97 10,100.00 90.97 14.72 6,357.89 6,198.39 0.00 0.00 21.03 10,200.00 90.97 14.72 6,356.19 6,196.69 0.00 0.00 22.15 10,300.00 90.97 14.72 6,354.50 6,195.00 0.00 0.00 23.30 10,400.00 90.97 14.72 6,352.81 6,193.31 0.00 0.00 15.49 10,500.00 90.97 14.72 6,351.12 6,191.62 0.00 0.00 15.75 10,600.00 90.97 14.72 6,349.43 6,189.93 0.00 0.00 16.03 10,700.00 90.97 14.72 6,347.73 6,188.23 0.00 0.00 16.32 10,800.00 90.97 14.72 6,346.04 6,186.54 0.00 0.00 16.63 10,900.00 90.97 14.72 6,344.35 6,184.85 0.00 0.00 16.95 11,000.00 90.97 14.72 6,342.66 6,183.16 0.00 0.00 17.29 11,100.00 90.97 14.72 6,340.97 6,181.47 0.00 0.00 17.64 11,200.00 90.97 14.72 6,339.28 6,179.78 0.00 0.00 18.00 11,300.00 90.97 14.72 6,337.58 6,178.08 0.00 0.00 18.37 11,400.00 90.97 14.72 6,335.89 6,176.39 0.00 0.00 18.75 11,500.00 90.97 14.72 6,334.20 6,174.70 0.00 0.00 19.14 11,600.00 90.97 14.72 6,332.51 6,173.01 0.00 0.00 19.55 11,700.00 90.97 14.72 6,330.82 6,171.32 0.00 0.00 19.96 2/19/2016 10:52::06AM Page 6 COMPASS 5000.1 Build 74 0 Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 11,800.00 90.97 14.72 6,329.12 6,169.62 0.00 0.00 20.37 11,900.00 90.97 14.72 6,327.43 6,167.93 0.00 0.00 20.80 12,000.00 90.97 14.72 6,325.74 6,166.24 0.00 0.00 21.23 12,100.00 90.97 14.72 6,324.05 6,164.55 0.00 0.00 21.67 12,200.00 90.97 14.72 6,322.36 6,162.86 0.00 0.00 22.12 12,300.00 90.97 14.72 6,320.66 6,161.16 0.00 0.00 22.57 12,400.00 90.97 14.72 6,318.97 6,159.47 0.00 0.00 23.03 12,500.00 90.97 14.72 6,317.28 6,157.78 0.00 0.00 23.49 12,600.00 90.97 14.72 6,315.59 6,156.09 0.00 0.00 23.96 12,700.00 90.97 14.72 6,313.90 6,154.40 0.00 0.00 24.44 12,800.00 90.97 14.72 6,312.21 6,152.71 0.00 0.00 24.91 12,900.00 90.97 14.72 6,310.51 6,151.01 0.00 0.00 25.40 13,000.00 90.97 14.72 6,308.82 6,149.32 0.00 0.00 25.88 13,100.00 90.97 14.72 6,307.13 6,147.63 0.00 0.00 26.37 13,200.00 90.97 14.72 6,305.44 6,145.94 0.00 0.00 26.86 13,300.00 90.97 14.72 6,303.75 6,144.25 0.00 0.00 27.36 13,400.00 90.97 14.72 6,302.05 6,142.55 0.00 0.00 27.86 13,500.00 90.97 14.72 6,300.36 6,140.86 0.00 0.00 28.36 13,600.00 90.97 14.72 6,298.67 6,139.17 0.00 0.00 28.87 13,700.00 90.97 14.72 6,296.98 6,137.48 0.00 0.00 29.38 13,800.00 90.97 14.72 6,295.29 6,135.79 0.00 0.00 29.89 13,900.00 90.97 14.72 6,293.59 6,134.09 0.00 0.00 30.40 14,000.00 90.97 14.72 6,291.90 6,132.40 0.00 0.00 30.92 14,100.00 90.97 14.72 6,290.21 6,130.71 0.00 0.00 31.44 14,200.00 90.97 14.72 6,288.52 6,129.02 0.00 0.00 31.96 14,300.00 90.97 14.72 6,286.83 6,127.33 0.00 0.00 32.48 14,400.00 90.97 14.72 6,285.14 6,125.64 0.00 0.00 33.00 14,500.00 90.97 14.72 6,283.44 6,123.94 0.00 0.00 33.53 14,600.00 90.97 14.72 6,281.75 6,122.25 0.00 0.00 34.05 14,700.00 90.97 14.72 6,280.06 6,120.56 0.00 0.00 34.58 14,800.00 90.97 14.72 6,278.37 6,118.87 0.00 0.00 35.11 14,900.00 90.97 14.72 6,276.68 6,117.18 0.00 0.00 35.65 15,000.00 90.97 14.72 6,274.98 6,115.48 0.00 0.00 36.18 15,100.00 90.97 14.72 6,273.29 6,113.79 0.00 0.00 36.72 15,200.00 90.97 14.72 6,271.60 6,112.10 0.00 0.00 37.25 15,300.00 90.97 14.72 6,269.91 6,110.41 0.00 0.00 37.79 2K-Pad T5 15,324.15 90.97 14.72 6,269.50 6,110.00 0.00 0.00 37.92 TD:15324.15'MD,6269.5'TVD-4-1/2"x 6-3/4"-2S-Nurse 2.Toe-2S-Nurse 2.Toe Circle 2/19/2016 10:52:06AM Page 7 COMPASS 5000.1 Build 74 • Schlumberger ID Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 2,952.30 2,585.50 10-3/4"x 13-1/2" 10-3/4 13-1/2 8,843.41 6,277.50 7-5/8"x 9-7/8"by 11" 7-5/8 11 15,324.15 6,269.50 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 279.50 279.50 top T-3 Sand 0.00 1,397.88 1,373.50 Base permafrost(?) 8,358.63 6,115.50 Upper Kalubik(base HRZ) 8,178.33 6,032.50 Top HRZ(K-2 mkr) 7,570.44 5,679.50 Base Bermuda 6,057.07 4,605.50 C-40 5,653.15 4,342.50 C-50 3,527.21 2,959.50 C-80 374.50 374.50 K-15 Marker 7,459.55 5,605.50 Top Bermuda 6,618.00 4,999.50 Growler-AA 9,135.28 6,332.50 Kuparuk C(Top C4) 7,641.30 5,725.50 C-35 7,324.48 5,512.50 Top Cairn 1,945.78 1,859.50 Top W Sak ON Sak D) 8,710.42 6,242.50 Lower Kalubik(K-1 mkr) 9,373.57 6,359.50 A4 6,311.92 4,779.50 C-37 9,204.06 6,342.50 A5 2,875.44 2,535.50 Base W Sak Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 400.00 400.00 0.00 0.00 KOP:Start 1.5°/100'DLS, 170°TF,for 200.09' 600.09 600.00 -5.16 0.91 Start 2.5°/100'DLS,0°TF,for 915.3' 1,515.40 1,480.50 -228.49 40.29 Hold for 111.15' 1,626.55 1,580.50 -276.27 48.71 Start 3°/100'DLS,-53.75°TF,for 998.71' 2,625.26 2,372.75 -784.30 347.30 Hold for 3384.3' 6,009.56 4,574.36 -2,693.60 2,068.06 Start 3.5°/100'DLS,-116.88°TF,for 2833.85' 8,843.41 6,277.50 -2,056.97 3,773.70 Hold for 20' 8,863.41 6,282.20 -2,039.07 3,781.27 Start 3.5°/100'DLS,-44.03°TF,for 166.97' 9,030.38 6,315.45 -1,886.22 3,839.48 Hold for 93.33' 9,123.72 6,330.64 -1,799.05 3,869.16 Start 3°/100'DLS,-43.18°TF,for 198.74' 9,322.46 6,355.50 -1,610.32 3,925.97 Start 2°/100'DLS,0°TF,for 298.47' 9,620.93 6,365.99 -1,321.95 4,001.70 Hold for 5703.22' 15,324.15 6,269.50 4,193.42 5,450.19 TD: 15324.15'MD,6269.5'TVD Checked By: Approved By: Date: 2119/2016 10:52:06AM Page 8 COMPASS 5000.1 Build 74 • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-05 Plan: 2S-05 2S-05wp08.2[Nurse] Clearance Summary Anticollision Report 19 February, 2016 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2S Pad-Plan:2S-05-Plan:2S-05-2S-05wp08.2[Nurse] Well Coordinates: Datum Height: Plan:39.5+120 @ 159.50usft(Doyon25) Scan Range: 0.00 to 15,324.15 usft.Measured Depth. Scan Radius is 1,728.47 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 III • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-05 -2S-05wpO8.2[Nurse] Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2S Pad-Plan:2S-05-Plan:2S-05-2S-05wp08.2[Nurse] Scan Range: 0.00 to 15,324.15 usft.Measured Depth. Scan Radius is 1,728.47 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 2S Pad 2S-01-2S-01-2S-01 349.86 117.14 349.86 110.93 350.00 18.861 Centre Distance Pass-Major Risk 2S-01-2S-01-2S-01 399.85 117.42 399.85 110.38 400.00 16.676 Clearance Factor Pass-Major Risk 2S-02-2S-02-2S-02 262.00 89.23 262.00 82.39 250.00 13.041 Centre Distance Pass-Major Risk 2S-02-2S-02-2S-02 361.96 89.86 361.96 81.60 350.00 10.886 Clearance Factor Pass-Major Risk 2S-04-2S-04-2S-04 511.89 26.47 511.89 17.75 500.00 3.037 Centre Distance Pass-Major Risk 2S-04-25-04-2S-04 710.95 28.09 710.95 16.93 700.00 2.518 Clearance Factor Pass-Major Risk 2S-04-2S-04PB1-2S-04PB1 511.89 26.47 511.89 17.75 500.00 3.037 Centre Distance Pass-Major Risk 2S-04-2S-04PB1-2S-04PB1 710.95 28.09 710.95 16.93 700.00 2.518 Clearance Factor Pass-Major Risk 2S-07-2S-07-2S-07 39.50 59.67 39.50 58.44 27.50 48.521 Centre Distance Pass-Major Risk 2S-07-2S-07-2S-07 911.34 62.87 911.34 43.23 900.00 3.202 Clearance Factor Pass-Major Risk 2S-08-2S-08-2S-08 286.99 88.79 286.99 83.74 275.00 17.553 Centre Distance Pass-Major Risk 2S-08-2S-08-2S-08 361.96 89.37 361.96 83.05 350.00 14.156 Clearance Factor Pass-Major Risk 2S-10-2S-10-2S-10 833.99 141.76 833.99 128.95 825.00 11.068 Centre Distance Pass-Major Risk 2S-10-2S-10-2S-10 882.22 142.21 882.22 128.69 875.00 10.517 Clearance Factor Pass-Major Risk Plan:25-06-Plan:2S-06-25-06wp06[Salmon] 511.48 30.11 511.48 21.30 500.00 3.416 Centre Distance Pass-Major Risk Plan:2S-06-Plan:2S-06-2S-06wp06[Salmon] 586.23 30.56 586.23 20.63 575.00 3.078 Clearance Factor Pass-Major Risk Plan:2S-09-Plan:2S-09-2S-09wp06[Tiger] 461.57 120.17 461.57 112.17 450.00 15.033 Centre Distance Pass-Major Risk Plan:2S-09-Plan:2S-09-2S-09wp06[Tiger] 911.81 123.33 911.81 109.03 900.00 8.620 Clearance Factor Pass-Major Risk Plan:2S-11-Plan:2S-11-2S-11wp08[Great White] 375.00 180.28 375.00 173.64 375.00 27.126 Centre Distance Pass-Major Risk Plan:2S-11-Plan:2S-11-2S-11wp08[Great White] 525.22 181.32 525.22 172.65 525.00 20.922 Clearance Factor Pass-Major Risk Plan:2S-12-Plan:2S-12-2S-12wp07[Bull] 361.50 210.19 361.50 203.80 350.00 32.899 Centre Distance Pass-Major Risk Plan:2S-12-Plan:2S-12-2S-12wp07[Bull] 436.57 210.69 436.57 203.08 425.00 27.690 Clearance Factor Pass-Major Risk Plan:2S-315-Plan:2S-315-25-315wp02 400.50 240.40 400.50 233.31 400.00 33.907 Centre Distance Pass-Major Risk Plan:2S-315-Plan:2S-315-2S-315wp02 450.61 240.70 450.61 232.87 450.00 30.774 Clearance Factor Pass-Major Risk Rig:2S-03-Rig:2S-03-2S-03wp09.2[Bamboo] 324.81 57.75 324.81 51.99 325.00 10.018 Centre Distance Pass-Major Risk Rig:2S-03-Rig:2S-03-2S-03wp09.2[Bamboo] 399.73 58.27 399.73 51.21 400.00 8.253 Clearance Factor Pass-Major Risk Rig:2S-03-Rig:2S-03-Rig:2S-03 324.81 57.75 324.81 51.99 325.00 10.018 Centre Distance Pass-Major Risk Rig:2S-03-Rig:2S-03-Rig:2S-03 399.73 58.27 399.73 51.21 400.00 8.253 Clearance Factor Pass-Major Risk 19 February,2016- 9:58 Page 2 of 5 COMPASS • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-05-2S-05wp08.2[Nurse] Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2S Pad-Plan:2S-05-Plan:2S-05-2S-05wp08.2[Nurse] Scan Range: 0.00 to 15,324.15 usft.Measured Depth. Scan Radius is 1,728.47 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 Sixgill-Sixgill-Sigxillwp0l 1,231.99 217.44 1,231.99 197.70 1,250.00 11.014 Centre Distance Pass-Major Risk Sixgill-Sixgill-Sigxillwp0l 1,253.84 217.65 1,253.84 197.58 1,275.00 10.845 Clearance Factor Pass-Major Risk Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.50 1,000.00 2S-05wp08.2[Nurse] GYD-GC-SS 1,000.00 2,000.00 2S-05wp08.2[Nurse] MWD 1,000.00 2,952.30 2S-05wp08.2[Nurse] MWD+IFR-AK-CAZ-SC 2,952.30 4,452.30 2S-05wp08.2[Nurse] MWD 2,952.30 8,843.41 2S-05wp08.2[Nurse] MWD+IFR-AK-CAZ-SC 8,843.41 10,343.41 2S-05wp08.2[Nurse] MWD 8,843.41 15,324.15 2S-05wp08.2[Nurse] 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. 19 February.2016- 9:58 Page 3 of 5 COMPASS • • 10:11, February 19 .016 Ladder View 2S-05w 08.2rNurse L ] The Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors 0 n° T E '4. -ii m a M cl E m a1 '8 m 3 a h. MN N N N N li J,l ,,111,1111'�I 411 300— Il Io I — 1 II f- nl / � I Ig III1y1 IIll 1lot a - nulI, VolJIf,„,.,. In,lmaI ; ' J I 1 lil II .. .,_-iii illr III 1 I I I ° �� waml lIalL ' II Ir ,l)IIU nl[ d � lll � —4,4310. I i. Ai Equivelant Magnetic Distance - -- - - '-- - 0 I , „ „ , „ , , , , „ , , , 0 1500 3000 4500 6000 7500 9000 10500 Displayed interval could be less than entire well:Measured Depth 39.50 To 15324.15 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.50 1000.00 25-05wp08.2[Nurse] (Plan: 25-05)GYD-GC-SS 2585.: 52.30 10-3/4"x 13-1/2" 1000.00 2000.00 25-05wp08.2[Nurse] (Plan: 25-05)MWD 6277.1.:43745/8"x 9-7/8" by 11" 1000.00 2952.30 25-05wp08.2[Nurse] (Plan: 25-05)MWD+IFR-AK-CAZ-SC 62691E324.15 4-1/2"x 6-3/4" 2952.30 4452.30 25-05wp08.2[Nurse] (Plan: 25-05)MWD 2952.30 8843.41 25-05wp08.2[Nurse] (Plan: 2S-05)MWD+IFR-AK-CAZ-SC 8843.4110343.41 25-05wp08.2[Nurse] (Plan: 2S-05)MWD 8843.4115324.15 2S-05wp08.2[Nurse] (Plan: 2S-05)MWD+IFR-AK-CAZ-SC 0 0 I o E P2. - N g 3 a I A, N A N N 60 g llr --, !r r '2'4110011111id 'IlipV --2 %NW' ii : N 30— ,111111 IIIl 0 Egmvelant Magnetic Distanc �'I'�'�I g IIMIIIll1111P co U 0 I I I I I I I I I I I I I I I I I I I I I I I I I I I I , I I I , 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth 4U 4UU 2S-05wp08.2[Nurse] • MD Inc Azi TVD Dleg T e Target 400 590 39.50 0.00 0.00 39.50 0.00 0.00 39.50 To 15324.15 400.00 0.00 0.00 400.00 0.00 0.00 590 770 600.09 3.00 170.00 600.00 1.50 170.00 770 960 1515.40 25.88 170.00 1480.50 2.50 0.00 10:10, February 19 2016 1626.55 25.88 170.00 1580.50 0.00 0.00 960 " 1140 2625.26 49.42 137.97 2372.75 3.00 -53.75 CASING DETAILS 6009.56 49.42 137.97 4574.36 0.00 0.00 1140 1330 8843.41 76.40 22.92 6277.50 3.50 -116.88 1330 """" 1510 TVD MD Name 8863.41 76.40 22.92 6282.20 0.00 0.00 2585.50 2952.30 10-3/9" x 13-1/2" 9030.38 80.63 18.81 6315.45 3.50 -44.03 6277.50 8893.41-5/8" x 9-7/8" by 11" 1510 1700 6269.50 15324.15 9-1/2" x 6-3/9'• 9123.72 80.63 18.81 6330.64 0.00 0.00 9322.46 85.00 14.72 6355.50 3.00 -43.18 20-Nurse 1.Heel 1700 2260 9620.93 90.97 14.72 6365.99 2.00 0.00 4"Ru,PR,4,, 15324.15 90.97 14.72 6269.50 0.00 0.00 2S-Nurse 2.Toe 2260 2830 39 50 1000 00 25 05,08 PINurseI 5,4.2["u=,., (._an:25.13-00-99 2830 3390 2952 30 9952 30 2S 8.2[Rnrse, `Plan,2340a, 3390 .""_ 3950 2952 30 9893.1 - .2[Rurse1 (Plan:2 4a SgN=PRM- -cu-ac 2[Rnr,e, 3950 4510 4510 " 5070 5070 """" """ 5640 5640 6200 2S-06wp06 [Salmon] 6200 7340 / v r 360 7340 "" 8480 ' 2S-10 8480 9620 , ' AOilh ---1 22 al 44., SI xillw 01 _ 1 '�7! i°�►re 9620 10760 g p 30/33+, 8'g� 1 I�aea,,,�,±I-��, 30 2S-01 jam ' fl� .Ai 10760 11900 2S-08 • P•w� ►` 1 a5-__ 9 �O�yJ�f?/ -i ► �� - 201 11900 13040 in j� �`� 180 - ' N,' Ar d. , �,j' `. .' - ,wa 13040 14180 2S-04PB1 ►��: ' `!i1 165 I 1 N 01•V 13040 C/1 14180 15324 -'a e4°: il- v'R G„� ��i'?v"'� 1 �,b 1;-4 -, N few®s!�® $. 2S-04--- •r,�, ,-,�er►,,a,s b-.� -,,,;,--,*-.4.41,1 . . �v�i' `11 ,< i r�� : ®I��1 i ---- " , G a�� - -60/300 .A vrrare U •:,4)q. 't/fQa 0 .�c ,i I/�r‘� .�,,• 1 p pv;i��j.� 1 ► '_1 j� \ �1' �i j , 60 L '.--VN '444klilliikt ISIA / 1i�tilek'i�'"s.Ay+02I����i�r'-'4,„4„,-, ►p.�y rr�ly`.-- ii t A --14.141 ij►o y ..i•l 90 '0 # \ i1f 1 .Ar \\ .lir 7♦♦l p.-...A4; _Iveiti;of :•,tare *44, \ \ �i 407, WA 2S-12wp07 [Bull [ _AN o,A;VI%i 1; 0: �.�► Rig:�4w�/� ��.,41 v� 1° 012e.,--irde....r,,,-.,,,E1.7-, ♦ % qtr/!• •: PP ♦. 1 � i p .1 1�- �Il�ii �I •� •.r� .' to � Ci�� i t4/f�i JG . ,1 eb®, 9a \ y s- ( R� -8 i iIp►7�i' LIt�•i[Iii„',,;;;;;"::'-'3\ �.`✓r/ CiP \ 's., ;�, ��yij����� rYl�'�\. • \ � 1,9, •IFj.. SI- ��'�'r � ` „ 1' r st+'o' .- `11 �� ` amuse ' ':Y4;' .®,,i; w ',i•._ i -.'�3 a[ ' 90/270' [ ,� q ' t • t_-90 4s p j A1r �%Clr.yr. i% moi, MAW' 75 % /G- /f F' \' !2S-09wp06 tri•. - 5^ /fJ 2S-11wp08 [Great P r��e] 10 ),,1,i -/.-- /� _'v „'I, A20/240 120 ,-.> ,--7,,, :/, 120 135 '; :" ��,� !'°"-- 2S-03wp09.2 [Bamboo 2S-07 150 �`` ' 1� '< 165 ,�416:.,;;. 180 I tW `l 195 j,0 �q�*filtittp, -2S-02 -150/210 - 210 41" 150 emiloolor/A 40' r. -180/180 S • 10:11,February 19 201E Easting(2500 usft/in) 1 1 1 1 1 1 1 I 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 I I 1 1 I 1 1 1 [ 1 1 1 1 1 1 1 1 l 1 l 1 I I I 1 1 1 ] [ I I I I [ 1 1 1 1 I 1 1 1 1 I 1 1 1 1 l 1 1 1 1 1 1 (NOT a Spider ' 2s-1lwpOS[Great White] 2S-09wp06[Tiger] 2S-04 2S-07 2S-05wp0S.2[Nurse] Kuparuk 2S Pas 2S-02 z 0 11 ,11.11,111 :p.,111 � �OI Z _ Rig:2S-03 2S-01 2S-315w.02 2S-12wp07[B'1128-05 2S-10 2S-06wp06[Salmon] Sigxillwp0l 2S-03wp09.2[Bamboo] 1 111111111111111111111111Iii 1111111111111111111111111111111111111111111111111 Easting(2500 usft/in) AC Flipbook • 0 Casing Detalk survey Progrsm 2S-05Wp08.2[NUrse] -r435 D MDep[h From Dep[h To SurveylPlan Tool ---- ---- 2585.50 2952.3D Name0 °3/4x+3+/2° oaa.0a wp0 [ 627750 889341 75/8 °"x97/8"by'1'• 3950 2S 05wp08.2[Nurze](PIan:2So5) GYDLC-55 4 400 6269.50 15324.15 q-�/2"x 63/9" 35-0 8.2 Nurze PIan:25-0 MWD 1000.00 2 1a0o.0o 29s2.30 2505wp08.2[Nurze](PIan:25-05) MWD+IFRAKCAZSC 3952.30 9952.30 is-o5wpo8.2[Nurse](Plan:z5-05) MWD O0 .. .. ° 39.xC)/0 To 1000.00 295230 8893.91 7505wp08.z[NRK urse](PIan:2505) MWD+IFACAZSC 4 59 8843.41 1344. 35-5wpos.z[Nurze](PIan:2S-os) MWD 884341 15532415 15 7505wp08.4Nurze](PIan:25-05) MWD+IFR AK CAZ-SC 590 770 MD Azi 2S-o6wpo6 [Salmon] 0 / 36o 25-03wpo9.2 [Bamboo] 770 960 39.5o o.00 go 96o 114o 400.00 0.00 -30 / 444PB10 Rig: 25-03 170.00 P:�.,- 1140 1330 1515.4o 170.00 a4 i®®�� 1330 1510 1626.55 170.00 � , Mrift\2S-o4 `rr a��, 2625.26 137.97 /�l* � ���0%4 1510 1700 6009.56 137.97 -60 / 300 1/`��� ;1 ,;�,4 60 1700 2260 0111010 8843.41 22.92 25-0 1�ip 4 (10) .•!IL 1 ��:`� 2260 2830 8863.41 22.92 7 k` 0®� ,�����-11�_" �'c', 4�.ni .....,, 2830 3390 9030.38 18.81 �� �0� "•4.419044 ` r I :? ��i��►.� �.o.. x, 3390 3950 9123.72 18.81 ���'���,�, � � 9322.46 14.72 �� F ) 3950 4510 9620.93 14.190 / 270 ,�1If�I','� v� wog 5 90 ii ; 4510 5070 15324.15 14.72 1'� 5070 564° 25-02 25-08 '- 3 0 5640 6200 6200 7340 -120 / 240 , . 120 7340 848o 6 0 8480 9620 9620 10760 10760 11900 -150 / 210 150 9 0 11900 13040 -180 / 180 13040 14180 14180 15324 10:13,February 19 2016 0 • Cazing Details Survey Program 2S-o5wpo 8•2[Nurse1 T7'51:,'5 D MD Name Depth From Depth To Survey/Plan Tool 2585.50 2952.30 o3/4"x+3'U2" o00aa 622].50 8893 9, ]518"xg)/8"by n„ 39Sa t x5-o5wPo8.2[Nurse](Plan:25o5) GYDLC-SS 40 40 0 qt/zx 3 oo.o0 2 So5wpo8.2[Nurse](Plan:2S-o5) MWD 626950 r5329r5 b'/4 woo 2952 3o Z5-05wP08.2[Nurse](Plan:2505) MWDAFR AKCAZSC To2952.30 4452.30 25-0520p08.2[Nurse](Plan:25-05) MWD 400 590 1000f002000 .00 2952 3.88434 t83434t 2505wpo82[Nurse](Plan:25o5) MWD 25 05) IFRAKCASC 88934, 15324 t5 2So5wP08.2[Nurse](Plan:25 05) MWDAFR AK-CAZ-SC 590- 770 MD AZA 25-04 ) / 36o 2S-o4PB1 770 96o 39.5o o.00 /°��`���90 96o- 1140 00.00 o.0000/479471111111k\:400/1M' ® 4 -30 / 33 o - 600.09 170.00 _-Oteztaii144 i0.114, 1140 1330 ogusik 1515.40 170.00 �..,,.t® �/� �� 1330 1510 1626.55 170.00 "`�� `' X440,, r 4 1510 1700 2625.26 137.97 - �++� -60 / 300 �� 60 1700 2260 11 6009.56 137.97 "ii�� 8843.41 22.92 ,1 1st v.: 2260 2830 25-0] I,wi�mik 8863.41 22. z :�r����•� } 30 283o 3390 34 9 9030.38 18.81 f/I 0 0 9123.72 18.81 /°/,i' 339 395 322.46 14.72 '�'` � ,, 3950 4510 9620.93 14.7 0 / 2]0 _ )90 4510 5070 15324.15 14.72 r„„pf iGi • • Casing Details Survey Program ND MD Name Depth From Depth To Survey/Plan Tool 25--05Wp08 [Nurse] 85.50 952.30 3l9"x,3.,,2" 000.00 6z]Z�So 88939, 7-5M"x Mr by," 39.50 2S05wpo8.414urse](Plom 25-o5) GYD-GC-55 40 400 • 9 2S -05) MWD 6269.50 15324.15 4-,h"x6-3/4" 1000.00 2952.30 2So5wpo8.z[Nurse](Nam 25.05) MWD.IFRAK CAM( 2952.30 4452.30 25-o5wpo8.2[Nurse](Plan:OS.05) MWD 2000.00 To 15324.15 1 952.30 889391 25-05wpo8.2[Nu e](PIan:2S05) MWD.IFPAKCAZ-SC 400 590 8893.91 1034341 z5-o5wpo8.2[Nurse](Plan:25-05) MWD 88939, 15324,5 25-05wp08.2[Nurse](PIan:2So5) MWD.IFRAK PAZ-SC 590 770 MD Azi 0 / 360 77o 960 39.5o 0.00 9 o 960 1140 400.00 0.00 -30 / 33 0 600.09 170.00 1140 1330 1515.40 170.00 1330 1510 1626.55 170.00 /' 60 1510 1700 2625.26 137.97 6009.56 137.97 -6o / 300 60 1700 2260 8843.41 22.92 2260 2830 8863.41 22.9277 , 3Oz830 3390 9030.38 18.81 9123.72 18.81 3390 3950 9322.46 14.72 3950 4510 9620.93 14.790 / 270 . 90 4510 5070 15324.15 14.72 507o 564o 30 564o 62oo 6200 7340 -120 / 240 ` 120 7340 848o 6o 848o 9620 9620 10760 10760 11900 -150 / 210 150 go 11900 13040 -180 / 180 13040 14180 14180 15324 1o:15,February 19 2016 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-05 Plan: 2S-05 Plan: 2S-05wp08.2[Nurse] Report - Errors T• -rrors: 19 February, 2016 Multiply b 1110 Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse] Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan:2S-05 Well Position +N/-S 0.00 usft Northing: usfl Latitude: +E/-W 0.00 usft Easting: usfl Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore Plan:2S-05 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 7/10/2016 18.12 80.86 57,480 Design 2S-05wp08.2[Nurse] Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.50 0.00 0.00 15.00 Survey Tool Program Date 2/19/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 1,000.00 25-05wp08.2[Nurse](Plan:2S-05) GYD-GC-SS Gyrodata gyro single shots 1,000.00 2,000.00 2S-05wp08.2[Nurse](Plan:2S-05) MWD MWD-Standard 1,000.00 2,952.30 2S-05wp08.2[Nurse](Plan:2S-05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,952.30 4,452.30 2S-05wp08.2[Nurse](Plan:2S-05) MWD MWD-Standard 1(Plan:2S 05 Nurse +I AK 2,952.30 8,843.41 2S 05wP [08.2 MWD+IFR-AK-CAZ SC MWD FRCAZ SCC ) 8,843.41 10,343.41 2S-05wp08.2[Nurse](Plan:2S-05) MWD MWD-Standard 8,843.41 15,324.15 2S-05wp08.2[Nurse](Plan:2S-05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (0) (usft) (usft) (usft) (usft) 39.50 0.00 0.00 0.00 -120.00 0.00 0.00 0.00 100.00 1.15 0.00 0.00 -59.50 1.15 0.04 0.04 200.00 1.15 0.00 0.00 40.50 1.15 0.19 0.19 279.50 1.15 0.00 0.00 120.00 1.15 0.33 0.33 top T-3 Sand 300.00 1.15 0.00 0.00 140.50 1.15 0.33 0.33 2119/2016 10:06:09AM Page 2 COMPASS 5000.1 Build 74 0 Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (°) (usft) (usft) (usft) (usft) 374.50 1.15 0.00 0.00 215.00 1.15 0.48 0.48 K-15 Marker 400.00 1.15 0.00 0.00 240.50 1.15 0.48 0.48 KOP:Start 1.5°/100'DLS,170°TF,for 200.09' 500.00 1.15 1.50 45.00 340.49 1.15 0.56 0.56 600.00 1.15 3.00 80.17 440.41 1.15 0.60 0.60 600.09 1.15 3.00 80.17 440.50 1.15 0.60 0.60 Start 2.5°/100'DLS,0°TF,for 915.3' 700.00 1.16 5.50 80.29 540.13 1.15 0.68 0.68 800.00 1.16 8.00 80.73 639.43 1.15 0.78 0.77 900.00 1.17 10.50 168.69 738.12 1.15 0.91 0.88 1,000.00 1.18 13.00 169.63 836.01 1.15 1.06 1.00 1,100.00 1.19 15.50 169.99 932.93 1.14 1.16 1.07 1,200.00 1.20 18.00 170.45 1,028.68 1.13 1.32 1.08 1,300.00 1.22 20.50 170.49 1,123.08 1.13 1.64 1.12 1,397.88 1.23 22.95 170.48 1,214.00 1.12 2.08 1.18 Base permafrost(?) 1,400.00 1.23 23.00 170.48 1,215.96 1.12 2.08 1.18 1,500.00 1.25 25.50 170.46 1,307.13 1.13 2.64 1.26 1,515.40 1.26 25.88 170.46 1,321.00 1.12 2.73 1.28 Hold for 111.15' 1,600.00 1.26 25.88 170.44 1,397.12 1.14 3.25 1.38 1,626.55 1.26 25.88 170.44 1,421.00 1.15 3.42 1.41 Start 3°/100'DLS,-53.75°TF,for 998.71' 1,700.00 1.28 27.24 170.23 1,486.70 1.17 3.87 1.52 1,800.00 1.33 29.24 169.32 1,574.81 1.20 4.49 1.72 1,900.00 1.41 31.39 167.91 1,661.14 1.24 5.17 1.96 1,945.78 1.52 32.41 166.21 1,700.00 1.29 5.91 2.22 Top W Sak(W Sak D) 2,000.00 1.52 33.66 166.21 1,745.46 1.29 5.91 2.22 2,100.00 1.44 36.02 167.45 1,827.54 1.20 3.04 1.72 2,200.00 1.50 38.46 165.40 1,907.15 1.23 3.37 1.84 2,300.00 1.59 40.96 163.33 1,984.08 1.26 3.73 1.97 2,400.00 1.69 43.51 161.28 2,058.12 1.31 4.11 2.09 2,500.00 1.80 46.11 159.29 2,129.06 1.36 4.52 2.21 2,600.00 1.93 48.75 157.37 2,196.70 1.43 4.96 2.33 2,625.26 1.96 49.42 156.94 2,213.25 1.44 5.07 2.36 Hold for 3384.3' 2,700.00 1.97 49.42 155.63 2,261.87 1.51 5.44 2.45 2,800.00 1.97 49.42 154.15 2,326.92 1.60 5.94 2.59 2,875.44 1.98 49.42 152.91 2,376.00 1.70 6.44 2.73 Base W Sak 2,900.00 1.98 49.42 152.91 2,391.98 1.70 6.44 2.73 2,952.30 2.02 49.42 151.83 2,426.00 1.73 6.93 2.80 10-3/4"x 13-1/2" 2/19/2016 10:06:09AM Page 3 COMPASS 5000.1 Build 74 S Schlumberger 1111 Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (°) (usft) (usft) (usft) (usft) 3,000.00 2.02 49.42 151.83 2,457.03 1.73 6.93 2.80 3,100.00 2.02 49.42 150.20 2,522.08 1.76 7.57 2.83 3,200.00 2.03 49.42 148.50 2,587.14 1.82 8.35 2.89 3,300.00 2.04 49.42 146.96 2,652.19 1.90 9.26 2.97 3,400.00 2.05 49.42 145.67 2,717.24 2.00 10.24 3.08 3,500.00 2.06 49.42 144.61 2,782.30 2.12 11.29 3.22 3,527.21 2.07 49.42 143.75 2,800.00 2.26 12.39 3.37 C-80 3,600.00 2.07 49.42 143.75 2,847.35 2.26 12.39 3.37 3,700.00 2.08 49.42 143.05 2,912.40 2.41 13.52 3.54 3,800.00 2.09 49.42 142.48 2,977.46 2.57 14.68 3.73 3,900.00 2.10 49.42 142.01 3,042.51 2.74 15.86 3.92 4,000.00 2.11 49.42 141.62 3,107.57 2.91 17.05 4.13 4,100.00 2.12 49.42 141.30 3,172.62 3.09 18.26 4.35 4,200.00 2.13 49.42 141.02 3,237.67 3.28 19.48 4.58 4,300.00 2.14 49.42 140.79 3,302.73 3.47 20.71 4.81 4,400.00 2.15 49.42 140.58 3,367.78 3.66 21.95 5.05 4,500.00 2.16 49.42 144.59 3,432.83 2.59 11.74 3.72 4,600.00 2.18 49.42 144.29 3,497.89 2.68 12.18 3.83 4,700.00 2.19 49.42 144.01 3,562.94 2.78 12.63 3.94 4,800.00 2.20 49.42 143.76 3,627.99 2.87 13.09 4.05 4,900.00 2.21 49.42 143.53 3,693.05 2.97 13.55 4.17 5,000.00 2.22 49.42 143.31 3,758.10 3.07 14.01 4.28 5,100.00 2.24 49.42 143.12 3,823.16 3.17 14.48 4.41 5,200.00 2.25 49.42 142.94 3,888.21 3.27 14.95 4.53 5,300.00 2.26 49.42 142.77 3,953.26 3.38 15.42 4.65 5,400.00 2.28 49.42 142.61 4,018.32 3.48 15.90 4.78 5,500.00 2.29 49.42 142.47 4,083.37 3.59 16.38 4.91 5,600.00 2.30 49.42 142.34 4,148.42 3.70 16.87 5.04 5,653.15 2.32 49.42 142.22 4,183.00 3.80 17.35 5.18 C-50 5,700.00 2.32 49.42 142.22 4,213.48 3.80 17.35 5.18 5,800.00 2.33 49.42 142.10 4,278.53 3.91 17.84 5.31 5,900.00 2.34 49.42 142.00 4,343.58 4.02 18.33 5.45 6,000.00 2.36 49.42 141.90 4,408.64 4.13 18.83 5.58 6,009.56 2.36 49.42 141.89 4,414.86 4.14 18.87 5.59 Start 3.5°/100'DLS,-116.88°TF,for 2833.85' 6,057.07 2.73 48.68 141.82 4,446.00 4.24 19.08 5.95 C-40 6,100.00 2.73 48.05 141.82 4,474.52 4.24 19.08 5.95 6,200.00 3.40 46.69 141.72 4,542.27 4.34 19.08 6.48 6,300.00 4.22 45.50 141.57 4,611.63 4.44 18.96 7.16 6,311.92 5.11 45.37 141.35 4,620.00 4.54 18.72 7.95 C-37 6,400.00 5.11 44.50 141.35 4,682.36 4.54 18.72 7.95 2/19/2016 10:06:09AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 6,500.00 6.04 43.71 141.07 4,754.19 4.64 18.34 8.84 6,600.00 6.99 43.13 140.73 4,826.86 4.73 17.83 9.79 6,618.00 7.95 43.04 140.33 4,840.00 4.82 17.18 10.75 Growler-AA 6,700.00 7.95 42.77 140.33 4,900.08 4.82 17.18 10.75 6,800.00 8.90 42.64 139.87 4,973.58 4.91 16.40 11.68 2S W16-Toe 6,900.00 9.85 42.75 139.36 5,047.10 5.00 15.52 12.56 7,000.00 10.78 43.08 138.81 5,120.36 5.09 14.56 13.34 7,100.00 11.70 43.64 138.22 5,193.09 5.18 13.54 14.00 7,200.00 12.59 44.42 137.60 5,265.01 5.27 12.51 14.53 7,300.00 13.46 45.40 136.95 5,335.85 5.36 11.51 14.92 7,324.48 14.29 45.67 136.28 5,353.00 5.45 10.55 15.16 Top Cairn 7,400.00 14.29 46.57 136.28 5,405.35 5.45 10.55 15.16 7,459.55 15.09 47.35 135.60 5,446.00 5.55 9.70 15.25 Top Bermuda 7,500.00 15.09 47.92 135.60 5,473.26 5.55 9.70 15.25 7,516.59 15.85 48.15 134.92 5,484.35 5.65 8.98 15.21 2S W16-Heel 7,570.44 15.85 48.96 134.92 5,520.00 5.65 8.98 15.21 Base Bermuda 7,600.00 15.85 49.42 134.92 5,539.32 5.65 8.98 15.21 7,641.30 16.57 50.09 134.24 5,566.00 5.75 8.42 15.05 C-35 7,700.00 16.57 51.08 134.24 5,603.27 5.75 8.42 15.05 7,800.00 17.24 52.86 133.57 5,664.89 5.85 8.05 14.77 7,900.00 17.86 54.76 132.91 5,723.95 5.96 7.88 14.40 8,000.00 18.44 56.77 132.29 5,780.22 6.07 7.92 13.95 8,100.00 18.96 58.86 131.69 5,833.49 6.19 8.13 13.43 8,178.33 19.43 60.56 131.14 5,873.00 6.31 8.50 12.86 Top HRZ(K-2 mkr) 8,200.00 19.43 61.04 131.14 5,883.57 6.31 8.50 12.86 8,300.00 19.84 63.29 130.65 5,930.26 6.44 8.99 12.26 8,358.63 20.19 64.64 130.21 5,956.00 6.57 9.57 11.63 Upper Kalubik(base HRZ) 8,400.00 20.19 65.60 130.21 5,973.40 6.57 9.57 11.63 8,500.00 20.48 67.97 129.84 6,012.83 6.70 10.23 11.01 8,600.00 20.71 70.38 129.56 6,048.38 6.84 10.94 10.39 8,700.00 20.88 72.83 129.37 6,079.94 6.99 11.68 9.81 8,710.42 20.99 73.09 129.30 6,083.00 7.14 12.45 9.27 Lower Kalubik(K-1 mkr) 8,800.00 20.99 75.31 129.30 6,107.39 7.14 12.45 9.27 8,843.41 21.21 76.40 128.13 6,118.00 7.11 12.67 9.03 Hold for 20'-7-518"x 9-7/8"by 11" 2/19/2016 10:06:09AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger III Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit ND Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 8,863.41 21.21 76.40 127.69 6,122.70 7.11 12.66 9.03 Start 3.5°/100'DLS,-44.03°TF,for 166.97' 8,900.00 21.24 77.32 126.89 6,131.02 7.11 12.76 8.82 9,000.00 21.28 79.86 124.73 6,150.80 7.14 13.14 8.29 9,030.38 21.29 80.63 124.08 6,155.95 7.15 13.27 8.15 Hold for 93.33' 9,100.00 21.29 80.63 122.54 6,167.28 7.18 13.42 8.17 9,123.72 21.29 80.63 122.00 6,171.14 7.19 13.47 8.18 Start 3°/100'DLS,-43.18°TF,for 198.74' 9,135.28 21.31 80.89 120.24 6,173.00 7.23 13.86 7.94 Kuparuk C(Top C4) 9,200.00 21.31 82.30 120.24 6,182.46 7.23 13.86 7.94 9,204.06 21.32 82.39 117.89 6,183.00 7.31 14.51 7.70 A5 9,300.00 21.32 84.50 117.89 6,193.95 7.31 14.51 7.70 9,322.46 21.32 85.00 117.34 6,196.00 7.33 14.67 7.66 Start 2°/100'DLS,0°TF,for 298.47'-2S-Nurse 1.Heel-2S-Nurse 1.Heel_Cirlce 9,373.57 21.37 86.02 115.26 6,200.00 7.40 15.09 7.59 A4 9,400.00 21.37 86.55 115.26 6,201.71 7.40 15.09 7.59 9,500.00 21.42 88.55 112.06 6,205.99 7.51 15.67 7.57 9,600.00 21.45 90.55 108.12 6,206.77 7.64 16.36 7.63 9,620.93 21.45 90.97 107.15 6,206.49 7.67 16.51 7.65 Hold for 5703.22' 9,700.00 21.45 90.97 102.94 6,205.15 7.78 17.14 7.76 9,800.00 21.45 90.97 95.81 6,203.46 7.94 18.01 7.92 9,900.00 21.46 90.97 86.04 6,201.77 8.11 18.96 8.09 10,000.00 21.46 90.97 74.30 6,200.08 8.29 19.97 8.27 10,100.00 21.46 90.97 63.27 6,198.39 8.48 21.03 8.47 10,200.00 21.46 90.97 54.90 6,196.69 8.69 22.15 8.67 10,300.00 21.47 90.97 49.02 6,195.00 8.90 23.30 8.89 10,400.00 21.27 90.97 120.26 6,193.31 7.64 15.49 7.62 10,500.00 21.27 90.97 119.77 6,191.62 7.71 15.75 7.69 10,600.00 21.27 90.97 119.28 6,189.93 7.78 16.03 7.76 10,700.00 21.28 90.97 118.77 6,188.23 7.85 16.32 7.84 10,800.00 21.28 90.97 118.23 6,186.54 7.93 16.63 7.91 10,900.00 21.28 90.97 117.67 6,184.85 8.01 16.95 8.00 11,000.00 21.28 90.97 117.06 6,183.16 8.10 17.29 8.08 11,100.00 21.29 90.97 116.39 6,181.47 8.18 17.64 8.17 11,200.00 21.29 90.97 115.63 6,179.78 8.27 18.00 8.26 11,300.00 21.29 90.97 114.73 6,178.08 8.37 18.37 8.35 11,400.00 21.30 90.97 113.62 6,176.39 8.46 18.75 8.45 11,500.00 21.30 90.97 112.17 6,174.70 8.56 19.14 8.55 11,600.00 21.30 90.97 110.10 6,173.01 8.66 19.55 8.65 11,700.00 21.30 90.97 106.82 6,171.32 8.77 19.96 8.75 2/19/2016 10:06:09AM Page 6 COMPASS 5000.1 Build 74 • Schlumberger 1111 Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 11,800.00 21.31 90.97 100.70 6,169.62 8.87 20.37 8.86 11,900,00 21.31 90.97 87.12 6,167.93 8.98 20.80 8.97 12,000.00 21.31 90.97 63.40 6,166.24 9.09 21.23 9.08 12,100.00 21.32 90.97 47.42 6,164.55 9.20 21.67 9.19 12,200.00 21.32 90.97 40.33 6,162.86 9.32 22.12 9.30 12,300.00 21.32 90.97 36.69 6,161.16 9.44 22.57 9.42 12,400.00 21.33 90.97 34.49 6,159.47 9.55 23.03 9.54 12,500.00 21.33 90.97 33.00 6,157.78 9.67 23.49 9.66 12,600.00 21.33 90.97 31.90 6,156.09 9.80 23.96 9.78 12,700.00 21.34 90.97 31.06 6,154.40 9.92 24.44 9.91 12,800.00 21.34 90.97 30.37 6,152.71 10.05 24.91 10.03 12,900.00 21.34 90.97 29.80 6,151.01 10.17 25.40 10.16 13,000.00 21.35 90.97 29.31 6,149.32 10.30 25.88 10.29 13,100.00 21.35 90.97 28.88 6,147.63 10.43 26.37 10.42 13,200.00 21.35 90.97 28.50 6,145.94 10.57 26.86 10.55 13,300.00 21.36 90.97 28.15 6,144.25 10.70 27.36 10.69 13,400.00 21.36 90.97 27.84 6,142.55 10.83 27.86 10.82 13,500.00 21.36 90.97 27.55 6,140.86 10.97 28.36 10.96 13,600.00 21.37 90.97 27.28 6,139.17 11.11 28.87 11.10 13,700.00 21.37 90.97 27.03 6,137.48 11.24 29.38 11.23 13,800.00 21.37 90.97 26.80 6,135.79 11.38 29.89 11.37 13,900.00 21.38 90.97 26.58 6,134.09 11.52 30.40 11.51 14,000.00 21.38 90.97 26.37 6,132.40 11.67 30.92 11.66 14,100.00 21.38 90.97 26.18 6,130.71 11.81 31.44 11.80 14,200.00 21.39 90.97 25.99 6,129.02 11.95 31.96 11.94 14,300.00 21.39 90.97 25.81 6,127.33 12.10 32.48 12.09 14,400.00 21.40 90.97 25.64 6,125.64 12.24 33.00 12.23 14,500.00 21.40 90.97 25.47 6,123.94 12.39 33.53 12.38 14,600.00 21.40 90.97 25.31 6,122.25 12.54 34.05 12.53 14,700.00 21.41 90.97 25.16 6,120.56 12.68 34.58 12.67 14,800.00 21.41 90.97 25.02 6,118.87 12.83 35.11 12.82 14,900.00 21.41 90.97 24.88 6,117.18 12.98 35.65 12.97 15,000.00 21.42 90.97 24.74 6,115.48 13.13 36.18 13.12 15,100.00 21.42 90.97 24.61 6,113.79 13.28 36.72 13.27 15,200.00 21.43 90.97 24.48 6,112.10 13.44 37.25 13.43 15,300.00 21.43 90.97 24.35 6,110.41 13.59 37.79 13.58 2K-Pad T5 15,324.15 21.43 90.97 24.33 6,110.00 13.62 37.92 13.62 TD:15324.15'MD,6269.5'ND-4-1/2"x 6-3/4"-2S-Nurse 2.Toe-2S-Nurse 2.Toe Circle 2/19/2016 10:06:09AM Page 7 COMPASS 5000.1 Build 74 0 Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-05 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-05 North Reference: True Wellbore: Plan:2S-05 Survey Calculation Method: Minimum Curvature Design: 2S-05wp08.2[Nurse] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 2,952.30 2,585.50 10-3/4"x 13-1/2" 10-3/4 13-1/2 8,843.41 6,277.50 7-5/8"x 9-7/8"by 11" 7-5/8 11 15,324.15 6,269.50 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 279.50 279.50 top T-3 Sand 0.00 1,397.88 1,373.50 Base permafrost(?) 8,358.63 6,115.50 Upper Kalubik(base HRZ) 8,178.33 6,032.50 Top HRZ(K-2 mkr) 7,570.44 5,679.50 Base Bermuda 6,057.07 4,605.50 C-40 5,653.15 4,342.50 C-50 3,527.21 2,959.50 C-80 374.50 374.50 K-15 Marker 7,459.55 5,605.50 Top Bermuda 6,618.00 4,999.50 Growler-AA 9,135.28 6,332.50 Kuparuk C(Top C4) 7,641.30 5,725.50 C-35 7,324.48 5,512.50 Top Cairn 1,945.78 1,859.50 Top W Sak(W Sak D) 8,710.42 6,242.50 Lower Kalubik(K-1 mkr) 9,373.57 6,359.50 A4 6,311.92 4,779.50 C-37 9,204.06 6,342.50 A5 2,875.44 2,535.50 Base W Sak Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 400.00 400.00 0.00 0.00 KOP:Start 1.57100'DLS, 170°TF,for 200.09' 600.09 600.00 -5.16 0.91 Start 2.5°/100'DLS,0°TF,for 915.3' 1,515.40 1,480.50 -228.49 40.29 Hold for 111.15' 1,626.55 1,580.50 -276.27 48.71 Start 3°/100'DLS,-53.75°TF,for 998.71' 2,625.26 2,372.75 -784.30 347.30 Hold for 3384.3' 6,009.56 4,574.36 -2,693.60 2,068.06 Start 3.5°/100'DLS,-116.88°TF,for 2833.85' 8,843.41 6,277.50 -2,056.97 3,773.70 Hold for 20' 8,863.41 6,282.20 -2,039.07 3,781.27 Start 3.5°/100'DLS,-44.03°TF,for 166.97' 9,030.38 6,315.45 -1,886.22 3,839.48 Hold for 93.33' 9,123.72 6,330.64 -1,799.05 3,869.16 Start 3°/100'DLS,-43.18°TF,for 198.74' 9,322.46 6,355.50 -1,610.32 3,925.97 Start 2°/100'DLS,0°TF,for 298.47' 9,620.93 6,365.99 -1,321.95 4,001.70 Hold for 5703.22' 15,324.15 6,269.50 4,193.42 5,450.19 TD: 15324.15'MD,6269.5'TVD Checked By: Approved By: Date: 2/19/2016 10:06:09AM Page 8 COMPASS 5000.1 Build 74 Pool Report • ID 1 10:30,February 19 2016 voELLBORE TARGET DETAILS WAR CO-ORDINATES) 2S-05wp08.2[Nurse] Hama TVO Shape 2S-Nurse 1.Heel 6355.50 Circle(Radius)10000) 25-Nuree 2.Toe 6268.50 Cede(Radius:100.00) Quarter Mile View 2S-Nurse 1.1-lee Clrlce 26-Nurse Glue Circle 6269.50 Circle(Radius 1320.00) 626950 Circle(Radius:13200.00) 6000 • —F • • 2s w • 2s 4 2S,� os �oe• •2tN„`ge7 • • • • 4000 1 •c • 411111111 . X000 • o i N • • • 2$o2 •• . Allift • • _C 0 r, ....illhi)r ................ t 'a4PB1 .- 11111/ Ilk I • 02000 10.1FIEridr, , • 4000 • . , AL , .•• .__ . •S..08S-10 -18: i 2S-01 —_-� -6000 -4000 -2000 0 2000 4,6 6000 8000 10000 West(-)/East(+) (2000 usft/in) 0 0 2S-05wp08.2[Nurse] 3-D View . 411110. 2S-O5wp08.2[Nurs: • • . • I • • • • • . ..diiiiiil : P �1 Eal • A• �� 41111441111 .y d6 o • w. fi • • 2S-05wp08.2[Nurse] 3-D View Effi .-......_.._...... EffiX 2S-05wp08.2[Nura• ................... ............................................ . i mow, - A 0 • 2S-05wp08.2[Nurse] 3-D View al , w�r. _,7 2S-05wp08.2rNurs• • • 2S-05wp08.2[Nurse] 3-D View tea I • 1 25-05wp08.2 Surface Location CPAI Coordinate Converter 1 I From: To: Datum: NAD83 ..i Region- [alaska Datum: 1NAD27 .i Region: !Alaska C Latitude/Longitude 'Decimal Degrees . f" Latitude/Longitude 'Decimal Degrees C UTM Zone: i 1 South C UTM Zone: True r South t:" State Plane Zone: fit . Units: us•ft . : State Plane Zone: 4 Units: us ft . i C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: 11621225.11 X: 1481191.791850198 Y: 15929760.47 Y: 15930010.8806618 Transform IQuit 1 Help , 25-05wp08.2 Intermediate Casing : . In CPAI Coordinate Converter :,-. .- .. , ,.,-, s., ... . I From Datum: INAD83 J. Region: lalaska z.1 Datum: jNAD27 LTJ Region: lalaska t" Latitude/Longitude )Decimal Degrees Latitude/Longitude 'Decimal Degrees UTM Zone: `"— )" South C UTM Zone: !True r South 3`= State Plane Zone: Units: us.ft . r' State Plane Zone: 14--7,D Units: Fri--ft . C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates X: li624993.19 X: 1484959.929166762 Y: 15927694.12 Y: 1 5927944.52223669 1----Transform J Quit I Help I 0 0 l''''..._ ����� �� � '�U��- ~~~~«~~~^� ^ ~~ �� MCPAlCoordinate ' ~~~~ . ' :-'''''''- :.,--,,,::;4 to—mixi:Imitio.j ~ — , � rmm. l FTo'— -- --_-- —__ | D«mm |NAD83 -1 Region: l,u~~k. _d Datum: /«AD27 ...7_1-: Region: /.~~~ , r Degrees 2„1 r LatitudelLongitude rome7incal Degrees -J r UTM Zone:1 [~ South | � r- UTM Zone: - [- Southmo ! ,� StateP�o� Zone Units- ' '� State Plane Zone: Units: -' /* �2 |v»� �] |4 _,..,......1 wx� �_ C' Legal Description(NAu//only) r Legal Description(NAD27 only) i Starting Coordinates: EndmgCoo��a�o ----------------- X: !lG2G6854U / X: |48SG5226�X�153 Y: 1593J83SG0 | 5934189,83561528 i | / Transform /1 . W�t Help V l � --------- � � — =-. • 0 25-05wp08.2 Surface Location CI CPAI Coordinate Converter From: Datum: INAD83 j Region: Jalaska ..7.J Datum: 1N + 9�'+� Region: ._..� alasa kAD2s C Latitude/Longitude !Decimal Degrees ...-7j C Latitude/Longitude 'Decimal Degrees ._7_ C UTM Zone:1 r South C UTM Zone:'True r South 4 State Plane Zone:147—'1„1 Units: us1t • C State Plane Zone: 4 Units: us-ft • I C .coal Descr ption(NAD27 only' t: Legal Description(NAD27 only) 1 n., Starting Coordinates: - Legal Description / X: 1162122511 Township: 1i 010 IN-.7.3., Range: 008 E + Y: 5929760.47 Meridian: 1U J Section:117 jFNL ......:1 13037.0634 FEL 11378.4825 r Transform Quit Help 25-05wp08.2 Intermediate Casing J n CP,4:Coe-c,-,ate Ccn.ertes From: . _ _ To: Datum: INAD83 ..:.1 Region: lalaske Datum: INAD27 Region: lalaska Latitude/Longitude !Decimal Degrees C Latitude/Longitude 'Decimal Degrees .3 C UTM Zone: 1 r South C UTM Zone: True r South r: State Plane Zone:14.--D. Urns: us-ft + ? C State Plane Zone: 4 + Units: us•ft • C N.,E, ',-tti, C Legal Description(NAD27 only) Starting Coordinates: -Legal Description X: 11624993.19 i Township: 010 F.--_;] Range: 11.--1.3 Y: 15927694.12 i Meridian: lU zi Section:116 s FNL 15095.1754 1FTC—E 12890.9621 Transform i Quit I Help I S S r 25-05wp08.2 TD CPAI Coordinate Converter From: To: Datum: RTskl-5E v 1 Region: lalaska 7.1 Datum: 1NAD 27 J Region: iZsTa---;.1. C Latitude/Longitude [Decimal Degrees 2:1 C Latitude/Longitude }Decimal Degrees _7:1 r UTM Zone. 1 r South r UTM Zone: [True r South ( State Plane Zone: 11 . . Units: Fir.--.J C State Plane Zone: 117,2] Units: Fit3 C ,eqal Dest-npttort INAD27 on t% Legal Description(NAD27 only) ..... Starting Coordinates: - Legal Description , X: 11626685.40 Township: 1010 rif-7.] Range: 1008 1E ,. Y: 1593393960 Meridian: lu ...7_1 Section:19 fFicir 14126.0644 Fir -,- 11195.4120 i Transform Quit Help viiiiimiwvo v v. , I' f 1 As - built REV DATE BY CK APP • DESCRIPTION REV DATE BY APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS 2 11/14/1 SZ MEH Add Well 13 per K150013ACS NOTES: 18 17 18 15 [ ,_ 115 1 in osm► "r93 I 1. BASIS OF LOCATION AND ELEVATION IS DS2S 6 '° 21 22 23 k MONUMENTATION PER LOUNSBURY & ASSOC. ,.--) CPR! 1 30 29 28 27 •5. �24 I' c8 27 '. 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES �� �u►r�1•—''r ARE NAD 27. ,, .3.&,, , 31 34�r 4 P� DUO T11N 3. ELEVATIONS ARE B.P.M.S.L. '�oP 3 11 6 " 5 T1ON 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED p � ti'� .. e`� SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, 2 ' 1�&�S 6 10 11 to 8 12 UMIAT MERIDIAN. w� J/ 18 16 15 14 13 18 17 18 15 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS O L15-28, L15-29, L15-32, L15-35, 11-13-2015 22 FIELD BOOK L15-75. 8 21 2.3 20 B 11111111 2 PROJECT LOCATION 6. ALL DISTANCES SHOWN ARE TRUE. ,0 2, �, 23 50 25 30 29 n 7. CONDUCTOR 15 WAS ORIGINALLY SET AS CONDUCTOR 13. as 3, 32 13 3., 35 ,5 31 32 33 34 N VICINITY MAP NTS AD_ 1 DS2S �3O T� 6 4 . . 14 12 10 .8 • • •5• •3 2 1 13 15 11 g 7 LEGEND O AS—BUILT CONDUCTOR LOCATION \ 17+16 • EXISTING CONDUCTOR LOCATIONS ` 20 21 GRAPHIC SCALE 0 100 200 400 , LOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS ft ASSOCIATES, INC. 1 inch = 200 ft.. ScSGURSVEYORS ENGINEERS PLANNERS )11P AREA:2S MODULE: XXXX UNIT: D2 ConocoPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CALK62 9d24 5/28/15 DRAWING NO. CEA—D2SX-6219D24 I PART: 1 OF 2 REV: 2 _ _.., • • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS 2 11/14/15 SZ MEH Add Well 13 Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, ` T. 10 N., R. 8 E., UMIAT MERIDIAN Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. 0.G. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70' 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70' 13' 11.873" 150' 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70' 13' 11.806" 150' 09' 06.242" 2243' 1378' 111.8' 120.0' 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70' 13' 11.684" 150° 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70' 13' 11.622" 150° 09' 08.804" 2224' 1467' 111.1' 120.0' 9 5,929,986.08 481,074.22 70' 13' 11.559" 150' 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5,929,979.72 481,044.13 70' 13' 11.496" 150' 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70° 13' 11.436" 150' 09' 11.362" 2205' 1555' 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150' 09' 12.212" 2199' 1584' 110.9' 120.0' * 13 5,929,948.70 480,898.09 70' 13' 11.187" 150' 09' 14.767" 2180' 1672' 110.5' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 2186' 1643' 110.5' 120.0' 15 5,929,961.45 480,956.55 70' 13' 11.314" 150' 09' 13.070" 2192' 1614' 110.6' 120.0' * CONDUCTOR AS BUILT THIS SURVEY SEE NOTE 7 SHEET 1 REGARDING CONDUCTOR 15. •``'�P 'OF ,,.�a SURVEYOR'S CERTIFICATE .'•lir • 'I 91 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND / �`'' y '.••• �/I LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF • 0 ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY '•JEREMIAH F. CORNELL� �r DONE BY ME OR UNDER MY DIRECT SUPERVISION AND • c, THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT LS-12663 •r .�� AS OF NOVEMBER 13, 2015. O f+ A�FESS IONAO" #� �������►���P# LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA:2S MODULE: XXXX UNIT: D2 C:onocoPhilli s - os25 WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV' LK6219d24 5/28/15 CEA-D2SX-6219D24 2 OF 2 ( 2 • 2S-05 Drilling Hazards Summary 13-1/2"Hole/10-3/4"Casing Interval Event I Risk Level I Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision Low Run Gyro as needed for magnetic interference.Third well on pad,so no real anti-collision risk,only with future plans. Gravel/Sand Sloughing Low Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections. Hole Swabbing/Tight Hole on Trips Moderate Circulate hole clean prior to trip. Proper hole fill(use of trip sheets), Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement.Use proper pump rate. 9-7/8"x 11"Hole/7-5/8"Casing Interval Event I Risk Level I Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to eliminate swab. High ECD and swabbing with higher Low Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology,add LCM. Use GKA LC decision tree. Keep ECD below known frac gradient of—12.5 ppg in Tam formations crossed in intermediate. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight,PWD monitor ECD. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. 6-3/4"Hole/4-1/2"Liner Interval Event I Risk Level I Mitigation Strategy High ECD and swabbing with higher Moderate Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology,add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. 0 • ~ 2 0 " ` V.10 C U Ad u `la, > L F. 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Y Q Q Q V1 U U U -0 'N N N v — -0 -0O � O O Q Q YY- Q V- Q .0 .0 .0 W .LZ _0 Q Q Q Vim- _0 ..0 Q .G Y _C }' N Y in Ln CO in N .-i eV n O 0 N. a N 0 W m tai) N m ca a; •• v d 3 u C '1 ri LNa tO 0 N 0 v m v c" `i ns E v 0 O O N N LD m Q N -O m ,-i E 0, 0 N t6 UO H co — 3 LA as 1.1.1 U -- U 00 X \ Y V U C Q CU Q 3 d C $ U Y Q Y X 0 IX CO OD > Y _� Q N Co -o Co C - L J Q +_' C c 0 2 Co l7 x l7 0_ = > 0 U Q 00 N U a) _, 0 C m (7 '- = V a) Y C OC C �. — v-- 0 — 0 ca 1" I. O- H N Y Y Q 0 0 o v a, ar v U Y Y U 0 O •a o t E v E O E t U f— Y N Q 00 0•.0 _= C ] - O a-' U O V Co 0 • 2 a) a) O Y O N O a1 2 J Y (7 2 0 m J I > io > io > -O • Loepp, Victoria T (DOA) From: Voss,Jake <Jake.Voss@conocophillips.com> Sent: Thursday, March 10,2016 1:32 PM To: Loepp,Victoria T(DOA) Subject: Well KRU 2S-05 - PTD Request Follow Up Flag: Follow up Flag Status: Flagged Good Afternoon Victoria, I wanted to follow up on well KRU 2S-05, based on the most recent information. Since there is a chance we may spud well KRU 2S-05 with Doyon 25 based current rig operations(Estimated spud 3/25/16),an approved PTD will be needed.Therefore,we request the current PTD for well KRU 2S-05 continue to be processed by the AOGCC with the current top set design.There is a chance that Doyon 25 will only drill surface hole and suspend with a kill string,due to financial constraints. If so, Doyon 142 will pick up operations after the Western North Slope campaign and subsequent Moraine 35-613 well. Within the next month, reservoir pressure will be evaluated for the feasibility of landing the Kuparuk A4 sand with 7- 5/8" Intermediate Casing.A revised PTD will be submitted,with changes in red if reservoir pressures allow. In regards to our conversation on the phone regarding the differences in cement sacks from the 2S-05 10-401 form and the Permit to Drill letter, please use Permit to Drill information in the Casing and Cement Program Table. Please let me know of any questions or comments. Thanks, Jake Voss Sr Drilling Engineer;ConocoPhillips Alaska I Office: (907)265-6935 I Mobile: (832)-499-9085 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. • TRANSMITTAL LETTER CHECKLIST WELL NAME: KRB. c9,S— C S PTD: ,2/(0 - o39 ?(Development 2`4, " o39 Development _Service Exploratory Stratigraphic Test _Non-Conventional FIELD: /2(74ItP givkAr POOL: ktratj< giv6r) X 1 V/,�( Co Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 0 11 —I To 0) 0 Nczc a) co o a O 0) N C co Q V0.: L 0 e M: a) C c o: d w! Oc' w' c . 0: m: 7 3 a o H0 E O . Z a. c I co oa _= < E o 0 co E. o) a o: 3: .- - D ° o m: co a a o , �. oU) ._: 0: •°: 0 1 w, N as Z m >: =: ": Eo y : as W. 0) ,�: �, 0: c: . a, a) C -a . O: 0) a: 0 Q •a U) c: �. @: Co N: �, Q• O ° ° N: M a ° , oI Y' c, a) �: , 3: - a • . •3 5 5 4 N Y �: �: �: c. E: 6 Y i, 8 2: .N ami ' ami' .o E, ii2 co. > �� �: -0 ai, : m c c CD co a a CO C CD �. w, o N N, Lo Y: Tv 8: o •3. U. m: •_ o: O 7. N: 3: 7. 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