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Home My WebLink About188-062KƌŝŐŝŶĂƚĞĚ͗ ĞůŝǀĞƌĞĚƚŽ͗ϭϳͲĞĐͲϮϱ,ĂůůŝďƵƌƚŽŶ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵ͘tŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ ƚƚŶ͗͘EĂƚƵƌĂůZĞƐŽƵƌĐĞdĞĐŚŶŝĐŝĂŶƚƚŶ͗&ĂŶŶǇ,ĂƌŽƵŶ ϯϯϯtĞƐƚϳƚŚǀĞŶƵĞ͕^ƵŝƚĞϭϬϬϲϵϬϬƌĐƚŝĐůǀĚ͘ ŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϬϭŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϭϴKĨĨŝĐĞ͗ϵϬϳͲϮϳϱͲϮϲϬϱ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵdŚĞƚĞĐŚŶŝĐĂůĚĂƚĂůŝƐƚĞĚďĞůŽǁŝƐďĞŝŶŐƐƵďŵŝƚƚĞĚŚĞƌĞǁŝƚŚ͘WůĞĂƐĞĂĚĚƌĞƐƐĂŶǇƉƌŽďůĞŵƐŽƌĐŽŶĐĞƌŶƐƚŽƚŚĞĂƚƚĞŶƚŝŽŶŽĨƚŚĞƐĞŶĚĞƌĂďŽǀĞt>>ED W/η ^Zs/KZZη &/>ED :KdzW ddzW >K''/E'd WZ/Ed^η /'/d>η ^dηϭ ϯ<ͲϯϮ ϱϬͲϬϮϵͲϮϮϳϲϯͲϬϬ ϵϭϬϰϳϰϯϬϭ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮͲĞĐͲϮϱ Ϭ ϭϮ ϯKͲϬϰ ϱϬͲϬϮϵͲϮϭϴϮϲͲϬϬ ŶͬĂ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϮͲEŽǀͲϮϱ Ϭ ϭϯϰϱϲϳϴϵϭϬW>^<EKt>'Z/Wdz^/'E/E'EZdhZE/E'KWzK&d,dZE^D/dd>>ddZdKd,ddEd/KEK&͗&ĂŶŶǇ,ĂƌŽƵŶ͕,ĂůůŝďƵƌƚŽŶtŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ͕ϲϵϬϬƌĐƚŝĐůǀĚ͕͘ŶĐŚŽƌĂŐĞ͕<ϵϵϱϭϴ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵĂƚĞ͗^ŝŐŶĞĚ͗dƌĂŶƐŵŝƚƚĂůĂƚĞ͗T41208T41209197-076188-062Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.12.17 13:39:32 -09'00'906188-062ϮϯKͲϬϰϱϬͲϬϮϵͲϮϭϴϮϲͲϬϬ ŶͬĂ<ƵƉĂƌƵŬZŝǀĞƌWůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂůϭϮͲEŽǀͲϮϱϬϭ 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 8984'feet 7901'feet true vertical 6785' feet 8694'feet Effective Depth measured 7901'feet 7746', 7920', 7951'feet true vertical 6003'feet 5894', 6016', 6038'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 J-55 7864' 7988' 5976' 6064' Packers and SSSV (type, measured and true vertical depth)7746' 7920' 7951' 5894' 6016' 6038' 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: 324-545 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB Blue Pack Max Packer: Northern Solutions Liner Top Packer: ZXP w/HD SSSV: None Cy Eller cy.eller@conocophillips.com (907) 265-6049 RWO/CTD Engineer 8622-8640', 8653-8669', 8675'-8698', 8710-8730' 6520-6533', 6542-6554', 6559-6575', 6584-6599' 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 115' Well Shut-In measured TVD 7" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-062 50-029-21826-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL002513 Kuparuk River Field/ Kuparuk Oil Pool KRU 3O-04 Plugs Junk measured Length Liner 8928' 899' Casing 6769' 6687' 8961' 8850' 5064' 115'Conductor Surface Production 16" 9-5/8" 80' 5099' 4029' 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 1:41 pm, Dec 12, 2024 Page 1/5 3O-04 Report Printed: 12/5/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/10/2024 22:00 11/11/2024 00:00 2.00 MIRU, MOVE DMOB P De-mob from 3O-18. Pulled off well at 0000. Pulled pit module away from sub base and staged at end of well row. Pulled Pit liner from under rig. 0.0 0.0 11/11/2024 00:00 11/11/2024 02:30 2.50 MIRU, MOVE MOB P Mobilize to 3O-04. Spot sub over well. 0.0 0.0 11/11/2024 02:30 11/11/2024 04:00 1.50 MIRU, MOVE MOB P Spread pit liner under front of rig. PJSM to spot pits into rig. 0.0 0.0 11/11/2024 04:00 11/11/2024 05:15 1.25 MIRU, MOVE MOB P Install rig mats under pits. RU hardline and spot in kill tanks. 0.0 0.0 11/11/2024 05:15 11/11/2024 06:45 1.50 MIRU, MOVE MOB P Spot in pits, cuttings tank, berm in cellar interconnect and front of rig, MU interconnect Prep pits for fluids, 0.0 0.0 11/11/2024 06:45 11/11/2024 07:30 0.75 MIRU, MOVE RURD P RU cellar for well kill Blow air to tiger tank all clear Continue to work post move checklist Well Pressures, 0/0/0 *** Note: Rig Accept 07:30am 11/11/24 0.0 0.0 11/11/2024 07:30 11/11/2024 15:30 8.00 MIRU, WELCTL RURD P Take on WBM fluid into pits, MW=14.8 ppg, dress up to 15.1 ppg, repeat until all well kill fluid/workover fluid on board. Unable to get addtional trucks, continue transferring WBM from 1B-WIF storage tank to rig location with one truck. 0.0 0.0 11/11/2024 15:30 11/11/2024 18:00 2.50 MIRU, WELCTL CIRC P Attemtped to pressure test hard line to kill tanks, made repairs as needed. Verified line up. Calculated volumes 3.5" - 68.2 bbls, 3.5"x7" - 207.6 bbls, 275.8 BBLS 15.1 ppg WBM Circulated 455 BBL's 15.1# at 5 bpm 1400PSI Final pump pressure. Mud weight returned at 14.2#. Not enough mud to continue with operations. 0.0 0.0 11/11/2024 18:00 11/12/2024 00:00 6.00 MIRU, WELCTL WAIT T Build mud in pits to 15.1# waiting on more mud to continue circulating. Continue loading DP in pipe shed. Move all hadling equipemnt to rig floor. Move power tongs to rig floor. Assemble test joints as needed for BOP testing. Clean and organize rig. 0.0 0.0 11/12/2024 00:00 11/12/2024 04:00 4.00 MIRU, WELCTL WAIT T Build mud in pits to 15.1# waiting on more mud to continue circulating. Continue loading DP in pipe shed. Move all hadling equipemnt to rig floor. Move power tongs to rig floor. Assemble test joints as needed for BOP testing. Clean and organize rig. Peform pilot testing to increase yield point to reduce possible sag. 0.0 0.0 11/12/2024 04:00 11/12/2024 06:30 2.50 MIRU, WELCTL WAIT T 1st truck on location verified weight at 15.2# offloaded 190 BBL's. Conditioned to 15.1#. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 11/17/2024 Page 2/5 3O-04 Report Printed: 12/5/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/12/2024 06:30 11/12/2024 11:30 5.00 MIRU, WELCTL CIRC P PJSM, confirm all surface lines are free of ice, flood lines. Come online Down the IA, line up to pits, (15.1 ppg)pressure up after 2 bbl away lockup @ 700 psi, bleed pressure off, line up down the tubing, unable to pump down tubing, wellhead freezing up, work pressure back and forth IA x tubing, seems to be working free, continue, come online down the IA @ 4 bpm/700 psi, 30 bbl away, shut down pump, holding 700 psi, bleed pressure off, line up down the tubing, continue circulating 4 bpm/1450 psi/275 away, mud weight at the choke 15.1 ppg, shut down pump, blow down surface lines and choke. Final Circ Pressure 1,450 psi 0.0 0.0 11/12/2024 11:30 11/12/2024 12:00 0.50 MIRU, WELCTL OWFF P Break surface lines in cellar, monitor well for flow 30 mins. (no flow) 0.0 0.0 11/12/2024 12:00 11/12/2024 13:00 1.00 MIRU, WHDBOP MPSP P Atttempt to install BPV, found SSSV to have bled off slightly. Function open SSV Install BPV and test 750 psi in the direction of flow 10 min (good test) 0.0 0.0 11/12/2024 13:00 11/12/2024 15:00 2.00 MIRU, WHDBOP NUND P Nipple down the tree, bleed hanger void & SSV, break bolts on tree, hang and secure old tree in cellar *** Note: Inspect hanger threads with LJ 10.5 turns 0.0 0.0 11/12/2024 15:00 11/12/2024 16:30 1.50 MIRU, WHDBOP NUND P NU BOPE, install riser, torque up kill line. 0.0 0.0 11/12/2024 16:30 11/12/2024 17:00 0.50 MIRU, WHDBOP SVRG P Service rig, grease crown and draw works. 0.0 0.0 11/12/2024 17:00 11/12/2024 18:00 1.00 MIRU, WHDBOP RURD P PU test tools FOSV on 3-1/2" test jt, blanking sub on top drive and purge lines w/H2O. 0.0 0.0 11/12/2024 18:00 11/12/2024 20:30 2.50 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4500 PSI for 5 Min each, Test Witness Waived by AOGCC rep Bob Noble. 1) Blind Rams, CMV 1, 2, 3, 16, Rig Floor Kill, OTSV, IBOP 2) CMV 4,5, 6, HCR Kill, ITSV, Man IBOP 3) CMV 7, 8, 9, Man Kill, HT-38 TIW 4) Hyd Super Choke, Manual Choke 5) CMV 10, 11, HT-38 Dart 0.0 0.0 11/12/2024 20:30 11/12/2024 21:00 0.50 MIRU, WHDBOP MPSP P Pump out the stack,BD the test pump, kill and choke. RU 2nd choke to IA. Pull BPV. 0.0 0.0 11/12/2024 21:00 11/12/2024 23:00 2.00 MIRU, WHDBOP CIRC P Close blinds and pump down the tubing and out the IA to the 2 nd choke line. Circulate a bottoms up 2.5 BPM at 600 PSI. 0.0 0.0 11/12/2024 23:00 11/13/2024 00:00 1.00 MIRU, WHDBOP MPSP P Install BPV and TWC. PT from below to 750 psi for 10 min. Good test 0.0 0.0 11/13/2024 00:00 11/13/2024 01:00 1.00 MIRU, WHDBOP RURD P BD 2 nd kill. RU test equipment. MU test joint. Fill stack and choke with fresh water. Purge all air. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 11/17/2024 Page 3/5 3O-04 Report Printed: 12/5/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/13/2024 01:00 11/13/2024 04:00 3.00 MIRU, WHDBOP BOPE P Continue testing BOPE. Initial BOPE test, Tested BOPE at 250/4500 PSI for 5 Min each, Test Witness Waived by AOGCC rep Bob Noble. 6) UVPR, 3.5" test joint, 3.5" FOSV, CMV 12, 13, 15 7) CMV 14 8) HCR choke 9) Manual choke 10) Annular to 3500 psi 11) LVPR Perform accumulator test. Initial pressure=3050 PSI, after closure=1600 PSI, 200 PSI attained = 19 sec, full recovery attained = 120 sec. UVBR's= 6 sec, Annular= 20 sec. Blinds= 6 sec. LVBRs=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. 0.0 0.0 11/13/2024 04:00 11/13/2024 05:00 1.00 MIRU, WHDBOP RURD P BD choke, kill and test pump. LD test joint and RD Test equipment. 0.0 0.0 11/13/2024 05:00 11/13/2024 05:30 0.50 MIRU, WHDBOP RURD P C/O elevators. RU power tongs. Prep floor to LD completion. 0.0 0.0 11/13/2024 05:30 11/13/2024 06:00 0.50 MIRU, WHDBOP PULL P MU landing joint to hanger 11.5 turns, pull hanger off seat 3', brake over 88k, PUW=85k 7,862.0 7,859.0 11/13/2024 06:00 11/13/2024 07:00 1.00 MIRU, WHDBOP CIRC P Circulate SXS, 5 bpm/1,134 psi 7,859.0 7,859.0 11/13/2024 07:00 11/13/2024 07:30 0.50 MIRU, WHDBOP OWFF P Observe well for flow Pump 17 ppg dry job 15 bbl 7,859.0 7,859.0 11/13/2024 07:30 11/13/2024 18:00 10.50 MIRU, WHDBOP PULL P POOH, laying down 3.5" EUE tubing 2,400' pump second dry job 17 ppg dry job. Cut joint 1.71' long 7,859.0 0.0 11/13/2024 18:00 11/13/2024 19:30 1.50 MIRU, WHDBOP RURD P Clean mud from rig floor. RD 3.5" handling equipment and power tongs. Install wear ring. 0.0 0.0 11/13/2024 19:30 11/13/2024 20:30 1.00 MIRU, WHDBOP BHAH P PU BHA #1 clean out assembly. 0.0 0.0 11/13/2024 20:30 11/13/2024 21:00 0.50 COMPZN, RPCOMP SVRG P Service top drive. 0.0 0.0 11/13/2024 21:00 11/14/2024 00:00 3.00 COMPZN, RPCOMP RGRP T Trouble Shoot pipe skate sensor, replace 2, clean up wire to ramp extension rig floor sensor. 0.0 0.0 11/14/2024 00:00 11/14/2024 00:30 0.50 COMPZN, RPCOMP RGRP T Trouble Shoot pipe skate sensor, replace 2, clean up wire to ramp extension rig floor sensor. Front sensor on rig floor was the problem. 0.0 0.0 11/14/2024 00:30 11/14/2024 01:30 1.00 COMPZN, RPCOMP BHAH P MU BHA #1 clean out assembly. PUW 36K 0.0 141.5 11/14/2024 01:30 11/14/2024 09:45 8.25 COMPZN, RPCOMP PULD P RIH with CO BHA picking up DP singles from pipe shed. 141.5 7,775.0 11/14/2024 09:45 11/14/2024 10:45 1.00 COMPZN, RPCOMP TRIP P On bottom, RIH, tag TOF @ 7,856', shoe bottomed out on no-go 7,864'. Confirm x 3 times, pins sheared while rotating in hole. Rack back 1 stands 7,775.0 7,864.0 11/14/2024 10:45 11/14/2024 11:15 0.50 COMPZN, RPCOMP CIRC P Polish anticipated packer setting area F/7744' T/7807' 7,864.0 7,744.0 11/14/2024 11:15 11/14/2024 12:00 0.75 COMPZN, RPCOMP CIRC P Circulate bottoms up until 15.1 ppg all the way around @ 5 BPM, 2180 psi 7,744.0 7,744.0 Rig: NABORS 7ES RIG RELEASE DATE 11/17/2024 Page 4/5 3O-04 Report Printed: 12/5/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/14/2024 12:00 11/14/2024 15:30 3.50 COMPZN, RPCOMP TRIP P Trip OOH racking back DP F/7744' T/141' UWT 145K / SOW 84K 7,744.0 141.0 11/14/2024 15:30 11/14/2024 17:00 1.50 COMPZN, RPCOMP BHAH P LD Clean out BHA #1 Clean and clear rig floor. 141.0 0.0 11/14/2024 17:00 11/14/2024 18:30 1.50 COMPZN, RPCOMP BHAH P PU test packer BHA #2 (COE 42.54'). Install Wear Ring. 0.0 49.0 11/14/2024 18:30 11/14/2024 23:00 4.50 COMPZN, RPCOMP TRIP P TIH F/49' T/7805' at 90 FPM PUW 145K / SOW 85K 49.0 7,805.0 11/14/2024 23:00 11/14/2024 23:30 0.50 COMPZN, RPCOMP SVRG P Service top drive, blocks and crown. 7,805.0 7,805.0 11/14/2024 23:30 11/15/2024 00:00 0.50 COMPZN, RPCOMP CIRC P Tag top pf stump at 7860.91' w/4K Circulate SxS 3 BPM, 1000 psi 7,805.0 7,861.0 11/15/2024 00:00 11/15/2024 01:30 1.50 COMPZN, RPCOMP CIRC P Tag top pf stump at 7860.91' w/4K Circulate SxS 3 BPM, 1000 psi 7,861.0 7,861.0 11/15/2024 01:30 11/15/2024 02:30 1.00 COMPZN, RPCOMP MPSP P Set Baker test packer COE 7843', PT 7" production casing w/15.1 ppg mud to 1000 psi for 30 minutes and charted. Test good. 7,861.0 7,861.0 11/15/2024 02:30 11/15/2024 04:00 1.50 COMPZN, RPCOMP CIRC P Circulate bottoms up before POOH and LD DP. 7,861.0 7,861.0 11/15/2024 04:00 11/15/2024 11:00 7.00 COMPZN, RPCOMP PULD P POOH LD DP. 7,861.0 49.4 11/15/2024 11:00 11/15/2024 12:00 1.00 COMPZN, RPCOMP BHAH P LD test packer BHA #2. 49.4 0.0 11/15/2024 12:00 11/15/2024 12:30 0.50 COMPZN, WHDBOP PUTB P Clean and prep RF for completion operations 0.0 0.0 11/15/2024 12:30 11/15/2024 13:00 0.50 COMPZN, WHDBOP PUTB P Verify and confirm tubing count and jewlery order. 0.0 0.0 11/15/2024 13:00 11/15/2024 23:30 10.50 COMPZN, WHDBOP PUTB P PU 3.5" EUE tubing completion. 0.0 7,960.0 11/15/2024 23:30 11/16/2024 00:00 0.50 COMPZN, WHDBOP SVRG P Change hose on tubing tongs 7,960.0 7,960.0 11/16/2024 00:00 11/16/2024 02:30 2.50 COMPZN, WHDBOP HOSO P Perform space out calcs and pick up pup joints 7,960.0 7,964.0 11/16/2024 02:30 11/16/2024 03:15 0.75 COMPZN, WHDBOP PRTS P Rig up test equipment close pipe rams // Pressure test hanger from above 2,500 psi 10 min // Good test 7,964.0 7,964.0 11/16/2024 03:15 11/16/2024 04:00 0.75 COMPZN, WHDBOP MPSP P Set BPV, test from below 1000 psi 10 min 7,964.0 7,964.0 11/16/2024 04:00 11/16/2024 06:00 2.00 COMPZN, WHDBOP CLEN P Flush BOPs, blow down surface lines 7,964.0 0.0 11/16/2024 06:00 11/16/2024 08:00 2.00 COMPZN, WHDBOP NUND P Nipple down BOPs 0.0 0.0 11/16/2024 08:00 11/16/2024 10:00 2.00 COMPZN, WHDBOP NUND P Nipple up production tree Test packoff void to 5k, (Good Test) Pull BPV and test dart. 0.0 0.0 11/16/2024 10:00 11/16/2024 13:30 3.50 COMPZN, WHDBOP DISP P Hook up reverse manifold in celler to tubing and IA, PT lines 3,500 psi, confirm tiger tank lines are free of ice. Bring pump online @ 1,050 psi 45 bbl SW spacer pill, followed by 275 bbls of 8.6 ppg CI Brine , 2.5 bpm, ICP=1,160 psi, FCP=2,643 psi, Spacer at choke, shut down pump. 0.0 0.0 11/16/2024 13:30 11/16/2024 15:00 1.50 COMPZN, WHDBOP PRTS P Close master valve, set ball and rod (105", 1.5" Roller stem w/o rollers w/1.375" fishing neck) in tree Install HES 4.5" Lubricator, 4 x3, crossover, and pressure cap. Function open Master Valve and launch ball and rod. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 11/17/2024 Page 5/5 3O-04 Report Printed: 12/5/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/16/2024 15:00 11/16/2024 17:00 2.00 COMPZN, WHDBOP PRTS P Rig up test equipment, Pressure up 3700 psi to set packer, hold for 30 min ( MIT-T ) good test, bleed tubing pressure to 1500 psi and trap, Pressure up IA to 2500 psi ( MIT-IA ) for 30 min good test, dump tubing pressure shear SOV, rig down test equipment 0.0 0.0 11/16/2024 17:00 11/16/2024 20:00 3.00 DEMOB, MOVE FRZP P Secure well LRS to pump 75 bbls Diesel DN IA take returns F/ TBG to open top tank ICP= 700 @ 2 bpm // jumper IA to T let U-tube for 1 HR B/D and R/D all circ lines Final Pressures T/IA/OA = 100/100/0 0.0 0.0 11/16/2024 20:00 11/17/2024 00:00 4.00 DEMOB, MOVE RURD P MT pits and bridal up to lower derrick // Rig down checklists // Prep to pull off well // Rig released 00:00 11/16/24 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 11/17/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Rev Reason: Update last tag while bailing BiSN beads 3O-04 12/23/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post RWO GLD install. Pulled B&R 3O-04 11/25/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: MILLED RESIN TO 8,730 CTMD = COMPLETE 1/27/2016 pproven NOTE: Placed total of 8.1-bbl SANDLOCK-V and 1509# sand behind pipe 10/2/2015 pproven NOTE: WAIVERED WELL: IA x OA COMMUNICATION 7/10/1994 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 35.0 115.0 115.0 62.50 H-40 Welded SURFACE 9 5/8 8.92 35.0 5,099.2 4,029.0 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 8,961.3 6,768.7 26.00 J-55 BTC LINER 4 1/2 3.96 7,951.4 8,850.0 6,686.8 12.60 L-80 IBTM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth 7,863.5 String Max No 3 1/2 Set Depth 5,975.9 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 33.0 33.0 0.08 Hanger 7.100 Cameron CXS 7-1/16" x 3-1/8" EUE 8RD tubing hanger Camero n CXS 2.950 3,103.4 2,603.3 44.96 Mandrel GAS LIFT 5.873 3.5" x 1.5" MMG GLM SLB MMG 2.920 6,035.0 4,690.3 45.98 Mandrel GAS LIFT 5.873 3.5" x 1.5" MMG GLM SLB MMG 2.920 7,685.4 5,850.7 45.26 Mandrel GAS LIFT 5.873 3.5" x 1.5" MMG GLM (ADAP) SLB MMG 2.920 7,746.2 5,893.5 45.34 Packer 5.990 7 X 3.5 BLUEPACK MAX RH, 10.2 Vam Top BxP SLB Bluepac k 2.894 7,803.9 5,933.9 45.42 Nipple - X 4.509 2.813" X-Nipple HES X Nipple 2.813 7,856.6 5,971.0 45.24 Overshot 6.000 3.5" INNO poor boy overshot (1' off fully located). Holes for additional fluid bypass added to the pup jt above overshot. 3.630 Top (ftKB) 7,862.1 Set Depth 7,987.9 String Max No 3 1/2 Set Depth 6,063.7 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd AB Mod 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) 7,901.6 6,002.8 45.10 NIPPLE 4.500 CAMCO 3.5" x 2.812" DS NIPPLE CAMCO DS 2.812 7,950.4 6,037.2 45.08 LOCATOR 4.500 BAKER GBH LOCATOR sub w/ 7-ft Space out 2.992 7,959.1 6,043.3 45.08 SEAL ASSY 4.000 Baker 80-40 Seals BAKER 80-40 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,862.0 5,974.8 45.23 CUT Pre-2024 RWO WELLTEC MECHANICAL TUBING CUT 11/1/2024 2.992 7,866.0 5,977.7 45.21 LEAK - TUBING TBG LEAK IDENTIFIED BY EL LDL 1/4/2022 2.990 7,868.0 5,979.1 45.21 LEAK - CASING 7" CASING LEAK 5/2/2022 0.000 7,897.0 5,999.5 45.11 CATCHER JUNK CATCHER 2.72" x 50" 10/31/2024 0.000 7,901.7 6,002.8 45.10 TUBING PLUG 2.812 CSA-2 Plug (29" OAL) 6/10/2023 0.000 7,920.0 6,015.7 45.09 Liner Top Packer Northern Solutions PTSA Liner Top Packer w/ 1.781" R Nipple. 9.79' OAL Length. (2.31" G F/N to Pull assembly) Stung into liner top @ 7930' RKB 4/16/2020 1.781 7,930.0 6,022.8 45.09 CTD Liner CTD Liner top from 3O-04L1- 01 4/10/2020 1.920 8,663.0 6,549.7 42.97 WHIPSTOCK 2.63" OD BAKER GEN 2, 3- 1/2" X 4-1/2" WHIPSTOCK, - 1.5° LOHS, RA TAG AT 8670.4' 12/29/2019 1.000 8,694.0 6,572.4 42.89 Fish SLIP STOP CATCHER SUB FISH. 1/2 OF A SLIP, 2 FULL SLIPS, SLIP RETAINER RING & 2.70" X 30" CATCHER. 10/24/2018 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,103.4 2,603.3 44.96 1 GAS LIFT GLV RK 5.78 3 1,190.0 11/24/2024 SLB MMG 0.188 6,035.0 4,690.3 45.98 2 GAS LIFT GLV RK 5.87 3 1,220.0 11/24/2024 SLB MMG 0.250 7,685.4 5,850.7 45.26 3 GAS LIFT OV RK 5.87 3 0.0 11/23/2024 SLB MMG 0.250 3O-04, 12/5/2024 3:28:08 PM Vertical schematic (actual) CTD Liner; 7,930.0 PRODUCTION; 33.0-8,961.3 LINER; 7,951.4-8,850.0 CMT SQZ; 8,710.0-8,730.0 Fish; 8,694.0 CMT SQZ; 8,675.0-8,698.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 WHIPSTOCK; 8,663.0 CMT SQZ; 8,653.0-8,669.0 CMT SQZ; 8,622.0-8,640.0 Liner Cement; 7,950.0 ftKB Liner Top Packer; 7,920.0 TUBING PLUG; 7,901.7 CATCHER; 7,897.0 LEAK - CASING; 7,868.0 LEAK - TUBING; 7,866.0 CUT; 7,862.0 Nipple - X; 7,803.9 Packer; 7,746.2 Mandrel GAS LIFT; 7,685.4 Mandrel GAS LIFT; 6,035.0 SURFACE; 35.0-5,099.2 Mandrel GAS LIFT; 3,103.4 CONDUCTOR; 35.0-115.0 Hanger; 33.0 KUP PROD KB-Grd (ft) 40.00 RR Date 7/9/1988 Other Elev 3O-04 ... TD Act Btm (ftKB) 8,984.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292182600 Wellbore Status PROD Max Angle & MD Incl (°) 51.60 MD (ftKB) 2,600.00 WELLNAME WELLBORE3O-04 Annotation Last WO: End Date 11/16/2024 H2S (ppm) 140 Date 9/25/2013 Comment SSSV:NIPPLE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,951.4 6,037.9 45.08 PACKER 5.860 2RH ZXP w/HD LINER TOP PACKER BAKER 2RH ZXP 4.310 8,805.6 6,654.2 42.85 LANDING COLLAR 5.250 BAKER LANDING COLLAR 3.930 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,622.0 8,640.0 6,519.7 6,532.9 C-4, C-1, UNIT B, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,653.0 8,669.0 6,542.4 6,554.1 A-3, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 3O-04 1/5/2015 6.0 APERF 2.5" 6SPF, 60 DEGREE PHASING, DEEP penetrating chgs 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 3O-04 8/8/2016 6.0 APERF 2.5'" POWERJET OMEGA CHARGES 6 SPF, 60 DEG PHASING 8,675.0 8,698.0 6,558.5 6,575.3 A-2, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-2, 3O-04 7/18/2013 6.0 APERF 3-3/8" OD 6 SPF MILLENNIUM 60 DEG PHASING 25gr HMX 8,710.0 8,730.0 6,584.1 6,598.8 A-1, 3O-04 9/25/1988 8.0 CMT SQZ 4 1/2" HSD Csg Gun, 45 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,950.0 8,850.0 6,036.9 6,686.8 Liner Cement 7/15/2013 3O-04, 12/5/2024 3:28:09 PM Vertical schematic (actual) CTD Liner; 7,930.0 PRODUCTION; 33.0-8,961.3 LINER; 7,951.4-8,850.0 CMT SQZ; 8,710.0-8,730.0 Fish; 8,694.0 CMT SQZ; 8,675.0-8,698.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 WHIPSTOCK; 8,663.0 CMT SQZ; 8,653.0-8,669.0 CMT SQZ; 8,622.0-8,640.0 Liner Cement; 7,950.0 ftKB Liner Top Packer; 7,920.0 TUBING PLUG; 7,901.7 CATCHER; 7,897.0 LEAK - CASING; 7,868.0 LEAK - TUBING; 7,866.0 CUT; 7,862.0 Nipple - X; 7,803.9 Packer; 7,746.2 Mandrel GAS LIFT; 7,685.4 Mandrel GAS LIFT; 6,035.0 SURFACE; 35.0-5,099.2 Mandrel GAS LIFT; 3,103.4 CONDUCTOR; 35.0-115.0 Hanger; 33.0 KUP PROD 3O-04 ... WELLNAME WELLBORE3O-04 ORIGINATED TRANSMITTAL DATE: 11/12/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5148 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 5148 3O-04 50029218260000 Tubing Cut Record 30-Oct-2024 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 188-062 T39761 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.12 09:38:00 -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): 8984'2980 8694' Casing Collapse Conductor Surface Production 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: 907-265-6049 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 Northern Solutions PTSA Packer 2RH ZXP w/HD Packer SSSV: None 6785' 7901' 6003' 7902' KRU 3O-04 8622-8730' 8928' 4-1/2"" 6520-6599' 5064' 8961' Perforation Depth MD (ft): 10/16/2024 8850'899' 3-1/2" 6687' 115' 5099' 6769'7" 16" 9-5/8" 80' Burst 7988' MD 115' 4029' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL002513 188-062 P.O. Box 100360, Anchorage, AK 99510 50-029-21826-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7920'MD/6016'TVD 7951'MD/6038'TVD Perforation Depth TVD (ft): Will perfs require a spacing exception due to property boundaries? 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. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field Cy Eller cy.eller@conocophillips.com RWO/CTD Engineer Subsequent Form Required: Suspension Expiration Date: L-80 TVD 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 8:25 am, Sep 23, 2024 324-545 SFD 10/4/2024 11/07/24 10-404X VTL 10/21/2024 BOP test to 3500 psig Annular preventer to 2500 psig DSR-9/27/24 X JLC 11/5/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.11.05 14:48:52 -09'00' RBDMS JSB 110824 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 19, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3O-04 (PTD# 188-062). Well 3O-04 was drilled in July of 1988 with Doyon 14 and completed in September of 1988 by Nordic 1 as a Kuparuk A and C sand producer. The well began producing rocks in 2005 and was shut-in in 2019. In 2013 the well was worked over with Nordic 3 and a 4-1/2” scab liner was run across the Kuparuk A and C sands and cemented in place. In 2020, Nabors CDR3 drilled 3 laterals into the Kuparuk A sands. The well was online until it failed a TIFL in 2021. Subsequent diagnostics revealed a tubing leak at 7866’ RKB. The well then failed a CMIT- TxIA in 2022 and a casing leak at 7868’ RKB was identified. In 2023 the tubing and casing leaks were unsuccessfully attempted to be remediated with BiSn beads. The BiSn beads were not placed where intended, so they were not heated. To bring the well back online, we request approval to proceed with a rig workover to pull and replace the tubing and stack a packer above the leak in the production casing. The 3-1/2” tubing will be pulled from a pre-rig cut above the packer, then the production casing leak depth will be identified with a test packer, and a new 3-1/2” completion including a non-sealing overshot, gas lift mandrels, and a stacked packer will be installed. If you have any questions or require any further information, please contact me at 907-265-6049. Cy Eller Rig Workover Engineer CPAI Drilling and Wells 3O-04 Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 188-062 Page 1 of 2 PPre-Rig Work Remaining 1. Bail BiSn beads from tubing to top of tubing plug at 7,901’ RKB. 2. Run CBL to survey BiSn beads in IA. 3. Cut tubing at ~7,870’ RKB or above BiSn beads in IA. 4. T-POT/PPPOT and IC-POT/PPPOT. 5. Function test LDS. 6. MIT-OA. 7. CDDT-TxIAxOA. 8. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3O-04. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater. Record shut-in pressures on the T & IA. Circulate KWF as needed and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/3,000 psi. Test annular 250/3,000 psi. Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the pre-rig cut at ~7,870’ RKB. a. If all tubing down to pre-rig cut cannot be pulled, move to “Contingency: Grow and stretch 7” casing” section. Contingency: Grow and stretch 7” casing 6. MU bait sub to tubing, RIH with DP and drop off tubing on tubing stub. 7. Set plug or storm packer in 7” casing. PT to confirm plug is set. 8. ND BOPE. ND tubing head using Cameron casing detensioning system to grow casing. Pull casing in tension and land in slips. Cut off excess casing and set packoffs, NU tubing head. 9. NU BOPs. Test flange breaks. 10. Release and pull plug/storm packer. 11. Pull remaining tubing section down to pre-rig cut at ~7,870’ RKB. Cleanout to Tubing Stub and Identify 7” PC Leak Depth 12. PU DP. RIH with wash pipe and junk baskets. Wash over tubing stub and retrieve BiSn beads. 13. RIH with casing scraper and dress off mill to tubing stub and dress off stub as needed. 14. MU test packer BHA. RIH and set test packer above known casing leak at 7,868’ RKB. Pressure up backside to 2,500 psi to test casing. If PT fails, release test packer and move up hole. Repeat as necessary to identify additional leaks in production casing. POOH LD DP. Install 3-1/2” Completion with Stacked Packer 15. MU new 3-1/2” completion with non-sealing overshot, packer, nipple profile, and GLMs. RIH to tubing stub. 3O-04 Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 188-062 Page 2 of 2 a. Packer will be stacked above the production casing leak. The estimated production casing TOC is 7,194’ RKB per the 8/3/1988 CBL. 16. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 17. Land tubing hanger, RILDS, drop ball/rod, and set packer. 18. Pressure test tubing to 3,000 PSI. 19. Pressure test IA to 2,500 PSI. ND BOP, NU Tree 20. Shear out SOV with pressure differential. 21. Install BPV and test. ND BOPE. NU tree. PT Tree and packoffs. 22. Pull BPV and freeze protect well. 23. RDMO. PPost-Rig Work 1. Pull DVs and SOV. Install GLD. 2. Pull ball/rod used for setting packer. 3. Pull RBP and catcher. General Well Information: Estimated Start Date: 10/16/2024 Current Operations: Shut-In Well Type: Producer Wellhead Type: CIW KRU Gen 4. 11” 3M casing head top flange. 7-1/16”- 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Static BHP: 3,578 psi / 5,979’ TVD measured on 6/20/2022 MPSP: 2,980 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut, perform cleanout runs to remove BiSn beads from IA as needed, perform test packer run to confirm casing integrity above known casing leak at 7,868’ RKB, install a new 3-1/2” completion with a stacked packer above casing leak. Personnel: Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com) Reservoir Surveillance Engineer: Kaylie Plunkett Production Engineer: Sydney Autry Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Rev Reason: Update last tag while bailing BiSN beads 3O-04 12/23/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update last tag while bailing BiSN beads 3O-04 12/23/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By Note: Unable to locate mandrels @ 7166 & 7832' RKB 10/31/2018 fergusp NOTE: MILLED RESIN TO 8,730 CTMD = COMPLETE 1/27/2016 pproven NOTE: Placed total of 8.1-bbl SANDLOCK-V and 1509# sand behind pipe 10/2/2015 pproven NOTE: WAIVERED WELL: IA x OA COMMUNICATION 7/10/1994 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 35.0 115.0 115.0 62.50 H-40 Welded SURFACE 9 5/8 8.92 35.0 5,099.2 4,029.0 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 8,961.3 6,768.7 26.00 J-55 BTC LINER 4 1/2 3.96 7,951.4 8,850.0 6,686.8 12.60 L-80 IBTM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.1 Set Depth … 7,987.9 Set Depth … 6,063.7 String Max No… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd AB Mod 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) 31.1 31.1 0.08 HANGER 7.000 CIW GEN IV TUBING HANGER w/ Type 'H' Profile Camero n Iron Works Gen IV type N- FBB 2.992 508.1 508.1 0.38 NIPPLE 4.520 CAMCO DS NIPPLE 3.5" x 2.875" CAMCO DS 2.875 3,098.4 2,599.8 44.99 GAS LIFT 5.390 WTF KBMG 2.920 4,760.7 3,787.1 45.03 GAS LIFT 5.390 WTF KBMG 2.920 6,117.1 4,747.2 46.14 GAS LIFT 5.390 WTF KBMG 2.920 7,166.4 5,485.2 44.27 GAS LIFT 5.390 WTF KBMG 2.920 7,843.2 5,961.6 45.29 GAS LIFT 5.390 WTF KBMG 2.920 7,901.7 6,002.8 45.10 NIPPLE 4.500 CAMCO 3.5" x 2.812" DS NIPPLE SN: T070815 CAMCO DS 2.812 7,950.4 6,037.2 45.08 LOCATOR 4.500 BAKER GBH LOCATOR sub w/ 7-ft Space out 2.992 7,959.1 6,043.3 45.08 SEAL ASSY 4.000 Baker 80-40 Seals BAKER 80-40 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,866.0 5,977.7 45.21 LEAK - TUBING TBG LEAK IDENTIFIED BY EL LDL 1/4/2022 2.990 7,868.0 5,979.1 45.21 LEAK - CASING 7" CASING LEAK 5/2/2022 0.000 7,901.7 6,002.8 45.10 TUBING PLUG 2,812 CSA-2 Plug (29" OAL) 12/9/2021 0.000 7,920.0 6,015.7 45.09 Liner Top Packer Northern Solutions PTSA Liner Top Packer w/ 1.781" R Nipple. 9.79' OAL Length. (2.31" G F/N to Pull assembly) Stung into liner top @ 7930' RKB 4/16/2020 1.781 7,930.0 6,022.8 45.09 CTD Liner CTD Liner top from 3O-04L1- 01 4/10/2020 1.920 8,663.0 6,549.7 42.97 WHIPSTOCK 2.63" OD BAKER GEN 2, 3- 1/2" X 4-1/2" WHIPSTOCK, - 1.5° LOHS, RA TAG AT 8670.4' 12/29/2019 1.000 8,694.0 6,572.4 42.89 Fish SLIP STOP CATCHER SUB FISH. 1/2 OF A SLIP, 2 FULL SLIPS, SLIP RETAINER RING & 2.70" X 30" CATCHER. 10/24/2018 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,098.4 2,599.8 44.99 1 GAS LIFT DMY BK 1 0.0 6/5/2023 0.000 4,760.7 3,787.1 45.03 2 GAS LIFT DMY BK 1 0.0 6/21/2022 0.000 6,117.1 4,747.2 46.14 3 GAS LIFT DMY BK 1 0.0 6/21/2022 0.000 7,166.4 5,485.2 44.27 4 GAS LIFT DMY BK 1 0.0 11/20/2023 0.000 7,843.2 5,961.6 45.29 5 GAS LIFT Open 1 0.0 6/8/2023 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) 7,951.4 6,037.9 45.08 PACKER 5.860 2RH ZXP w/HD LINER TOP PACKER BAKER 2RH ZXP 4.310 8,805.6 6,654.2 42.85 LANDING COLLAR 5.250 BAKER LANDING COLLAR 3.930 3O-04, 12/25/2023 11:15:26 AM Vertical schematic (actual) CTD Liner; 7,930.0 PRODUCTION; 33.0-8,961.3 LINER; 7,951.4-8,850.0 FLOAT SHOE; 8,848.4-8,850.0 LANDING COLLAR; 8,805.6- 8,806.4 CMT SQZ; 8,710.0-8,730.0 Fish; 8,694.0 CMT SQZ; 8,675.0-8,698.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 WHIPSTOCK; 8,663.0 CMT SQZ; 8,653.0-8,669.0 CMT SQZ; 8,622.0-8,640.0 Liner Cement; 7,950.0 ftKB SBE; 7,979.8-7,998.6 HANGER; 7,970.0-7,979.8 SEAL ASSY; 7,959.1 PACKER; 7,951.4-7,970.0 LOCATOR; 7,950.4 Liner Top Packer; 7,920.0 TUBING PLUG; 7,901.7 NIPPLE; 7,901.6 LEAK - CASING; 7,868.0 LEAK - TUBING; 7,866.0 GAS LIFT; 7,843.2 GAS LIFT; 7,166.4 GAS LIFT; 6,117.1 SURFACE; 35.0-5,099.2 FLOAT SHOE; 5,097.3-5,099.2 FLOAT COLLAR; 5,016.2- 5,018.0 GAS LIFT; 4,760.7 GAS LIFT; 3,098.4 NIPPLE; 508.1 CONDUCTOR; 35.0-115.0 CASING HANGER; 35.0-39.8 HANGER; 31.1 KUP PROD KB-Grd (ft) 40.00 RR Date 7/9/1988 Other Elev… 3O-04 ... TD Act Btm (ftKB) 8,984.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292182600 Wellbore Status PROD Max Angle & MD Incl (°) 51.60 MD (ftKB) 2,600.00 WELLNAME WELLBORE3O-04 Annotation Last WO: End Date 7/21/2013 H2S (ppm) 140 Date 9/25/2013 Comment SSSV:NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,622.0 8,640.0 6,519.7 6,532.9 C-4, C-1, UNIT B, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,653.0 8,669.0 6,542.4 6,554.1 A-3, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 3O-04 1/5/2015 6.0 APERF 2.5" 6SPF, 60 DEGREE PHASING, DEEP penetrating chgs 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 3O-04 8/8/2016 6.0 APERF 2.5'" POWERJET OMEGA CHARGES 6 SPF, 60 DEG PHASING 8,675.0 8,698.0 6,558.5 6,575.3 A-2, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-2, 3O-04 7/18/2013 6.0 APERF 3-3/8" OD 6 SPF MILLENNIUM 60 DEG PHASING 25gr HMX 8,710.0 8,730.0 6,584.1 6,598.8 A-1, 3O-04 9/25/1988 8.0 CMT SQZ 4 1/2" HSD Csg Gun, 45 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,950.0 8,850.0 6,036.9 6,686.8 Liner Cement 7/15/2013 3O-04, 12/25/2023 11:15:26 AM Vertical schematic (actual) CTD Liner; 7,930.0 PRODUCTION; 33.0-8,961.3 LINER; 7,951.4-8,850.0 FLOAT SHOE; 8,848.4-8,850.0 LANDING COLLAR; 8,805.6- 8,806.4 CMT SQZ; 8,710.0-8,730.0 Fish; 8,694.0 CMT SQZ; 8,675.0-8,698.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 WHIPSTOCK; 8,663.0 CMT SQZ; 8,653.0-8,669.0 CMT SQZ; 8,622.0-8,640.0 Liner Cement; 7,950.0 ftKB SBE; 7,979.8-7,998.6 HANGER; 7,970.0-7,979.8 SEAL ASSY; 7,959.1 PACKER; 7,951.4-7,970.0 LOCATOR; 7,950.4 Liner Top Packer; 7,920.0 TUBING PLUG; 7,901.7 NIPPLE; 7,901.6 LEAK - CASING; 7,868.0 LEAK - TUBING; 7,866.0 GAS LIFT; 7,843.2 GAS LIFT; 7,166.4 GAS LIFT; 6,117.1 SURFACE; 35.0-5,099.2 FLOAT SHOE; 5,097.3-5,099.2 FLOAT COLLAR; 5,016.2- 5,018.0 GAS LIFT; 4,760.7 GAS LIFT; 3,098.4 NIPPLE; 508.1 CONDUCTOR; 35.0-115.0 CASING HANGER; 35.0-39.8 HANGER; 31.1 KUP PROD 3O-04 ... WELLNAME WELLBORE3O-04 3O-04 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 115 115 16 15.06 62.5 H40 Welded Surface 5099.2 4029 9.625 8.92 36 J55 BTC Production 8961.3 6768.7 7 6.28 26 J55 BTC Liner 8850 6686.8 4.5 3.96 12.6 L80 IBTM Tubing 7987.9 6063.7 3.5 2.992 9.3 L80 EUEM PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" x 1-1/2" MMG gas lift mandrels @ TBD 3.5" x 7.0" Packer @ xxxx' RKB (4" ID) 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE 2.812" DS Nipple @ 7902' RKB 2-3/8" LTP @ 7920' RKB 2-3/8" Liner 4.5" LTP @ 7951' RKB 4.5", 12.6# Cemented Liner Surface Casing 5099' RKB Production Casing 8961' RKB Conductor A-sand CTD Lateral 8663' - 8961' RKB PC Leak ~7868' RKB 4.5" Liner LTP ~7951' RKB 2-3/8" Liner LTP ~7920' RKB Estimated PC TOC ~7194' RKB TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 3G-10 50-103-20134-00 190084_3G-10_IPROF_08Jan2023 3G-13 50-103-20137-00 190116_3G-13_Puncher_03Oct2022 3G-20 50-103-20141-00 190123_3G-20_IPROF_28Apr2022 3H-35 50-103-20805-00 219064_3H-35_IPROF_03Aug2023 3I-11A 50-029-21932-01 210074_3I-11A_SBHPS-PLUG_25Jul2023 3M-05 50-029-21706-00 187025_3M-05_TBG_09Jan2022 3O-04 50-029-21826-00 188062_3O-04_CBL Post BiSN_24Aug2023 188062_3O-04_LDL_04Jan2022 3O-06 50-029-21824-00 188060_3O-06_CBL Pre-BiSN_24Aug23 3R-18 50-029-22249-00 192017_3R-18_LDL_21Feb2022 192017_3R-18_PressTemp_22Mar2022 3S-03 50-103-20458-00 203091_3S-03_IBC-CBL_04Sep2023 203091_3S-03_MechCut_14Jul2023 9of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38395 T38396 T38397 T38398 T38399 T38400 T38401 T38402 T38403 T38404 2/29/2024 3O-04 50-029-21826-00 188062_3O-04_CBL Post BiSN_24Aug2023 188062_3O-04_LDL_04Jan2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:12:37 -09'00' JLC 3/15/2023 RBDMS JSB 031523 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-02_21066_KRU_3O-04_ArcherVIVID-SRO_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21066 KRU 3O-04 50-029-21826-00 Archer VIVID™- SRO 02-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:188-062 T36557 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.09 13:57:24 -08'00' Originated: Delivered to:14-Jan-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 3M-05 50-029-21706-00 905919689 Kuparuk River Jet Cut Record Field- Final 12-Dec-21 0 12 3M-05 50-029-21706-00 905919689 Kuparuk River String Shot Record Field- Final 12-Dec-21 0 13 3O-04 50-029-21826-00 907483748 Kuparuk River Multi Finger Caliper Field & Processed 12-Jan-22 0 145678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:01/14/2022Wd͗ϭϴϴϬϲϮϬͲ^Ğƚ͗ϯϲϮϰϭBy Abby Bell at 12:45 pm, Jan 14, 2022 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: 2nd CO216B WHIPSTOCK Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,984 feet None feet true vertical 6,785 feet 8,694 feet Effective Depth measured 8,850 feet 7920, 7951 feet true vertical 6,687 feet 6016, 6038 feet Perforation depth: Tubing (size, grade, measured and true vertical depth)3.5 ''L-80 7,988' MD 6,064' TVD Packers and SSSV (type, measured and true vertical depth) PACKER Baker ZXP Liner Top 7,951' MD 6,038' TVD PACKER PTSA LINER TOP 7,920' MD 6,016' TVDMD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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 GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: James Ohlinger Contact Name:Jeff Connelly Authorized Title:Staff CTD Engineer Contact Email:jeff.s.connelly@cop.com Contact Phone:907 328-8854 Authorized Name: Authorized Signature with date: Senior Engineer: Senior Res. Engineer: PRODUCTION 8,928 feet 7 '' 8,961' MD 6769' TVD Printed and Electronic Fracture Stimulation Data WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-143 øø ø 1404 ø 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure øø ø 1180 ø N/A Representative Daily Average Production or Injection Data Measured depth: True Vertical depth: 8622-8730 feet 6520-6599 feet CONDUCTOR 80 feet 16 '' 115' MD 115' TVD LINER 899 feet 4 1/2 '' 8,850' MD 6687' TVD SURFACE 5,064 feet 9 5/8 '' 5,099' MD 4029' TVD Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River Field / Kuparuk River Oil Pool Plugs measured Junk measured Burst Collapse 3. Address:P. O. Box 100360, Anchorage, Alaska 99510 50-029-21826-00 8. Well Name and Number:KRU 3O-04ADL 25513 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name:ConocoPhillips Alaska, Inc.4. Well Class Before Work: 5. Permit to Drill Number: 188-062 GINJ SUSP SPLUG Gas Service Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Digitally signed by Jeff Connelly DN: C=US, OU=CTD, O=ConocoPhillips, CN=Jeff Connelly, E=jeff.s.connelly@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-04-21 09:59:12 Foxit PhantomPDF Version: 9.7.0 Jeff Connelly By Samantha Carlisle at 10:27 am, Apr 21, 2020 DSR-4/21/202 RBDMS HEW 4/21/2020 SFD 4/23/2020 -00 VTL 4/28/20 3O-04 Final CTD Schematic Updated: JSC (4/13/2020) TOWS @ 8620' MD 16" 62# H-40 shoe @ 115' MD 3O-04L1-01 TD @ 12,079' MD Slotted liner: 12,035' to 7930.5' (NS seal-bore recepticle) 3O-04L1 TOWS @ 8660' MD Seal-bore deployment sleeve For liner-top packer post rig Top at 7930' Packer not yet set: 4/12/2020 3O-04L1_PB1 Slotted Liner: 8718' to 8656' (to preserve perf's) Wash-down depth = 8751' (No new hole drilled) Note: FCO of lateral L1-01 will require pulling liner from 8621' to 7930' Slotted liner: 11,874' to 9447' MD (liner-top billet) TD @ 11,874'' MD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: ELMD, TIED INTO K1 MARKER AT 8344' MD 8,684.0 12/29/2019 3O-04 condijw Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set LTP 4/16/2020 3O-04 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 5,099.2 Set Depth (TVD) … 4,029.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,961.3 Set Depth (TVD) … 6,768.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,951.4 Set Depth (ftKB) 8,850.0 Set Depth (TVD) … 6,686.8 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,951.4 6,037.9 45.08 PACKER 2RH ZXP w/HD LINER TOP PACKER 4.310 7,970.0 6,051.0 45.08 HANGER DG FLEX-LOCK LINER HANGER 4.400 7,979.8 6,058.0 45.08 SBE BAKER SEAL BORE EXTENSION 4.000 Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.1 Set Depth (ft… 7,987.9 Set Depth (TVD) (… 6,063.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd AB Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.1 31.1 0.08 HANGER CIW GEN IV TUBING HANGER w/ Type 'H' Profile 2.992 508.1 508.1 0.38 NIPPLE CAMCO DS NIPPLE 3.5" x 2.875" 2.875 7,901.7 6,002.8 45.10 NIPPLE CAMCO 3.5" x 2.812" DS NIPPLE SN: T070815 2.812 7,950.4 6,037.2 45.08 LOCATOR BAKER GBH LOCATOR sub w/ 7-ft Space out 2.992 7,959.1 6,043.3 45.08 SEAL ASSY Baker 80-40 Seals 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,920.0 6,015.7 45.09 Liner Top Packer Northern Solutions PTSA Liner Top Packer w/ 1.781" R Nipple. 9.79' OAL Length. (2.31" G F/N to Pull assembly) Stung into liner top @ 7930' RKB 4/16/2020 1.781 7,930.0 6,022.8 45.09 CTD Liner CTD Liner top from 3O-04L1-01 4/10/2020 1.920 8,663.0 6,549.7 42.97 WHIPSTOCK 2.63" OD BAKER GEN 2, 3-1/2" X 4-1/2" WHIPSTOCK, - 1.5° LOHS, RA TAG AT 8670.4' 12/29/201 9 1.000 8,694.0 6,572.4 42.89 Fish SLIP STOP CATCHER SUB FISH. 1/2 OF A SLIP, 2 FULL SLIPS, SLIP RETAINER RING & 2.70" X 30" CATCHER. 10/24/201 8 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,622.0 8,640.0 6,519.7 6,532.9 C-4, C-1, UNIT B, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,653.0 8,669.0 6,542.4 6,554.1 A-3, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 3O-04 1/5/2015 6.0 APERF 2.5" 6SPF, 60 DEGREE PHASING, DEEP penetrating chgs 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 3O-04 8/8/2016 6.0 APERF 2.5'" POWERJET OMEGA CHARGES 6 SPF, 60 DEG PHASING 8,675.0 8,698.0 6,558.5 6,575.3 A-2, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-2, 3O-04 7/18/2013 6.0 APERF 3-3/8" OD 6 SPF MILLENNIUM 60 DEG PHASING 25gr HMX 8,710.0 8,730.0 6,584.1 6,598.8 A-1, 3O-04 9/25/1988 8.0 CMT SQZ 4 1/2" HSD Csg Gun, 45 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 7,950.0 8,850.0 6,036.9 6,686.8 LINER CMT 7/15/2013 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,098.4 2,599.8 WTF KBMG 1 GAS LIFT GLV BK 0.156 1,329.0 12/11/2019 2 4,760.7 3,787.1 WTF KBMG 1 GAS LIFT GLV BK 0.188 1,354.0 12/11/2019 3 6,117.1 4,747.2 WTF KBMG 1 GAS LIFT OV BK 0.250 0.0 12/10/2019 4 7,166.4 5,485.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/14/2019 5 7,843.2 5,961.6 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/18/2014 3O-04, 4/21/2020 6:38:33 AM Vertical schematic (actual) CTD Liner; 7,930.0 PRODUCTION; 33.0-8,961.3 LINER; 7,951.4-8,850.0 CMT SQZ; 8,710.0-8,730.0 Fish; 8,694.0 CMT SQZ; 8,675.0-8,698.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 WHIPSTOCK; 8,663.0 CMT SQZ; 8,653.0-8,669.0 CMT SQZ; 8,622.0-8,640.0 Liner Cement; 7,950.0 ftKB SEAL ASSY; 7,959.1 LOCATOR; 7,950.4 Liner Top Packer; 7,920.0 NIPPLE; 7,901.6 GAS LIFT; 7,843.2 GAS LIFT; 7,166.4 GAS LIFT; 6,117.1 SURFACE; 35.0-5,099.2 GAS LIFT; 4,760.7 GAS LIFT; 3,098.4 NIPPLE; 508.1 CONDUCTOR; 35.0-115.0 HANGER; 31.1 KUP PROD KB-Grd (ft) 40.00 Rig Release Date 7/9/1988 3O-04 ... TD Act Btm (ftKB) 8,984.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292182600 Wellbore Status PROD Max Angle & MD Incl (°) 51.60 MD (ftKB) 2,600.00 WELLNAME WELLBORE3O-04 Annotation Last WO: End Date 7/21/2013 H2S (ppm) 140 Date 9/25/2013 Comment SSSV:NIPPLE Notes: General & Safety End Date Annotation 10/31/2018 Note: Unable to locate mandrels @ 7166 & 7832' RKB 1/27/2016 NOTE: MILLED RESIN TO 8,730 CTMD = COMPLETE 10/2/2015 NOTE: Pumped SANDLOCK-V resin frac with 8-PPA Jordan Unimin sand, 8.9-BPM, 5000-psi. 3O-04, 4/21/2020 6:38:34 AM Vertical schematic (actual) CTD Liner; 7,930.0 PRODUCTION; 33.0-8,961.3 LINER; 7,951.4-8,850.0 CMT SQZ; 8,710.0-8,730.0 Fish; 8,694.0 CMT SQZ; 8,675.0-8,698.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 WHIPSTOCK; 8,663.0 CMT SQZ; 8,653.0-8,669.0 CMT SQZ; 8,622.0-8,640.0 Liner Cement; 7,950.0 ftKB SEAL ASSY; 7,959.1 LOCATOR; 7,950.4 Liner Top Packer; 7,920.0 NIPPLE; 7,901.6 GAS LIFT; 7,843.2 GAS LIFT; 7,166.4 GAS LIFT; 6,117.1 SURFACE; 35.0-5,099.2 GAS LIFT; 4,760.7 GAS LIFT; 3,098.4 NIPPLE; 508.1 CONDUCTOR; 35.0-115.0 HANGER; 31.1 KUP PROD 3O-04 ... WELLNAME WELLBORE3O-04 DTTMSTAJOBTYP SUMMARYOPS 3/27/20 DRILLING SIDETRACK Received plan forward, circulate sweep, pump multiple BU's, RIH, attempt to drill down 8,702'-8,717', pulled wipers up to above window and then continue to the TT, on wiper from 8,717' became detained @ 8,585', pulled free, continued circulating sweeps cleaning well, confer with town, POOH, PUD build section assembly, PD BHA #3, cleanout assembly w/ Weatherford 1 deg fixed motor w/ D331 Ridge set. RIH, tie in, Close Electronic disconnect and circulating sub. Set rate, Launch barrage of sweeps. RIH to 8675, RIH to 8716.6', WOB to 190lbs, PU 41k lbs - Clean. Tried to pack off, RIH, pulled up slowly and cleaned window area. RBIH to 8716.6, WOB 4.1k lbs, pick up clean. RBIH to 8715' MD, WOB 2.8k. PU 41K - Clean, Window - Clean. Trace sweeps out of hole - seen reduced solids to surface over time. RBIH, and dry tag @ 8718', 8k WOB, PU 40k - Clean. PUH and Tie In. RBIH, drilled from 8715.4-8717.4' MD w/200- 300 PSI motor work, WOB 1.9-2.6k. POOH, Slug of dirt @ 3000'. Slowed and sent 1 5x5, continued to POOH. Micro Motion been showing influx all day. Manual straps says - Losses. 12.3 lbs/gallon has been perfect. Flushed MM, PUD BHA #3, PD BHA #4, Build assembly (2.55 AKO). RIH, logged formation for depth, passed through window clean, brought pump up to rate, RIH with no WOB set down and stall @ 8,717’ x 3, RBIH, continued past last set down depth to 8,751’ with no WOB, PUH for change of plans, circulate while transferring fluids to make room for displacement. 3/28/20 DRILLING SIDETRACK POOH, displacing well to completion fluid, LD build assembly, PU/MU slotted liner 3 joints, RIH, unable to make it bottom, POOH, LD setting tools, LO 1 joint, PU/MU BHA #6, RIH with 2 slotted joints of liner, RIH, released liner @ 8,718', TOL=8655.95', POOH, LD setting tools, PU/MU WS setting assembly BHA #7, RIH, set TOWS @ 8,720', stacked out 3.7 k, POOH, checked well for flow, LD setting tools, PU/MU window milling assembly BHA #8, RIH, log formation for depth, mill window 3O-04 2nd WHIPSTOCK 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: CO216B WHIPSTOCK 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 8,984'feet NONE feet true vertical 6,785'feet 8,694'feet Effective Depth measured ,8850'feet 7,951'feet true vertical 6,687'feet 6,038'feet Perforation depth Measured depth 8675-8695 feet True Vertical depth 6559-6575 feet Tubing (size, grade, measured and true vertical depth)3 1/2 L-80 7,988'6,064' Packers and SSSV (type, measured and true vertical depth)PACKER BAKER ZXP LINER TOP 7,951' 6,038' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: James Ohlinger Contact Name: Authorized Title:Staff CTD Engineer Contact Email: Contact Phone: MD 115 5,099' 8850 TVD 115 4029 8961 ADL 25513 ø Oil-Bbl measured true vertical Packer 7 4 1/2 8,961' ø Representative Daily Average Production or Injection Data øø Casing Pressure Tubing Pressure ø Water-Bbl 1180 KRU 3O-04 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-062 50-029-28126-00-00 5. Permit to Drill Number: P.O. Box 100360, Anchorage, Alaska 99510 3. Address: 4. Well Class Before Work: 899 ø Gas-Mcf measuredPlugs Junk measured N/A ø Kuparuk River Field/Kuparuk River Oil Pool 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 319-555 ø Size Authorized Signature with date: Authorized Name: Liner 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 8928 Conductor Surface Production Burst N/A Casing 16 9 5/8 Length 80 5064 ConocoPhillips Alaska, Inc. 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse 6687 Jeff Connelly jeff.s.connelly@coop.com (907) 328-8854 WINJ WAG 1404 Development Service GINJ SUSP SPLUG Gas Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Digitally signed by Jeff Connelly DN: C=US, OU=CTD, O=ConocoPhillips, CN=Jeff Connelly, E=jeff.s.connelly@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-04-16 06:42:45 Foxit PhantomPDF Version: 9.7.0 Jeff Connelly By Samantha Carlisle at 8:19 am, Apr 16, 2020 DSR-4/16/2020VTL 4/17/20 RBDMS HEW 4/16/2020 261B DTTM START JOBTYP SUMMARYOPS 12/10/19 DRILLING SUPPORT - CAPITAL SET 3.5'' SLIP STOP CATCHER @ 6298' RKB. PULLED DMY @ 6116' RKB & SET OV (RESIN IN TOOLS). IN PROGRESS. 12/11/19 DRILLING SUPPORT - CAPITAL PULLED DV & SET GLV'S @ 3097' & 4760' RKB (OBTAIN GOOD IA DDT); BAILED RESIN AND PULLED CATCHER @ 6298' RKB; DRIFT W/ DMY WHIPSTOCK & TAG @ 8580' RKB (TARGET DEPTH @ 8675' RKB). IN PROGRESS. 12/12/19 DRILLING SUPPORT - CAPITAL WORKED 2.5" BAILER FROM 8591' RKB DOWN TO TAG DEPTH @ 8701' RKB (RECOVERED RESIN CHUNKS IN BAILER); DRIFT TBG W/ 2.79" GAUGE RING DOWN TO SAME; DRIFT W/ BAKER DMY WHIPSTOCK DOWN TO 8701' RKB. JOB COMPLETE & READY FOR E-LINE. 12/13/19 DRILLING SUPPORT - CAPITAL PERFORM 24 MULTI-FINGER CALIPER LOG, LOG 2 REPEAT PASSES OVER 4.5" LINER. LOG MAIN PASS FROM 8685' TO SURFACE. 12/29/19 DRILLING SUPPORT - CAPITAL SET BAKER 3-1/2" X 4-1/2" GEN 2 WHIPSTOCK. TIED INTO K1 MARKER AT 8344' MD, WHIPSTOCK ORIENTED TO 1.5 DEG LOHS PRIOR TO SETTING. TOP OF WHIPSTOCK SETTING DEPTH = 8663', CCL TO TOW = 14.8', CCL STOP DEPTH = 8648.2'. JOB COMPLETE. 3/9/20 DRILLING SUPPORT - CAPITAL DRIFT W/ 2.76" GAUGE RING DOWN TO WHIPSTOCK @ 8663' RKB; MEASURED BHP @ 8640' (3943 PSI). JOB COMPLETE. 3O-04 CO261B WHIPSTOCK 3O-04 Final CTD SchematicUpdated: JSC (4/13/2020)TOWS @ 8620' MD16" 62# H-40 shoe @ 115' MD3O-04L1-01TD @ 12,079' MDSlotted liner: 12,035' to 7930.5' (NS seal-bore recepticle)3O-04L1TOWS @ 8660' MDSeal-bore deployment sleeveFor liner-top packer post rigTop at 7930'Packer not yet set: 4/12/20203O-04L1_PB1Slotted Liner: 8718' to 8656' (to preserve perf's)Wash-down depth = 8751' (No new hole drilled)Note: FCO of lateral L1-01 will require pulling liner from 8621'to 7930'Slotted liner: 11,874' to 9447' MD (liner-top billet)TD @ 11,874'' MD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: ELMD, TIED INTO K1 MARKER AT 8344' MD 8,684.0 12/29/2019 3O-04 condijw Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET WHIPSTOCK 12/29/2019 3O-04 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 5,099.2 Set Depth (TVD) … 4,029.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,961.3 Set Depth (TVD) … 6,768.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,951.4 Set Depth (ftKB) 8,850.0 Set Depth (TVD) … 6,686.8 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,951.4 6,037.9 45.08 PACKER 2RH ZXP w/HD LINER TOP PACKER 4.310 7,970.0 6,051.0 45.08 HANGER DG FLEX-LOCK LINER HANGER 4.400 7,979.8 6,058.0 45.08 SBE BAKER SEAL BORE EXTENSION 4.000 Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.1 Set Depth (ft… 7,987.9 Set Depth (TVD) (… 6,063.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd AB Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.1 31.1 0.08 HANGER CIW GEN IV TUBING HANGER w/ Type 'H' Profile 2.992 508.1 508.1 0.38 NIPPLE CAMCO DS NIPPLE 3.5" x 2.875" 2.875 7,901.7 6,002.8 45.10 NIPPLE CAMCO 3.5" x 2.812" DS NIPPLE SN: T070815 2.812 7,950.4 6,037.2 45.08 LOCATOR BAKER GBH LOCATOR sub w/ 7-ft Space out 2.992 7,959.1 6,043.3 45.08 SEAL ASSY Baker 80-40 Seals 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,663.0 6,549.7 42.97 WHIPSTOCK 2.63" OD BAKER GEN 2, 3-1/2" X 4-1/2" WHIPSTOCK, - 1.5° LOHS, RA TAG AT 8670.4' 12/29/201 9 1.000 8,694.0 6,572.4 42.89 Fish SLIP STOP CATCHER SUB FISH. 1/2 OF A SLIP, 2 FULL SLIPS, SLIP RETAINER RING & 2.70" X 30" CATCHER. 10/24/201 8 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,622.0 8,640.0 6,519.7 6,532.9 C-4, C-1, UNIT B, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,653.0 8,669.0 6,542.4 6,554.1 A-3, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 3O-04 1/5/2015 6.0 APERF 2.5" 6SPF, 60 DEGREE PHASING, DEEP penetrating chgs 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 3O-04 8/8/2016 6.0 APERF 2.5'" POWERJET OMEGA CHARGES 6 SPF, 60 DEG PHASING 8,675.0 8,698.0 6,558.5 6,575.3 A-2, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-2, 3O-04 7/18/2013 6.0 APERF 3-3/8" OD 6 SPF MILLENNIUM 60 DEG PHASING 25gr HMX 8,710.0 8,730.0 6,584.1 6,598.8 A-1, 3O-04 9/25/1988 8.0 CMT SQZ 4 1/2" HSD Csg Gun, 45 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 7,950.0 8,850.0 6,036.9 6,686.8 LINER CMT 7/15/2013 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,098.4 2,599.8 WTF KBMG 1 GAS LIFT GLV BK 0.156 1,329.0 12/11/2019 2 4,760.7 3,787.1 WTF KBMG 1 GAS LIFT GLV BK 0.188 1,354.0 12/11/2019 3 6,117.1 4,747.2 WTF KBMG 1 GAS LIFT OV BK 0.250 0.0 12/10/2019 4 7,166.4 5,485.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/14/2019 5 7,843.2 5,961.6 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/18/2014 Notes: General & Safety End Date Annotation 10/31/2018 Note: Unable to locate mandrels @ 7166 & 7832' RKB 1/27/2016 NOTE: MILLED RESIN TO 8,730 CTMD = COMPLETE 10/2/2015 NOTE: Pumped SANDLOCK-V resin frac with 8-PPA Jordan Unimin sand, 8.9-BPM, 5000-psi. 3O-04, 4/13/2020 10:43:54 AM Vertical schematic (actual) PRODUCTION; 33.0-8,961.3 LINER; 7,951.4-8,850.0 CMT SQZ; 8,710.0-8,730.0 Fish; 8,694.0 CMT SQZ; 8,675.0-8,698.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 WHIPSTOCK; 8,663.0 CMT SQZ; 8,653.0-8,669.0 CMT SQZ; 8,622.0-8,640.0 Liner Cement; 7,950.0 ftKB SEAL ASSY; 7,959.1 LOCATOR; 7,950.4 NIPPLE; 7,901.6 GAS LIFT; 7,843.2 GAS LIFT; 7,166.4 GAS LIFT; 6,117.1 SURFACE; 35.0-5,099.2 GAS LIFT; 4,760.7 GAS LIFT; 3,098.4 NIPPLE; 508.1 CONDUCTOR; 35.0-115.0 HANGER; 31.1 KUP PROD KB-Grd (ft) 40.00 Rig Release Date 7/9/1988 3O-04 ... TD Act Btm (ftKB) 8,984.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292182600 Wellbore Status PROD Max Angle & MD Incl (°) 51.60 MD (ftKB) 2,600.00 WELLNAME WELLBORE3O-04 Annotation Last WO: End Date 7/21/2013 H2S (ppm) 140 Date 9/25/2013 Comment SSSV:NIPPLE 1 Carlisle, Samantha J (CED) From:Connelly, Jeff <Jeff.S.Connelly@conocophillips.com> Sent:Thursday, April 16, 2020 6:50 AM To:AOGCC Permitting (CED sponsored) Cc:Haggerty-Sherrod, Ann (Northland Staffing Services); Connelly, Jeff Subject:3O-04 10-404 1st Whipstock Attachments:30-04 10-404 1st Whipstock Binder1(Signed).pdf Hello, Attached,pleasefindthecompleted10Ͳ404binderfor3OͲ04CTDwhipstock#1(Note:2whipstocksweresetforthis wellandanther10Ͳ404willbecompletedsoon) Ifthereareanyquestionsorcomments,pleasedon’thesitatetoreachout. Regards, Jeff ͲͲ JeffConnelly Senior CTD engineer 907Ͳ328Ͳ8854(mobile) 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: CO261B Whipstock 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 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,984'N/A Casing Collapse Conductor Surface Production Liner Packers and SSSV Type: 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 Commission Representative: GINJ Op Shutdown Abandoned James Ohlinger Contact Name:Jeff Connelly Staff CTD Engineer Contact Email: Contact Phone:(907) 328-8854 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ConocoPhillips Alaska, Inc.188-062 8694 P. O. Box 100360, Anchorage, Alaska 99510 50-029-21826-00-00 KRU 3O-04 ADL 25513 Kuparuk River Field / Kuparuk River Oil Pool PRESENT WELL CONDITION SUMMARY 6,785'8850 6687 3588psi Length Size MD TVD Burst 5,064'10''5,099'4,029' 80'16''115'1,115' 8,928'7''8,961'6,769' 7,988' Packers and SSSV MD (ft) and TVD (ft): 899'5''8,850'6,687' Perforation Depth MD (ft):Perforation Depth TVD (ft):Tubing Size:Tubing Grade:Tubing MD (ft): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 8675 - 8695 6559 - 6573 3 1/2 L-80 PACKER - BAKER ZXP LINER TOP PACKER NIPPLE - CAMCO DS NIPPLE 7951 MD and 6038 TVD 508 MD and 508 TVD 3/28/2020 3/27/2020 Victoria Loepp Authorized Name: Authorized Title:jeff.s.connelly@cop.com Authorized Signature: COMMISSION USE ONLY m n s 66 t ckk Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate Staff CTD Engineer 3/31/2020 By Samantha Carlisle at 10:49 am, Mar 31, 2020 320-143 X BOP test to 4000 psig Annular preventer test to 2500 psig 10-404 DLB 03/31/20 VTL 3/31/20 X X DSR-3/31/2020dts 3/30/2020 4/1/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 27, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock to drill three laterals out of the KRU 3O-04 (PTD# 188-062) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in March 25 (currently in operations on 3O-04 with one failed window off whipstock set at 8660’). The objective will be to drill three laterals, KRU 3O-04L1, 3O-04L1-01, and 3O-04L1- 02, targeting the Kuparuk A-sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500’ from the original point. Attached to the sundry application are the following documents: Sundry Application Form (10-403) for 3O-04 Operations Summary in support of the 10-403 Sundry Application Current Wellbore Schematic Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4597. Sincerely, Jeff Connelly Coiled Tubing Drilling Engineer ConocoPhillips Alaska Sincerely, 3/27/2020 Page 1 of 1 3/27/2020 KRU 3O-04 (PTD: 188-062) CTD Summary for Sundry Summary of Operations: KRU well 3O-04 is a Kuparuk A-Sand producer equipped with 3-1/2” tubing and 4-1/2” liner. The CTD sidetrack will utilize three laterals to target the A-sands to the north and east of 3O-04. The laterals will increase A-sand resource recovery and throughput. To replace a failed window at 8660’ (due to geologic wash-out outside the window), CDR3 will set a new whipstock at 8620’. The 3O-04L1 lateral will exit through the 4-1/2” liner and 7” casing at 8675’ MD and drill to a planned TD at 12,000’ MD, targeting the A sand to the north. The lateral will be completed with 2-3/8” slotted liner from TD up to 9250’ MD with an aluminum billet for kicking off. The 3O-04L1-01 lateral will kick off at 9250’ MD and drill to a planned TD of 12,000’ MD targeting the A sand to the north. It will be completed with 2-3/8” slotted liner from TD up to 8775’ MD with an aluminum billet for kicking off. The 3O-04L1-02 lateral will kick off at 8775’ MD and drill to a planned TD of 10,350’ MD targeting the A sand to the east. It will be completed with 2-3/8” slotted liner from TD up into the 4-1/2” liner at 8670’ MD with a deployment sleeve. CTD Drill and Complete 3O-04 Laterals: Pre-CTD Work 1. RU Slickline: Dummy whipstock drift, C/O GLV’s (complete) 2. RU E-Line: Caliper, set top of whipstock at 8660‘ MD (complete) 3. Prep site for Nabors CDR3-AC. (compete) Rig Work 1. MIRU Nabors CDR3-AC rig using 2” coil tubing. NU 7-1/16” BOPE, test. (complete) 2. 3O-04L1 Lateral (A sand - North) a. Set 2nd WS at 8620’ MD b. Mill 2.80” window at 8620’ MD. c. Drill 3” bi-center lateral to TD of 12,000’ MD. d. Run 2-3/8” slotted liner with an aluminum billet from TD up to 9250’ MD. 3. 3O-04L1-01 Lateral (A sand - North) a. Kick off of the aluminum billet at 9250’ MD. b. Drill 3” bi-center lateral to TD of 12,000’ MD. c. Run 2-3/8” slotted liner with an aluminum billet from TD up to 8775’ MD. 4. 3O-04L1-02 Lateral (A sand - East) a. Kick off of the aluminum billet at 8775’ MD. b. Drill 3” bi-center lateral to TD of 10,350’ MD. c. Run 2-3/8” slotted liner with deployment sleeve from TD up to 8670’ MD 5. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post-Rig Work 1. Return to production Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 8,696.0 9/26/2019 3O-04 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth 9/26/2019 3O-04 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 5,099.2 Set Depth (TVD) … 4,029.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,961.3 Set Depth (TVD) … 6,768.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,951.4 Set Depth (ftKB) 8,850.0 Set Depth (TVD) … 6,686.8 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,951.4 6,037.9 45.08 PACKER 2RH ZXP w/HD LINER TOP PACKER 4.310 7,970.0 6,051.0 45.08 HANGER DG FLEX-LOCK LINER HANGER 4.400 7,979.8 6,058.0 45.08 SBE BAKER SEAL BORE EXTENSION 4.000 Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.1 Set Depth (ft… 7,987.9 Set Depth (TVD) (… 6,063.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd AB Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.1 31.1 0.08 HANGER CIW GEN IV TUBING HANGER w/ Type 'H' Profile 2.992 508.1 508.1 0.38 NIPPLE CAMCO DS NIPPLE 3.5" x 2.875" 2.875 7,901.7 6,002.8 45.10 NIPPLE CAMCO 3.5" x 2.812" DS NIPPLE SN: T070815 2.812 7,950.4 6,037.2 45.08 LOCATOR BAKER GBH LOCATOR sub w/ 7-ft Space out 2.992 7,959.1 6,043.3 45.08 SEAL ASSY Baker 80-40 Seals 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,694.0 6,572.4 42.89 Fish SLIP STOP CATCHER SUB FISH. 1/2 OF A SLIP, 2 FULL SLIPS, SLIP RETAINER RING & 2.70" X 30" CATCHER. 10/24/201 8 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,622.0 8,640.0 6,519.7 6,532.9 C-4, C-1, UNIT B, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,653.0 8,669.0 6,542.4 6,554.1 A-3, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 3O-04 1/5/2015 6.0 APERF 2.5" 6SPF, 60 DEGREE PHASING, DEEP penetrating chgs 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 3O-04 8/8/2016 6.0 APERF 2.5'" POWERJET OMEGA CHARGES 6 SPF, 60 DEG PHASING 8,675.0 8,698.0 6,558.5 6,575.3 A-2, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-2, 3O-04 7/18/2013 6.0 APERF 3-3/8" OD 6 SPF MILLENNIUM 60 DEG PHASING 25gr HMX 8,710.0 8,730.0 6,584.1 6,598.8 A-1, 3O-04 9/25/1988 8.0 CMT SQZ 4 1/2" HSD Csg Gun, 45 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 7,950.0 8,850.0 6,036.9 6,686.8 LINER CMT 7/15/2013 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,098.4 2,599.8 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/30/2018 2 4,760.7 3,787.1 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/30/2018 3 6,117.1 4,747.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/1/2018 4 7,166.4 5,485.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/14/2019 5 7,843.2 5,961.6 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/18/2014 Notes: General & Safety End Date Annotation 7/10/1994 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 9/8/2003 NOTE: 31" Surf CSG Patch covering hole located 32" below OA valve. PT @ 1,500 psi - good 2013 RWO 5/18/2009 NOTE: View Schematic w/ Alaska Schematic9.0 10/2/2015 NOTE: Placed total of 8.1-bbl SANDLOCK-V and 1509# sand behind pipe 10/2/2015 NOTE: Pumped SANDLOCK-V resin frac with 8-PPA Jordan Unimin sand, 8.9-BPM, 5000-psi. 1/27/2016 NOTE: MILLED RESIN TO 8,730 CTMD = COMPLETE 10/31/2018 Note: Unable to locate mandrels @ 7166 & 7832' RKB 3O-04, 9/26/2019 6:31:57 PM Vertical schematic (actual) PRODUCTION; 33.0-8,961.3 LINER; 7,951.4-8,850.0 CMT SQZ; 8,710.0-8,730.0 Fish; 8,694.0 CMT SQZ; 8,675.0-8,698.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 CMT SQZ; 8,653.0-8,669.0 CMT SQZ; 8,622.0-8,640.0 Liner Cement; 7,950.0 ftKB SEAL ASSY; 7,959.1 LOCATOR; 7,950.4 NIPPLE; 7,901.6 GAS LIFT; 7,843.2 GAS LIFT; 7,166.4 GAS LIFT; 6,117.1 SURFACE; 35.0-5,099.2 GAS LIFT; 4,760.7 GAS LIFT; 3,098.4 NIPPLE; 508.1 CONDUCTOR; 35.0-115.0 HANGER; 31.1 KUP PROD KB-Grd (ft) 40.00 Rig Release Date 7/9/1988 3O-04 ... TD Act Btm (ftKB) 8,984.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292182600 Wellbore Status PROD Max Angle & MD Incl (°) 51.60 MD (ftKB) 2,600.00 WELLNAME WELLBORE3O-04 Annotation Last WO: End Date 7/21/2013 H2S (ppm) 140 Date 9/25/2013 Comment SSSV:NIPPLE #NAME? Modified: JSC 3-27-20203O-04 Proposed CTD Schematic3-1/2" Camco DS nipple @ 508' MD (2.875" min ID)3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrel @ 3098', 4761', 6117', 7166', & 7843'3-1/2" Camco DS landing nipple @ 7902' MD (2.812" min ID)Baker ZXP liner top packer @ 7951' MDDG Flex-Lock Liner HangerBaker SBE @ 7980' MD7" 26# J-55 shoe @ 8961' MDA-sand perfs 8653' - 8669' MD8675' - 8698' MD (7/18/13)8710' - 8730' MDProposed KOP @ 8620' C-sand perfs 8622' - 8640' MD9-5/8" 36# J-55 shoe @ 5099' MD16" 62# H-40 shoe @ 115' MD3O-04L1-02 wp02TD @ 10,350' MDTOL @ 8670' MD3O-04L1-01 wp01TD @ 12,000' MDTOL @ 8775' MD3O-04L1 wp02TD @ 12,000' MDTOL @ 9250' MDFailed window @ 8660' 1 Haggerty-Sherrod, Ann (Northland Staffing Services) From:Connelly, Jeff Sent:Sunday, March 29, 2020 10:58 AM To:'victoria.loepp@alaska.gov' Cc:Connelly, Jeff Subject:3O-04 Update (CDR3) Follow Up Flag:Follow up Flag Status:Flagged Hello Victoria, I wanted to pass along an update per our conversation from Friday (3/27/20). CDR3 attempted to drill the build for the 3O-04L1 and was unable to find bottom. The drill bit tracked along the outside of the parent well-bore & departure was not achieved. No new hole was drilled once exiting the window. Approximately 60’ of liner was run to preserve the perforation destroyed in the window milling process. We have since set a new whip-stock up higher (8620’) and milled a new window. The failed window has become the 3O- 04L1_PB1 (plug-back). I will get a 10-403 for the new whip-stock sent your way Monday & attach the approval email as requested. CDR3 will continue drilling operations using the currently approve PTD’s (10-401’s) Thanks for all of your help on Friday as we did end up needing to go with a new window. Regards, Jeff Connelly -- Jeff Connelly Senior CTD engineer 907-328-8854 (mobile) 1 Haggerty-Sherrod, Ann (Northland Staffing Services) From:Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent:Friday, March 27, 2020 12:03 PM To:Connelly, Jeff Subject:[EXTERNAL]Plugback While Drilling KRU 3O-04L1 (PTD 219-184) Whipstock approval Follow Up Flag:Follow up Flag Status:Flagged Thank you Jeff, Approval is granted to set a new whipstock and continue operations as outlined below. Include this approval with the approved PTD. Please submit a 10-403 for the new whipstock at your earliest convenience. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Connelly, Jeff <Jeff.S.Connelly@conocophillips.com> Sent: Friday, March 27, 2020 11:49 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Starck, Kai <Kai.Starck@conocophillips.com>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: Plugback While Drilling KRU 3O-04L1 (PTD 219-184) Victoria, Resending due to incorrect WS depth. Per our conversation earlier today: Currently CDR3 is attempting to find bottom of the current rat-hole in order to use the window milled on 3O-04 for the 3O-04L1 lateral KOP. Should that not work out and a new window is required, ConocoPhillips wanted to have this sent to you prior to end of business day for your review & input. Background: CDR3 milled a window on 3O-04 (as the KOP of the 3O-04L1 lateral) at 8660’ through existing perforations. Once outside the window, washed-out hole conditions were encountered causing an inability to continue with drilling operations through the existing window. As discussed approximately 25 ft of slotted liner will be run to preserve the existing perforations exited in window milling operations. 2 CDR3 plans set a new whipstock at 8620’, mill a new window, and continue drilling operations with the current PTD’s (3O- 04L1, 3O-04L1-01, and 3O-04L1-02). Verbiage: ConocoPhillips expects to plugback and redrill the KRU 3O-04L1 lateral (PTD # 219-184) due to adverse bore-hole conditions just outside the window. The KRU 3O-04L1_PB1 plugback will be from 8663’ MD (top of whipstock) to approximately 8685’ (end of rat-hole), which is TD achieved in the 3O-04L1_PB1. Approximately 25 ft of slotted liner will be run to replace the perforations damaged due to the failed window exit. The 3O-04L1 lateral will be redrilled to the original proposed TD. Nabors CDR2-AC expects to begin redrilling the 3O-04L lateral on 3/27/2020. Thanks much for your help. Please contact me if you have any questions. -- Jeff Connelly Senior CTD engineer 907-328-8854 (mobile) WL I Caliper I FINAL 30.04 1 50-029.21826.00 1 EOSH-00123 I KUPARUK RIVER WL •� rnnvrt rtircrt WL LDL FINAL FIELD 16 -Dec -19 1 37 KUPARKRIVER Memory PPROF FINAL FIELD 18 -Dec -19 1 52 KUPARUK RIVER WL Caliper FINAL FIELD 19•Dec-19 1 1A-17 50.029-22102-00 DV1J-00159 KUPARUK RIVER WL LDL FINAL FIELD 31 Dec 19 I 1 to 15 2071-1 uu 1 EOSH nnj9R 1 K11 I -__ __.__ .-_, (,KUK RIVER I WL I I LDL FINAL non Jan -20—I r — I I 1 7 ✓ ATransmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X C— package have been verified to match the media noted above. - Print Name Sign ture Date specific content of the CDs and/or hardcopy prints may or may Please return via courier or sign/scan and email a copy to 5 tuber er and CPAI. not have been verified for correctness or quality level at this g point. AlaskaPTSPrin---tCenter slb.com Tom.Osterkam conoco hilli s.com SLB Auditor- �W Schlumberger -Private 168®62 Originated: Delivered to: TRANSMITrAL• 24 -Jan -20C umber PTS -PPRINT CENTER TER AOGCC 24Jan20-JW01 6411AStreet ATTN: Natural Resources Technician II Anchorage, AK 99518 .�'Alaska Oil& Gas Conservation COmmision y 3 195 5 (907)273-1700 main (907)273-4760 fax - 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 WL I Caliper I FINAL 30.04 1 50-029.21826.00 1 EOSH-00123 I KUPARUK RIVER WL •� rnnvrt rtircrt WL LDL FINAL FIELD 16 -Dec -19 1 37 KUPARKRIVER Memory PPROF FINAL FIELD 18 -Dec -19 1 52 KUPARUK RIVER WL Caliper FINAL FIELD 19•Dec-19 1 1A-17 50.029-22102-00 DV1J-00159 KUPARUK RIVER WL LDL FINAL FIELD 31 Dec 19 I 1 to 15 2071-1 uu 1 EOSH nnj9R 1 K11 I -__ __.__ .-_, (,KUK RIVER I WL I I LDL FINAL non Jan -20—I r — I I 1 7 ✓ ATransmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X C— package have been verified to match the media noted above. - Print Name Sign ture Date specific content of the CDs and/or hardcopy prints may or may Please return via courier or sign/scan and email a copy to 5 tuber er and CPAI. not have been verified for correctness or quality level at this g point. AlaskaPTSPrin---tCenter slb.com Tom.Osterkam conoco hilli s.com SLB Auditor- �W Schlumberger -Private THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-04 Permit to Drill Number: 188-062 Sundry Number: 319-555 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v✓viw. oogcc.al aska.gov Enclosed is the approved application for the 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. Sincerel^y,q- J e y !!!rice Chair DATED this Q day of December, 2019. RBDMS Imo✓ DEC 13 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 N7 JJ DEC - 6 2019 i. i ype m Request Abandon LJ Plug Perforations O Fracture Stimulate /TV Repair Well ❑ r on hutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Sus p Well ❑ Alter Casing ❑ Other: CO261B Whipstock Q. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory F-1Development0 188-062 ' 3. Address: Stratigraphic El Service El 6. API Number: PO Box 100360, Anchorage, AK 99510 50-029-21826-00 00 7. If perforating: Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A TWell KRU 30-04 Will planned perforations require a spacing exception? Yes ❑ No R- 9. 9. Property Designation (Lease Number): 10. Field/Pool(s): + ADL 25513 Ku aruk River Field / Ku aruk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8984 6785 8850 6687 3588 8694 N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 115' 115' Surface 5064' 9-5/8" 5099' 4029' Production 8928' 7" 8961' 6769' Liner 899' 4-1/2" 8850' Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: !6687'Perforation Tubing TMD8675'- 8695' 6559'-6573'3-1/2" 0 Packers and SSSV Type: Baker ZXP Liner Tap Packer Packers and SSSV MD (ft) and TVD (ft): Cameo DS Nipple 7951' / 6038', 508'/ 508' 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 14 -Oct -19 Commencing Operations: OIL � WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Shane Germann Authorized Title: Staff CTD Engineer Contact Email: Shane. Germann COP.COm Authorized Signatur . Date: /1 /g Contact Phone: 907-263-4597 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -sss �/ Plug Integrity ❑ BOP Test Lj Mechanical Integrity Test ❑ Location Clearance ❑ Other-— BoP t'�sfi�rrss u �r -710�¢dOO y: ' ff`jnrr/c��pr�vG�rtrr fr5Y- to Z 0 5-r� DEC 13 ROMS�'!� 2019 Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes No Subsequent Form Required: /Q �a 2 APPROVED BY !_�) Approved by: \ - FM' COMMISSIONER THE COMMISSION Date: L W r I n I Form 10-403 Revised 4/2017 Approved application .il-/.o Ii " I'/h E�1°�I O I4 T�f Submit Forman r t e date Of ap�rov�al,. Attachments in Duplicate {w 1.71—(1-1 .. �/./��%Q.� 'L ?, IZ/10/1A ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 3, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock to drill three laterals out of the KRU 30-04 (PTD# 188-062) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in mid December 2019. The objective will be to drill three laterals, KRU 30-041-1, 30-041-1-01, and 30-04L1-02, targeting the Kuparuk A -sand interval. • To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the sundry application are the following documents: - Sundry Application Form (10-403) for 30-04 - Operations Summary in support of the 10-403 Sundry Application - Current Wellbore Schematic - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4597. i ly, Shane Germann Coiled Tubing Dritling Engineer ConocoPhillips Alaska KRU 30-04 (PTD: 188-062) CTD Summary for Sundry Summary of Operations: KRU well 30-04 is a Kuparuk A -Sand producer equipped with 3-1/2" tubing and 4-1/2" liner. The CTD sidetrack will utilize three laterals to target the A -sands to the north and east of 30-04. The laterals will increase A -sand resource recovery and throughput. Prior to CTD rig up, E -Line will set a mechanical whipstock (TTWS) inside the 4-/2" liner at the planned kick off point of 8675' MD. The 30-041-1 lateral will exit through the 4-1/2" liner and 7" casing at 8675' MD and drill to a planned TD at 12,000' MD, targeting the A sand to the north. The lateral will be completed with 2-3/8" slotted liner from TD up to 9250' MD with an aluminum billet for kicking off. The 30-041-1-01 lateral will kick off at 9250' MD and drill to a planned TD of 12,000' MD targeting the A sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 8775' MD with an aluminum billet for kicking off. The 30-0411-02 lateral will kick off at 8775' MD and drill to a planned TD of 10,350' MD targeting the A sand to the east. It will be completed with 2-3/8" slotted liner from TD up into the 4-1/2" liner at 8670' MD with a deployment sleeve. CTD Drill and Complete 30-04 Laterals: Pre -CTD Work <; V./ p TD 1. RU Slickline: Dummy whipstock drift, C/O GLV's 2. RU E -Line: Caliper, set top of whipstock at 8675' MD 3. Prep site for Nabors CDR3-AC. Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 30-0411 Lateral (A sand - North) a. Mill 2.80" window at 8675' MD. b. Drill 3" bi-center lateral to TD of 12,000' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 9250' MD, 3. 30-041-1-01 Lateral (A sand - North) a. Kickoff of the aluminum billet at 9250' MD. b. Drill 3" bi-center lateral to TD of 12,000' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8775' MD. 4. 30-041-1-02 Lateral (A sand - East) a. Kickoff of the aluminum billet at 8775' MD. b. Drill 3" bi-center lateral to TD of 10,350' MD. c. Run 2-3/8" slotted liner with deployment sleeve from TD up to 8670' MD 5. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post-Riq Work Page 1 of 1 1. Return to production 12/4/2019 272| rr = 23 fm 02 4& � SO !8! ® G! 't 2 «7« @ § \ $[_ f § ( \ / /0 } mp§CMM. �� \ k \ Kit 0 m \ )it ( . - - ) \ it , it ti \ it 800 ti it it . °s- it it � \\� � \ i « SO my WWW6 p 01N +m(miiH O ° W W.0D N V W N ry O <n woo m,y � Ny y O W fON O NN 0 3 3 3 n m 000 (� mD mom mow N m N WKX mo T Jr� m � O oiD � N N ° s � y m J N an � W N 000 �m ° � 0 N O N 0000 S y fob �aE °per iO ON mom mow N m N WKX mo T Jr� m � O oiD � N N ° s � y m J N an � W N om �m ° � 0 N O N y S y O N IQ r 0 ✓_....- ,,jj[ftk KUP PROD WELLNAME 30-04 WELLBORE 30-04 Lonocophimps �-,,7 11111axAngloli,MO 7D Ala4ka. ir)D. Flele Name Welhore926m)I WeaOore Stabs cl t'1 MO (she) q[I atm (nNB1 K PAR RI R N 5002921 2 ROD 1.60 2,fi00.00 8,884.0 $BSV:NPPLE H2a (ppm Data Annofetlon EnJ pah Ka.Gre (11) Rig Raleesl Data 140 9/252013 Lest WO: )12112013 40.00 ]NI1888 3044. 9ddeggi g63l a]PM Last lag .dMPIl xhemnlc Pei 1LN4GER: at Annotaacn Depth bman End Oate milbore Last Moe By Last Tog: RKB 8,696.0 &262018 -01 zembaej Last Rev Reason Annombn nine Date Wenbore LaetMW ey Rev Reason: Updated Tag Death 92612019 30-04 zembaej aI $, .. . Me CONDVLTOR: 35.61150 Lasing Descl on Op(Ia) 11D (in) Top VNIR So l pepN (ttKat set OepN O grDI... Wlllan 0I Grade Topmreatl CONDUCTOR 16 15.06 35.0 115.0 115.0 62.50 HAO Welded Lasing Desch pfw OD ton) ID (In) Top (RKB) set DeplM1 tM1Ka) set Delnn(rvD)... NbLen g... Gbde Tep Thread SURFACE 9518 8.92 35.0 5,099.2 4,029.0 36.0 J55 BTC rvIPPLE: ms't casing pes[npuon OD (in) 01 91) Top (nice) setD pN (RKB) see DepN (TVD)... w1ILen 0_ G de ropinreae PRODUCTION > 628 33.0 8.961.3 6)fi5> 26.00 J-55 BTC casing Dea[npilon oD (in) 01101) Top (nKB) Set Depth (flKa) set Depm (rvm... Wr/Len p... Graae Topmreae LINER 4112 3.96 ],951.4 98500 6,686.8 12fi0 L-80 IBTM Liner!?stalls.. f � _ GAS LIFT: ads) .d Top RNRR To North (RK6) Top led (°) Man As Com Nominalb Ilnl 7,951.4 603).9 45.08 PACKER 2RH ZXP WHO LINER TOP PACKER 4.310 ],9]0.0 6,051.0 45.08 HANGER OG FLEX -LOCK LI NET HANGER 4400 GAs uFppW.] 7,979.8 6058.0 45.08 SBE BAKER SEAL BORE EXTENS ION 4.000 Tubing Strings Tuhng postal top ming Ma... 01(11) Top lnKe) set Depm (R.. set Depm ITVDI (... vn (Ian) G, de Tap connection TUBINGAO 31/2 2.99 31.1 7,987.9 61163.] 9.30 L-80 EUEBrtl AB Motl Oomplaflon Details bongoes a,paper,Top RAIR IDD ma Nominal Top (RKa) (1x87 (") Ibm Des coin mpnl 31 .08 HANG .1 31.1 0ER CIW GEN IVTUBING HANGER Wl Type'H'Pon]. 2,992 and UFT. 6,11 .1 508.1 508.1 0.36 NIPPLE CAMCO DS NIPPLE 35"x2.9)5" 2.875 7,9013 6,002.8 45.10 NIPPLE CAMC03.5"x2812DS NIPPLE SN: T07015 2.812 7,9504 6,0332 45.08 LOCATOR BAKER GBH LOCATOR sub vd 7-R Space 00 2,992 GAS IIFT: ],1fi8I 7,959.1 6043.3 45.08 SEALASSY Baker 80-4 -SERI, 2,990 Other In Hole (Wireline retrievable plugs, valves, tough s, fish, etc.) mpIND) Topmq .a uR;],ea3] Top(RKB) 8,6940 (MKIR 6,5724 (") 42.89 Des Com Fish SLIP STOP CA TC HER SUB FI SH. la OF A SLIP,2 FULLSUPS, S LIPFETANERRING&230'X30" Run Oeh 10/24/201 8 IO tin) 0.000 CATCHER. Perforations & Slots NIPPLE. 7,9016 Top(RKa) alm(RKa) Top(rvot (RKa) atm Di (RKa) Undid zone Date snw Den (.non. ) rya Com 8,fi22.0 8,5400 65193 6532.9 C-4. C-1. UNIT B,30-04 5011989 12.0 TWTSOZ 2118' EnerJet,60deg, Phasing --Squeezetl behintl 4-112"Then during 2013 RWO muTOr 7and4 8,653.0 8,669.0 6542.4 6554.1 A-3, 30-04 5011989 12.0 CMTSOZ 2118- Sonora. 60 deg. phasing-- Squeezetl behind SEAL Posy. 7.559.1 4-112" than during 2013 RWO 7675.0 8.695.0 6558.5 6,573.1 4-1,30-01 1/512015 6.0 APERF 1 -56-SPF 60 DEDEGREE PHASING, DEEP penetrating chgs tirercemallashavas 8.675.0 5695.0 6558.5 6573.1 A-1, 30-01 8l 12016 6.0 APERF 25'"POWERJETOMEGA CHARGES SERF, 60 DEG PHASING 66]5.0 8,698.0 6,558.5 6575.3 A -2,30-N 51711989 120 CMTSOZ 21/8" Epaulet, 60 deg. phasing -- Squeezetl behind Cmrd,RAGgg..p 4-112' liner during 2013 RWO 8.675.0 8,695D. 6.5585 6.573.1 A-2,30-04 71182013 60 PERE 3318"DD6SPF MILLENNIUM 60 DEG PHASING 25gr HMX 67104 6]30.0 6584.1 6598.8 A-1, 30-W 912511888 8.0 CMT SOZ 41/2"HSD Ceg Gug46 CMTSad', asts.urdi tleg. phasing -Squeezed behind 4 -la' l'mer tluring 2013 RWO angRHe.e]a...'get a APERF, 8,,6Tv.Da.W6 Cements Q ueeZea 8,675 a AP ERF;%a.a.. MT 302', QB]50$&19.D Top(TVp) Top (RKB) aM (RI(B) IRKB) Blm(NO) (RKB) Des Com ).9500 8,850.0 603fi.9 6,686.8 LINER CMT 7U.11 Manahan Inserts Dant S,egd.0 51 ^I CMTSQzrRmpe,7a3p� a N Top DVD) Valve Lahti Po(in) TRO Run Top (RKB) 111KB) Make M.R. OO tin) $erV Type Type (In) (psg RYn D. Com 1 3,098.4 2599.8 WTF 93 MG 1 GASLIFT DMV BK 0000 OR 3MO18 2 47 07 ,787.1 WTF KBMG 1 GASLIFT OMY BK 0.00 00 /3012018 3 611].1 4,747.2 WTF TB MG 1 GASLIFT DMY BK 0.000 0.0 10/1/2718 4 7,166.4 5,4852 WTF KBMG 1 GASLIFT OMY BK 0000 0.0 5114/2019 5 7,843.2 5,961.6 WTF KBMa t GASLIFT DMY BK 0.000 00 11/1812014 Notes: General 8 safety 711011994 End pate Annotation NOTE: WAVERED WELL IAxOACOMMUNICAT10N IN 20M NOTE: 31" Sod CS Patch covering M1OIe locatetl 32"below OA valve. PT 1,500 psi -goad 2013 RWO 5/1812009 NOTE'. View Schemalicwl Alaska SCM1ematic9.0 10/2/2015 NOTE: PIacedtolalof 8.1 -bbl SANDLOCK-Vaud 1509# sand behindpipe 11 LINER: ],[614d65D.0 1I27I2016 015 NOTE: Pumped SANDLODK-V resin frac wbM1 B-PPAJartlen Unimin send, 8.9 -BPM, 5000-s p l' NOTE MILLED RESIN T08,]30 GTMD=COMPLETE 10131/2018 Note: Unable to lube man tlrels@7166&7837RKB PRODLGTION: 31.049613 Loepp, Victoria T (CED) From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Monday, December 9, 2019 9:13 AM To: Loepp, Victoria T (CED) Cc: Ohlinger, James J Subject: KRU 30-04 PTD & Sundry Applications Attachments: 30-04 Proposed Schematic V1.1.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, I'm following up after our conversation on Friday concerning the naming of the proposed 30-04 CTD laterals (L1, 1-1-01, & 1-1-02). After some research, the 4-1/2" scab liner that was cemented in place on 7/15/2013 was perforated through to the A2 sand for production. It was perforated on 3 occasions (7/18/2013, 1/5/2015, & 8/8/2016) from 8675'— 8695' MD. The original CTD schematic sent with the PTD applications made it unclear if the cemented scab liner had been perforated, so I've updated and attached the schematic to show these perforations. I believe this would make the L1, 1-1-01, and L1-02 naming convention correct. Please let me know if you have any questions or would like to discuss further. 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O 4? z co B V J Q w O 0 > o 1.1 0 o00 43 d v 00 • z °.G gxteru 33 � 3 � �Cc2 zap _ � � w 0 r cecewrereww W W W W W W W W > > > > > > > 4 z Y Y Y Y Y Y Y 0 > > > 0 > > > w Q Q Q Q Q Q Q a)111 r a a LL a a a a Y 0000007 co • CiiY Y Y Y Y Y Y N cc O ce X N G LIU W - r V CO N O 00 0 t0 M M o O D: 0 0 0 0 0 0 0 0 0 0 0 0 0 0 La u N 0 CO 0 0 0 0 0 ra ® 7,..4 U ccoo ILL- H F- F I-- co E MIo ai 1).-1 > C7 00000 C9 ro CD N 0 0 0 0 0 0 0 j 4 a c C o 0 0 0 0 u c �p 0 0 0 0 0 0 0 o E ) N. tD 00 O N N .., O �6 I- CO N CO CO M M vvi Q '; N tD CO O h l a Y ra N. _ 0 N 0 N N ♦' _ p_ N a.. N N N N N N N - nO O a M D) O) O E c = g NNNONNN 0 9 0 0 0 0 C o o O O O O O O O ,- O u to N t() LI) In N I) �,,, +' c O COMis co cc a) a) O U C! E y m d aa ua' a0 E E E .a I,iC Qco a v Q co v v 1a v c y co Gi rn z o N- O N N 4' t+ al Y v 1 = d Q e ^ - = M Om M r2 E 2 Z ammo N w O O .0 s4 71 LJ 83, E 0.ra E E - COS K S F- a - Fo-- - L: • • Pro /88 -o & 2--- Loepp, Victoria T (DOA) From: Wallace, Chris D (DOA) Sent: Thursday,January 14, 2016 1:27 PM To: hazenmc@conocophillips.com Cc: Loepp, Victoria T(DOA) Subject: Hydraulic Fracturing Sundry Report 315-520 KRU 30-04 (PTD 1880620) Follow Up Flag: Follow up Flag Status: Flagged SCANNED MAY 1 9 2016 Mike, We have received the 10-404 for the referenced well,thank you. I am questioning how the regulations 20 AAC 25.283 and stipulations written on the sundry itself relating to FracFocus chemical reporting and CAS numbers have been satisfied? A check of the Alaska data in fracfocus.org registry doesn't seem to show this well? The Sundry does not appear to comply? 20 AAC 25.283 (h)(2)(B) (B)the chemical ingredient name of, and the Chemical Abstracts Service (CAS) registry number assigned to, each base fluid and additive used; the actual or maximum concentration of each chemical ingredient in each base fluid and additive used must be provided in percent by mass; the actual or maximum concentration of each chemical ingredient in the hydraulic fracturing fluid must be provided in percent by mass; freeze-protect fluids pumped before or after hydraulic fracturing may not be included. (i) Before submitting a Report of Sundry Well Operations under(h) of this section,the operator shall (1)post information required by the Interstate Oil and Gas Compact Commission and the Ground Water Protection Council on the FracEocus Chemical Disclosure Registry, or its successor database, maintained on the Internet by those organizations; and (2) file a printed copy and electronic copy of that information, in a format acceptable to the commission and as an attachment with the Report of Sundry Well Operations. Please let me know how you intend to correct these apparent deficiencies on current and future Sundries? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wal lacePalaska.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, 1 • please delete it,without first saving or forwarding it,and,so that the AOG is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 2 • • 1 c a) E E v: o c3 0 V 04 to. 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O c .T o o c ca) co Q LET o >, E_c= E.E m L L L cL o� E co —pT ' 2 c N� c9ax � ma (a❑ owwa > i �1- ate D m (a CO Q. • c ❑'- -p O LL O O 7 13 C O N C d C N O- U ) - a" U L Q' Ca O (a LL U 3 -c cwC) N E W, 0 O O 0 O` o a� U• j N D E U >'.7 -O To E2 O U Na) aaai U w C L N O O C coO'00 0 C E >O 7 L N Cp O „) a E >.- D O� C . d O LL C C6 @ Q C N O O C O c H— O m . + Z c STATE OF ALASKA ALA"OIL AND GAS CONSERVATION COIVOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate gr. Pull Tubing r Operations Shutdown r Performed: Suspend Perforate p j"` Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool Repair Well Re-enter Susp Well `""` Other: 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 188-062 3.Address: 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-21826-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25513 KRU 30-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8984 feet Plugs(measured) none true vertical 6785 feet Junk(measured) none Effective Depth measured 8850 feet Packer(measured) 7951 true vertical 6687 feet (true vertical) 6038 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 115 115 SURFACE 5064 9.625 5099 4029 LINER 899 4.5 8850 6687 PRODUCTION 8928 7 8961 6769 eitZUEIVEi OCT 232015 Perforation depth: Measured depth: 8675-8695' True Vertical Depth: 6559'-6573' AOGCC Tubing(size,grade,MD,and ND) 3.5, L-80, 7988 MD, 6064 TVD Packers&SSSV(type,MD,and TVD) PACKER-2RH ZXP LINER TOP PACKER @ 7951 MD and 6038 TVD NIPPLE-CAMCO DS NIPPLE @ 508 MD and 508 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8675-8695' Treatment descriptions including volumes used and final pressure: 8.1 bbls SANDLOCK-V 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations P' Exploratory r Development J Service r Stratigraphic r Copies of Logs and Surveys Run r 000 .Well Status after work: Oil P Gas r WDSPL Printed and Bectronic Fracture Stimulation Data I' GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG 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: 315-520 Contact Mike Hazen @ 265-1032 Email hazenmc(aconocophillips.com Printed Name Mike H -n Title Wells Engineer Signature � AIM.. Phone:265-1032 Date Z1 2C.r IS / Form 10-404 Revised 5/2015 RBDMS (N'T 13 206 Submit Original Only 0-04 WELL WORK SUMMARY • DATE SUMMARY 5/25/2014 ATTEMPTED DRIFT TBG WITH 2.5" BLR; TAGGED HYDRATES @ 1914' SLM. ATTEMPTED TO MOVE ICE PLUG BY PUMPING INTO WELL, NO SUCCESS. JOB SUSPENDED. 5/27/2014 BEGINING T/I/O 250/1400/20 ENDING T/I/O 500/1400/20 PUMPED 1.4 BBLS INTO THE TUBING LOCKED UP JOB COMPLETE 6/3/2014 DO WEEKLY BOP TEST, RIH WITH 2.2" DJN AND JET OUT ICE PLUG, LIGHT TAG @ 1837' PICK UP AND START JETTING, TAG @ 1910',1925',2450', ESTABLISHED INJECTIVITY, DRIFT TO 8700' CTMD. TURN OVER TO DSO 7/27/2014 (AC EVAL): MIT OA TO 1800 PSI. (PASSED). 8/21/2014 RE-ENERGIZE IC PO. IC POT (PASS) (COMPLETE) 11/14/2014 BRUSH & FLUSH TBG &TAGGED @ 8526' SLM ( EST. 146' OF FILL) DRIFTED TBG W/ 15' x 2.73" DMY PERF GUN TO 8549' RKB; SET 2.81" CA-2 PLUG W/SINGLE SPARTEK GAUGE @ 7902' RKB. DEPLOYED BAITED PULLING TOOL. PULLED GLV @ 7166' RKB & SET DV. ATTEMPT PULL GLVs @ 6117' &4761' RKB. IN PROGRESS. 11/15/2014 PULLED GLVs @ 6117', 4761' & 3098' RKB. SET DVs @ 3098' &4761' RKB. IN PROGRESS. 11/16/2014 SET DV @ 6117' RKB; PULLED OV @ 7843' RKB & LEFT POCKET OPEN (READY FOR CIRC OUT). IN PROGRESS. 11/17/2014 circ-out well, pump 202 bbls CRW S/W down tbg followed by 80 dsl, taking returns up IA, u-tube well. Ready for Slickline 11/18/2014 SET DV @ 7843' RKB. ATTEMPT MITT TO 4000 PSI ( FAILED, SUSPECT PLUG LEAKING) MIT x IA TO 3500 PSI ( PASS) REPLACED 2.81" CA-2 PLUG @ 7902' RKB. MITT TBG TO 4000 PSI ( PASS) IN PROGRESS. 11/23/2014 PULLED 2.81" CA-2 PLUG @ 7902' RKB. DRIFTED TO 10' SLM WITH DUAL BRUSHES &2.906" GAUGE RING FOR TREESAVER. READY FOR CTU. 12/5/2014 B&C CTU#1: PERFORM FILL CLEAN OUT TO HARD TAG AT 8783' RKB (53' RATHOLE)WITH JSN, SLICK DIESEL, AND DIESEL GEL. PUMP INJECTIVITY TEST POST FCO WITH SLICK DIESEL. PUMPING 0.5 BPM, 3270 PSI CIRC PRESSURE, 2950 PSI WHP. PUMPING 1.0 BPM, 3870 PSI CIRC, 3160 PSI WHP. PUMPING 2 BPM, 5880 PSI CIRC, 3460 PSI WHP. ADDITIONAL PERFS WILL BE REQUIRED PRIOR TO PUMPING SANDLOCK RESIN. READY FOR ELINE. 1/3/2015 ATTEMPTED TO PERFORATE INTERVAL OF 8675' -8695' BUT THE TOOLSTRING TAGGED HARD AT 8610' ELM. JOB SUSPENDED. 1/4/2015 RAN 2.5" BAILER WORKED PAST TIGHT SPOT @ 8606' SLM TAG BTM @ 8773' SLM, CLEAN UP TIGHT SPOT WITH 2.78" GAUGE, DRIFT WITH 20' OF 2 1/2 DUMMY GUNS TAG @ 8773' SLM NO PROBLEMS. COMPLETE READY FOR E-LINE 1/5/2015 CORRELATE TO PERFORATING RECORD DATED 18-JULY-2013 AND PERFORATE 8675'-8695'WITH 2.5"6 SHOT PER FOOT, 60 DEGREE PHASING. DEEP PENETRATING CHARGES. PERFORM SBHP SURVEY @ 8695'AND GRADIENT STOP @ 8560' 8560' PRESSURE =4107 PSIi; TEMPERATURE = 157 DEG 8695' PRESSURE =4142 PSIi; TEMPERATURE = 160 DEG 1/10/2015 PERFORM INJECTIVITY TEST ON TBG (JOB COMPLETE) 1/20/2015 injectivity test, maintained 3.5 bbls/min at 4000 psi for 30 bbls dsl,job complete 9/30/2015 DRIFT TBG &TAG @ 8783' SLM. READY SANDLOCK FRAC JOB. 10/2/2015 Pumped SANDLOCK-V resin frac with 8-PPA Jordan Unimin sand, 8.9-BPM, 5000-psi. Placed total of 8.1-bbl SANDLOCK-V and 1509#sand behind pipe Let resin cure 3-5 days then CT motor/mill run and injectivity test. KUP PROD • 30-04 Cone i hiIJips _ Well Attributes Max Angle&MD TD • AlaskaIncWellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) c r..,nd'r„,,, 500292182600 KUPARUK RIVER UNIT PROD 51.60 2,600.00 8,984.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 30-04,1/8201512.11;33 PM SSSV:NIPPLE 140 9/25/2013 Last WO: 7/21/2013 40.00 7/9/1988 • Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,773.0 1/4/2015 Rev Reason:TAG,PERFORATIONS lehallf 1/8/2015 ...._ I f HANGER;31.1 �L iL�_J� Casing Strings • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 Welded MARSERMISMENIMI95q 5,04i” 51151 sii l _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread j11�-'] SURFACE 95/8 8.921 35.0 5,099.2 4,029.0 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.0 8,961.3 6,768.7 26.00 J-55 BTC CONDUCTOR;35.4115.0 - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER 4 1/2 3.958 7,951.4 8,850.0 6,686.8 12.60 L-80 IBTM Liner Details NIPPLE;508.1IIN Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,951.4 6,037.9 45.08 PACKER 2RH ZXP w/HD LINER TOP PACKER 4.310 7,970.0 6,051.0 45.08 HANGER DG FLEX-LOCK LINER HANGER 4.400 r- 7,979.8• 6,058.0 45.08'SBE BAKER SEAL BORE EXTENSION 4.000 GAS LIFT;3.098.4in Tubing Strings t Tubing Description String Ma...ID(in) Top(ftKB) .Set Depth(ft..Set Depth(ND)(...Wt(Ib/(t) Grade Top Connection 71 TUBING WO 3 1/2 2.992 31.1 7,987.9 6.063.7 9.30 L-80 EUE 8rd AB Mod Completion Details Nominal ID GAS LIFT;4,760.7 Top(ftKB) Top(ND)((MB) Top not(°) Item Des Com (in) 4 31.1 31.1 0.08 HANGER CIW GEN IV TUBING HANGER w/Type'H'Profile 2992 508.1 508.1 0.38 NIPPLE CAMCO DS NIPPLE 3.5"x 2.875" 2.875 7,901.7 6,002.8 45.10 NIPPLE CAMCO 3.5"x 2.812"DS NIPPLE SN:T070815 2.812 ' 7,950.4 6,037.2 45.08'LOCATOR BAKER GBH LOCATOR sub w/7-ft Space out 2.992 7,959.1 6,0433 45.08 SEAL ASSY Baker 80-40 Seals 2.990 suRFACE;3s.o-s,o99.z Perforations&Slots Shot Dens GAS LIFT;6,117.1-16Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 8,622.0 8,640.0 6,519.7 6,532.9 C-4,C-1, 5/7/1989 12.0 CMT 2 1/8"EnerJet,60 deg. UNIT B,30- SQZ phasing--Squeezed _ 04 behind 4-1/2"liner during 2013 RWO GAS LIFT;7,166.4 8,653.0 8,669.0 6,542.4 6,554.1 A-3,30-04 5/7/1989 12.0 CMT 2 1/8"EnerJet,60 deg. SQZ phasing--Squeezed behind 4-1/2"liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-1,30-04 1/5/2015 6.0 APERF 2.5"6SPF,60 DEGREE PHASING,DEEP GAS LIFT;7,843.2 penetrating chgs _ 8,675.0 8,695.0 6,558.5 6,573.1 A-2,30-04 7/18/2013 6.0 APERF 3-3/8"OD 6 SPF MILLENNIUM 60 DEG -- • PHASING 25gr HMX 8,675.0 8,698.0 6,558.5 6,575.3 A-2,30-04 5/7/1989 12.0 CMT 2 1/8"EnerJet,60 deg. NIPPLE;7,901.6 3E SQZ phasing--Squeezed • behind 4-1/2"liner during 2013 RWO 8,710.0 8,730.0 6,584.1 6,598.8 A-1,30-04 9/25/1988 ' 8.0 CMT 4 1/2"HSD Csg Gun,45 SQZ deg.phasing- Squeezed behind 4-1/2" LOCATOR;7,950.4 - 5 liner during 2013 RWO it Cement Squeezes SEAL ASSY;7,959.1 '.':'. ( Top(ND) Etc(TVD) /I. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn C 11 -r 7,950.0 8,850.0 6,036.9 6,686.8 LINER CMT 7/15/2013 I Mandrel Inserts `?!,') St C ✓ ati � on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(inT e TRun Date Co) Sery YP YPe (in) (psi) Corn -� 1 3,098.4 2,599.8 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/15/2014 CMT SW;8.622.0.8,640.0- ( C 2 4,760.7 3,787.1 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/15/2014 3 6,117.1 4,747.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/16/2014 CMT SOZ;8,65308.669.0 C 4 7,166.4 5,485.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/14/2014 S APERF;8,675.0-8.695 0 APERF;8,675.0-8,696.0a _ 5 7,843.2 5,961.6 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/18/2014 CMT SU;8,675.0.8,698.0 Notes:General&Safety End Date Annotation 7/100994 NOTE:WAIVERED WELL:IA x OA COMMUNICATION CMT SOZ;8,770.0$730.0 9/8/2003 NOTE:31"Surf CSG Patch covering hole located 32"below OA valve. PT @ 1,500 psi-good 2013 RWO 5/18/2009 NOTE:View Schematic w/Alaska Schematic9.0 1 LINER;7,951.48,850.5 PRODUCTION;33.0.8,961.3 KUP PROD • 30-04 • COnOCOPhiIIlps o Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status Ind(°) MD(ftKB) Act Btm(ftKB) c„..,Jnafir, 500292182600 KUPARUK RIVER UNIT PROD 51.60 2,600.00 8,984.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-D4,1/8/201512.11;33 PM SSSV:NIPPLE 140 9/25/2013 Last WO: 7/21/2013 40.00, 7/9/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _ Last Tag:SLM 8,773.0 1/4/2015 Rev Reason:TAG,PERFORATIONS lehallf 1/8/2015 HANGER,31.1. LL='IJJ Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D(... Wt/Len(I...Grade Top Thread nnnn CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread SURFACE 9 5/8 8.921 35.0 5,099.2 4,029.0 36.00 J-55 BTC ° 'Casing Description OD(in) ID(in) Top(ftKB) -Set Depth(ftKB) 'Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7, 6276 33.0 8,961.3 6,768.7 26.00 J-55 BTC CONDUCTOR;35.0.115.0 ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 412 3.958 7,951.4 8,850.0 6,686.8 12.60 L-80 IBTM Liner Details NIPPLE;508.1 Nominal ID Top(ftKB) Top(ND)(ftKB) Top not(°) Item Des Corn (in) IN 7,951.4 6,037.9 45.08 PACKER 2RH ZXP w/HD LINER TOP PACKER 4.310 all 7,970.0 6,051.0 45.08 HANGER DG FLEX-LOCK LINER HANGER 4.400 7,979.8 6,058.0 45.08 SBE BAKER SEAL BORE EXTENSION 4.000 GAS LIFT;3,098.4 Tubing Strings Tubing Description String Ma...ID lin) Top(ftKB) Set Depth(k..Set Depth(NO)I...WI(IWft) Gratle Top Connection TUBING Completion Details 31/21 29921 31.11 7,987.91 6,063.7) 9.301E-80 IEUESrdABMod I Nominal ID GAS LIFT;4,760 7 Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) 31.1 31.1 0.08 HANGER CIW GEN IV TUBING HANGER w/Type'H'Profile 2992 508.1 508.1- 0.38 NIPPLE CAMCO DS NIPPLE 3.5"x 2.875" 2.875 7,901.7 6,002.8 45.10 NIPPLE CAMCO 3.5"x 2.812"DS NIPPLE SN:T070815 2.812 7,950.4 6,037.2 45.08 LOCATOR BAKER GBH LOCATOR sub w/7-ft Space out 2.992 7,959.1 6,043.3 45.08 SEAL ASSY Baker 80-40 Seals 2.990 SURFACE;35.0-5,099.2 4. Perforations&Slots Shot Dens GAS LIFT;6,117.1 Top(ND) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,622.0 8,640.0 6,519.7 6,532.9 C-4,C-1, 5/7/1989 12.0 CMT 2 1/8"EnerJet,60 deg. - UNIT B,30- SQZ phasing-Squeezed .. 04 behind 4-1/2"liner during 2013 RWO • GAS LIFT;7,166.4 8,653.0 8,669.0 6,542.4 6,554.1 A-3,30-04 5/7/1989 12.0 CMT 2 1/8"EnerJet,60 deg. SQZ phasing--Squeezed behind 4-1/2"liner al during 2013 RWO 8.675.0 8,695.0 6,558.5 6,573.1 A-1,30-04 1/5/2015 6.0 APERF 2.5"6SPF,60 DEGREE PHASING,DEEP GAS LIFT;7,843.2 penetrating chgs 8,675.0 8,695.0 6,558.5 6,573.1 A-2,30-04 7/18/2013 6.0 APERF 3-3/8"OD 6 SPF MILLENNIUM 60 DEG • PHASING 25gr HMX 8,675.0 8,698.0 6,558.5 6,575.3 A-2,30-04 5/7/1989 12.0 CMT 2 1/8"EnerJet,60 deg. NIPPLE;7,901.6 SQZ phasing--Squeezed Ibehind 4-12"liner during 2013 RWO 8,710.0' 8,730.0 6,584.1 6,598.8 A-1,30-04 9/25/1988 8.0 CMT 4 1/2"HSD Csg Gun,45 SQZ deg.phasing- 2 'F Squeezed behind 4-1/2' liner during 2013 RWO LOCATOR;7,950.4 rirW'V'4 Cement Squeezes SEAL ASSY;7,959.1 I Top(ft(ND)I Btm(ND) Top(ftKB) Btm(ftKB) KB) (ftKB) Des Start Date I Com 7,950.0 8,850.0 6,036.9 6,686.8 LINER CMT 7/15/2013 $ Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 'I 1' 3,098.4 2,599.8 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/15/2014 CMT SOZ;8,622.0-8,6400- 2 4,760.7 3,787.1 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/15/2014 C ` 3 6,117.1 4,747.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/16/2014 CMT SO2;8,653.0-8.669.0- ` 4 7,166.4 5,485.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/14/2014 APERF;8,675.0.8.695.0'�(1 0 APERF;8,675.0-8.695.0_ 5 7,843.2 5,961.6 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/18/2014 CMT SQZ;8,675.0.8,698.0 Notes:General&Safety End Date Annotation 7/10/1994 NOTE:WAIVERED WELL:IA x OA COMMUNICATION CMT SU;8.710.0.8,730.0- ` 9/8/2003 NOTE:31"Surf CSG Patch covering hole located 32"below OA valve. PT @ 1,500 psi-good 2013 RWO ••:', 5/18/2009 NOTE:View Schematic w/Alaska Schematic9.0 I LINER;7,951.4-8,850.0 PRODUCTION;330-8,961.3 • • N c a) E E cr o .v 0 V (O V OM) N M 0') 0 0 CO COO C M W N- 0) n ((0 N N (MO CMO E c o 'p N V a1 N l0 V V N N = •- (C a ai - 0 0 0 0 0 0 n E -0 LL E `ui X N C „ T U L _ U c a = U v z „„„ O po .c a....., i J C --(ii 3 (O CO- 0 N CO CO O O V W V E C O a) co O I"" X 7 N .' c0 N 0 LT. 8 v CO CD r CO cs'i CV r r r r o 2 o Cca � N O �.. av �/ 3a) m47 E W r- oo (0 L a) U < • O O) M 1..- O M O) o 4.- us O 00 V r N Q 00 0 r t` 0 0 0 N Q 7 N C- O 0) 0() CO r0 N -^J c wen O 44 W N C .N+ CO N ,-N t "O c O Ln Lf) co - O c N O co co 0 O C) O c x.,•N y 5 ^ E y c a ^ r r• - 0 a) 0 0 0 CO CO y .---.-2 >. T p c _T 0. O O co 0 0 e r� Q Z Ln CO a r p N.. v O M M < >+ O 0 O Ns Q CO Lfi N °' v °m U aai O O a) N L N O) f Z 0) >>N N- Xo a) x n'a> t 'p c,' ami ;+ m � c � � o do.� mr' >aE `=a0- ° o y � � E _ O O Cl) N c .L. C.) N a m > > .X�Lov (n��. m m aCi �o Q f cnc0 0 E U cem Ea .a o T d U 'n AO n ., n 0 c o 1.. = O 0 c0i'y rnca- �_ o o a � >CQ mo 3 m<w a o+ 0 N. C Q to) 3a)aE LL o 0 O. ° yN r O N m�rmO000G E 0) Q 1 •L O RI CO C _ E _0 = a = >. aa) a $ n a) ate0 ,t _o U mZ(13 = °c) cQ a) 0 0 o LL CL En a: . co c Z Z _i m E > cn N a III L > d p_ N N > L Ct V t) O cc) a) E i6 0 i a) v a Z � F— � Z LL E c. Li) co t� Z Lm m = a) O O H 73 T6 Ca 'a H 0 I I— I aW m= • • . . i• v-- •• E • 1 t• .• • • •- • • N N- CO V N O CO N V V 0 O 0 6) CO — N O V a () O (O C) O O O O 0 0 (O (O V V N 0 0 0 0 0 0 0 0 0 O 00000, 0 O O O O O O d O O O O O O O O O O O O O iTi 0 (/) (D CD V V a) N- 0) d' f- co N- co M ✓ CO 0 N CO CO CO CO 6) ,- 0 I� V CO h t- _ LO N N V (O 0 N0) 0 0 0 0 N 7o 6) N- COLU (O V _N 0 0 0 0 N ✓ N N 0 0 0 0 0 0 0 0 0 0 O 0 O O O O O O O O (73 O O O O O O .c cocn (a 0 >, a) fa fn To N O (O (O CO '5O co () O N co C- CO LU LO '1 �i 6)LO . N N co 0)) C N o) oo co o0 COh a CO O 0 D 00 () N- N- O M N uo O N a) a M M h M N O 0 CO 0 O CO 0 . y N- (O N (M (O r 0 (O 0 (O 0 N V 0 a wO N O .- CO (O N N. r- ,- N OO co i�O) O co E O c O U 0 t o CD c c w a) O O -c v N E >, W C a O > a) c U o U'5, L N pEs a) •d• a) L-�0 7 N (`0 a) 1. p fa .c a) 3 >, c 0 c E °� x n —_ Z O > -p to z E- 5,2 m O E o U (o w 0 E c f0 0-c0m • U Z• mo IX C E c :9 w , •w p po a) x E p p >,it) ova o 'c cEa`) E ( oC > y .cls o 5„ II .UflIllHI !i .2Q N�c7 d X H a).Tr ash W W d > o vH Q n w?c -co (6 a) O. 3 c o p CL O o m s D D+� a) C,- O ao N U -°a 3 It 8 YU ,c l0 co 1 6 N 2 N o O N O O U a a� U• j Y N E U >•743 N N N O U N O d O U C C C m U • C E N o p Oa wO O O C E N >2 7 2 a) m Z - E '- 'O O ▪ C N O C -- .CO Eo c LL _ To o o c m E F: z o) c STATE OF ALASKA ALIDA OIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon j`" Rug Perforations f Fracture Stimulate j;r Pull Tubing Operations Shutdown -1-- Performed: Performed: Sus end Perforate Suspend ]— Other Stimulate 1--- Alter Casing r Change Approver] Program Ru for Redrill Repair� Perforate New Pool j� Well j— Re-enter Susp Well r Other: I- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory (" 188-062 _ 3.Address: (�" 6.API Number: Stratigraphic I Service 7 P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21826-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25513 KRU 30-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8984 feet Plugs(measured) none true vertical 6785 feet Junk(measured) none Effective Depth measured 8850 feet Packer(measured) 7951 true vertical 6687 feet (true vertical) 6038 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115 SURFACE 5064 9.625 5099 4029 LINER 899 4.5 8850 6687 PRODUCTION 8928 7 8961 6769 RECEIVED AUG 132015 Perforation depth: Measured depth: 8622-8640, 8653-8669, 8675-8698, 8710-8730 True Vertical Depth: 6520-6533, 6542-6554, 6559-6575, 6584-6599 /r,O("'�CC Tubing(size,grade,MD,and TVD) 3.5, L-80, 7988 MD, 6037 TVD Packers&SSSV(type,MD,and TVD) PACKER-2RH ZXP w/HD LINER TOP PACKER @ 7951 MD and 6038 TVD NIPPLE-CAMCO DS NIPPLE©508 MD and 508 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): stimulation treatment not complete but will be continued under a new sundry Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ( Exploratory I— Development Service i Stratigraphic '— Copies of Logs and Surveys Run j 16.Well Status after work: Oil j Gas E WDSPL 1 Printed and Electronic Fracture Stimulation Data r GSTOR 1— WINJ f WAG [-" GINJ r SUSP [ SPLUG 1- 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: 314-359 Contact Mike Hazen 265-1032 Email Michael.C.Hazen( cop.com Printed Name Mike Hazen Title Wells Engineer Signature ' Phone:265-1032 Date /2 ,:l VCj / 5 3122/« cA)g4/ %.r/`S RBDMgA\ AUG 1 4 2015 //v )0 /. EP re c e t ue-ck Z1 ,)A141 ca Form 10-404 Revised 5/2015 Submit Original Only Aft 30-04 FRAC SUMMARY DATE SUMMARY 11/14/2014 BRUSH & FLUSH TBG &TAGGED @ 8526' SLM ( EST. 146' OF FILL) DRIFTED TBG W/ 15'x 2.73" DMY PERF GUN TO 8549' RKB; SET 2.81" CA-2 PLUG W/SINGLE SPARTEK GAUGE @ 7902' RKB. DEPLOYED BAITED PULLING TOOL. PULLED GLV @ 7166' RKB &SET DV. ATTEMPT PULL GLVs @ 6117' &4761' RKB. IN PROGRESS. 11/15/2014 PULLED GLVs © 6117', 4761' & 3098' RKB. SET DVs © 3098' &4761' RKB. IN PROGRESS. 11/16/2014 SET DV @ 6117' RKB; PULLED OV @ 7843' RKB & LEFT POCKET OPEN (READY FOR CIRC OUT). IN PROGRESS. 11/17/2014 circ-out well, pump 202 bbls CRW S/W down tbg followed by 80 dsl, taking returns up IA, u-tube well. Ready for Slickline 11/18/2014 SET DV @ 7843' RKB. ATTEMPT MITT TO 4000 PSI ( FAILED, SUSPECT PLUG LEAKING) MIT x IA TO 3500 PSI ( PASS) REPLACED 2.81" CA-2 PLUG @ 7902' RKB. MITT TBG TO 4000 PSI PASS) IN PROGRESS. 11/23/2014 PULLED 2.81" CA-2 PLUG @ 7902' RKB. DRIFTED TO 10' SLM WITH DUAL BRUSHES &2.906" GAUGE RING FOR TREESAVER. READY FOR CTU. 12/5/2014 B&C CTU #1: PERFORM FILL CLEAN OUT TO HARD TAG AT 8783' RKB (53' RATHOLE)WITH JSN, SLICK DIESEL, AND DIESEL GEL. PUMP INJECTIVITY TEST POST FCO WITH SLICK DIESEL. PUMPING 0.5 BPM, 3270 PSI CIRC PRESSURE, 2950 PSI WHP. PUMPING 1.0 BPM, 3870 PSI CIRC, 3160 PSI WHP. PUMPING 2 BPM, 5880 PSI CIRC, 3460 PSI WHP. ADDITIONAL PERFS WILL BE REQUIRED PRIOR TO PUMPING SANDLOCK RESIN. READY FOR ELINE. 1/3/2015 ATTEMPTED TO PERFORATE INTERVAL OF 8675' - 8695' BUT THE TOOLSTRING TAGGED HARD AT 8610' ELM. JOB SUSPENDED. 1/4/2015 RAN 2.5" BAILER WORKED PAST TIGHT SPOT @ 8606' SLM TAG BTM @ 8773' SLM, CLEAN UP TIGHT SPOT WITH 2.78" GAUGE, DRIFT WITH 20' OF 2 1/2 DUMMY GUNS TAG @ 8773' SLM NO PROBLEMS. COMPLETE READY FOR E-LINE 1/5/2015 CORRELATE TO PERFORATING RECORD DATED 18-JULY-2013 AND PERFORATE 8675'-8695' WITH 2.5" 6 SHOT PER FOOT, 60 DEGREE PHASING. DEEP PENETRATING CHARGES. PERFORM SBHP SURVEY @ 8695'AND GRADIENT STOP @ 8560' 8560' PRESSURE =4107 PSIi; TEMPERATURE = 157 DEG 8695' PRESSURE =4142 PSIi; TEMPERATURE = 160 DEG 1/10/2015 PERFORM INJECTIVITY TEST ON TBG (JOB COMPLETE) 1/20/2015 injectivity test, maintained 3.5 bbls/min at 4000 psi for 30 bbls dsl,job complete mf KUP PROD • 30-04 li ConocoPhillips ,1 Welt Attributes Max Angle&MD TD Alaska,ii "r Wellbore API/UINI Field Name Wellbore Status Inc!I") MO(ftKB) Act Btm(ftKB) morn nrbaBP, ' 500292182600 KUPARUK RIVER UNIT PROD 51.60 2,600.00 8,984.0 """ Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-04,1/8201512:11:33 PM SSSV:NIPPLE 140 9/252013 Last WO: 7/21/2013 40.00 7/9/1988 Verb al schematic{actua() Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,773.0 1/4/2015 Rev Reason:TAG,PERFORATIONS lehallf 1/8/2015 HANGER 31.1 14-"A jI Casing Strings Casing Description OD lin) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt./Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 Welded -.1„...J., ,: t Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 11 SURFACE 95/8 8.921 35.0 5,099.2 4,029.0 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread -�' PRODUCTION 7 6.276 33.0 8,961.3_ 6,768.7 26.00 J-55 BTC CONDUCTOR;35.0-115.0 • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread LINER 41/2 3.958 7,951.4 8,850.0 6,686.8 12.60 L-80 IBTM Liner Details NIPPLE',508.7 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl rt Item Des Corn (in) 7,951.4 6,037.9 45.08 PACKER 2RH ZXP w/HD LINER TOP PACKER 4.310 7,970.0 6,051.0 45.08 HANGER DG FLEX-LOCK LINER HANGER 4.400 7,979.8 6,058.0' 45.08 SBE BAKER SEAL BORE EXTENSION 4.000 GAS LIFT;3.098.4 Tubing Strings.. Tubing Description 'String Ma...I ID(in) 'Top(ftKB) 'Set Depth(tt..1 Set Depth(TVD)(...I Wt(Ibttt) 'Grade 'Top Connection TUBING WO 312 2.992 31.1 7,987.91 6,063.7 9.30 L-80 EUE 8rd AB Mod Completion Details Nominal ID GAS LIFT;4.760.7 1 Top(ftKB) Top(ND)(ftKB) Top hal(") Item Des Corn (in) 31.1 31.1 0.08 HANGER CIW GEN IV TUBING HANGER w/Type'H'Profile 2.992 508.1 508.1 0.38 NIPPLE CAMCO DS NIPPLE 3.5"x 2.875" 2.875 7,901.7 6,002.8 45.10 NIPPLE CAMCO 3.5"x 2.812"DS NIPPLE SN:T070815 2.812 7,950.4 6,037.2 45.08 LOCATOR BAKER GBH LOCATOR sub w/7-ft Space out 2.992 1.'`i 7,959.1 6,043.3 45.08 SEAL ASSY Baker 80-40 Seals 2.990 SURFACE;35.0-5,099.2 Perforations&Slots Shot Dens GAS LIFT;6117.111 Top(ND) Btm(ND) (shots tt Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 8,622.0 8,640.0 6,519.7 6,532.9 C-4,C-1, 5/7/1989 12.0 CMT 21/8"EnerJet,60 deg. UNIT B,30- SQZ phasing--Squeezed 04 behind 4-1/2"liner during 2013 RWO GAS LIFT;7,166.4 II 8,653.0 8,669.0 6,542.4 6,554.1 A-3,30-04 5/7/1989 12.0 CMT 2 1/8"EnerJet,60 deg. SQZ phasing--Squeezed behind 4-1/2"liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-1,30-04 1/5/2015 6.0 APERF 2.5"6SPF,60 DEGREE GAS LIFT,7,843.2 II PHASING,DEEP penetrating chgs 8,675.0 8,695.0 6,558.5 6,573.1 A-2,30-04 7/18/2013 6.0 APERF 3-3/8"OD 6 SPF MILLENNIUM 60 DEG PHASING 25gr HMX 8,675.0 8,698.0 6,558.5 6,575.3 A-2,30-04 5/7/1989 12.0 CMT 2 1/8"EnerJet,60 deg. NIPPLE,7901.6 SQZ phasing--Squeezed behind 4-1/2"liner during 2013 RWO 8,710.0 8,730.0 6,584.1 6,598.8 A-1,30-04 9/25/1988 8.0 CMT 4 1/2"HSD Cog Gun,45 SQZ deg.phasing- s ir Squeezed behind 4-1/2" liner during 2013 RWO LOCATOR,7,950.4 - m.g:V Cement Squeezes SEAL ASSY;7,959.1 -.:. Top(TVD) Btm(TVD) ,. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des I Start Date I Com i K 7,950.0 8,850.0 6,036.9 6,686.8 LINER CMT 7/15/2013 Mandrel Inserts St a au ;. on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type lin) (psi) Run Date Corn o - l' 3,098.4 2,599.8 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/15/2014 CMT SQZ,8,622.0-8,640.0 2 4,760.7 3,787.1 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/15/2014 C J 3 6,117.1 4,747.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/16/2014 CMT SQZ,8.653.0-8.669.0 4 7,166.4 5,485.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/14/2014 APERF;8,675.0-8,6950 APERF,8,675.0-8,695.0- 'm 5 7,843.2 5,961.6 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/18/2014 CMT SOZ;8,675.0-8,698.0 ` i. Notes:General&Safety 1 End Date Annotation -', 7/10/1994 NOTE:WAIVERED WELL: IA OA COMMUNICATION CMT SQZ;8,710.0-8,730.0- C C - 9/8/2003 NOTE:31"Surf CSG Patch covering hole located 32"below OA valve. PT @ 1,500 psi-good 2013 RWO r. 5/18/2009 NOTE View Schematic w/Alaska Schematic9.0 2 ri C ,. .1 h LINER,7,951.4-8,850.0 i 1 1 PRODUCTION,330-8,961.3 L177714' • • �� s, THE STATE Alaska Oil and Gas �4`1,;,- - of Conservation Commission u : 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 a ":77 Main: 907.279.1433 ALAFax: 907.276.7542 www.aogcc.alaska.gov Mike Hazen Wells Engineer icA$NEP DEC 0 2 2015 ConocoPhillips Alaska, Inc. I 8 y 0 62-- P.O. Box 100360 v Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-04 Sundry Number: 315-520 Dear Mr. Hazen: 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, O1� �! �RBDMS SEP 15 2015 Cathy . Foerster Chair DATED this I i day of September,2015 Encl. 8 Er .. STATE OF ALASKA A•KA OIL AND GAS CONSERVATION COMA ION AUG 2 25 2015 APPLICATION FOR SUNDRY APPROVALS ' IS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate 1 Pull Tubing r Operations Shutdown [— Suspend Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well Re-enter Susp P Well r Other: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 17 188-062 3.Address: Stratigraphic r Service 6.API Number. P.0. Box 100360,Anchorage,Alaska 99510 50-029-21826-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No KRU 30-04 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25513 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8984 6785 8850' 6687' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115' 115' SURFACE 5064 9.625 5099' 4029' LINER 899 4.5 8850' 6687' PRODUCTION 8928 7 8961' 6769' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8675-8695' 6559'-6573' 3.5 L-80 7988 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-2RH ZXP LINER TOP PACKER MD=7951 TVD=6038 NIPPLE-CAMCO DS NIPPLE MD= 508 TVD=508 12.Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program BOP Sketch rExploratory r Stratigraphic r Development F Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/9/2015 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Hazen @ 265-1032 Email: hazenmcconocophillips.com Printed Name Mi e azen Title: Wells Engineer Signature — Phone:265-1032 Date 2_41-A1/4)6. r j Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 315 - 62-C" Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: FOS-1- � ffDdi& t l/Ul f e-6( A) 1C4- Frac roc-os Gtie-r✓12.Go¢ t 1), ,..(0 SJre141 IS. 7/K Wk.,.421(do WS.a1- ?lids o 1l.a.]. rf4Ui r.e ri e#*5 4 20 M C AS: 2$3 . Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: I0 — 4.D 4_ / / /0 4.,.„7 / APPROVED BY Approved by: �� }[`,�� COMMISSIONER THE COMMISSION Date: 9 —l( 7)' Approved app Icatlon Is valid tor 11 the o the date of approval. RRnailles(� ,P is Oil Form 10-403 Revise.5/2015 ORIGINAL ' ac ments in 1 p iccatte g g�2or Kuparuk Well 30-04 (PR 188-062) Hydraulic Fracturing PGCC Sundry Application Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that 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 THE ALASKA OIL AND GAS CONSERVATION CO IISSION 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 30-04 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. I am over 19 years old and 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 August 11, 2015, 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 11th day of August, 2015. Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 11th day of August, 2015, by Paul K.Wharton. Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA NOTARY PUBLIC REBECCA SWENSEN My Commission Expires Aug.27,2016 • • 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) 30-04 Well Kuparuk River Unit, Alaska ADL 25513, KRU Tract 3 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 30-04 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about August 11, 2015. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well on lease ADL 25513, KRU Tract 3 as depicted on Exhibit 1 as follows: Surface Location: 789' FNL, 1,879' FWL, Section 22, T13N, RO9E, UM Target Location: 1,320' FSL, 2,398' FWL, Section 16, T13N, RO9E, UM Bottomhole Location: 1,399' FSL, 2,220' FWL, Section 16, T13N, RO9E, 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, Paul Wharton Staff Landman cc: Mike Hazen 30-04 Hydraulic Fracturing Notice Letter August 11, 2015 Page 2 Exhibit 1 a ADL373301 l CPAI �.•'� BPXA r \ CHEVRON ADL355023 � EXXONMOBILAK AK! CPAI J -' BPXA l l CHEVRON 11 EXXONMOBILAK / / uuKTOK i X P12 I _ .,....J • 1 >. s, % Mile Radius t7 � from Well 6 30-04 Well ADL025513 Path CPAI X BPXA '''v, CHEVRON ADL025514 ADL025512 XONMOBILAK i HILCORP CPAI BPXA BPXA 1 Milne Kuparuk P 1 Point Unit EXXONMOBILAK River Unit 30-04 1 • .. ADL025519 ADL025521 CPAI ADLO2 Legend BPXA CHEVRON 6P, • SDE_DATA.AK_WELL_SURF_HOLE_ATDB_DD83 EXXONMOBILAK - CHEV X SDE_DATA.AK_WELL_BOTTOM_TD_ATDB_DD83 EKXONM SDE_DATA.AK_WELL_SURV_SPDR_ATDB_A483 / Producing Zone (=Trajectory 1/2 mile radius i_.iAK Units ll t REFERENCES: Well Data:ConocoPhillipsAlaska Welts Database ATDB ConocoPhillips Surface Facilities:North Slope 6K Survey 7/25/12 Published 3/20/13 Alaska Statewide Oil&Gas Leases 1/12/2015 Alaska,Inc. Water Well Data:DNR-Groundwater Division N _ >No Potable Water Wells are in the Kuparuk River Unit. m les >No Potable Water Aquifers are in the Kuparuk River Unit 30-04 Well • 30-04 Hydraulic Fracturing Notice Letter • August 11, 2015 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Patrick J. Wolfe, NS Development Manager 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 Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director Kuparuk Well 30-04 (PTD 188-062) Hydraulic FracturingtGCC Sundry Application Section 2 — Plat 20 AAC 25.283 (a)(2) 3Q 2. - 1.3R-26 3Q-16 \\\•,' • : Milne Point Atatiblike fl Unit lt ' , !L04 • �` .33'8= ,H:93 1' 03 7 Kuparuk River Unit Legend Wells Within 1/2 Mile of Open Section —Wells within radius Well Pad APERF 3N 7 SQUEEZED 1=l1/2 mile Trajectory radius 1/2 Mile Open Section Radius 3o041ine CPAI Operated Units Other Operated Units Alaska Protracted Sections nBLM Townships REFERENCES: Well Data:ConocoPhillips Alaska Wells Database ATDB ConocoPh i I lips Surface Facilities:North Slope 6K Survey 7/25/12 Published 3/20/13 Alaska Statewide Oil&Gas Leases 1/12/2015 Alaska,Inc. Water Well Data:DNR-Groundwater Division >No Potable Water Wells are in the Kuparuk River Unit. N 30-04 Well Analysis >No Potable Water Aquifers are in the Kuparuk River Unit IN\ 7/27/2015 1 os Miles Kuparuk Well 30-04 (PTD 188-062) Hydraulic Fracturing IIGCC Sundry Application WELL_NAME PERMIT_NUM API BUS_AREA_ID DRILLSITE FLUID STATUS WELL 30-01 188-073 500292183600 KRU 30 OIL ACTIVE PROD 30-02 188-074 500292183700 KRU 30 OIL PA PROD 30-02A 207-158 500292183701 KRU 30 OIL ACTIVE PROD 30-02AL1 207-159 500292183760 KRU 30 OIL ACTIVE PROD 30- 02AL1PB1 207-159 500292183770 KRU 30 PA EXPEND 30-02AL2 207-160 500292183761 KRU 30 OIL ACTIVE PROD 30-02AL2-01 207-161 500292183762 KRU 30 OIL ACTIVE PROD 30-03 188-075 500292183800 KRU 30 OIL ACTIVE PROD 30-04 188-062 500292182600 KRU 30 OIL ACTIVE PROD 30-05 188-076 500292183900 KRU 30 MWAG ACTIVE INJ 30-06 188-060 500292182400 KRU 30 MWAG ACTIVE INJ 30-07 188-077 500292184000 KRU 30 MWAG ACTIVE INJ 30-08 188-064 500292182800 KRU 30 OIL ACTIVE PROD 30-09 188-061 500292182500 KRU 30 OIL ACTIVE PROD 30-10 188-059 500292182300 KRU 30 MWAG ACTIVE INJ 30-11 188-042 500292180500 KRU 30 OIL ACTIVE PROD 30-12 188-041 500292180400 KRU 30 OIL ACTIVE PROD 30-12L1 215-003-0 500292180460 KRU 30 OIL ACTIVE PROD 30-12L1-01 215-047-0 500292180461 KRU 30 OIL ACTIVE PROD 30-13 188-040 500292180300 KRU 30 OIL ACTIVE PROD 30-13L1 215-009-0 500292180360 KRU 30 OIL ACTIVE PROD 30-13L1-01 215-010-0 500292180361 KRU 30 OIL ACTIVE PROD 30-13L1-02 215-011-0 500292180362 KRU 30 OIL ACTIVE PROD 30-13L1-03 215-013-0 500292180363 KRU 30 OIL ACTIVE PROD 30-13L1-04 215-014-0 500292180364 KRU 30 OIL ACTIVE PROD 30-14 188-039 500292180200 KRU 30 MWAG ACTIVE INJ 30-15 188-031 500292179700 KRU 30 OIL ACTIVE PROD 30-16 188-030 500292179600 KRU 30 PA PROD 30-16A 188-043 500292179601 KRU 30 PA INJ 30-16B 215-057-0 500292179602 KRU 30 OIL ACTIVE PROD 30-16BL1 215-030-0 500292179661 KRU 30 OIL ACTIVE PROD 30-16BL2 215-031-0 500292179662 KRU 30 OIL ACTIVE PROD 30-16BPB1 215-057-0 500292179670 KRU 30 PA EXPEND 30-16BPB2 215-057-0 500292179671 KRU 30 PA EXPEND 30-17 188-029 500292179500 KRU 30 MWAG ACTIVE INJ 30-18 188-026 500292179300 KRU 30 OIL ACTIVE PROD 30-19 197-050 500292275300 KRU 30 MWAG ACTIVE INJ 30-20 197-045 500292275000 KRU 30 OIL ACTIVE PROD 3Q-16 186-179 500292166700 KRU 3Q MWAG ACTIVE INJ 3R-26 195-187 500292262600 KRU 3R OIL ACTIVE PROD Kuparuk Well 30-04 (Pit 188-062) Hydraulic Fracturing PGCC Sundry Application 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. See conclusion of the Aquifer Exemption Title 40 CFR 147.102 (b) (3), which states "The portions of 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." ELECTRONIC CODE OF FEDERAL REGULATIONS View past updates to the e-CFR. Click here to learn more. e-CFR data is current as of August 18, 2015 Title 40 —>Chapter I —>Subchapter D —> Part 147 —*Subpart C Title 40: Protection of Environment PART 147—STATE, TRIBAL,AND EPA-ADMINISTERED UNDERGROUND INJECTION CONTROL PROGRAMS Subpart C—Alaska Contents §147.102 Aquifer exemptions. §147.102 Aquifer exemptions. (a)This section identifies any aquifers or their portions exempted in accordance with §§144.7(b) and 146.4 of this chapter at the time of program promulgation. EPA may in the future exempt other aquifers or portions, according to applicable procedures, without codifying such exemptions in this section. An updated list of exemptions will be maintained in the Regional office. (b)The following aquifers are exempted in accordance with the provisions of§§144.7(b) and 146.4 of this chapter for Class II injection activities only: (1)The portions of aquifers in the Kenai Peninsula, greater than the indicated depths below the ground surface, and described by a '/4 mile area beyond and lying directly below the following oil and gas producing fields: (i) Swanson River Field-1700 feet. (ii) Beaver Creek Field-1650 feet. (iii) Kenai Gas Field-1300 feet. (2)The portion of aquifers beneath Cook Inlet described by a V4 mile area beyond and lying directly below the following oil and gas producing fields: (i) Granite Point. (ii) McArthur River Field. (iii) Middle Ground Shoal Field. (iv)Trading Bay Field. (3)The portions of 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. Kuparuk Well 30-04 (P!D 188-062) Hydraulic Fracturing GCC Sundry Application 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. Kuparuk Well 30-04 (P!D 188-062) Hydraulic Fracturing ftGCC Sundry Application 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. Kuparuk Well 30-04 (PTD 188-062) Hydraulic Fracturing ItGCC Sundry Application 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: KRU 30-04: The 16" casing cement pump report on 7/2/1988 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped using 199 sx of Arctic Set (AS) Ill cement and full returns were observed throughout the job. The 9-5/8" casing cement pump report on 7/6/1988 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 1200 sx of AS III and 375 sx of 15.8ppg Class G cement. A top job was also pumped using 150 sx of AS I. Full returns were observed throughout the job. The 7" casing cement pump report on 7/10/1988 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 100 sx 50/50 pozzolan-cement blend lead followed by 200 sx 15.8ppg Class G cement. Full returns were observed throughout the job. Cement was pressure tested to 3500-psi. Cement bond logging performed over the 7" cement interval (6980-8866') on 8/3/1988 also indicates good cement (logs provided 8/26/88). The well was also worked over in mid-2013 where a new 4-1/2" scab liner was installed and cemented in from 7099-8850'MD. A new 3-1/2", 9.3#, L80 tubing, gas-lift completion was also installed to 7987'. All existing perfs were squeezed of with cement at the time of the recompletion. In cementing the 4-1/2" liner, a 27-bbl of 15.8# Class G slurry with 45# (17- bbl) CemNet was pumped preceded by a 10-bbl 13.7# Mud Push lead. Good returns were observed throughout the job and the dart bumped at 59-bbl as designed. The well was later perforated in its currently only open zone of A2-sand at 8675-8695'MD. A composite plug was set at 8600'. 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. Kuparuk Well 30-04 (Pit 188-062) Hydraulic Fracturing figGCC Sundry Application Section 7 — Pressure Test Information and Plans to Pressure-Test Casings and Tubings Installed in the Well 20 AAC 25.283(a)(7) On 7/2/1988 the 16" casing was pressure tested to 2500-psi for 30-min. On 7/6/1988 the 9-5/8" casing was pressure tested to 2500-psi for 30-min. On 7/10/1988, the 7" casing was pressure tested to 2500-psi for 30-min. On 7/15/2013 the 4.5" liner was pressure tested to 3500-psi for 30-min. On 7/19/2013 the 3.5" tubing was pressure tested to 2500 psi for 30-min. The 3.5" tubing will again be pressure tested to 3500-psi prior to starting the fracturing stimulation. The 7" casing will also be pressure tested again to 3500-psi prior to the fracturing treatment. Kuparuk Well 30-04 (At 188-062) Hydraulic Fracturing GCC Sundry Application 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 16" 62.5 H-40 1,640-psi 630-psi 9-5/8" 36 J-55 3,520-psi 2,020 -psi 7" 26 J-55 4,980-psi 4,330-psi 4.5" 12.6 L-80 8,430-psi 7,500-psi 3.5" 9.3 L-80 10,160-psi 10,540-psi ilig Kuparuk Well 30-04 (Pit 188-062) Hydraulic Fracturing GCC Sundry Application Stimulation Surface Rig-Up �s c Bleed t Tattle Tale Tank � � 1 • Minimum pressure rating on all surface i� �� treating lines 10,000-psi di / w r // V • Main treating line PRV is set to 95% of max 8 treating pressure • IA parallel PRV set to 3500-psi 14 111( • Frac pump trip pressure setting are staggered and set below main treating line PRV 43 rrir • Tree saver used on all fracs rated for 15,000- 5 psi. �r =V 4a H r�r A >fl dwnd c� Pop Off Tank Pop-Off Talk Pump Truck P-J V C .d. Frac Pump Fra'_,Pump Frac Pump - - - Frac Pump Frac Pump J- —c1- Fiat:Pump • Kuparuk Well 30-04 (PTD 188-062) Hydraulicdraulic FracturSundry Application Stimulation Tree Saver OPEN PosmoN CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDRIL INSERTED) FRAC IRON 6 /'CONNECTION ,fri i i I i • onnwrimme TT.. . /REMOTE OPERATED „� �� J C.I - MASTER VALVE ;s 4� brei Nor 4, MANUAL OPERATED ♦ • 1...�. MASTER VALVE a i d•••••Ilwro wwwwwww • ' CY, r ( Stinger Stinger \ t i.„.............„, VENT I ti , i I,,,___VALVE OPEN €t1 lini E !JJ f/JJIi� N k 1 2, ...,,t ,..... ,..-, ,,,,_ It' FLOW TEE AND k.... •4 j e VENT VALVEI NV"'MI11 VALVES m J/+lr JA� OPEN u WELLHEAD VALVES , j k. h urm CLOSED �, a* ; ''-., y 'i'' 'Y' . 1 ., QUAD PACK4FF ✓1 ASSEMBLY IN by +u. PLACE INTUBING N.-f \ q ' , rv, N,' • The universal tool is rated for 15,000-psi and has 84" of stroke. • Tool ID 2.25" down 4-'/2" tubing and 1.75" down 3-W tubing. • Max rate with 2.25" mandrel is 60-bpm and with 1.75" mandrel 36-bpm • KUP PROD • 30-04 ConocoPhilhps - Well Attributes Max Angle&MD TD Alaska,IFtc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Ccmcdftilkrn 500292182600 KUPARUK RIVER UNIT PROD 51.60 2,600.00 8,984.0 .°. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 30-04,1/8/2015 12 11 33 PM SSSV:NIPPLE 140 9/25/2013 Last WO: 7/21/2013 40.00 7/9/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _J Last Tag:SLM 8,773.0 1/4/2015 Rev Reason:TAG,PERFORATIONS lehallf 1/8/2015 HANGER;31.1 �' sr' L„ ° ICasing CasingStrings " Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD). Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 Welded �, Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread F SURFACE 95/8 8.921 35.0 5,099.2 4,029.0 36.00 J-55 ETC .. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD(...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.0 8,961.3 6,768.7 26.00 J-55 BTC CONDUCTOR;35.0-115.0-.8 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 7,951.4 8,850.0 6,686.81 12.60 L-80 IBTM liner Details NIPPLE;508.1 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°I Item Des Corn (in) 7,951.4 6,037.9 45.08 PACKER 2RH ZXP w/HD LINER TOP PACKER 4.310 'i 7,970.0 6,051.0 45.08 HANGER DG FLEX-LOCK LINER HANGER 4.400 7,979.8 6,058.0 45.08 SBE BAKER SEAL BORE EXTENSION 4.000 GAS LIFT;3,098.4 Tubing Strings II Tubing Description (String Ma...I ID(in) (Top(ftKB) (Set Depth(ft..f Set Depth(ND)(...I Wt Ilb/ft) (Grade (Top Connection I al ill TUBING WO 3 1/2 2.992 31.1 79879 6,063 9.30 L-80 EUE 8rd AB Mod Completion Details Nominal ID GAS LIFT;4,760.7II. Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 31.1 31.1 0.08 HANGER CIW GEN IV TUBING HANGER w/Type'H'Profile 2.992 I 508.1 508.1 0.38 NIPPLE 6,002.8 45.10 NIPPLE CAMCO DS NIPPLE 3.5"x2.875" 2.875 7,901.7CAMCO 3.5"x 2.812"DS NIPPLE SN:T070815 2.812 7,950.4 6,037.2 45.08 LOCATOR BAKER GBH LOCATOR sub w/7-ft Space out 2.992 7,959.1 6,043.3 45.08 SEAL ASSY Baker 80-40 Seals 2.990 SURFACE;35.0-5,099.2 Perforations&Slots I Shot Dens GAS LIFT;6,117.1 Top(ND) Btm(ND) (shots/f , Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,622.0 8,640.0 6,519.7 6,532.9 C-4,C-1, 5/7/1989 12.0 CMT 2 1/8"EnerJet,60 deg. UNIT B,30- SQZ phasing--Squeezed 04 behind 4-1/2"liner during 2013 RWO GAS LIFT;7,166.4 -III- 8,653.0 8,669.0 6,542.4 6,554.1 A-3,30-04 5/7/1989 12.0 CMT 2 1/8"EnerJet,60 deg. IF SQZ phasing--Squeezed behind 4-1/2"liner A. during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-1,30-04 1/5/2015 6.0 APERF 2.5"6SPF,60 DEGREE PHASING,DEEP GAS LIFT;7,843.2 penetrating chgs 8,675.0 8,695.0 6,558.5 6,573.1 A-2,30-04 7/18/2013 6.0 APERF 3-3/8"OD 6 SPF MILLENNIUM 60 DEG PHASING 25gr HMX 8,675.0 8,698.0 6,558.5 6,575.3 A-2,30-04 5/7/1989 12.0 CMT 21/8"EnerJet,60 deg. NIPPLE;7,901.6 SQZ phasing--Squeezed behind 4-1/2"liner during 2013 RWO 8,710.0 8,730.0 6,584.1 6,598.8 A-1,30-04 9/25/1988 8.0 CMT 4 1/2"HSD Csg Gun,45 SQZ deg.phasing- Squeezed behind 4-1/2" liner during 2013 RWO LOCATOR;7,950.4 011% Cement Squeezes SEAL ASSY;7,959.1 - Top(ND) Btm(TVD) pp4 Top(ftKB) Btm(ftKB) (19(13) (51(13) Des Start Date Corn . 7,950.0 8,850.0 6,036.9 6,686.8 LINER CMT 7/15/2013 Mandrel Inserts 7 St an Si 5 on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (51(0) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com 'y '� 3,098.4 2,599.8 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/15/2014 CMT SOZ;8,622.08,640.0- i5 2 4,760.7 3,787.1 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/15/2014 x 3 6,117.7 4,747.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/16/2014 CMT SQZ,8,653.0E,669.0- 4 7,166.4 5,485.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/14/2014 APERF;8,675.0-8,695.0 APERF;8,675.08,695.0 5 7,843.2 5,961.6 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/18/2014 CMT SQZ;8,675.0-8,698.0 2 S Notes:General&Safety End Date Annotation .. 7/10/1994 NOTE:WAIVERED WELL: IA OA COMMUNICATION CMT SOZ;8,710.08.730.0- 9/8/2003 NOTE:31"Surf CSG Patch covering hole located 32"below OA valve. PT @ 1,500 psi-good 2013 RWO l'l' , 8; 5/18/2009 NOTE:View Schematic w/Alaska Schemetic9.0 ?p4 - i' LINER;7,951.4-8,850.0 PRODUCTION;33.0-8,961.3 • Kuparuk Well 30-04 (• 188-062) Hydraulic Fracturing AOGCC Sundry Application 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 104' TVD (143' MD) thick, with the top of the Kuparuk A starting at 6475' TVDSS (8641' 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 14 ppg. The overlying confining zone has an overall thickness of 411' TVD (571' MD) and consists of Kuparuk D, Kalubik and HRZ mudstones. The estimated fracture pressure for the confining layer is 16 ppg. Top HRZ is 6047' TVDSS (8048' MD). S Kuparuk Well 30-04 ( D 188-062) Hydraulic Fracturing AOGCC Sundry Application 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: 30-02A: 7" Casing cement job was pumped on 8/4 and 8/5/1988 as designed, indicating competent cement operations. The cement pumped was 200-sx 15.8 ppg Class G cement, displaced by 347-bbl 10 ppg brine. The plug was bumped to 3500 psi and floats held. Pipe was reciprocated slowly throughout job and full returns maintained entire job. 30-06: 7" Casing cement job was pumped on 6/25/1988 as designed, indicating competent cement operations. The cement pumped was 300-sx 15.8 ppg Class G cement; the plug was bumped to 3000 psi and floats held. Cement bond logging performed over the 7" cement interval (5187-8052') on 8/2/1988 also indicates good cement (logs provided 8/26/88). 30-10: 7" Casing cement job was pumped on 6/17/1988 as designed, indicating competent cement operations. The cement pumped was 100-sx 12 ppg 50/50 fly ash lead cement followed by 200 sx 15.8 ppg Class G tail. Cement bond logging performed over the 7" cement interval (7346-8715') on 6/19/1988 also indicates good cement (logs provided 7/1/88). 3Q-16: 7" Casing cement job was pumped on 11/20/1986 as designed, indicating competent cement operations. The cement job was pumped with 100 sx 50/50 pozzolan-cement blend lead followed by 200 sx 15.8ppg Class G cement, and displaced with 274-bbl 10 ppg brine. The plugs (3) bumped to 3500-psi and floats held. 3R-26: 7-5/8" Casing cement job was pumped 12/13/1995 as designed indicating competent cement operations. The job pumped was 318-bbl lead 15.8-ppg Class G and 61-bbl 15.8-ppg Class G cement tail. Rig pumps displaced cement and the plugs did not bump. A top job was performed pumping 75 sx 15.8# Class G. The casing was tested to 2000-psi for 30-min prior to drilling out and FIT. • Kuparuk Well 30-04 (PTD 188-062) Hydraulic Fracturing AOGCC Sundry Application 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 two mapped faults that transect the Kuparuk A interval and enter the confining zone within one half mile radius of the wellbore trajectory for 30-04. These mapped faults do not intersect the 30-04 wellbore. The 30-04 well was previously hydraulically fractured three times between 1989 and 1997. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. • Kuparuk Well 30-04 (• 188-062) Hydraulic Fracturing AOGCC Sundry Application ADL373301 ADL355023 ADL025512 ADL025514 3Q APERF 1i 41. 30 Milne Point DLO2 Unit 30 Kuparuk River Unit ADL025521 ADL025519 Legend Well Pad APERF SQUEEZED SEGID — Faults within Radius Q 1/2 mile Trajectory radius • 1/2 Mile Open Section Radius —Trajectory QCPAI Operated Units Q Other Operated Units AK Leases ADL025520 CPAI HILCORP REFERENCES: Well Data:ConocoPhillips Alaska Wells Database ATDB ConocoPhil lips Surface Facilities:North Slope 6K Survey 7/25/12 Published 3/20/13 Alaska Statewide Oil&Gas Leases 1/12/2015 Alaska,Inc. Water Well Data:DNR-Groundwater Division >No Potable Water Wells are in the Kuparuk River Unit. N 30-04 Fault Analysis >No Potable Water Aquifers are in the Kuparuk River Unit '/J\\, 7/31/2015 05 0 Miles 2N338FRAC.m.1 CSR 214,2015 • Kuparuk Well 30-04 (PTD 188-062) Hydraulic Fracturing AOGCC Sundry Application Section 12 — Proposed Hydraulic Fracturing Program 20 AAC 25.283(a)(12) Kuparuk well 30-04 was drilled in 1988, initially completed in the A-sand, and produced at rates of less than 100-BPD total liquid. It was fracture stimulated in 1989 and production improved to over 600-BOPD and 0% water cut (WC). The C-sand was perforated in May 1989 but little or no benefit was noted and the splits remained 100% `A' sand. In October 1991 both sands were re-fractured with 109,000-lb of sand in formation. Production went from 950 bopd to 2200-BOPD initially, but the well started producing high water cut again in 1992. The well was again re-fractured in August 1997 using 237,000-lb of proppant, but little oil benefit was attained and water production increased from 550 to 800- BWPD. In July 1994 the well was waivered due to a slow thread leak and by May 2000 a gas-to- surface leak via the 9-5/8" conductor annulus was discovered. In November that year lift gas was discontinued. The OA was treated with Seal-Tite in May 2003 but the job later proved unsuccessful. In June, 2003 a split in the 9-5/8" casing was discovered at a depth of 32". The leak was excavated and repaired and the well returned to gas lift production in October 2003. The first indication of a rock problem occurred in January 2005 when gravel was recovered during a slickline brush run. The well continued to produce normally until May 2009 when the rock and sand production problem became so bad that the wellbore would fill up within days of going back on line following a fill cleanout. A video log run in March 2010 suggests that we may have exited the casing during fill cleanout operations. The log quality is poor however and definitive conclusions are not made. In July 2013 the well was worked over; the rig pulled the 3-%" tubing and fished the packer, then cleaned and evaluated the 7" production casing. A 4-'/2' scab liner was installed and cemented, and the Kuparuk A-sands perforated. New 3-'/z' tubing was installed and the well put back on production. The well was fracture stimulated at the time of completion placing 344k# of 16/20 proppant, and again re-fractured on August 1997 placing 237k# of 12/18 proppant. The proposed frac will place an additional 41k-lb of 20/40 Jordan Unimin proppant in 60# HEC and SandLock V resin. Proposed Procedure: 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any preexisting 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 two 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. 749- bbls are required for the treatment with breakdown, maximum pad, 450-bbls usable volume per tank, and 150 bbl contingency extra). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. • • Kuparuk Well 30-04 (PTD 188-062) Hydraulic Fracturing AOGCC Sundry Application 7. PT Surface lines to 6,000 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 100-bbl breakdown stage (2%KCI and 60# HEC) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 10-BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500-psi to 3,500-psi as the tubing pressures up. 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. Pump the Frac job by following schedule @ 10-bpm with a maximum expected treating pressure of 4375-psi. • 50 bbl SandLock V w/ 8 ppa 20/40 Jordan Unimin • 100 bbl 2% KCI • 50 bbl 60# HEC • 48 bbl SandLock V w/ 10 ppa 20/40 Jordan Unimin • 100 bbl 2% KCI • 50 bbl 60# HEC • 45 bbl SandLock V w/ 12 ppa 20/40 Jordan Unimin • 100 bbl 2% KCI • Flush with 68 bbl of linear fluid and freeze protect • Total Sand: Approx. 40,914 lb. of 20/40 Jordan Unimin 12. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO frac Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and CTU). 01 CP • 2 N o 2 Z O a Ic ,N 0) U) cl N O N N O h h ¢ N O : o n- 0 0 0 0 0 66 K v m 0 R Ow N 2 ,...0 Z y d 0 O 5'j w2=-1 ,-, 0 w J^ 0 1-- 00 0m ,„, Q C a 7 U m - O U m M N M M rV h i�f) O Z o- o O 0 W o a > p a 2 z II 11 II II h n II II II w O w0 viu .N O ! 1I`o a E. o a W � a } F Iy d I- p N Q = W W 0 C G c 2 c CC 10 N (l N 0 ¢ # O N 0 0 0 V V V 0 0 00 N N N a d c n F I- 0 I-Z 2 0 to 0 In u) u) 7 ;o Q 2 M a 2 y M M M 1 2 m a m M CO M N N N O _ _ _ _ a LLO U. O U N N N N N N 0 0 0 0 0 0 0) 0. a 1 M o 4 = Z V .n- LA, N v 2 O 11 11 II )1 )1 W_. w M 000 0) V Q 2 U U p 2 am < MO 0000 oco w w m a a 23x O1--1 In W c4 V. O O m K O Q 555 C LL Z '; `,21- 2 2 a a a a w + (fl N W N o N o 0 O0 0 W G W W K 2 2 a d F5)- > 2 C7 m N J J O O O O t0 CO Z o o 2 O 2 J O O O 2 J 0 0 O O 0 P ' o 0 M 2 N o 0 i6-. 02..c7+ 0 T. >0 Q O N > 7 ¢ O r n O O 0 W ¢ . 0. 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N # •,- ' N N N y P') N1 l+) Z O C c E d a a U m m a m 2 R a m a 0) CI § Og O' d U � c v OJ N U Z F# a # N M E '0 IO co E n co O) J LL Z J iE Y ` o. o 0L •,- N In F• _ y ro 1-2 co N N F N ¢ f- 3 N C 0 0 E O O FW- Q - _ O O J a a 2 • • TD 0 U (0 1L1 0 O M • o c0_ 0 0 0 0 0 0 0 0 0 0 a 0 0 0 0 co o 0 0 0 0 ,_ o v 0) y O O O N N N C C C Can cs_ msD a3 D al ail) i- -2 o 72 o N N T— O " rz Cl) CCI o f o coo o o coo coo o coo coo 0 O U U C y CZ C.) a) y , � Q o 0 0 0 o m 0 o cn m 73 L O _0 In �' "Cr CO M O LQU) `/ O Cl) O N 11. _4 AS G > p c > c > c > a - fC CO Cfl U CCI Co U CO CO U «S F— Z Z U U J U U J U U J ,- Y TS Y LLJ Y I-U73 Y 1-1-1 ac N = m = m U O O J ryM CD II N oN a N J o SD n. d = N _J (n tt3 C110) ... E E o 0 0 0 O O 0 0 0 U E a Q Q 0 ,0 Q o Q o Q L (I) Z 0 a. 0 � N LL N . \F W o C O O L 2 C U C 0) N -c N E O C O E .= ocu) �' O LC) N O Nu) COO O I` O .L c Cin � U) -0 1imo inommi C6, gym E c o E 5 c a) . N O 0 c ,r ♦12K +0 DI ESE as c_ U) a) > E 44— to E E 73 Q O = .WLo i O E o E O E-2 L. m L. o4-' EOc E -C Q. o w 4_ c o •— v 4-1 s- = a cQ � i i -0 15 92 Q5 E U U Q _ D c .▪1 }+ 0RS RS ' , a) a' a) m2 ▪ ._ .. O > 6CON C° U) L o O rt) (1) Z -O a) N u) L Ecl _ c y Ecao � .- u) � E- a) U N as V N • • Client: ConocoPhillips Alaska Inc. Schisbuir Wein 30-04 Basin/Field: Colville-Prudhoe Basin/ Kuparuk River Unit State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: Date Prepared: 7/17/2015 4:41 PM Report ID: RPT-38021 Fluid Name&Volume Additive Additive Description Concentration Volume J218 Breaker 0.9 Lb/1000 Gal 20.0 Lb J512 Viscosifier 10.4 Gal/1000 Gal 240.3 Gal K187 Catalyst 1 0.2 Gal/1000 Gal 5.0 Gal K230B Resin 25.8 Gal/1000 Gal 595.0 Gal 2%KCI,SANDLOCK K235B t Resin 8.7 Gal/1000 Gal 200.0 Gal V,60ppt HEC 23,054 Gal L041 Chelating Agent 3.7 Lb/1000 Gal 85.0 Lb L071 Clay Control Agent 0.4 Gal/1000 Gal 9.0 Gal M117 1 Clay Control Agent 167 Lb/1000 Gal 3,850.0 Lb S020 Propping Agent varied concentrations 40,914.0 Lb W059 Demulsifier I 2.6 Gal/1000 Gal 1 60.0 Gal The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. t Proprietary Technology CAS Number Chemical Name Mass Fraction Water(Including Mix Water Supplied by Client)* —77 % 14808-60-7 Quartz,Crystalline silica "'17 % 7447-40-7 Potassium chloride -2 % 25085-99-8 Oxirane,2,2'-[(1-methylethylidene)bis(4,1-phenyleneoxymethylene)]bis-,homopolymer —1 % 111-77-3 2-(2-methoxyethoxy)ethanol —1 % 64742-47-8 Distillates(petroleum),hydrotreated light <1 % Proprietary Polymethylene polyphenylamine alkoxy silane <1 % 9004-62-0 Hydroxyethylcellulose <1 % 8002-13-9 Rapeseed oil <1 % 8001-78-3 Castor oil,hydrogenated <1 % 67-63-0 Propan-2-ol <0.1 % 7647-14-5 Sodium chloride <0.1 % 61789-68-2 Alkyl hydroxyethyl benzyl ammonium chloride <0.1 % 1330-20-7 Xylene <0.1 % 64-02-8 Tetrasodium ethylenediaminetetraacetate <0.1 % 67-48-1 2-hydroxy-N,N,N-trimethylethanaminiumchloride <0.1 % 25338-55-0 Dimethylaminomethylphenol _ <0.1 % 65071-95-6 _ Ethoxylated tall oil <0.1 % 100-41-4 Ethylbenzene(impurity) <0.01 % 7727-54-0 Diammonium peroxidisulphate <0.01 % 108-95-2 Phenol <0.01 % 8002-26-4 Tall oil(impurity) <0.001 % Total 100°% *Mix water is supplied by the client. Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. co Schlumberaer 2015.Used by ConocoPhillias Alaska Inc.by aermission. PREP!1/1 Kuparuk Well 30-04 (PTD 188-062) Hydraulic Fracturing AOGCC Sundry Application Section 13 — Post-Fracture Wellbore Cleanup and Fluid Recovery Plan 20 AAC 25.283(a)(13) Flowback will be initiated through test equipment 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 clean enough for production.) 110 • Wallace, Chris D (DOA) From: Hazen, Mike C <Michael.C.Hazen@conocophillips.com> Sent: Thursday, September 03, 2015 7:00 AM To: Wallace, Chris D (DOA) Subject: FW: Sundry 315-520 Hydraulic Fracture Well KRU 30-04 (PTD 1880620) Attachments: ConocoPhillips Alaska - 30-04 - Prejob Disclosure Report V1.pdf; K230B MSDS.pdf; K235B MSDS.pdf; K187 MSDS.pdf Chris, Attached is the revised chemical disclosure form with the CAS numbers listed for each chemical ingredient contained in the fracturing fluid including the previously labeled proprietary component. Also attached are the MSDSs for the same and two other related materials. Please let me know if you have any questions or require any additional information. Regards, Mike Mike Hazen Wells Engineer—ConocoPhillips Alaska, Inc. Office(907)265-1032;Mobile(907)268-9279; Home(907)868-3424;700 G Street,ATO-2048,Anchorage,AK 99501 "Our work is never so urgent or important that we cannot take the time to do it safely and in an environmentally prudent manner." From: Gunther Rutzinger [mailto:grutzinger@slb.com] Sent: Tuesday, September 01, 2015 4:52 PM To: Hazen, Mike C Subject: [EXTERNAL]RE: Sundry 315-520 Hydraulic Fracture Well KRU 30-04 (PTD 1880620) Mike, The attached report should resolve these issues. Regards, Gunther From: Hazen, Mike C [mailto:Michael.C.Hazen@conocophillips.com] Sent: 25 August 2015 11:29 To: Gunther Rutzinger Subject: FW: Sundry 315-520 Hydraulic Fracture Well KRU 30-04 (PTD 1880620) Gunther, Can you please help me out here? I submitted the attached chemical disclosure (pp 27), however the AOGCC requires additional information. Mike Hazen Wells Engineer—ConocoPhillips Alaska, Inc. Office(907)265-1032; Mobile(907)268-9279;Home(907)868-3424;700 G Street,ATO-2048,Anchorage,AK 99501 1 111 • "Our work is never so urgent or important that we cannot take the time to do it safely and in an environmentally prudent manner." From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Tuesday, August 25, 2015 11:07 AM To: Hazen, Mike C Subject: [EXTERNAL]Sundry 315-520 Hydraulic Fracture Well KRU 30-04 (PTD 1880620) Mike, We are progressing the Hydraulic Fracturing Sundry Application. Please provide the 20 AAC 25.283 (a)(12)(c) chemical disclosure with the CAS numbers for each chemical ingredient contained in the fracturing fluid? For confidential "trade secret" chemicals please refer to 20 AAC 25.283(k) or contact me for the submission process. We need the CAS number for the claimed proprietary ingredient "polymethylene polyphenylamine alkoxy silane". Looks like it may be related to the additive K235B which is marked as"proprietary technology". We are also requesting that the non-confidential MSDS be provided to us for the confidential claimed proprietary chemicals. If additional details are required, please contact me and we can work through the process. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907) 793-1250(phone) (907) 276-7542(fax) chris.wallace@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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 2 io • Client: ConocoPhillips Alaska Inc. Schlumberger Well: 30-04 Basin/Field: Colville-Prudhoe Basin/ Kuparuk River Unit State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: Date Prepared: 9/1/2015 4:33 PM Report ID: RPT-39021 Fluid Name&Volume Additive Additive Description Concentration Volume J218 Breaker 0.9 Lb/1000 Gal 20.0 Lb J512 Viscosifier 10.4 Gal/1000 Gal 240.3 Gal K187 _ Catalyst 0.2 Gal/1000 Gal 5.0 Gal K230B Resin 25.8 Gal/1000 Gal 595.0 Gal 2%KCI,SANDLOCK K235B t Resin 8.7 Gal/1000 Gal 200.0 Gal 23,054 Gal V,6oppt HEC L041 Chelating Agent 3.7 Lb/1000 Gal 85.0 Lb L071 Clay Control Agent 0.4 Gal/1000 Gal ', 9.0 Gal M117 Clay Control Agent 167 Lb/1000 Gal 3,850.0 Lb 5020 Propping Agent varied concentrations 40,914.0 Lb W059 Demulsifier 2.6 Gal/1000 Gal 60.0 Gal The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. T Proprietary Technology CAS Number Chemical Name Mass Fraction - Water(Including Mix Water Supplied by Client)* _77 % 14808-60-7 Quartz,Crystalline silica `17 % 7447-40-7 Potassium chloride -2 % 25085-99-8 Oxirane,2,2'-[(1-methylethylidene)bis(4,1-phenyleneoxymethylene)]bis-,homopolymer -1 111-77-3 2-(2-methoxyethoxy)ethanol -1 % 64742-47-8 Distillates(petroleum),hydrotreated light <1 % 9004-62-0 Hydroxyethylcellulose <1 % 8001-78-3 Castor oil,hydrogenated <1 % 8002-13-9 Rapeseed oil <1 % 101-77-9 Benzenamine,4,4'-methylenebis- <1 % 25214-70-4 Polymethylene polyphenylamine <1 % _ 2530-83-8 Glycidoxypropyltrimethoxysilane <0.1 % 67-63-0 Propan-2-ol <0.1 % 7647-14-5 Sodium chloride <0.1 % 61789-68-2 Alkyl hydroxyethyl benzyl ammonium chloride <0.1 % 1330-20-7 _ Xylene <0.1 % 64-02-8 Tetrasodium ethylenediaminetetraacetate <0.1 % 67-48-1 2-hydroxy-N,N,N-trimethylethanaminium chloride <0.1 % 25338-55-0 DImethylaminomethylphenol <0.1 % 65071-95-6 Ethoxylated tall oil _ <0.1 % 100-41-4 Ethylbenzene(impurity) <0.01 % 7727-54-0 Diammonium peroxidisulphate <0.01 % 108-95-2 Phenol _ <0.01 % 8002-26-4 Tall oil(impurity) _ <0.001 % 62-53-3 Aniline <0.0001 % Total 1GG% a Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. 0 Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. Page:1/1 • • Schlumberger MATERIAL SAFETY DATA SHEET (USA) (Complies with USA OSHA 29 CFR 1910.1200 and ANSI Z 400.1) Version: 1 Revision date:27 September 2006 1. IDENTIFICATION OF THE SUBSTANCE/PREPARATION AND THE COMPANY/UNDERTAKING Product code: K187 Product name: Catalyst K187 Company identification: Schlumberger Technology Corporation 110 Schlumberger Drive Sugar Land, Texas 77478, USA Telephone: 1-281-285-7873 Emergency telephone number: USA: 1-281-595-3518 2. HAZARDS IDENTIFICATION EMERGENCY OVERVIEW WARNING Main physical hazards: Corrosive to metals. Main health hazards: Harmful if absorbed through the skin. Harmful if swallowed. Causes burns to mouth, throat and stomach. Causes severe eye burns. Causes burns to respiratory tract. Causes severe skin burns. Main environmental hazards: Harmful to aquatic organisms. Precautions: Avoid contact with eyes. Do not get on skin or clothing. Wash thoroughly after handling. Do not breathe vapors or spray mist. HMIS classification: Health:3 Flammability: 1 Physical hazard: 0 Form: Liquid Color: Red - Dark brown Odor: Phenolic Principle routes of exposure: Eye contact. Skin contact. Respiratory system. 3. COMPOSITION/INFORMATION ON INGREDIENTS Components classified as hazardous: Component CAS-No Weight%-Range Amine phenol derivative Proprietary 60- 100 • Phenol 108-95-2 10-30 4. FIRST AID MEASURES Eye contact: Immediately flush eyes with water for 30 minutes while holding eyelids open. Seek medical attention at once. Skin contact: Take off contaminated clothing and shoes immediately. After contact with skin, wash immediately with plenty of soap and water for at least 30 minutes. Seek medical attention at once. 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 1 of 9 • • SchlumbergerProduct code: K1 87 Revision date:27 September 2006 Ingestion: Rinse mouth. DO NOT induce vomiting. Seek medical attention. If delayed, consider giving activated charcoal in water, or 2 glasses of milk or water. Never give anything by mouth to an unconscious person. Inhalation: Move to fresh air. Seek medical attention at once. If breathing has stopped, begin artificial respiration. 5. FIRE-FIGHTING MEASURES Flash point: > 100 °C/212 °F Method: Tag closed cup Autoignition temperature: No data available. Flammability limits in air: Lower: 1.5 Upper: 8.6% Oxidizing properties: None. Suitable extinguishing media: Water Fog, Alcohol Foam, CO2, Dry Chemical. Extinguishing media which must not be used for safety reasons: None known. Special exposure hazards arising from the substance or preparation itself, its combustion products, or released gases: Thermal decomposition can lead to release of irritating gases and vapors. Special protective equipment for firefighters: Wear protective fire fighting clothing and avoid breathing vapors. Use self-contained breathing apparatus in closed areas. NFPA rating: Health: 3 Flammability: 1 Instability: 0 Special: None 6.ACCIDENTAL RELEASE MEASURES Main physical hazards: Corrosive to metals. Personal precautions: Avoid contact with eyes. Do not get on skin or clothing. Wash thoroughly after handling. Do not breathe vapors or spray mist. Methods for cleaning up: Dam up. Absorb spill with inert material (e.g. dry sand or earth), then place in a chemical waste container. Environmental precautions: Prevent further leakage or spillage. 7. HANDLING AND STORAGE Handling: Precautions: Avoid contact with eyes. Do not get on skin or clothing. Wash thoroughly after handling. Do not breathe vapors or spray mist. Safe handling advice: Keep airborne concentrations below exposure limits. Avoid contact with skin and eyes. Do not breathe vapors or spray mist. Wear suitable protective equipment. Technical measures/ Keep containers tightly closed in a dry, cool and well-ventilated place. storage conditions: Store in well ventilated area out of direct sunlight. 110 Schlumberger Drive,Sugar Land,Texas 77478, USA.Phone(281)285-7873 Page 2 of 9 • • SchlumbergerProduct code: K187 Revision date:27 September 2006 Packaging requirements: High density polyethylene (HDPE)drum or can. Incompatible products: Oxidizing agents. 8. EXPOSURE CONTROLS/PERSONAL PROTECTION Engineering measures Ensure adequate ventilation to reduce exposure: Hygiene measures: Keep airborne concentrations below exposure limits. Avoid contact with skin, eyes and clothing. Do not breathe vapors or spray mist. Respiratory protection: In case of insufficient ventilation, wear suitable respiratory equipment. Use NIOSH approved respirator with organic vapor/acid gas protection (color coded yellow). Use SCBA(self contained breathing apparatus) in confined areas and for emergencies. Eye protection: Tightly fitting safety goggles. Hand protection: Impervious gloves. Butyl. Skin and body protection: Chemical resistant suit. Chemical resistant boots. Occupational Exposure Limits ACGIH-TLVs OSHA-PELs Component TWA/Ceiling STEL Skin TWA/C STEL Final PELs -Skin Phenol 5 ppm TWA Skin Notation 19 mg/m3 TWA Listed 5 ppm TWA Nuisance dust: ACGIH: inhalable particulate TLV-TWA=10 mg/m3; respirable particulate TLV-TWA=3 mg/m3 110 Schlumberger Drive,Sugar Land,Texas 77478, USA.Phone(281)285-7873 Page 3 of 9 • • SchlumbergerProduct code: K187 Revision date:27 September 2006 9. PHYSICAL AND CHEMICAL PROPERTIES Chemical characterization: Amine. Form: Liquid Color: Red - Dark brown Odor: Phenolic Odor threshold: No information available. pH: 9.5- 11 Boiling point/range: 260 °C/500 °F Flash point: > 100 °C/212 °F Method: Tag closed cup. Flammability limits in air: Lower: 1.5 Upper: 8.6% Bulk density: Not applicable. Melting point/range: No data available. Decomposition temperature: No data available. Solubility: Water solubility: No information available. Fat solubility: No information available. Partition coefficient No information available. (n-octanol/water): Relative density: 1.02 (@ 20°C) Vapor pressure: 0.3 kPa(@ 38°C) Vapor density: > 1 (air= 1) Viscosity: No data available. Evaporation rate: No data available. Volatile: No data available. 10. STABILITY AND REACTIVITY Stability: Stable under recommended storage conditions. Conditions to avoid: None known. Incompatibility with other substances: Oxidizers. Hazardous decomposition products: When heated strongly or burned, oxides of carbon, nitrogen oxides, ammonia and harmful organic chemical fumes are released. Hazardous polymerization: Hazardous polymerization does not occur. 11.TOXICOLOGICAL INFORMATION PRODUCT TOXICOLOGICAL INFORMATION Acute Health Hazard 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 4 of 9 • • SchlumbergerProduct code: K1 87 Revision date:27 September 2006 Eye contact: Corrosive. Rapidly causes pain, burns, corneal injury. May cause permanent damage and blindness. Skin contact: Toxic; may cause illness or death. Corrosive. Rapidly causes pain, burns, redness, swelling and damage to tissue. Ingestion: Toxic; can cause illness or death. Corrosive. Causes pain and severe burns to mouth, throat and stomach. Inhalation: Corrosive. Short exposure can injure lungs, throat, and mucous membranes. Causes pain, burns, choking, and coughing. Sensitization-lung: Not known to cause allergic reaction. Sensitization-skin: Not known to cause allergic reaction. Toxicologically synergistic None known. products: Chronic Health Hazard Carcinogenic effects: None known. Mutagenic effects: Not known to cause heritable genetic damage. Teratogenic effects: Not known to cause birth defects or have a deleterious effect on a developing fetus. Reproductive toxicity: Not known to adversely affect reproductive functions and organs. Target organ effects: See COMPONENT TOXICOLOGICAL INFORMATION below. COMPONENT TOXICOLOGICAL INFORMATION Component Target Organ Effects LD50/LC50 Phenol liver,kidneys,skin,eyes,respiratory system =317 mg/kg(Oral LD50;Rat) =525 mg/kg(Dermal LD50;Rat) =630 mg/kg(Dermal LD50;Rabbit) Component IARC: ACGIH- OSHA Regulated NTP: Carcinogens: Carcinogens Phenol A4-Not Classifiable as a Human Carcinogen 12. ECOLOGICAL INFORMATION PRODUCT INFORMATION Main environmental hazards: Harmful to aquatic organisms. Aquatic toxicity: See component information below COMPONENT INFORMATION Phenol Freshwater Algae Data =150 mg/L(EC50;Selenastrum capricornutum) Freshwater Fish Species Data 5-12 mg/L(LC50;Oncorhynchus mykiss) =23.88 mg/L(LC50;Lepomis macrochirus) =24 mg/L(LC50;Pimephales promelas) =27.8 mg/L(LC50;Brachydanio rerio) =40 mg/L(LC50;Poecilia reticulata) =8.9 mg/L(LC50;Oncorhynchus mykiss) 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 5 of 9 • S SchlumbergerProduct code: K1 87 Revision date:27 September 2006 Water Flea Data =13 mg/L(LC50;Daphnia magna) =23.0 mg/L(EC50;water flea) 13. DISPOSAL CONSIDERATIONS Waste from residues/ unused products: Dispose of by injection or other acceptable method in accordance with local regulations. Contaminated packaging: Dispose of in accordance with local regulations. If reusable containers are used, send them back to the product supplier, after the required rinsing. EPA RCRA Hazardous Waste Code: None 14.TRANSPORT INFORMATION DOT: UN/NA Number: UN 2922 CERCLA RQ: 580 gallons(phenol). Packing size: <580 gals Hazard class: 8 Subsidiary hazard(s): 6.1 Proper shipping name: Corrosive liquid,toxic, n.o.s.(contains phenol), 8,(6.1), UN 2922, PG III Label(s): Corrosive 8,Toxic 6.1 Packing size: >580 gals Hazard class: 8 Subsidiary hazard(s): 6.1 Proper shipping name: Corrosive liquid,toxic, n.o.s.(contains phenol), 8, (6.1), UN 2922, PG III, RQ Label(s): Corrosive 8,Toxic 6.1 IMDG/IMO Shipping name: CORROSIVE LIQUID,TOXIC, N.O.S.(contains phenol) Label(s): Corrosive 8,Toxic 6.1 Class or Div.: 8 Subsidiary risk(s): 6.1 UN number: UN 2922 Packing group: III EMS: F-A, S-B ICAO/IATA Shipping name: Corrosive liquid,toxic, n.o.s.(contains phenol) Label(s): Corrosive 8,Toxic 6.1 Class or Div.: 8 Subsidiary risk(s): 6.1 UN number: UN 2922 Packing group: III Packing instruction 818 Max Net Qty/Pkg: 5 L (passenger aircraft): Packing instruction 820 Max Net Qty/Pkg: 60 L (cargo aircraft): TDG(Canada): Shipping name: CORROSIVE LIQUID,TOXIC, N.O.S.(contains phenol), 8, (6.1), UN 2922, PG III Label(s): Corrosive 8,Toxic 6.1 PIN: UN 2922 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 6 of 9 • • SchlumbergerProduct code: K1 87 Revision date:27 September 2006 Class: 8 Subsidiary hazard(s): 6.1 Packing group: III Note 1: For the applicable placard selection refer to the appropriate transport regulations;the selection may vary depending on the cargo size and categories of other hazardous materials in the cargo. 15. REGULATORY INFORMATION International Chemical Inventories Inventory-United States TSCA-This product complies with TSCA requirements. Canada DSL Inventory List- This product complies with DSL requirements. EC-No This product complies with EINECS/ELINCS requirements. China inventory of existing This product complies with China inventory requirements. chemical substances list- Inventory-Japan-Existing This product does not comply with JPENCS and New Chemicals list- Australia(AICS): All the constituents of this material are listed on the Australian Inventory of Chemical Substances(AICS). U.S.A. Regulations OSHA Hazard Communication Standard: (Complies with USA OSHA 29 CFR 1910.1200 and ANSI Z 400.1) EPA RCRA Hazardous Waste Code: None EPA,Sections 311 and 312-Material Safety Data Sheet Requirements(40 CFR 370): Immediate(Acute) Health Hazard: YES Delayed(Chronic)Health Hazard: None Fire Hazard: None Sudden Release or Pressure Hazard: None Reactive Hazard: None EPA,Sections 313-List of Toxic Chemicals(40 CFR 372): This product contains the following substance(s),which appear(s)on the List of Toxic Chemicals: Additional Regulatory Information Amine phenol derivative EPA, CERCLA Section 102a1103 Hazardous Substances(40 CFR 302.4): None CERCLA/SARA-Hazardous Substances and their RQs: None EPA,SARA TITLE III Section 304, Extremely Hazardous Substances(40 CFR 355.40): None California Proposition 65: None Phenol EPA,CERCLA Section 102a/103 Hazardous Substances(40 CFR 302.4): Listed CERCLA/SARA-Hazardous Substances and their RQs: 1000 lb final RQ 454 kg final RQ EPA, SARA TITLE III Section 304, Extremely Hazardous Substances(40 CFR 355.40): 10000 lb TPQ upper threshold 500 lb TPQ lower threshold California Proposition 65: None International Hazard Class 110 Schlumberger Drive,Sugar Land,Texas 77478, USA.Phone(281)285-7873 Page 7 of 9 S ! Schlumberger Product code: K187 Revision date:27 September 2006 WHMIS Hazard Class: E (CORROSIVE MATERIAL) D1 B (Immediate and Serious Toxic Effects-Toxic Material) D2B (Other Toxic Effects-Toxic Material) 16. OTHER INFORMATION Current references: 1. Threshold Limit Values for Chemical Substances and Physical Agents and Biological Exposure Indices. American Conference of Governmental Industrial Hygienists, Cincinnati OH. 2. IARC Monograms on the Evaluation of the Carcinogenic Risk of Chemicals to Man. World Health Organization, International Agency for Research on Cancer. Geneva, Switzerland. 3. Annual Report on Carcinogens. National Toxicology Program. U.S. Department of Heath and Human Services, Public Health Service. 4. NIOSH Registry of Toxic Effects of Chemical Substances(RTECS). National Institute for Occupational safety and Health. Cincinnati, OH. 5. LOLI Database. Explanation of terms: ACGIH: American Conference of Governmental Industrial Hygienist ACGIH-TL: Threshold Limit Value DSL: Domestic Substance List HMIRC: Hazardous Materials Information Review Commission IARC: International Agency for Research on Cancer NTP: National Toxicology Program NIOSH: National Institute of Occupational Safety&Health NIOSH-REL: Recommended Exposure Limit OSHA: Occupational Safety&Health Administration OSHA-PEL: Permissible Exposure Limit TSCA: Toxic Substance Control Act(Inventory) Occupational Exposure Limits indicators:TWA-Time Weighted Average;STEL-Short Term Limit; C-Ceiling Limit;units: [mg/m3] ACGIH Notations: "Skin"refers to the potential significant contribution to the overall exposure by the cutaneous route, including mucous membranes and the eyes, either by contact with vapors or by direct skin contact with the substance. "A"notation indicates carcinogenicity as follows: ACGIH classification:Al -Confirmed Human Carcinogen;A2-Suspected Human Carcinogen;A3-Confirmed Animal Carcinogen with Unknown Relevance to Humans;A4-Not Classifiable as a Human Carcinogen;A5-Not suspected as a Human Carcinogen. "SEN"refers to the potential for an agent to product sensitization as confirmed by human and animal data. Section(s)revised: MSDS fully updated in the new database. Additional advice: Consult your supplier if the material is to be used for special applications such as in the food industry or for hygiene, medical or surgical end-use. Prepared by: Well Services Safety&Environment(WSSE) Revision date: 27 September 2006 The information and recommendations contained herein are based upon tests believed to be reliable. However,Schlumberger does not guarantee their accuracy or completeness NOR SHALL ANY OF THIS INFORMATION CONSTITUTE A WARRANTY, WHETHER EXPRESSED OR IMPLIED,AS TO THE SAFETY OF THE GOODS,THE MERCHANTABILITY OF THE GOODS,OR THE FITNESS OF THE GOODS FOR A PARTICULAR PURPOSE. Adjustment to conform to actual conditions of usage may be required. Schlumberger assumes no responsibility for results obtained or for incidental or consequential damages,including lost profits arising from the use of these data. No warranty against infringement of any patent,copyright or trademark is made or implied. End of the Material Safety Data Sheet 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 8 of 9 • • SchlumbergerProduct code: K1 87 Revision date:27 September 2006 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 9 of 9 • 1111 Schlumberger MATERIAL SAFETY DATA SHEET (USA) (Complies with USA OSHA 29 CFR 1910.1200 and ANSI Z 400.1) Version: 2 Revision date:31 October 2008 1. IDENTIFICATION OF THE SUBSTANCE/PREPARATION AND THE COMPANY/UNDERTAKING Product code: K235B Product name: Curing Agent K235B Company identification: Schlumberger Technology Corporation 110 Schlumberger Drive Sugar Land,Texas 77478,USA Telephone: 1-281-285-7873 Emergency telephone number: USA: +1-281-595-3518 (24hr) 2. HAZARDS IDENTIFICATION EMERGENCY OVERVIEW CAUTION Main physical hazards: No classified physical hazards. Main health hazards: May cause birth defects based on animal data. Harmful if swallowed. May cause eye irritation. May be mildly irritating if inhaled. May cause Central Nervous System (CNS)depression. Precautions: Avoid contact with eyes. Do not get on skin or clothing. Wash thoroughly after handling. Keep away from open flames, hot surfaces and sources of ignition. HMIS classification: Health:2 Flammability: 1 Physical hazard: 0 Form: Liquid Color: Amber Odor: Ether-like Principle routes of exposure: Eye contact. Skin contact. Respiratory system. 3. COMPOSITION/INFORMATION ON INGREDIENTS Components classified as hazardous: Component CAS-No Weight%-Range Polymethylene polyphenylamine alkoxy Proprietary 30-60 silane 2-(2-methoxyethoxy)ethanol 111-77-3 30-60 4. FIRST AID MEASURES Eye contact: Immediately flush eyes with water for 15 minutes while holding eyelids open. Seek medical attention. Skin contact: Rinse with water. Seek medical attention if irritation occurs. Ingestion: DO NOT induce vomiting. Call a physician or Poison Control Center immediately. Never give anything by mouth to an unconscious person. If vomiting occurs spontaneously, minimize the risk of aspiration by properly positioning the affected person. 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 1 of 7 • Schlumbcrgcr Product code:K235B Revision date:31 October 2008 4. FIRST AID MEASURES Inhalation: Move to fresh air. Consult a physician if necessary. 5. FIRE-FIGHTING MEASURES Fire hazard: Combustible material. OSHA Flammability Class: Ill B Flash point: 99 °C/ 210 °F Method: Setaflash CC Autoignition temperature: No data available. Flammability limits in air: Lower: No information available. Upper: No information available. Oxidizing properties: None. Suitable extinguishing media: Water Fog, Alcohol Foam, CO2, Dry Chemical. Extinguishing media which must not be used for safety reasons: None known. Special exposure hazards arising from the substance or preparation itself, its combustion products, or released gases: Thermal decomposition can lead to release of irritating gases and vapors. Other information: Vapors are heavier than air and may spread along floors. Special protective equipment for firefighters: Wear protective fire fighting clothing and avoid breathing vapors. Use self-contained breathing apparatus in closed areas. NFPA rating: Health: 2 Flammability: 1 Instability: 0 Special: None 6. ACCIDENTAL RELEASE MEASURES Main physical hazards: No classified physical hazards. Personal precautions: Do not get on skin or clothing. Wash thoroughly after handling. Methods for cleaning up: Dam up. Absorb spill with inert material (e.g. dry sand or earth), then place in a chemical waste container. Environmental precautions: Prevent further leakage or spillage. 7. HANDLING AND STORAGE Handling: Precautions: Avoid contact with eyes. Do not get on skin or clothing. Wash thoroughly after handling. Keep away from open flames, hot surfaces and sources of ignition. Safe handling advice: Avoid contact with skin and eyes. Technical measures/ Store in well ventilated area out of direct sunlight. Keep away from open storage conditions: flames, hot surfaces and sources of ignition. Packaging requirements: High density polyethylene(HDPE)drum or can. 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 2 of 7 • • SchlumbcrycrProduct code:K235B Revision date:31 October 2008 7. HANDLING AND STORAGE Incompatible products: Oxidizing agents. 8. EXPOSURE CONTROLS / PERSONAL PROTECTION Engineering measures Ensure adequate ventilation to reduce exposure: Hygiene measures: Avoid contact with the skin and the eyes. Respiratory protection: In case of insufficient ventilation, wear suitable respiratory equipment. None normally needed. Use NIOSH approved respirator with organic vapor protection (color coded black or yellow)if vapors are generated and for emergencies. Eye protection: Tightly fitting safety goggles. Hand protection: Impervious gloves. PVC. Skin and body protection: Clean, body-covering clothing. Occupational Exposure Limits ACGIH-TLVs OSHA-PELs Particles Not Otherwise Regulated/Specified[PNORor PNOS](insoluble or poorly soluble): OSHA PEL's for Inert or Nuisance Dust are covered by PNOR limits:respirable fraction:5 mg/m3;total dust 15 mg/m3. ACGIH PNOS Recommendations:airborne concentrations should be kept below 3 mg/m3,respirable particulate,and 10 mg/m3, inhalable particles. 9. PHYSICAL AND CHEMICAL PROPERTIES Chemical characterization: Aqueous solution of synthetic polymer. Fire hazard: Combustible material. Form: Liquid Color: Amber Odor: Ether-like Odor threshold: No information available. pH: 9 Boiling point/range: 184°C/363 °F Flash point: 99 °C/210 °F Method: Setaflash CC. Flammability limits in air: Lower: No information available. Upper: No information available. Bulk density: Not applicable. Melting point/range: No data available. Decomposition temperature: No data available. Solubility: Water solubility: Insoluble Fat solubility: No information available. Partition coefficient No information available. (n-octa nol/water): Relative density: 1.1 (@ 20°C) Vapor pressure: 0.7 kPa(@ 38°C) Vapor density: > 1 (air= 1) Viscosity: No data available. Evaporation rate: No data available. %Volatile (VOC): 40 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 3 of 7 • • Schlumbcrg6r Product code:K235B Revision date:31 October 2008 10. STABILITY AND REACTIVITY Stability: Stable under recommended storage conditions Conditions to avoid: Keep away from heat and sources of ignition. Incompatibility with other substances: Oxidizers. Hazardous decomposition products: When heated strongly or burned, oxides of carbon and harmful organic chemical fumes are released. Hazardous polymerization: Hazardous polymerization does not occur. 11. TOXICOLOGICAL INFORMATION PRODUCT TOXICOLOGICAL INFORMATION Acute Health Hazard Eye contact: Irritant. May cause pain, redness, discomfort. Skin contact: No effect expected. Prolonged or repeated contact may cause mild irritation. Ingestion: Harmful if swallowed; large amounts may cause illness. Inhalation: No effect expected. Prolonged or repeated exposure may cause mild irritation. Sensitization - lung: Not known to cause allergic reaction. Sensitization -skin: Not known to cause allergic reaction. Toxicologically synergistic None known. products: Chronic Health Hazard Carcinogenic effects: None known. Mutagenic effects: Not known to cause heritable genetic damage. Teratogenic effects: Possible birth defect hazard based on animal data. Reproductive toxicity: Not known to adversely affect reproductive functions and organs. Target organ effects: Liver. Renal toxicity. CNS. COMPONENT TOXICOLOGICAL INFORMATION Component Target Organ Effects LD50/LC50 2-(2-methoxyethoxy)ethanol =4 mL/kg(Oral LD50;Rat) =2500 uL/kq(Dermal LD50;Rabbit) 12. ECOLOGICAL INFORMATION PRODUCT INFORMATION Aquatic toxicity: See component information below 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Rhone(281)285-7873 Page 4 of 7 410 • Schlumbcrycr Product code:K235B Revision date:31 October 2008 COMPONENT INFORMATION 2-(2-methoxyethoxy)ethanol Freshwater Algae Data >500 mg/L(EC50;Scenedesmus subspicatus) Freshwater Fish Species =1000 mg/L(LC50;Oncorhynchus mykiss) Data =5741 mg/L(LC50;Rmephales promelas) =7500 mg/L(LC50;Leporris macrochirus) Water Flea Data =1192 mg/L(EC50;Daphnia magna) >500 mg/L(EC50;water flea) 13. DISPOSAL CONSIDERATIONS Waste from residues/ unused products: Dispose of by injection or other acceptable method in accordance with local regulations. Contaminated packaging: Dispose of in accordance with local regulations. If reusable containers are used, send them back to the product supplier, after the required rinsing. EPA RCRA Hazardous Waste Code: None 14.TRANSPORT INFORMATION DOT: CERCLA RQ: None Hazard class: Not regulated. Proper shipping name: Not regulated Label(s): None required. IMDG/IMO Shipping name: Not regulated. UN number: None ICAO/IATA Shipping name: Not regulated. UN number: None TDG(Canada): Shipping name: Not regulated. PIN: None 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 5 of 7 I • Schlumbcrgcr Product code:K235B Revision date:31 October 2008 14.TRANSPORT INFORMATION Note 1: For the applicable placard selection refer to the appropriate transport regulations;the selection may vary depending on the cargo size and categories of other hazardous materials in the cargo. 15. REGULATORY INFORMATION International Chemical Inventories Inventory-United States TSCA- This product complies with TSCA requirements. Canada DSL Inventory List- Some components of this material are not on the Canada DSL or exempt.Any import of the product to Canada is restricted or requires an appropriate notification. EC-No Some components of this material are not on the EINECS inventory,and notification has not been made for ELINCS.This material can not be used commercially in the European Community. China inventory of existing This product does not comply with China inventory requirements. chemical substances list- Inventory-Japan-Existing This product does not com ply with JPENCS and New Chemicals list- Australia(AICS): This product does not complywith AICS U.S.A.Regulations OSHA Hazard Communication Standard: (Complies with USA OSHA 29 CFR 1910.1200 and ANSI Z400.1) EPA RCRA Hazardous Waste Code: None EPA,Sections 311 and 312-Material Safety Data Sheet Requirements(40 CFR 370): Immediate(Acute)Health Hazard: YES Delayed(Chronic)Health Hazard: YES Fire Hazard: None Sudden Release or Pressure Hazard: None Reactive Hazard: None EPA,Sections 313-List of Toxic Chemicals(40 CFR 372): This product contains the following substance(s),which appear(s)on the List of Toxic Chemicals: Additional Regulatory Information Polymethylene polyphenylamine alkoxysilane EPA,CERCLA Section 102a/103 Hazardous Substances(40 CFR 302.4): None CERCLA/SARA-Hazardous Substances and their RQs:None EPA,SARA TITLE III Section 304,Extremely Hazardous Substances(40 CFR 355.40): None California Proposition 65: None 2-(2-m ethoxyethoxy)ethanol EPA,CERCLA Section 102a/103 Hazardous Substances(40 CFR 302.4): None CERCLA/SARA-Hazardous Substances and their RQs:None EPA,SARA TITLE III Section 304,Extremely Hazardous Substances(40 CFR 355.40): None California Proposition 65: None International Hazard Class 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 6 of 7 SCh IumbcrOCP Product code:K235B Revision date:31 October 2008 WHMIS Hazard Class: D2A (Other Toxic Effects -Very Toxic Material) D2B (Other Toxic Effects -Toxic Material) 16. OTHER INFORMATION Current references: 1. Threshold Limit Values for Chemical Substances and Physical Agents and Biological Exposure Indices. American Conference of Governmental Industrial Hygienists, Cincinnati OH. 2. ARC Monograms on the Evaluation of the Carcinogenic Risk of Chemicals to Man. World Health Organization,International Agency for Research on Cancer. Geneva,Switzerland. 3. Annual Report on Carcinogens.National Toxicology Program.U.S.Department of Heath and Human Services,Public Health Service. 4. NIOSH Registry of Toxic Effects of Chemical Substances(RTECS).National Institute for Occupational safety and Health. Cincinnati, OH. 5. LOLI Database. Explanation of terms: ACGIH: American Conference of Governmental Industrial Hygienist ACGIH-TL: Threshold Limit Value DSL: Domestic Substance List HMIRC: Hazardous Materials Information Review Commission IARC: International Agency for Research on Cancer NTP: National Toxicology Program NIOSH: National Institute of Occupational Safety&Health NIOSH-REL: Recommended Exposure Limit OSHA: Occupational Safety&Health Administration OSHA-PEL: Permissible Exposure Limit TSCA Toxic Substance Control Act(Inventory) Occupational Exposure Limits indicators:TWA-Time Weighted Average;STEL-Short Term Limit;C-Ceiling Lim Units:[mg/m3] ACGIH Notations: "Skin"refers to the potential significant contribution to the overall exposure by the cutaneous route,including mucous membranes and the eyes,either by contact with vapors or by direct skin contact with the substance. "A"notation indicates carcinogenicity as follows: ACGIH classification:Al -Confirmed Human Carcinogen;A2-Suspected Human Carcinogen;A3-Confirmed Animal Carcinogen with Unknown Relevance to Humans;A4-Not Classifiable as a Human Carcinogen;A5-Not suspected as a Human Carcinogen. "SEN"refers to the potential for an agent to product sensitization as confirmed by human and animal data. Section(s)revised: 4,8 Additional advice: Consult your supplier if the material is to be used for special applications such as in the food industry or for hygiene,medical or surgical end-use. Prepared by: Well Services Safety&Environment(WSSE). Revision date: 31 October 2008 The information and recommendations contained herein are based upon tests believed to be reliable. How ever,Schlumberger does not guarantee their accuracy or completeness NOR SHALL ANY OF THIS INFORMATION CONSTITUTE A WARRANTY, WHETHER EXPRESSED OR IMPLIED,AS TO THE SAFETY OF THE GOODS,THE MERCHANTABILITY OF THE GOODS,OR THE FITNESS OF THE GOODS FOR A PARTICULAR PURPOSE Adjustment to conform to actual conditions of usage may be required. Schlumberger assumes no responsibility for results obtained or for incidental or consequential damages,including lost profits arising from the use of these data. No warranty against infringement of any patent,copyright or trademark is made or implied. End of the Material Safety Data Sheet 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 7 of 7 S Schlumberger MATERIAL SAFETY DATA SHEET (USA) (Complies with USA OSHA 29 CFR 1910.1200 and ANSI Z 400.1) Version: 2 Revision date:31 October 2008 1. IDENTIFICATION OF THE SUBSTANCE/PREPARATION AND THE COMPANY/UNDERTAKING Product code: K230B Product name: Resin Solution K230B Company identification: Schlumberger Technology Corporation 110 Schlumberger Drive Sugar Land,Texas 77478, USA Telephone: 1-281-285-7873 Emergency telephone number: USA: +1-281-595-3518 (24hr) 2. HAZARDS IDENTIFICATION EMERGENCY OVERVIEW WARNING Main physical hazards: Combustible liquid. Main health hazards: May cause birth defects based on animal data. May cause allergic reaction upon repeated skin exposure. May cause eye irritation. May cause skin irritation. May be mildly irritating if inhaled. May cause Central Nervous System (CNS)depression. Main environmental hazards:Toxic to aquatic organisms. May cause long-term adverse effects in the aquatic environment. Precautions: Avoid contact with eyes. Do not get on skin or clothing. Wash thoroughly after handling. Keep away from open flames, hot surfaces and sources of ignition. HMIS classification: Health:2 Flammability: 2 Physical hazard: 0 Form: Liquid Color: Colorless Odor:Aromatic Principle routes of exposure: Eye contact. Skin contact. Respiratory system. 3. COMPOSITION/INFORMATION ON INGREDIENTS Components classified as hazardous: Component CAS-No Weight%-Range Bisphenol a-epichlorohydrin polymer 25068-38-6 60-100 2-(2-methoxyethoxy)ethanol 111-77-3 30-60 Xylene 1330-20-7 1 -5 4. FIRST AID MEASURES Eye contact: Immediately flush eyes with water for 15 minutes while holding eyelids open. Seek medical attention. 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 1 of 9 I 1110 Schlumbcrycr Product code:K230B Revision date:31 October 2008 4. FIRST AID MEASURES Skin contact: Take off contaminated clothing and shoes immediately. After contact with skin, wash immediately with plenty of soap and water for at least 15 minutes. Seek medical attention. Ingestion: DO NOT induce vomiting. Call a physician or Poison Control Center immediately. Never give anything by mouth to an unconscious person. If vomiting occurs spontaneously, minimize the risk of aspiration by properly positioning the affected person. Inhalation: Move to fresh air. Consult a physician if necessary. 5. FIRE-FIGHTING MEASURES Fire hazard: Combustible material. OSHA Flammability Class: III A Flash point: 71 °C/ 160 °F Method: Setaflash CC Autoignition temperature: No data available. Flammability limits in air: Lower: No information available. Upper: No information available. Oxidizing properties: None. Suitable extinguishing media: Water Fog, Alcohol Foam, CO2, Dry Chemical. Extinguishing media which must not be used for safety reasons: None known. Special exposure hazards arising from the substance or preparation itself, its combustion products, or released gases: Thermal decomposition can lead to release of irritating gases and vapors. Special protective equipment for firefighters: Wear protective fire fighting clothing and avoid breathing vapors. Use self-contained breathing apparatus in closed areas. NFPA rating: Health: 2 Flammability: 2 Instability: 0 Special: None 6. ACCIDENTAL RELEASE MEASURES Main physical hazards: Combustible liquid. Personal precautions: Do not get on skin or clothing. Wash thoroughly after handling. Methods for cleaning up: Dam up. Absorb spill with inert material (e.g. dry sand or earth), then place in a chemical waste container. Environmental precautions: Prevent further leakage or spillage. Keep out of waterways. 7. HANDLING AND STORAGE Handling: Precautions: Avoid contact with eyes. Do not get on skin or clothing. Wash thoroughly after handling. Keep away from open flames, hot surfaces and sources of ignition. 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 2 of 9 • • Schlumbcrycr Product code:K230B Revision date:31 October 2008 7. HANDLING AND STORAGE Safe handling advice: Keep airborne concentrations below exposure limits. Avoid contact with skin and eyes. Technical measures/ Store in well ventilated area out of direct sunlight. Keep containers tightly storage conditions: closed in a dry, cool and well-ventilated place. Keep away from open flames, hot surfaces and sources of ignition. Packaging requirements: High density polyethylene(HDPE)drum or can. Incompatible products: Strong acids. Strong bases. Oxidizing agents. 8. EXPOSURE CONTROLS/ PERSONAL PROTECTION Engineering measures Ensure adequate ventilation to reduce exposure: Hygiene measures: Keep airborne concentrations below exposure limits. Avoid contact with the skin and the eyes. Respiratory protection: In case of insufficient ventilation, wear suitable respiratory equipment. None normally needed. Use NIOSH approved respirator with organic vapor protection (color coded black or yellow)if vapors are generated and for emergencies. Eye protection: Tightly fitting safety goggles. Hand protection: Impervious gloves. PVC. Skin and body protection: Chemical resistant apron. Occupational Exposure Limits ACGIH-TLVs OSHA-PELs Component TWA/Ceiling STEL Skin TWA/C STEL Final PELs -Skin Xylene 100 ppm 150 ppm 100 ppm TWA 435 rng/m3 TWA Particles Not Otherwise Regulated/Specified[PNORor PNOS](insoluble or poorly soluble): OSHA PEL's for Inert or Nuisance Dust are covered by PNOR limits:respirable fraction:5 mg/m3;total dust 15 mg/m3. ACGIH PNOS Recommendations:airborne concentrations should be kept below 3 mg/m3,respirable particulate,and 10 mg/m3, inhalable particles. 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 3 of 9 S Schlumbcrycr Product code:K230B Revision date:31 October 2008 9. PHYSICAL AND CHEMICAL PROPERTIES Chemical characterization: Aqueous solution of synthetic polymer. Fire hazard: Combustible material. Form: Liquid Color: Colorless Odor: Aromatic Odor threshold: No information available. pH: 9 Boiling point/range: 190 °C/ 374 °F Flash point: 71 °C/ 160 °F Method: Setaflash CC. Flammability limits in air: Lower: No information available. Upper: No information available. Bulk density: Not applicable. Melting point/range: Decomposition temperature: No data available. Solubility: Water solubility: Completely miscible with water. Fat solubility: No information available. Partition coefficient No information available. (n-octanol/water): Relative density: 1.1 (@ 20°C) Vapor pressure: 6.9 kPa(@ 100°C) Vapor density: > 1 (air= 1) Viscosity: No data available. Evaporation rate: No data available. %Volatile (VOC): - 38 10. STABILITY AND REACTIVITY Stability: Stable under recommended storage conditions Conditions to avoid: Keep away from heat and sources of ignition. Incompatibility with other substances: Strong acids and strong bases. Oxidizers. Hazardous decomposition products: When heated strongly or burned, oxides of carbon, oxides of chlorine, hydrogen chloride and harmful organic chemical fumes are released. Hazardous polymerization: May occur with acid, base, or excess hardener. 11. TOXICOLOGICAL INFORMATION PRODUCT TOXICOLOGICAL INFORMATION Information given is based on data on the components and the toxicology of similar products. Acute Health Hazard 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 4 of 9 11110 • SchlumbcrgcrProduct code:K230B Revision date:31 October 2008 Eye contact: Irritant. May cause pain, redness, discomfort. Skin contact: Irritant; may cause pain, redness, dermatitis. Ingestion: Accidental ingestion of small amounts is not expected to cause adverse effects. Swallowing large amounts may be harmful. Inhalation: May be mildly irritating if inhaled. Sensitization - lung: Not known to cause allergic reaction. Sensitization -skin: May cause sensitization by skin contact. Toxicologically synergistic None known. products: Chronic Health Hazard Carcinogenic effects: None known. Mutagenic effects: Not known to cause heritable genetic damage. Teratogenic effects: See COMPONENT TOXICOLOGICAL INFORMATION below. Reproductive toxicity: Not known to adversely affect reproductive functions and organs. Target organ effects: Renal toxicity. Liver. See COMPONENT TOXICOLOGICAL INFORMATION below. COMPONENT TOXICOLOGCAL INFORMATION Component Target Organ Effects LD50/LC50 Bisphenol a-epichlorohydrin =11400 mg/kg(Oral LD50;Rat) polymer 2-(2-methoxyethoxy)ethanol =4 mL/kg(Oral LD50;Rat) =2500 uL/kg(Dermal LD50:Rabbit) Xylene =4300 mg/kg(Oral LD50;Rat) =47635 mg/L(Inhalation LC50;Rat)4 h =5000 ppm(Inhalation LC50;Rat)4 h >1700 mg/kg(Dermal LD50;Rabbit) 100 ppm Component IARC: ACGIH- OSHA Regulated NTP: Carcinogens: Carcinogens Xylene A4-Not Classifiable as a Human Carcinogen Component OTHER TOXICOLOGICAL INFORMATION Xylene Moderate skin irritation.Fetotoxic and teratogenic effects observed in controlled animal studies. Central nervous system(CNS)depressant by repeated inhalation or ingestion of large amounts. 12. ECOLOGICAL INFORMATION PRODUCT INFORMATION Main environmental hazards: Toxic to aquatic organisms May cause long-term adverse effects in the aquatic environment COMPONENT INFORMATION 2-(2-methoxy ethoxy)ethanol Freshwater Algae Data >500 rng/L(EC50;Scenedesmus subspicatus) Freshwater Fish Species =1000 mg/L(LC50;Oncorhynchus mykiss) Data =5741 mg/L(LC50;Rmephales promelas) =7500 mg/L(LC50;Lepomis macrochirus) 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 5 of 9 • S Schlumbcrycr Product code:K230B Revision date:31 October 2008 Water Flea Data =1192 mg/L(EC50;Daphnia magna) >500 mg/L(EC50;water flea) Xylene Bioaccumulation: log Pow =3.1 Persistence/degradability: Biodegradable. Freshwater Fish Species =13.4 mg/L(LC50;Fimephales promelas) Data =16.1 rng/L(LC50;Lepomis macrochirus) =26.7 mg/L(LC50;Pimephales promelas) =8.05 mg/L(LC50;Oncorhynchus mykiss) Water Flea Data =0.6 mg/L(LC50;Ganmarus lacustris) =3.82 rng/L(EC50;water flea) 13. DISPOSAL CONSIDERATIONS Waste from residues/ unused products: Dispose of by injection or other acceptable method in accordance with local regulations. Contaminated packaging: Dispose of in accordance with local regulations. If reusable containers are used, send them back to the product supplier, after the required rinsing. EPA RCRA Hazardous Waste Code: None 14.TRANSPORT INFORMATION DOT: CERCLA RQ: 546 gal(Xylene). Packing size: <119 gals Hazard class: Not regulated. Proper shipping name: Not regulated Label(s): None required. Packing size: 119-546 gals UN/NA Number: NA 1993 Hazard class: Combustible liquid Proper shipping name: Combustible liquid,n.o.s. (contains xylene),NA 1993,PG III Packing size: >546 gals Hazard class: Combustible liquid Proper shipping name: Com bustible liquids,n.o.s. (contains xylene),NA 1993,PG III,RQ IMDGIMO Shipping name: Not regulated. UN number: None ICAO/IATA Shipping name: Not regulated. UN number: None TDG(Canada): Shipping name: Not regulated. 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 6 of 9 • S Schlumhcrycr Product code:K230B Revision date:31 October 2008 14.TRANSPORT INFORMATION PIN: None Note 1: For the applicable placard selection refer to the appropriate transport regulations;the selection may vary depending on the cargo size and categories of other hazardous materials in the cargo. 15. REGULATORY INFORMATION International Chemical Inventories Inventory-United States TSCA- This product corn plies with TSCA requirements. Canada DSL Inventory List- This product complies with DSL requirements. EC-No Some components of this material are not on the EINECS inventory,and notification has not been made for ELINCS.This material can not be used commercially in the European Community. China inventory of existing This product complies with China inventory requirements. chemical substances list- Inventory-Japan-Existing This product complies with JPENCS and New Chemicals list- Australia(AICS): All the constituents of this material are listed on the Australian Inventory of Chemical Substances (AICS). U.S.A.Regulations OSHA Hazard Communication Standard: (Complies with USA OSHA 29 CFR 1910.1200 and ANSI Z 400.1) EPA RCRA Hazardous Waste Code: None EPA,Sections 311 and 312-Material Safety Data Sheet Requirements(40 CFR 370): Immediate(Acute)Health Hazard: YES Delayed(Chronic)Health Hazard: YES Fire Hazard: YES Sudden Release or Pressure Hazard: None Reactive Hazard: None EPA,Sections 313-List of Toxic Chemicals(40 CFR 372): This product contains the following substance(s),which appear(s)on the List of To>dc Chemicals: Additional Regulatory Information Bis phenol a-epichlorohydrin polymer EPA,CERCLA Section 102a/103 Hazardous Substances(40 CFR 302.4): None CERCLA/SARA-Hazardous Substances and their RQs:None EPA,SARA TITLE III Section 304,Extremely Hazardous Substances(40 CFR 355.40): None California Proposition 65: None 2-(2-m ethoxyethoxy)ethanol EPA,CERCLA Section 102a1103 Hazardous Substances(40 CFR 302.4): None CERCLA/SARA-Hazardous Substances and their RQs:None EPA,SARA TITLE III Section 304,Extremely Hazardous Substances(40 CFR 355.40): None California Proposition 65: None Xylene EPA,CERCLA Section 102a/103 Hazardous Substances(40 CFR 302.4): Listed CERCLA/SARA-Hazardous Substances and their RQs:100 lb final RQ 45.4 kg final RQ 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 7 of 9 • ! SchIumbcrycr Product code:K230B Revision date:31 October 2008 Bis phenol a-epichlorohydrin polymer EPA,SARA TITLE III Section 304,Extremely Hazardous Substances(40 CFR 355.40): None California Proposition 65: None International Hazard Class WHMIS Hazard Class: B3 (Combustible Liquids) D2A (Other Toxic Effects-Very Toxic Material) D2B (Other Toxic Effects-Toxic Material) 16. OTHER INFORMATION Current references: 1. Threshold Limit Values for Chemical Substances and Physical Agents and Biological Exposure Indices. American Conference of Governmental Industrial Hygienists, Cincinnati OH. 2. IARC Monograms on the Evaluation of the Carcinogenic Risk of Chemicals to Man. World Health Organization,International Agency for Research on Cancer. Geneva,Switzerland. 3. Annual Report on Carcinogens.National Toxicology Program.U.S.Department of Heath and Human Services,Public Health Service. 4. NIOSH Registry of Toxic Effects of Chemical Substances(RTECS).National Institute for Occupational safety and Health.Cincinnati, OH. 5. LOLI Database. Explanation of terms: ACGIH: American Conference of Governmental Industrial Hygienist ACGIH-TL: Threshold Limit Value DSL: Domestic Substance List HMIRC: Hazardous Materials Information Review Commission IARC: International Agencyfor Research on Cancer NTP: National Toxicology Program NIOSH: National Institute of Occupational Safety&Health NIOSH-REL: Recommended Exposure Limit OSHA Occupational Safety&Health Administration OSHA PEL: Permissible Exposure Limit TSCA: Toxic Substance Control Act(Inventory) Occupational Exposure Limits indicators:TWA-Time Weighted Average;STEL-Short Term Limit;C-Ceiling Lim Units:[mg/m3] ACGIH Notations: "Skin"refers to the potential significant contribution to the overall exposure by the cutaneous route,including mucous membranes and the eyes,either by contact with vapors or by direct skin contact with the substance. "A"notation indicates carcinogenicity as follows: ACGIH classification:Al -Confirmed Human Carcinogen;A2-Suspected Human Carcinogen;A3-Confirmed Animal Carcinogen with Unknown Relevance to Humans;A4-Not Classifiable as a Human Carcinogen;A5-Not suspected as a Human Carcinogen. "SEN"refers to the potential for an agent to product sensitization as confirmed by human and animal data. Section(s)revised: 4,8 Additional advice: Consult your supplier if the material is to be used for special applications such as in the food industry or for hygiene,medical or surgical end-use. Prepared by: Well Services Safety&Environment(WSSE). Revision date: 31 October 2008 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 8 of 9 • s SchIumbEryEr Product code:K230B Revision date:31 October 2008 The information and recommendations contained herein are based upon tests believed to be reliable. How ever,Schlumberger does not guarantee their accuracy or completeness NOR SHALL ANY OF THIS INFORMATION CONSTITUTE A WARRANTY, WHETHER EXPRESSED OR IMPLIED,AS TO THE SAFETY OF THE GOODS,THE MERCHANTABILfTY OF THE GOODS,OR THE FITNESS OF THE GOODS FOR A PARTICULAR PURPOSE Adjustment to conform to actual conditions of usage may be required. Schlumberger assumes no responsibility for results obtained or for incidental or consequential damages,including lost profits arising from the use of these data. No warranty against infringement of any patent,copyright or trademark is made or implied. End of the Material Safety Data Sheet 110 Schlumberger Drive,Sugar Land,Texas 77478,USA.Phone(281)285-7873 Page 9 of 9 • 0 O 1 � j 1 D a I G) I n ! I p 1 -a. < -0 '; CU (-) 'O 0.) 0) e-r, ..% ' 1 i I al O ' UQ I 1 o -a I ! N! S i I ! c1 I •• I a. 11 I i N __ _.._ _ 1- 1 aS `� ' 1 1 CO - - 5 v n,3 1 °' „I T - > n I0" Ull c c ii ' H= FF • aoILA Q.: o. 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S �D = o v °, n ' ` ...... c^ DV pn ooi o cc0 i0 O m• m CM i -� v, (1) n• I Z 11 -� 3 �, _ (D m3 � ' aimo 's n W '� �' CS' o -a 3 O �, a;r* o I 5' 'Y o r' �° e-� �, - ' n -a ,� '- y < .7 C m - o m a - cl, ° v l °: v °� N ': ( I • a 0 cu = ' s CD OP I a N ;\ 1 , °14' CL I y o rDa3 1t o 2 o � (DD X D•� (Dna - � an— D - ( Q- D ! O NfX 13\ N• H S N "° m X .13 Wv g -s m O _ (D '� n 7 " n 7.- � I � X - J `i ° ° m om j (DI� � ? ca eS `^gp i o -h C S • �1 o u�a i.4, ao }. n (1) . .,-,t 0-, c o O H ill. ? D - --i 11 n o o Imo_ oy o, c n o• c -N o v oi, -moi,, O 1 T eL �. O C (D v n aft, OO O 0 3• c N ro 7 C (O/f O O EU" n N v N n fD O fl, N N fft O N rrDD 'Q rD a N N 5. = ? ell I 011 10 % < S a CD I O *. O i 0 O vi d 'O -, CD rD r Q. CD O O < C a!v v W'N N!� v H 3 n n O O ' (MD . D tn r. n 1c < c co C'1 p • o v 0.:2D ro ro a N O A a. O a- VI - rt CD:•• �' < O = rD v oletil — co , O . 1 O a „.„ 0 „ ., N D o, G CD ao r, °1 00 n,' a1= n < v 0 rD m co ; oa 1 v 0 a. C11 R n' rD c 0 a + I I v W j N a a N I n 1 0 * rD N O = -0 'o O O In r) I O = 7 , rD s' C n ' N 7 zCL 1 rap ; A rD 3 } 1 . j c ' I , m z oa i ! i T m ! I 0 -' UJ I I I i 0.) W i - im. 1 'n v =. 1 I X a I 1 I X ry A. I X 1 ' i 1 O X co 3 ' X r+; i i I 1 I el rD `— vi I et ._.--_.... _ , _ _ I I K II Ii n' ro r+ N m 0 1 �, prD1BP> -o6 z Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday,August 12, 2015 9:44 AM To: 'Hazen, Mike C' Subject: RE:30-04 expired sundry to frac, sundry#314-359 PTD 188-062 Please submit a 10-404 for work done to date under sundry 314-359 with a note that work was not complete but will be continued under new sundry. Please include PTD# in subject line on all correspondence :ANND Thanx, Victoria From: Hazen, Mike C [mailto:Michael.C.Hazen@conocophillips.com] Sent: Tuesday, August 11, 2015 12:26 PM To: Loepp, Victoria T(DOA) Cc: Allsup-Drake, Sharon K Subject: 30-04 expired sundry to frac, sundry #314-359 Victoria— The frac work on KRU well 30-04, sundry#314-359, was not completed. Some pre-frac wellwork had begun to prep the well but the stimulation itself was not finished. We could not return to the well to accomplish our objectives of the frac before the sundry expired. The sundry#314-359 expired 6/19/2015. We are submitting a new sundry in the near future. Our question is whether we should submit a 10-404 with the work done to date or wait until all the work is complete. Thank you. Mike Hazen Staff Wells Engineer 265-1032 Mike Hazen Wells Engineer—ConocoPhillips Alaska, Inc. Office(907)265-1032, Mobile(907)268-9279, Home(907)868-3424, 700 G Street,ATO-2048,Anchorage,AK 99501 "Our work is never so urgent or important that we cannot take the time to do it safely and in an environmentally prudent manner." 1 Pro /88- a6, Z... Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, June 24, 2015 8:28 AM To: 'Hazen, Mike C' Subject: KRU 30-04; Fracture Stimulation (PTD188-062, Sundry 314-359) Mike, This sundry was approved before the new frac regulations became effective. The sundry will need to be re-submitted under the new frac regs for approval. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska 1't T �O�� Oil&Gas Conservation Commission JUL 2 J 333 W. 7th Ave, Ste 100 Anchorage,AK 99501 SCANNED Work: (907)793-1247 Victoria.Loepp(a�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.Loeop@alaska.gov From: Hazen, Mike C [mailto:Michael.C_Hazen@conocophillips.com] Sent: Tuesday, June 23, 2015 3:01 PM To: Loepp, Victoria T(DOA) Subject: ConocoPhillips Kuparuk Producer 30-04; Fracture Stimulation Sundry Good Afternoon Victoria, I would like to please request the extension of a sundry application approval that we received approximately one year ago.The approval expired on June 19, 2015, but we still would like to frac this well. We ran into delays procuring materials, obtaining internal new chemical evaluations, and then prioritizing and executing pre-frac wellwork. For these reasons we missed our expiration. We intend to complete the frac outlined in the application by August 28th, if a ten (10)week extension to the sundry approval might be possible. Thank you for your consideration. Regards, Mike 253't1 WELL LOG TRANSMITTAL DATA LOGGED 2/Cl/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. February 4, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 9ECEIV D FEB 06 2015 RE: Bottom Hole Pressure Survey&Perforation Record: 30-04 4°UGC Run Date: 1/5/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 30-04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21826-00 Shut-In Bottom Hole Pressure Survey 1 Color Log 50-029-21826-00 SCANNED lt PLEASE ACKNOWI EDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 FRS_ANC@halliburton.com .96/4.4a4t4:ka< Y Date: Signed: Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Organization (done) Well History File Identifier [] Rescan Needed RESCAN DIGITAL DATA OVERSIZED (Scannable) o Color items: o Diskettes, No. [] Maps: o Grayscale items: [3 Other, No/Type o Other items scannable by large scanner o Poor Quality originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds o Other TOTALPAGES: 1 I NOTES: ORGANIZEO BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL -DATE: ISl Project, Proofing I Iii]111111111111111 !111111111111111111 l e,~.. Staff PrD°a~~ PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE. ~SI P AG E S: ( a t~PFC~7~Te~s~ n,-,in9) SCANNED BY] BEVERLY BREN VINCENT SHERYfL MARIA LOWELt ISI ReScanned (done) RESCANNEOBY~ BEVERLY BREt~EN~SHERYL MARIA LOWELL General Notes or Comments about this file: Quality Checked {done: STATE OF ALASKA � 03 R ALI.OIL AND GAS CONSERVATION COMMON ' REPORT OF SUNDRY WELL OPERATIONS �y 1.Operations Performed: tai Abandon j""° Repair j Rug Perforations `1-- Perforate r Other (y" Scab Iner Alter Casing p Rill Tubing j Stimulate-Frac E Waiver Time Extension j` Change Approved Program ( Operat. Shutdown r Stimulate-Other 3 Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: I , ConocoPhillips Alaska, Inc. Development Exploratory r 188-062 • 3.Address: 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-21826-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25513 30-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 8984 feet Plugs(measured) 8599 true vertical 6785 feet Junk(measured) none Effective Depth measured 8850 feet Packer(measured) 7951 true vertical 6687 feet (true vertical) 6038 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115 SURFACE 5064 9.625 5099 4029 PRODUCTION 8928 7 8961 6769 LINER 899 4.5 8850 6687 schwa NO ' 1 2 2013 Perforation depth: Measured depth: 8675-8695 True Vertical Depth: 6559-6573 Tubing(size,grade,MD,and ND) 3.5, L-80, 7988 MD,6064 TVD Packers&SSSV(type,MD,and ND) PACKER-ZXP w/HD LINER TOP PACKER @ 7951 MD and 6038 TVD NIPPLE-CAMCO DS NIPPLE @ 508 MD and 508 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory P Development . Service r Stratigraphic 16.Well Status after work: Oil [ . Gas r WDSPL P Daily Report of Well Operations XXX GSTOR P WINJ 1 WAG r GINJ r SUSP F SPLUG 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: 313-274 Contact Paul Chan @ 263-4759 Email Paul.Chanacontractor.conocophillips.com Printed Name Paul Chap'" _7 Title Workover Engineer Signature ,..� Phone:263-4759 Date I� I j/ E-. / ° /loJ l3 RBrms AUG 2020 A . ' ' L% Form 10-404 Revised 10/2012 Submit Original Only i KUP PROD 30-04 Con ocoPhillips 1 \ Well Attributes Max Angle&MD TD Inc Wellbore API/UWI Field Name Wellbore Status Intl(°) MD(ftKB) Act Btm(ftKB) ilaSici. 500292182600 KUPARUK RIVER UNIT PROD 51.60 2,600.00 8,984.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date Well Cope9 -3o-048/82013859.8AM SSSV:NIPPLE 150 1/16/2009 Last WO: 7/21/2013 40.00 7/9/1988 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,668.0 9/8/2012 Rev Reason:GLV C/O osborl 8/7/2013 HANGER 31 '1eJy __Ii. k S Casing Strings 1 Casing Description 1 String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String... String Top Thrd CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 Welded Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE i g0 8.g ID 35.0 Set Dept 2 4,pth(T 9. 36.00 r-55 BTC T Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR, PRODUCTION 7 6.276 33.0 8,961.3 6,768.7 26.00 J-55 BTC 35-115 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd -_- SCAB LINER 4 1/2 3.958 7,951.3 8,850.0 6,686.8 12.60 L-80 IBTM Liner Details NIPPLE,508 - `f Top Depth (ND) Top Inot Noml... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) Ilk 7,951.3 6,037.9 45.22 PACKER 2RH ZXP w/HD LINER TOP PACKER 4.310 all 7,969.9 6,051.0 45.16 HANGER DG FLEX-LOCK LINER HANGER 4.400 GAS LIFT. - 7,979.7 6,057.9 45.13 SBE BAKER SEAL BORE EXTENSION 4.000 3,098 Tubing Strings -" Tubing Description Strin 0... Strip ID...To ftKB Set Depth f...Set Depth ND Strip Wt...Strip Strip Top Thrd 9 P 9 9 P( ) P ( P (TVD)�� 9 9�� 9 P TUBING WO 3 1/2 2.992 31.1 7,987.9 6,063.7 9.30 L-80 EUE 8rd AB Mod Completion Details GAS LIFT. Top Depth' 4,761 (TOD) Top Intl Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) i __ 31.1 31.1 0.18 HANGER CIW GEN IV TUBING HANGER w/Type'H'Profile 2.992 508.1 508.1 0.38 NIPPLE CAMCO DS NIPPLE 3.5"x 2.875" 2.875 7,901.7 6,003.1 45.37 NIPPLE CAMCO 3.5"x 2.812"DS NIPPLE SN:T070815 2.812 7,950.4 6,037,3 45.22 LOCATOR BAKER GBH LOCATOR sub w/7-ft Space out 2.992 SURFACE, I 7,959.1 6,043.4 45.19 SEAL ASSY !Baker 80-40 Seals 1 2.990 Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT, --- Top Depth 6,117 (ND) Top Inc! Top(ftKB) (RKB) (1 Description Comment Run Date ID(in) 8,599.0 6,503.0 43.13 PLUG COMPOSITE BRIDGE PLUG 7/18/2013 0.000 Perforations&Slots GAS LIFT, Top(ND) Shot 7,166 -- - Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (sh- Type Comment OF 8,622.0 8,640.0 6,519.7 6,532.9 C-4,C-1,UNIT 5/7/1989 12.0 CMT 21/8"EnerJet,60 deg.phasing- B,30-04 SQZ Squeezed behind 4-1/2"liner during 2013 RWO GAS LIFT, 8,653.0 8,669.0 6,542.4 6,554.1 A-3,30-04 5/7/1989 12.0 CMT 2 1/8"EnerJet,60 deg.phasing- 7 843 ks SQZ Squeezed behind 4-1/2'liner during 2013 RWO ak 8,675.0 8,695.0 6,558.5 6,573.1 A-2,30-04 7/18/2013 6.0 APERF 3-3/8"OD 6 SPF MILLENNIUM 60 la DEG PHASING 25gr HMX NIPPLE,7,902 a 8,675.0 8,698.0 6,558.5 6,575.3 A-2,30-04 5/7/1989 12.0 CMT 2 1/8"EnerJet,60 deg.phasing- SQZ Squeezed behind 4-1/2"liner during ill 2013 RWO III 8,710.0 8,730.0 6,584.6 6,599.1 A-1,30-04 9/25/1988 8.0 CMT 4 1/2'HSD Csg Gun,45 deg. SQZ phasing-Squeezed behind 4-1/2" 1 liner during 2013 RWO Cement Squeezes LOCATOR, , Top Depth Btm Depth 7950 (NO) (ND) y, \i Top IRKS) Btm(RKB) (ftKB) (5KB) Description Start Date Comment SEAL�SSr, '''r�,., 7,950.0 8,850.0 6,0370' 6,686.8 LINER CMT 7/15/2013 a Notes:General&Safety I 1 End Dote _ Annotation 7/10/1994 NOTE:WAIVERED WELL: IA x OA COMMUNICATION -R 9/8/2003 NOTE:31"Surf CSG Patch covering hole located 32"below OA valve. PT @ 1,500 psi-good 2013 RWO PLUG.8.589 'l/'® 5/18/2009 NOTE:View Schematic w/Alaska Schematic9.0 8,622-9 80440 Ail 1 _ APERF, 8,675-6695 _°_ CMT SOZ, 8,675-8,698 3) Mandrel Details Top Depth Top Port CMT 602, S (TVD) 1801 OD Valve Latch Size TRO Run 8,770-8,730 N...Top(ftKB) RKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 3,098.4 2,599.8 44.99 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 7/13/2013 III 2 4,760.7 3,787.1 44.76 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 7/13/2013 3 6,117.1 4,747.1 45.98 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 7/13/2013 4 7,166.4 5,485.1 43.91 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 7/132013 Liner Cement, 5 7,843.2 5,961.6 45.29 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/5/2013 7,950 SCAB LINER, 7,951-8,850 PRODUCTION, 33-8,961 TD,8,984 30-04 Pre and Post Rig Workover Well Work Pre Rig • • ° DATE SUMMARY 6/8/2013 SET JUNK CATCHER ON PLUG @ 8504' RKB; PULL DV @ 8421' RKB. CMIT TO 3000 PSI (PASS) DRAWDOWN TEST( PASS) ***NOTE: TREE VALVES SERVICED&ARE ALL LEAKING AFTER 2 RUNS- VALVE CREW& DSO NOTIFIED***. READY FOR BPV 6/26/2013 LOCKED OPEN TRDP-1A SSA @ 1829' RKB. CALLED FOR BPV TO GET INSTALLED**ALL VALVES ON TREE LEAK** Post Rig 8/5/2013 Set Catcher @ 7902' RKB; Replaced Sov W/Dv @ 7843' RKB (Pressure Tested TBG to 1000 psi); Pulled Catcher @ 7902' RKB. Ready for Coil. • • ConocoPhillps Time Log & Summary Wellview Web Reporting Report Well Name: 30-04 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6/30/2013 11:00:00 PM Rig Release: 7/20/2013 6:00:00 AM TImLvLOgS` Date From l To Due'"' S.Depth E.Jegth Phase `Code Subcode T -Comment y . G = 36/29/2013 24 hr Summary Moved rig to 3B pad.Transported mats for coverage over soft road areas 02:30 06:00 3.50 0 0 DEMOB MOVE RURD P Rig down pull off of well. Clean up location. Prepare to move rig. Pulling off of well witnessed by DSO and Rig Supervisor. 06:00 13:30 7.50 0 0 MIRU MOVE MOB X Standby for rig mats to be delivered and set,do soft road and mats being used for other in field rig moves that occurred during the past 24 hrs 13:30 15:30 2.00 0 0 MIRU MOVE MOB P Road rig from 3F pad to 1/8 mile from 3B and found soft spot in road,and rig was able to back out. 15:30 22:00 6.50 0 0 MIRU MOVE MOB X Bring in mats to move rig onto 3B pad. 22:00 22:30 0.50 0 0 MIRU MOVE MOB P Road rig from 1/8 mile from 3B pad to 3B pad. 22:30 00:00 1.50 0 MIRU MOVE MOB X Bring in mats to move rig on to CPF-3 36/30/2013 Moved rig from CPF-3 to 30-04 shuffling mats over soft areas. Spot rig over the well. Begin rig up to kill well and take on fluid to the pits. 00:00 01:30 1.50 0 0 MIRU MOVE MOB P Move rig over mats from 3B pad to CPF-3. 01:30 06:00 4.50 0 0 MIRU MOVE MOB X Move mats around rig for replacement ahead of rig 06:00 12:00 6.00 0 0 MIRU MOVE MOB P Road rig from CPF-3 to 30 access 12:00 20:30 8.50 0 0 MIRU MOVE MOB X Mat shuffle down 30 access road onto the pad. 20:30 21:00 0.50 0 0 MIRU MOVE MOB P Moved rig on pad and align with well. 21:00 22:00 1.00 0 0 MIRU MOVE MOB P Hung tree in cellar 22:00 23:00 1.00 0 0 MIRU MOVE MOB P Spot rig over well, DSO and Rig Supervisor witnessed spotting rig over well. Berm up rig,spot boiler and cuttings box.Conduct Conoco Phillips rig acceptance checklist. Accept rig at 23:00hrs 6/30/2013 23:00 00:00 1.00 0 0 MIRU WELLPF RURD P Rig up kill line and choke lines in cellar.Take on 12.8ppg Flow Pro mud top the pits. 37/01/2013 Rigged up to kill well. Pulled BPV. Circulated 330bbls of 12.8ppg Water based mud to surface. No flow check-good. Dry rod in BPV and test from below to 1,000psi 10min. N/D tree and adapter. Nipple up BOPE and begin to test 250/5000psi Page f of le Time'Oat' , iB iii" ii .. o _ .; Date From To, Dur ,,. S. Depth E.Depth Phase Code Subcode'th, Comment 9100 °.. 00:00 04:00 4.00 0 0 MIRU WELLPF RURD P Lay liner and set berms for Tiger Tank. Set Tiger Tank and hook up hard lines. Finish hooking up lines to tree and IA in cellar. Load shed with lubricator. Finish filling pits with 12.8ppg water based mud. 04:00 04:30 0.50 0 0 MIRU WELLPF SFTY P Conduct pre-spud meeting for 30-04 work over. Discuss potential hazards and well control. 04:30 06:00 1.50 0 0 MIRU WELCTL MPSP P Pick up lubricator and stab onto tree. Pressure test to 3500psi. Pull BPV 100psi on tubing, no pressure on IA, 320psi on OA. 06:00 10:30 4.50 0 0 MIRU WELCTL KLWL P RU and PT kill lines @ 250/5,000 psi. Open up well-SITP= 100 psi, SICP=0 psi. PJSM, Notify Security and DSO for possibility of venting gas to kill tank. Pump 12.8 wbm down Tubing @ 3 BPM @ 60 PSI Maintaining back pressure on choke manifold,taking returning to kill tank-pumped 330 bbls with 307 bbls returned w/PR of 3 bpm @ 600 psi. Recovered 12.8 ppg WBM at CM. NFT tbg for 30 minutes at CM, and monitor IA at cellar. Well Static. 10:30 12:00 1.50 0 0 MIRU WHDBO MPSP P Dry rod in 3"Type'H' BPV, PT to 1,000 psi from under neath in direction of flow. Hold for 10 minutes -good test. 12:00 14:30 2.50 0 0 MIRU WHDBO NUND P ND tree and Adapter. Clean and inspect hanger and flanges. Install Cameron Test plug. 14:30 18:00 3.50 0 0 MIRU WHDBO NUND P PJSM, Nipple up 11"5M BOPE stack with 3 1/2"x 5"VBR's in top and bottom rams. 18:00 00:00 6.00 0 0 MIRU WHDBO BOPE P Pressure test BOPE: 1-Kill line valve, Blind Rams, Choke Valves 4,11,12, Hydraulic IBOP Top Drive,3 1/2"IF Floor Valve. 250/5,000psi-Good 2-Blinds, Lower TD Manual IBOP, 3 1/2"IF Dart, CV 3,7,9,10. Flange leaked between Mud Cross and Lower Pipe Rams, Flange leaked between Mud Cross and Choke HCR.Tightened both and re-tested good to 250/5,000psi. 3-HCR kill, Blinds, CV 2,5,6. HCR kill leaked,greased and re-tested good. 250/5,000psi. 4-Manual Kill,Blinds,CV 2,5,8. 250/5,000psi. 5-Lower Pipe Rams with 3 1/2"test joint-250/5,000psi Page 2 Of 19 Time Logs ,. ru Date From To Dur,, k' Depth E.Depth Phase Code Subcode 'f !Comment ' 07/02/2013 24 hr Summary Finish testing BOPE 250/5,000psi. Pull test dart and BPV. Circulate 1.5 hole volumes to condition mud. Rig up Halliburton SL and attempt to pull Catcher on top of CA2 Plug at 8514'. Tag high at 8431'. Add Weight Bar and Stem and attempt again-tag at 8431'. RIH with Pump Bailer 8431'tag,work to 8434'. POOH. 00:00 02:30 2.50 0 0 COMPZ WHDBO BOPE P Continue testing BOP's 6-Annular w/3 1/2"Test Joint 250/3,500psi 7-Upper Pipe Rams 3 1/2"Test Joint, Manual Kill 250/5,000psi-Good 8-Lower Pipe Rams 4 1/2"Test Joint 250/5,000psi-Good 9-Annular w/4 1/2"Test Joint 250/3,500psi-Good 10-Upper Pipe Rams w/4 1/2"Test Joint 250/4,000psi-Had to work air out-Good Accumulator Draw Down Test: Initial Accumulator Pressure-3,025psi After Draw Down-1,850psi 15 seconds for the first 200psi, 90 seconds final pressure 3,000psi. 4 Nitrogen Backup bottles @1950 Avg. Closing times: Annular 14 seconds Upper Rams 7 seconds Lower Rams 7 seconds Choke HCR lsecond Kill HCR lsecond 02:30 04:30 2.00 0 0 COMPZ WHDBO PLUG P Drain Stack. Pick up"T"bar. Engage test dart and poppit in BPV. Check for pressure-none. Pull BPV. 04:30 05:30 1.00 0 0 COMPZ WELLPF CIRC P Rig up to circulate down the tubing taking returns to the IA. 05:30 12:30 7.00 0 0 COMPZ WELLPF CIRC P Circulate 1.5x's hole volume at 2BPM. Rate limited by gas buster vs. Mud weight. Mud weight coming back 12.4ppg. Stopped and weighted pits back up and continued to circulate.2BPM 637psi. Flow check -well balanced. 12:30 14:00 1.50 0 0 COMPZ WELLPF RURD P R/U SL 40 ft lubricator with retrieving tool, pressure test surface equipment to 5K. 14:00 21:00 7.00 0 0 COMPZ WELLPF SLKL P RIH with SL, had to pump down 1/2 bpm from 3800ft on.Tag at 8431' SLM, POOH. No fish. R/U additional roller stem and weight bar. RIH for second attempt. Tag at 8431, POOH, No Catcher. 21:00 00:00 3.00 0 0 COMPZ WELLPF SLKL P MU Bailer, RIH on SL to 8400', Pump assist 1/2 bpm at 400 psi. Proceed to 8431'. Work down to 8434'and POOH. Page 3 of 1,9 Time Logs 3 Date , From Tb' Dur" S. Depth E.Death Phase Code Subcode T 37/03/2013 24 hr Summary Perform multiple 2-1/2"Bailer runs with HES SL and bail fill frrom 8489'to top of catcher at 8504'. Unable to latch Catcher with GR Pulling Tool. RIH with 2"Bailer to 8505'to clear top of Catcher. 00:00 01:30 1.50 0 0 COMPZ WELLPF SLKL P Continue RIH with SL Bailer to 8431', work down to 8434'. POOH. 01:30 02:30 1.00 0 0 COMPZ WELLPF SLKL P On surface nothing recovered in Bailer. Add 3'of Wt Bar and remove 5'of Bailer. 02:30 03:30 1.00 0 0 COMPZ WELLPF SLKL P Circulate 300 bbls at 5 bpm to contition mud. 1540 ICP, 1540 FCP. 03:30 04:45 1.25 0 0 COMPZ WELLPF SLKL P RIH with Bailer while pumping 3 bpm at 780 psi. Tag at 8467'and work to 8472'. POOH. Recover fine black Sand with some Frac Carbo. Clean and inspect bottom and no marks. 04:45 17:30 12.75 0 0 COMPZ WELLPF SLKL P RIH with Bailer while pumping 3 bpm at 780 psi. Tag at 8472'and continue to work down 3'-5'bailing runs. P/U 2.73"locator tool for depth correction @ 8400'bottom GLM+22' correction-8422'corrected depth. P/U 2.5"Bailer BHA-RIH tag up early @ 8494'-made 3ft-POOH. RIH and made additional 8ft on next run to 8502'. Bailer filled with mud and light debris. P/U smaller 2"bailer to drift inside fishing neck. RIH down to 8200'-start pumping string down to 8505. POOH and LD Bailer. 17:30 20:00 2.50 0 0 COMPZ WELLPF SLKL P PU GR Tool and RIH with Pump assist 1 bpm at 530 psi to 8503'. POOH, no Catcher. 20:00 23:30 3.50 0 0 COMPZ WELLPF SLKL P MU 2-1/2"x 5' Bailer, PT 3500 psi, RIH to 8503'and make it down to 8503.5. POOH, no marks, MU same Bailer, PT 3500 psi, RIH with pump assist at 1 bpm at 500 psi to 8504.5', POOH, No marks. 23:30 00:00 0.50 0 0 COMPZ WELLPF SLKL P MU 2"x 5' Bailer, PT 3500 psi, RIH 07/04/2013 Pull Catcher and CA-2 plug. Monitor well. Establish Circulation, hole took 28BBLS,circulate bottoms up. 00:00 02:30 2.50 0 0 COMPZ WELLPF SLKL P Continue RIH with 2"x 5 Bailer with pumps at 1 bpm at 570 psi to 8505'. POOH. PJSM with new HES SL Crew. Clean and inspect Bailer. No new marks. 02:30 05:00 2.50 0 0 COMPZ WELLPF SLKL P MU GR Pulling Tool. PT 3500 psi. RIH to 8504'and latch Catcher Sub. POOH and LD 10'Catcher Sub Page 4 of 1!9 Time Logs g A o Rio Date From£;iTo Dur ' S. Depth `E.kDepth Phase,;Code Subcode T liil'!a'Comment » .iiri6 'I 05:00 09:00 4.00 0 0 COMPZ WELLPF SLKL P MU 2-1/2"Split Skirt RB to pull Prong. PT 3500 psi. RIH-stop prior to latching prong, put 200 psi on well, line up valves and SI on choke. Try to latch prong, no pressure or weight indication of prong being latched. Continue to work string, no pressure change. Manually bleed down choke to 50 psi. POOH with SL.Total of 1 bbls loss while POOH. Shut in and monitor well for 30 minutes. No change. Inspect SL- prong pulled. RD SL lubricator to change out pack offs. 09:00 11:30 2.50 0 0 COMPZ WELLPF CIRC P Line up fluid lines and pressure up to 700 psi on tubing to try and bullhead. No losses, IA to 400 psi. 3/4 BBL pumped. Bleed down lines, 3/4 BBL returned, and monitor well while wait on Slick line to change the pack offs, cut 200ft of wire and re-head.Well static. 11:30 16:30 5.00 0 0 COMPZ WELLPF SLKL P PJSM&RLG meeting with new Slick line crew. Make tool string back up with Hydrostatic bailer. Pressure test to 250/3,500psi.Trip in hole with Hydrostatic bailer to top of plug. Hold 100 psi on tubing while working bailer string,good indication of hydrostatic tool. POOH while holding 100 psi on Tubing. Small amount of debris in the Hydrostatic bailer. 16:30 18:30 2.00 0 0 COMPZ WELLPF SLKL P P/U CA-2 plug fishing tool. Pressure test-RIH. Pump to get tool down. Try to latch without pumping. No luck, pump 1 bpm and try to latch. Stop pumping and hold 600 psi on tubing and 200 psi on choke. Did not have a good indication of latching. Prior to POOH pressure dropped off to 300 psi and choke to 40 psi. POOH to inspect BHA and possible fish. Crew change. No fish recovered. 18:30 23:00 4.50 0 0 COMPZ WELLPF SLKL P Lay down RB retrieving tool and pick up RS retrieving tool.Pull out of hole with CA-2 plug. Rig down Slick line and lubricator. Monitor well. 23:00 00:00 1.00 0 0 COMPZ WELLPF CIRC P Begin pumping at 2BPM 715psi. Circulation established at 28BBLS pumped away. 15%average losses at 2BPM circulation rate. 07/05/2013 Attempt to pull 3-1/2"Tubing from PBR at 8464'. Unable to Pull. Rig up HES Eline and perform String Shot and RCT Cut at 8447'. Cut Successful. Pull Hanger and Circulate 1.5 x BU and perform NFT-Static. Pull completion from 8447'. 24 hour losses=61 bbls/Total well= 120 bbls Page 5 of 19 • ,Time Logs A! ` pigiti Date, -I''Prom To Dur , S. Depth E.Depth Phase Code,-. Subcode ° T Comment 1 00:00 03:00 3.00 0 0 COMPZ WELLPF CIRC P Circulate 1.5 Hole volumes. 2BPM 715PSI, reduce pump rate to 1 BPM at 570psi and monitor losses,same as pumping 2BPM 13%. 03:00 03:45 0.75 0 0 COMPZ WELLPF SIPB P Flow check well 30minutes. No flow, slight suction on annulus. FIll back side after 30min and took 6BBLS to fill,fluid collumn at 227'. 03:45 04:30 0.75 0 0 COMPZ WELLPF RURD P Rig down circulating swedge and hoses. Make up XO and Top Drive to pull hanger. BOLDS. Check for pressure on annulus-none. 04:30 05:00 0.50 0 0 COMPZ RPCOM PULL P PJSM on pulling the tubing hanger. Original string weight w/o blocks 63K. Nordic 3 traveling blocks and Top Drive 35K. Unseat hanger and pull up to 140K Wt indicator, 105K string weight,42K over string weight, no movement.Work pipe 8 times at this weight limit.Work pipe up to 145K Wt indicator, 110K pull on string,47K over original string weight. No movement 05:00 06:00 1.00 0 0 COMPZ RPCOM ELNE P PJSM, Stage E-Line equipment and tools. Monitor well on the trip tank. 06:00 10:30 4.50 0 0 COMPZ RPCOM ELNE P Crew change for rig and Eline group. Double check up weight-120 K- 20K over string weight. PJSM-rig up lubricator, pump in sub,X-overs and wireline valves. Pressure test to 3500 psi. P/U Eline BHA#1 with sting shot. Well is taking fluid average 6 bbbls/hour 10:30 14:30 4.00 0 0 COMPZ RPCOM ELNE P RIH 100fpm,tie in with+21 ft correction. RIH and identify above and below the joint of pipe using GLM 8421'&AVA locator sub (8463'). Set and fire string shot @ 8447', POOH. Good fire indication. RD tools. Fluid loss slowling down to 2-3 bbls/hour. 14:30 17:30 3.00 0 0 COMPZ RPCOM ELNE P RIH&stop hole fill to equalize well while tripping in hole with RTC BHA. Tie in with+21 ft correction, correlate depth and double check logs with previous run. BHA depth 8437'with 10'offset-Cut pipe @ 8447'. Good indication of cut-CCL minus 2ft POOH past collars. POOH 17:30 20:00 2.50 0 8,447 COMPZ RPCOM ELOG P Inspect BHA-set Eline equipment to the side&prepare to pull on pipe to ensure a clean cut. 20:00 20:30 0.50 8,447 8,418 COMPZ RPCOM PULL P Kelly Up, Pull Hanger to the Rig Floor, Up 106k#, PU to 8418' Page 6of49 'Tine"Logs " Date From To Dur ` °S. Depth E.Depth Phase Code Subcode T ;P"Comment 20:30 22:30 2.00 8,447 8,418 COMPZ RPCOM OWFF P Establish Slow Pump Rates at 8418', 12.9 ppg. MP1:20 spm at 575 psi, 40 spm at 690 psi. MP2:40 spm at 560 psi,40 spm at 680 psi. Montor well for flow-Static. 22:30 00:00 1.50 8,418 8,300 COMPZ RPCOM PULL P PJSM. LD 3-1/2"EUE Tubing Decompletion from 8418'to 8300'. Up wt 105k# 37/06/2013 Pull out of hole with 3 1/2"tubing completion. Recover all 31 bands,joint 259 cut length 11.82'. Pick up#1 Fishing BHA for 3 1/2"Tubing cut joint. P/U drill pipe. 00:00 06:00 6.00 8,447 5,200 COMPZ RPCOM PULL P Pull out of the hole with 3 1/2"tubing completion. Lay down SSSV. **Recovered all 31 Bands from well.** Monitor hole displacment on the trip tank. 06:00 09:30 3.50 5,200 3,200 COMPZ RPCOM PULL P Crew change-PJSM continue TOOH sideways with decompletion string. Kicking pipe out and flow check every 15 joints. 09:30 10:15 0.75 3,200 3,200 COMPZ RPCOM SFTY P Kick while tripping drill with full AAR. Jakes Crew. 10:15 15:00 4.75 3,200 0 COMPZ RPCOM PULL P Continue TOOH sideways with decompletion string. Clean cut on bottom joint#259 length at surface 11.82ft. Fish length 20.58' 15:00 17:00 2.00 0 0 COMPZ RPCOM RURD Clean up rig floor, unload pipe shed, prep rig floor and load fishing BHA. 17:00 18:00 1.00 0 0 COMPZ RPCOM RURD Install wear ring ID 6 3/8" 18:00 20:30 2.50 0 313 COMPZ RPCOM PULD PJSM, P/U BHA#1 Cut lip guide overshot with 3 1/2"spiral grapple. 20:30 00:00 3.50 313 3,540 COMPZ RPCOM PULD PJSM, P/U 3 1/2"Drill pipe. Monitor hole displacement on the trip tank. 07/07/2013 Cont. TIH in hole to 8,400'. Cut and Slip drill line. CBU. Engage seal assembly and pull free. CBU. Pull 5stds flow check pump slug. POOH with seal assembly and lay down same. Pick up spear.Trip in the hole. 24 hour losses 44 bbls/total=200 bbls. 00:00 04:30 4.50 3,540 8,290 COMPZ RPCOM TRIP P Trip in the hole with 3 1/2"Drill pipe to 8,290'. Monitor hole fill to trip tank while tripping in. No losses to formation. 04:30 08:00 3.50 8,290 8,413 COMPZ RIGMN1 SLPC P Slip and Cut 84'of 1 1/8"Drill Line. Monitor hole on the trip tank during the slip and cut operation. Pre-jar derrick inspection. PJSM-crew change. Page-7 of 19 'Time Logs Date From To Dur' S.Depth E.Depth Phase Code Subcode T Comment 08:00 09:00 1.00 8,413 8,436 COMPZ RPCOM FISH P Circ hole volume prior to latching into fish. 20 spm=775 psi @ 8413' 40 spm=980 psi @ 8413' 120 spm= 1700 psi @ 8413' 150 spm=2600 psi @ 8413' Up weight 132K/Dwn 100K-Slowly roll pumps while RIH,engage fish @ 8436'-Set down 15K, P/U 155K, Set down 25K-P/U 190 K,jars fired- straight pull 55K over,seals came free.Work pipe up/dwn one time to check for seal travel or packer movement. Seal travel noted. 09:00 12:00 3.00 8,436 8,385 COMPZ RPCOM CIRC P Circ B/U @ 150 spm,2640 psi. Flow check-PJSM-POOH slowly for the first stands, pump 10 bbl dry-job, monitor well. 12:00 19:00 7.00 8,385 313 COMPZ RPCOM TRIP P TOOH standing back DP, no indication of swabbing. Hole taking correct hole fill. Monitoring hole fill on the trip tank. 19:00 21:00 2.00 313 313 COMPZ RPCOM TRIP P Lay down seal assembly and cut joint-32.07'. Make up BHA#2,spear and 3.885 shoulder type grapple. 21:00 00:00 3.00 313 2,154 COMPZ RPCOM TRIP P Trip in the hole with fishing BHA#2. Monitoring hole displacement to the trip tank. 37/08/2013 RIH with Baker Itco Spear Fishing Assembly and locate PBR at 8457'. Jar 3 times and shear Packer, allow time for Elements to relax and monitor well. Attempt to pull Packer-not pulling. Continue jaring and working pipe. Circulate bottoms up, note 3 bbl gain,shut in well and circulate out packer gas through Poor Boy Degasser at 1 bpm. Shut well back in, bleed to 0 psi, open well and observe well for flow-Static. Continue working pipe,jarring and rotating. Packer comes free after 128 jar licks. POOH with Packer. 24 hour losses= 17 bbls/Total well=217 bbls 00:00 04:00 4.00 2,154 8,400 COMPZ RPCOM TRIP P TIH with Fishng BHA#2. Monitor hole displacement to the trip tank. 04:00 05:00 1.00 8,400 8,400 COMPZ RPCOM CIRC P Circulate B/U prior to latching PBR. 6bpm @2,060psi. No losses to formation. Page 80119 'Date frdrii:2Ifo Dur S. Depth E.Depth Phase Code Subcode T Comment 9'r 05:00 06:00 1.00 8,400 8,462 COMPZ RPCOM FISH P Establish parameters. 135k up, 115 rotating, 95k dn, Block weight 35k. Pump at 3bpm 990psi. Engage fish and pressure up to 1,140psi. Shut down pump. Top of fish @8,457'. Bull nose of spear @8,462'. Line up to monitor hole on trip tank. P/U To 155k,20k over and slack off to 75k 20 down. confirm grapple engaged. P/U to 180k and bleed jars off. Attempt straight pull release of packer(pinned at 65k) Cycle up at 180k, 210k,215k,225k,235k,250k, returning to 160k down after each up stroke. S/O to 90k and cock jars P/u to 200k,65k over and fire jars 3 times cycling up to 250k after jars fire and down to 90k to cock. After 3 jarring attempt and pull to 250k,weight dropped to 225k appearing that the packer released. Slack off to 115k(neutral)monitor well while elements relax. 06:00 11:00 5.00 8,462 8,470 COMPZ RPCOM CIRC P Attempt to move packer up max pull 290K,fish will move freely down hole. Work string and jars for 20 minutes. No luck. Start circulated B/U @ 5 bpm,slow rate down to 2 bpm @ 140 bbls,started to get packer gas @ 165 bbls. Shut in bag, line up choke and record pressures. Circ out packer gas @ 1 bpm. SIDP 110 psi SICP 90 psi. After bottoms up shut in and check for pressure. SIDP 0 SICP 0 Open annular and circulate bottoms up to condition mud. Begin at 5bpm and reduce to 3bpm due to losses while circulating. 12.9ppg in 12.9ppg out Page 9 of 19 Time Logs `,14 - Date From' .To .".Dur U S.`Deithr'E.Depth Phase Code Subcode T :Comment ;11,: 11:00 13:00 2.00 8,470 8,487 COMPZ RPCOM FISH P Work pipe pull to 235k and fire jars then straight pull to 275k.When working back down to re-cock jars will not take weight and continue to move packer do wn the hole. Attempt to rotate with 10k pulled over rotating weight(115K). Free torque was 3k apply 4 1/2 wraps and toque up to 5k stall limit.Attempt to work pipe from 150k-125k. Release torque and set down to 90k then pick up to 125k, rotate and able to get in 8 1/2 wraps before torque limit. Work pipe 150k-125k. No progress. Release torque and travel downward free to 8,493'able to set down to 90k and cock jars. Begin jaring up 240k then straight pull to 300k. 13:00 17:00 4.00 8,487 8,487 COMPZ RPCOM FISH P Continue jarring. No luck.Attempt to rotate,good rotation on pipe,torque values 4500-5600psi. Make 30 revelutions then work pipe, light reverse torque 1-2 rotations per 30. Continue with sequence, straight pull &jarring in between rotation sequence. Continue to rotate pipe with weight pulled over 20k-30k. 17:00 18:00 1.00 8,487 8,446 COMPZ RPCOM FISH P At 128 Jar Licks, Packer pulls free. PU to 8414', Up 145k#approx 10k# overpull, RIH to 8563'and set down 15k#, PU to 8446' 18:00 19:30 1.50 8,446 COMPZ RPCOM OWFF P Monitor well and perform a post jarring derrick inspection. 19:30 21:00 1.50 8,446 7,935 COMPZ RPCOM PULL P POOH 5 Stands, Dragging 4k#over, Up wt 149k#. Tight spot noted at 8267'. 21:00 22:00 1.00 7,935 7,935 COMPZ RPCOM CIRC P Circulate 256 bbls at 5 bpm. ICP 2120, FCP 1990 psi. 22:00 22:30 0.50 7,935 7,935 COMPZ RPCOM OWFF P No Flow Test-Static. Blow Down Top Drive. 22:30 00:00 1.50 7,935 6,250 COMPZ RPCOM PULL P POOH slowly to 6250'. 37/09/2013 Trip out of the hole with Packer, Perform weekly BOP Test, made up 6 1/8"concaved mill assembly and start trip in. 00:00 04:00 4.00 6,250 515 COMPZ RPCOM PULL P Continue POOH with Packer from 6250' 04:00 04:30 0.50 515 515 COMPZ RPCOM OWFF P Perform Kick while Tripping Drill and Monitor Well-Static. 04:30 07:00 2.50 515 0 COMPZ RPCOM PULD P Lay down Packer fishing BHA. 07:00 09:00 2.00 0 0 COMPZ WHDBO RURD P Flush stack, pull wear ring and install test plugs. Page 10 of 19 • �d 1 Time Legs G0w Date From Toy '`'bDur S. Depth E.Depth Phase Code Subcode T Comment 09:00 17:00 8.00 0 0 COMPZ WHDBO BOPE P Begin BOPE testing 250/5000 psi. Sizes to be tested 2 7/8", 3.5"& 4.5". State witness waived by**Lou Grimaldi** Blind, Kill line, 3 1/2"Dart, Choke, 4,11,12 valves Blind, HCR, 3 1/2"FOSV, choke, 3,7,9,10 Blind, Manual Kill,Choke 2,5,8 Blind, Manual choke,2,5,6 Lower&upper 2 7/8"VBR Annular 3500 psi Lower&Upper 3 1/2"VBR Annular 3500 psi Lower&Upper 4 1/2" Annular 3500 psi-Light leak off on annular pulled test joint to inspect- file down die marks, re-test Passed. Draw down test-passed. 17:00 18:00 1.00 0 0 COMPZ WHDBO PULD P Remove test plug, install wear ring, set up rig floor for milling/FCO run. 18:00 00:00 6.00 0 2,651 COMPZ WELLPF TRIP P PJSM load mill assembly on floor. Make up 6 1/8" concaved&string mill assembly BHA#3 begin to RIH Mill @2651 '. Up Wt. 73 K DN Wt. 65 K 07/10/2013 clean out with 6 1/8"mill assembly.tagged @ 8663'clean out to 8673'mill slow down . POOH with mill. recovered metal shavings, packer slips and clay on magnets.concaved mill show wear to center of mill.and minor wear on waer pads on string mill. 00:00 06:30 6.50 8,560 COMPZ WELLPF TRIP P Continue TIH-Stop 8560'-Pump B/U 5 bpm 1775 psi. Up weight 130K /Down 95K,free spin 30 rpm 115K, 3000 psi free torque. 06:30 08:30 2.00 8,563 8,668 COMPZ WELLPF MILL P PJSM-crew change-RIH, pumps @ 2bpm/740 psi,with no rotation. Tagged up 8663.5'-P/U weight 135k, Down 95K. 4 bpm/1140 psi, RPM 15,Torque 3700psi, Slowly work down 5 fph,7K down. Returns-light metal shavings, light sand/formation. Stall @ 8668'-Stop rotating, lower pump rate, P/U 160K, broke over- P/U 15ft and increase pumps to 5 bpm @ 1720 psi.Work pipe. 08:30 11:30 3.00 8,668 8,671 COMPZ WELLPF MILL P RPM 20,torque 3200,5 bpm-1750 psi, 10K down. Start milling from 8667'. Still showing metal curly shavings to surface,small rubber(element chinks)&light sand. 8670'-set down additional 5K to get reactive torque. P/U weight 135K- clean. String mill potentially going through tight spot. 5 bpm, 1739 psi, RPM 20,Torque 3600, 7-10K down. Page 11 of 19 Gate From' To " vDur S. Deoth:NE.,Depth Phase Code W Subcode T Comment 11:30 14:30 3.00 8,671 8,678 COMPZ WELLPF MILL P Increase RPM in stages to try to increase ROP. 10K down, 30 RPM-torque 3200, 5 BPM @ 1710 psi-no change 10K down,45 RPM-torque 4100, 5 BPM @ 1730 psi-increase ROP to 6 fph. P/U @ 8673'-Slight drag @ 8665'-3K over.Work static pipe- clean drift down to 8672'-P/U weight clean 135K. 6K down 60 RPM-torque 4100,5 BPM, 1720 psi,6 fph.good reactive torque. ROP dropping off, P/U and drift through area-clean drift. P/U weight 130K, Down 103K. 14:30 15:30 1.00 8,678 8,150 COMPZ WELLPF SFTY P P/U to 8600'-flow check for 30 minutes&call town to discuss. No-flow decision made to POOH to inspect BHA&P/U 6"flat bottom mill. PJSM for TOOH. 15:30 22:30 7.00 8,150 0 COMPZ WELLPF TRIP P Pull 5 stands, pump 15 bbl dry-job- TOOH. String mill showed minor wear on wear pads,concaved showed wear to center of mill.Also recovered clay material on stabilizers , magnets with metal shavings and packer slips. 22:30 23:00 0.50 0 COMPZ WELLPF OTHR P Broke down BHA#3 Milling assembly. 23:00 00:00 1.00 0 COMPZ WELLPF OTHR P Cleaned off floor. load tools. PJSM on BHA#4 37/11/2013 continue to clean out with BHA#4 to 8730 ft.getting back 60/40 frac sand&formation sand with light metal shavings.Avg. ROP to 8719 ft 4 FPH. reduced 1 FPH @ 8719 ft. 00:00 00:30 0.50 0 306 COMPZ WELLPF OTHR P Made up BHA#4.6"flat bottom mill,6"slick string mill. BS,Jars. 00:30 05:30 5.00 306 8,678 COMPZ WELLPF TRIP P RIH with BHA#4. Broke circulation @ 2 BPM @ 690 psi. 05:30 08:30 3.00 8,678 8,682 COMPZ WELLPF MILL P Tagged @ 8678'continue to attempt to clean out to 8880 ft with BHA#4. P/U weight 137K,dwn 112K.60 RPM-work string down slowly from 8672'. Start milling from 8677' 5K Down,60 RPM,5 bpm @ 1720 psi,2 fph. B/U Sample light metal shavings, &light frac sand. Losing torque @ 8681' 08:30 11:30 3.00 8,682 8,692 COMPZ WELLPF MILL P Increase RPM to 80 fpm,torque 3300,5 bpm @ 1680 psi.-B/U sample 100%frac sand with light metal shavings. P/U and drift through area dry-clean. Continue milling increase pump rate to 6 bpm @ 2250 psi. ROP 5 fph.-frac sand 90%, light shale&metal. Page 12 of 1;9 Time Logs ' Date = From Tor Der'£'` S. Depth°E.Death Phase Code }$!Subcode "T k Comment = . y 11:30 16:30 5.00 8,692 8,712 COMPZ WELLPF MILL P ROP fluctuating between 2-7 fph, pending on torque values.Trend of milling indicates bit work with increase torque,then slower ROP decrease in torque when string mill engages area. Good metal shaving in cuttings,60%frac sand,40% formation shale/sand. RPM 80,torque 3800,6 BPM @ 2200 psi. 16:30 17:30 1.00 8,712 8,712 COMPZ WELLPF MILL P Wier trip/back reaming for 30'. P P 9 17:30 00:00 6.50 8,712 8,730 COMPZ WELLPF MILL P Continued to mill out as prior operation appeared to contact gun @ 8719, ROP reduced to 1 ft PH. Tourge increased to 3600 increased mill wt to 20K from 16K and RPM's to 100.tourge increased to 4900.ROP increased to 2 ft per hour. cuttings coming back silica sand and light metal shavings. unable to weight cuttings due to lack of scale. current depth @ 8730 ft. 37/12/2013 continued to mill to 8733 ft with 6"bladed F/B junk mill. POOH with mill assembly. PU 6"rock bit assembly. RIH continued to clean out to 8766 ft. 00:00 01:00 1.00 8,730 8,733 COMPZ WELLPF MILL P Continue to clean out with BHA#4 to 8733 with ROP of 3 FPH with torque @ 4500 reduced RPM to 60 RPM's torque dropped to 3025 holding smooth. UP WT. 1115K, DN WT. 105 K cuttings recovered silica sand&metal shavings. 01:00 01:30 0.50 8,733 8,500 COMPZ WELLPF CIRC P circulated bottoms up. pump dry job. 01:30 02:00 0.50 8,500 8,500 COMPZ WELLPF OWFF P monitor well for flow. 02:00 02:30 0.50 8,523 8,523 COMPZ WELLPF TRIP P pull tail to 8523 ft. 02:30 04:30 2.00 8,523 8,523 COMPZ WELLPF SLPC P slip&cut drilling line 04:30 10:30 6.00 8,523 323 COMPZ WELLPF TRIP P POOH with BHA#4. Crew change- PJSM with day crew. Continue TOOH from 6800' 10:30 12:00 1.50 323 0 COMPZ WELLPF PULD P Lay down BHA-String mill in gauge, flat bottom mill 1/16"out&had a 2 7/8"-3"ring cut on the face. 12:00 13:00 1.00 0 300 COMPZ WELLPF PULD P P/U new 6"Mill tooth Rock Bit,jets 3-20's/.92 TFA. 13:00 17:00 4.00 300 8,623 COMPZ WELLPF TRIP P TIH down to 8623' Page 13 of 19 Date =__c% From To Dural S. Depth E.Depth Phase.:.Code Subcode , T Commn'ient 17:00 18:00 1.00 8,623 8,733 COMPZ WELLPF DRLG P P/U weight Dry 143K, Down 100K. Establish SCR 20-660 psi 40-790 psi P/U weight 130K, Down 95K pumping 6 bpm-2220 psi,40 RPM =3000#. Slow Pump rate to 2 bpm, Slide in hole start seeing drag @ 8722', tagged @ 8733' P/U weight 135K 18:00 20:30 2.50 8,733 8,747 COMPZ WELLPF DRLG P Begin Drilling -6 bpm,2260 psi,40 RPM 3100#,w/6K on bit. increased RPM's to 70=3200-3400 torque with 10 K on bit. ROP=9±FPH. Began recovering formation sands. Drilled down to 8747 MD.appeared to take an influx of fluid. picked up off bottom. @ 20:22 hrs 20:30 21:30 1.00 8,747 8,720 COMPZ WELCTt DRLG X Monitor well for flow. No flow for 30 min's conducted full simulation of kick while drilling&review 21:30 00:00 2.50 8,720 8,766 COMPZ WELLPF DRLG P continue clean out with 6"bit from 8747 ft @ 6 BPM @ 2300 psi . RPMs @ 60 @ 3350 torque.With ROP of 9 FPH 8,766 COMPZ 37/13/2013 continue to C/O to 8850 ft. pump dry job. POOH with BHA#5 00:00 07:00 7.00 8,766 8,810 COMPZ WELLPF DRLG P continue to drill out fill from 8766 ft to 8880 ft with bit BHA. @ 6 BPM @ 2250 psi..80 RPM's @ 3300 torque. ROP 7-9 FPH. recovering formation sand and shale 07:00 12:00 5.00 8,810 8,849 COMPZ WELLPF DRLG P Crew change-drilled through tight spot @ 8815'-right at connection, P/U 35K over. Came free, backream area,clean weight-Continue to drill out fill.6 BPM @ 2240 psi, RPM 80 @ 3320K torque, Roughly 7 fph. Returns are 80%shale,20%sand& light scale. 12:00 13:00 1.00 8,849 8,850 COMPZ WELLPF DRLG P ROP dropped off to 2 fph, no collar in area, call town to discuss TD. No improvement on ROP-Decision made to call TD 8850' Page 14 of 19 • Time Logs N. Date ry3Eroin ° To bur= S. Depth-h E.Depth Phase Code Subcode T Comment 13:00 15:00 2.00 8,850 8,819 COMPZ WELLPF JAR T Circ B/U&drift drilled section from 8733'to TD. Drifted through tight spot @ 8815-clean-broke connection while BHA stuck with P/U next stand. Cannot get jars to fire or bumper sub travel.-pumping 6 bpm, 100%returns. Continue to work pipe -no luck max. P/U 275K, Down 75K. Max torque 7K. Worked free-no pumps, sat down into, let it relax,worked pipe, broke over. P/U,stop 1 joint up, check weights and string torqued up again. Work area before making break. Overpull again-free at 8781' 15:00 16:15 1.25 8,819 8,751 COMPZ WELLPF TRIP T Work up to 8751'-free weight& torque @ 8781'. Up weight 135K, down 107K. Break connection- break out single joint in the mousehole. kelly back up. 16:15 19:00 2.75 8,751 8,235 COMPZ WELLPF TRIP P Cycle pipe-spot Hi-visc pill across perfs,TOOH above perfs. Flow check, Pump dry job and drop 2 1/8" drift. 19:00 19:30 0.50 8,235 8,235 COMPZ WELLPF OWFF P monitor for flow 30 min's 19:30 00:00 4.50 8,235 445 COMPZ WELLPF TRIP P Trip out of hole with 6"bit assembly. 07/14/2013 ran 40 arm caliper I;og with CCL, GR. review log for liner top placement. Made up 4.5 L-80 IBTM liner with Baker HF-Lock hanger and ZXP packer. 00:00 00:30 0.50 445 0 COMPZ WELLPF TRIP P continue to POOH with BHA#5 inspect bit. Still in gauge missing one tooth. all teeth are roled. 00:30 01:30 1.00 0 COMPZ WELLPF OTHR P Broke down BHA and kicked out 01:30 03:00 1.50 0 COMPZ WELLPF NUND P Nu Dutch riser to run Caliper log 03:00 06:00 3.00 0 0 COMPZ WELLPF ELOG P PJSM: RU HES slick line to run Battery operated 40 arm caliper, CCL,GR log from 8700 ft to surface. 06:00 11:00 5.00 0 0 COMPZ WELLPF ELOG P PJSM-Pressure test-RIH with Slick Line memory. RIH 150 fpm. Log from 8700'to surface @ 50 fpm. 11:00 12:30 1.50 0 0 COMPZ WELLPF ELOG P Caliper had two broken fingers and clay/mud&light metal shavings lodged behind the centrilizers&bow springs. Download data-successful logging run,date shows good pipe around 7200'-7250'. Compare data logs with previous cement bond log-depth correction -8ft. 12:30 14:30 2.00 0 0 COMPZ WELLPF RURD P PJSM-Rig Down SLick line equipment, lay down Dutch riser. 14:30 23:00 8.50 0 900 COMPZ WELLPF PULD P PJSM-swap floor equipment. Reviewed caliper log for top setting depth and P/U 4.5"liner completion string.filling liner every 5 jts. Page 15 of 19 9 .,. - Date ...,,_ , From, To Dur S. Depth E.Depth Phase Code Subcode' T !T Comment �; 11'7,47k. 23:00 23:30 0.50 COMPZ WELLPF CIRC P circulated 14.5 bbls of 12.9#thru liner @ 2 BPM @ 140 PSi 23:30 00:00 0.50 COMPZ WELLPF OTHR P Change over equipment for Drill pipe 37/15/2013 RIH with 900 ft of 4.5 L-80 IBT liner.to 8850 ft. cemented in place with 28 bbls of G w/2#cemnet cement. set liner hanger and released from hanger reversed circ. 1.5 DP vol. begin TOOH with setting tool. 00:00 06:30 6.50 900 7,100 COMPZ WELLPF TRIP P Continue to RIH with 4.5 liner filling DP every 5 stands.Wt @ 6700 ft. Up=107K. Dn Wt 83 K. 06:30 10:00 3.50 7,100 8,850 COMPZ CASING RNCS P PJSM-Continue to TIH filling pipe every 5 stands. P/U stand 82', break top joint and install&drift 10'pup. Kelly up&TIH slowly and tag bottom 8851.58'. Up weight 138K/Down weight 95K. 10:00 12:00 2.00 8,850 8,850 COMPZ CEMEN-CIRC P Start conditioning hole from 8849'. Metal shavings,frac sand,visc pill& formation sand over shakers. Continue pumping until well cleans up. 1 BPM=830 psi 2 BPM=970 psi 3 BPM= 1100 psi 4 BPM= 1350 psi 12:00 14:00 2.00 8,849 8,849 COMPZ CEMEN-RURD P Nordic Crew change-PJSM for cement rig up and cement job with SLB. Rig up cement head and hard lines. 14:00 16:00 2.00 8,849 8,849 COMPZ CEMEN-CMNT P Begin pumping Cement job 5 bbls water-P-test 4000 psi. 10 bbls mud push, 13.7#2 BPM @ 900 psi- 27 bbls cement slurry 15.8#,45# cemnet(17bbls)2.5 bpm @ 915 psi Drop plug-good indication 6 bbls water-2 BPM @ 800 psi Switch to 12.8#mud,dart bumped up at 59 bbls,good returns- pressure up to 3000 psi @ 1.5 bpm. Pump additional 12bbls of displacement total 72 bbls, Shut in 2000 psi. Bleed off SLB,flush to cutting box. 16:00 18:00 2.00 8,849 7,950 COMPZ CEMEN'PACK P Nuetral weight-Rig pump-Pressure up on hanger to 3500 psi. Set down 50K, bleed off pressure, Set down additional 20K. Cycle twice. P/U to neutral weight-rotate 15 turns- 2500 psi torque. P/U 8ft over string weight to 147K- set down packer sheared @ 27K down. P/U weight 125K.to mark, rotate 20 RPM, set down 40K-Start pumping @ 4 bpm, increase to 8 bpm. P/U 30 ft-circ out cement. 8 BPM @ 3290 psi-full returns. Lay down Cement head. Page 16 of 19 Time Logs,,, '"r ;y ' Date From To Dur S. Depth E.Depth Phase Code Subcole T Comment H 18:00 18:30 0.50 7,950 COMPZ WELLPF OTHR P RD cement head, RD Schlumberger cementers 18:30 19:30 1.00 7,950 7,820 COMPZ WELLPF CIRC P Circulated 230 bbls @ 8 BPM ICP 3020 psi. FCP 3200 psi while reciprocating drill pipe above liner top @ 7950 ft 19:30 00:00 4.50 7,950 0 COMPZ WELLPF TRIP P Pump dry job. POOH with D/P and liner setting tool 07/16/2013 test BOPE 250/5000 psi. RIH with BHA#6.3 3/4"mill and 4.5"all weight scraper. cleaned out to 8790 ft from 8653'. getting back cement returns 00:00 02:30 2.50 0 0 COMPZ WELLPF OTHR P rinse out BOPE pull wear ring .set test plug. RU test line. 02:30 08:30 6.00 0 0 COMPZ WELLPF BOPE P Begin BOPE testing:Test Waived by Bob Noble AOGCC @ 18:45, 7/15/13.Test conponets 250/5000 psi,Annular 250/3500 psi.Test(1) Lower PR with 2 7/8 TJ ,choke 1. Pass. (2) Annular 2 7/8"test jt.Pass. (3)Uppers P/R's 2 7/8"TJ ,Choke HCR, Kil line pass. (4) Lowers P/R's 3.5 TJ. Pass. (5) Annular 3.5"T/J Pass. (6)UPR 3.5" T/J , Kill HCR, Choke Man. Pass. (7)Kill Man, CSO, Choke 4,11,12,3.5 IF Dart,TD Hyd. Pass. 8)CSO, Kill Man, Lower TD, 3.5 IF FOSV, Choke 3,7,9,10. Pass. (9) CSO, Kill Man,3.5 8 Rd FOSV, Choke 2,5,8, Pass. (10)CSO, Kill Man,choke 2,5,6, Pass. 08:30 09:00 0.50 0 0 COMPZ WELLPF OTHR P Pull test plug and set wear ring 09:00 18:00 9.00 0 8,653 COMPZ WELLPF TRIP P Pick up&RIH with 3 3/4"mill 864.59-ft of 2 7/8"Hydril 511 &3.5 D/P to 7,965-ft and set down 2k, PU and continue to RIH to 8,653-ft, Tagged cmt 18:00 00:00 6.00 8,653 8,790 COMPZ WELLPF CIRC P Bring pumps on line and circulate @ 6 BPM @ 3100-3300 psi.cleaned out to 8790 ft. 07/17/2013 Laid down work string. RU HES run Gyro log from 8800 to surface 00:00 01:30 1.50 8,790 8,800 COMPZ WELLPF DRLG P continue to clean out to 8800 ft mill torqued up.circulated well clean 01:30 02:30 1.00 8,800 7,860 COMPZ WELLPF PULD P laid down 30 jts drill pipe to 7860.tail out of liner @ 7950 ft. 02:30 03:30 1.00 7,860 COMPZ WELLPF PRTS P PT and record liner test of 3000 psi for 30 min's. Good test 03:30 16:00 12.50 7,860 COMPZ RPCOM PULD P continue to POOH laying down work string 16:00 17:30 1.50 COMPZ RPCOM OTHR P installed test plug washed BOPE 17:30 18:30 1.00 COMPZ EVALWE RURD P NU dutch riser 18:30 00:00 5.50 COMPZ EVALWE ELOG P RU HES Eline to run Gyro log from 8800 to surface. ,. Page 17 of 19 • Time Logs Date From To ;...Dur S.Depth E..-Depth Phase Code` '-Subcode. T Cor iment u: : 07/18/2013 24 hr Summary Perforated well from 8675-95 6SPF @ 60°phasing.set composite plug @ 8600'. RD Eline.test plug to 2500 psi. RIH with completion string.space out. 00:00 15:30 15.50 0 8,800 COMPZ PERF FLOG P continue to run Gyro log from 8800 ft to surface. Perforate from 8675-95 W/3 3/8" 6-SPF Millennium 60° phasing ,25 gr HMX EHD=.45". Set composite bridge plug @ 8600 ft (center of element)RD E-Line. 15:30 16:30 1.00 0 0 COMPZ PERF RURD P Pull dutch riser 16:30 00:00 7.50 0 7,961 COMPZ RPCOM PULD P PJSM, Prepare to RIH w/3-1/2 gas lift completion string as per run order.Engaged seals spaced out tubing.. Up WT.= 112K Dwn Wt.= 70K 37/19/2013 circulated mud from well and pump in treated brine. land tubing. ND BOPE. NU Tree and began testing tree. 00:00 03:00 3.00 7,950 COMPZ RPCOM CIRC P reverse circ.@ 5 BPM , ICP= 1875. 50 BBL hi-vis sea water pill, 100 bbls sea water 50 bbls Hi-vis. pill.sea water. 03:00 04:00 1.00 8,600 COMPZ RPCOM OWFF P Neg. PT test on CBP @ 8600 ft MD, 6503 TVD with sea water in the hole. Hydostatic=2908 PSI W/mud= 4362 psi.-1454 psi under balance fluid change. NF for 30 min's. PT to 2500 PSI 15 mins.Good test. 04:00 06:00 2.00 COMPZ RPCOM CIRC X Wait on sea water to continue to cleaning up mud from well. 06:00 09:00 3.00 COMPZ RPCOM CIRC P Continue to circulate with sea water to clean up 12.9 mud from hole. 09:00 11:00 2.00 COMPZ RPCOM CRIH P Change hole over to Cl 9.8 ppg brine 11:00 12:00 1.00 COMPZ RPCOM THGR P Locate seals w/charge pump on, drain stack and land hanger 12:00 16:00 4.00 COMPZ RPCOM PRTS P RU and PT TBG @ 2,500 psi for 15 minutes, bleed back to 1,500 psi. PT 2,500 psi for 30 minutes-Good test. Bleed off IA pressure and follow with TBG pressure. Pressure up on IA to 2,800 psi and shear out SOV. pump 5 bbls thru @ 2 bpm. PT OA @ 1,500 psi for 15 minutes-good test. Bleed off. RD test Equipment. 16:00 16:30 0.50 COMPZ WHDBO OWFF P Monitor well for flow-good. Pull landing jt. 16:30 17:00 0.50 COMPZ WHDBO MPSP P Install BPV-PT form below @ 1,000 PSI-Good Test 17:00 23:00 6.00 COMPZ WHDBO NUND P Pull Riser, ND Choke and Kill line. Open LPR's and inspect cavities- Good. ND BOPE. NU tree 23:00 00:00 1.00 COMPZ RPCOM PRTS P PT tree to 250/5000 psi. 07/20/2013 continue to test tree.freeze protect well RDMO 00:00 00:30 0.50 COMPZ RPCOM PRTS P continue to Pressure test tree to 5000 psi. Page 78 of i9 .. T1me Logs. _ 'Date From To Dur S. Depth E.Depth Phase Code : Subctide. T C mment nlil 00:30 01:00 0.50 COMPZ RPCOM MPSP P pull BPV 01:00 03:30 2.50 COMPZ RPCOM FRZP P RU LRS to pump 80 bbls of diesel down IA to freeze protect well. RD LRS. Let well equalize tubing/ casing 03:30 04:00 0.50 COMPZ RPCOM MPSP P Set BPV secured well.Tubing 0 psi. IA 0 psi OA 100 psi. 04:00 06:00 2.00 COMPZ RPCOM OTHR P Continue to clean pits--Rig released @ 06:00 hrs Page 19 of 19 • �S�O • GZ 30 -04 Rig Workover Rev 1 2 Pull 3- Completion, Cleanout to PBTD 3 3 Install 4 1 /2" Scab Liner & Run 3 1 /2" Completion l l g l 3 (PTD #: 188 -062) Current Status: This well has been shut in since May 2009. Well is secured with CA -2 plug set at 8514' RKB. Scope of Work: Pull the 3 -W' tubing, fish the AVA PBR/packer, cleanout to PBTD, run & cement a 4 ' /2" scab liner across the Kuparuk sands, and run a 3 1/2" gas lift completion. General Well info: Well Type: Producer MPSP: 2,195 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 4,177 psi / 6,445' TVD (12.5 ppg) from Panex gauges on 09/09/12 Wellhead type /pressure rating: Cameron Gen IV, 7- 1/16" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: CMIT -T x -IA, passed on 07/11/12 Earliest Estimated Start Date: June 30, 2013 Production Engineer: Mike Heumann / Suzanne Short / Toon Changklungdee Workover Engineer: Paul Chan (263 -4759 / pchan4 @conocophillips.com) Pre -Rig Work ��►l� 1. RU Slickline: SCANNED JUL 0 8 2013 a. Set catcher sub on top of CA -2 plug @ 8,514' RKB b. Pull dummy GLV from GLM #7 @ 8422' RKB and leave pocket open c. Pull catcher sub d. Pull CA -2 plug @ 8,514' RKB e. RIH w/ dual Panex gauges to 8600' RKB, obtain 30 min. SBHPS, pull uphole 100' TVD and obtain 15 min. gradient stop f. Isolate or lock out SSSV g. RDMO 2. Set BPV within 24 hrs of rig arrival Proposed Procedure 1. MIRU 2. Pull BPV. Circulate 12.8 ppg KWF. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 3. Set BPV and ND tree. NU BOPE & test. 4. Pull BPV, screw in landing joint, BOLDS's, un -land tubing hanger. 5. POOH laying down 3 -1/2" tubing. 6. MU spear & single in on drill pipe. Spear AVA PBR/packer and release packer. POOH standing back drillpipe. Lay down fish. 7. RIH with 7" casing cleanout assembly to at least 8880' MD and circulate the wellbore clean. POOH. 8. RU E -line: R111 w/ caliper and log from PBTD back to surface. 9. PU 4 -1/2" liner (w/ centralizers), 5" x 7" Flex -lock liner hanger, 5" x 7" ZXP liner top packer, running tool, and RIH on drill pipe to PBTD. 30 -04 Rig Workover Rev 1 • Pull 3 -' /2" Completion, Cleanout to PBTD Install 4 ' /2" Scab Liner & Run 3 1 /2" Completion (PTD #: 188 -062) 10. RU SLB cementers, establish circulation rate, pump 10 bbl spacer followed by —29 bbls Class G cement, drop wiper plug plug bumps. �8 er lu and chase w/ KWF until lu bum s. Pressure up to 3500 psi to set liner hanger at —8,300' RKB. Slack off 50K lbs to check hanger is set. 11. PU to expose rotating dog sub and slack off 45K lbs. to set ZXP packer. Pick up and circulate cement out of the hole until clean fluid returns. POOH and WOC. 12. PU liner cleanout assembly and cleanout 4-l/2" scab liner to landing collar. POOH LDDP. 13. RU e -line and perforate Kuparuk A sand from 8675' -8695' MD. POOH. Set 4 -', composite bridge plug at 8600' MD. POOH and RD e -line. 14. Single in w/ new 3-1/2" tubing to just above the SBE. Sting into SBE. space out 7' from fully located, mark pipe and pull out of SBE. 15. Swap the well over from 12.8 ppg mud to 9.8 ppg brine by reverse circulating at maximum rate. 16. Space out w/ pups, MU hanger. Load the IA with corrosion inhibited brine. Land the hanger, RILDS. 17. PT the tubing to 3,000 psi, bleed tubing to 2500 psi, PT the IA to 3,500 psi for 30 min and record. Bleed the tubing pressure to zero quickly to shear the SOV. 18. Pull the landing joint, install two -way check. 19. ND BOPE. NU tree and test. Pull BPV /dart. 20. Freeze protect through the SOV with diesel. Set BPV. 21. RDMO Post -Rig Work 1. Pull BPV 2. RU Slickline: a. Set a catcher sub b. Pull the SOV and replace with DV c. Pull catcher sub d. RDMO 3. Turn well over to operations • /% - s THE STATE Alaska Oil and Gas °f Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF e. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Paul Chan I a Workover Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 30 -04 Sundry Number: 313 -274 SCANNED JUN 1 3 2013 . Dear Mr. Chan: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Daniel T. Seamount, Jr. Commissioner DATED this) Zday of June, 2013. Encl. STATE OF ALASKA n A KA OIL AND GAS CONSERVATION COMMSION f,'L' �.,j ;t ;I I 3 013 s APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AO 1. Type of Request: Abandon I Rug for Redrill I — Perforate New Pool r Repair w ell I"4, • Change Approved Program i Suspend E Plug Perforations r Perforate r Pull Tubing jr . Time Extension E Operational Shutdown r Re -enter Susp. Well )"°" Stimulate f Alter casing 1— Other: 'cad lihQit. V 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: v ConocoPhillips Alaska, Inc. Development F.;• , Exploratory E 188 - 062. a 11 3 3. Address: Stratigraphic i Service ( 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21826 - 00 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes E No 9' 30 - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25513. Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 8984 .6785 8514' • 8718' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115' 115' SURFACE 5064 9.625 5099' 4029' PRODUCTION 8928 7 8961' 6769' Perforation Depth MD (ft): . Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3622 -8640, , 8653 -8669, 8675 -8698, 8710 -873( 6520 -6533, 6542 -6554, 6559 -6575, 6585 -6599 3.5 J - 8548 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - AVA'RHS' RETRIEVABLE PACKER • MD= 8477 TVD= 6414 SSSV - CAMCO TRDP SSSV • MD= 1829 TVD= 1738 12. Attachments: Description Summary of Proposal I • 13. Well Class after proposed work: Detailed Operations Program I BOP Sketch r Exploratory I Stratigraphic r Development F.7 ` Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/30/2013 Oil )✓ • Gas h WDSPL F Suspended r 16. Verbal Approval: Date: VVINJ E GINJ Is WAG I Abandoned E Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Paul Chan @ 263 -4759 Email: Paul. Chan @contractor.conocophillios.com <29( Printed Name Paul Chan Title: Workover Engineer Signature Phone: 263 -4759 Date . ,/ 3 / /,J Commission Use Only Sundry Number:. i 1 q Conditions of approval: Notify Commission so that a representative may witness Plug Integrity P BOP Test '' ^ Mechanical Integrity Test L Location Clearance E RBDAS JUN 13 2O1 . Other: /3 ) P te t- /-o 3.00 C.7 p S , Spacing Exception Required? Yes ❑ No [( Subsequent Form Required: 1 0 — 4_6 /r APPROVED BY C/(2/1-3 I N th OT val. Date: Approved by: App ovcd application is vaRa the f em 0 Form 10 -403 (Revised 10/2012) S Submit Form and Attachments in Duplicate , ` 1 ), v> 14,/-- 0 R I G i' ; :, A • ::■n D ConocoPhillips 4 0,;# i.e. 0 ,. r. Alaska f t.; v :0' P.O. BOX 100360 b ANCHORAGE, ALASKA 99510 - 0360! ��,"` May 30, 2013 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover Kuparuk Well 30- 04 (PTD# 188 -062). Well 30 -04 was drilled in 1988 and completed as a 3 -'/2" simple gas lifted completion. The 7" production casing appears to be damaged as rocks were recovered in January 2005 during a slickline brush run. The well continued to produce normally until May 2009 when the rock and fill production became problematic and the well was shut -in. The purpose of the workover is to remove the 3 -'h" tubing and packer, cleanout the wellbore to PBTD at ±8880' MD, and run & cement a 4 ''/2" scab liner across the Kuparuk A and C sands. The well will be completed with a 3- ' /2" gas lifted completion. If you have any questions or require any further information, please contact me at 263 -4759. Sincerely, CL Paul Chan Workover Engineer CPAI Drilling and Wells • • 30 -04 Rig Workover Pull 3-Y2" Completion, Cleanout to PBTD Install 4 1 /2" Scab Liner & Run 3 1 /2" Completion (PTD #: 188 -062) Current Status: This well has been shut in since May 2009. Well is secured with CA -2 plug set at 8514' RKB. Scope of Work: Pull the 3 -' /2" tubing, fish the AVA PBR/packer, cleanout to PBTD, run & cement a 4 'h" scab liner across the Kuparuk sands, and run a 3 ' /2" gas lift completion. General Well info: Well Type: Producer MPSP: 2,195 psi using 0.1 psi/ft gradient Reservoir Pressure /TVD: 4,177 psi / 6,445' TVD (12.5 ppg) from Panex gauges on 09/09/12 Wellhead type /pressure rating: Cameron Gen IV, 7- 1/16" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: CMIT -T x -IA, passed on 07/11/12 Earliest Estimated Start Date: June 30, 2013 Production Engineer: Mike Heumann / Suzanne Short / Toon Changklungdee Workover Engineer: Paul Chan (263 -4759 / pchan4 @conocophillips.com) Pre -Rig Work 1. RU Slickline: a. Set catcher sub on top of CA -2 plug @ 8,514' RKB b. Pull dummy GLV from GLM #7 @ 8422' RKB and leave pocket open c. Pull catcher sub d. Pull CA -2 plug @ 8,514' RKB e. RIH w/ dual Panex gauges to 8600' RKB, obtain 30 min. SBHPS, pull uphole 100' TVD and obtain 15 min. gradient stop f. Isolate or lock out SSSV g. RDMO 2. Set BPV within 24 hrs of rig arrival Proposed Procedure 1. MIRU 2. Pull BPV. Circulate 12.8 ppg KWF. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 3. Set BPV and ND tree. NU BOPE & test. 4. Pull BPV, screw in landing joint, BOLDS's, un -land tubing hanger. 5. POOH laying down 3 -' /2" tubing. 6. MU spear & single in on drill pipe. Spear AVA PBR/packer and release packer. POOH standing back drillpipe. Lay down fish. 7. RIH with 7" casing cleanout assembly to at least 8880' MD and circulate the wellbore clean. POOH. 8. RU E -line: RIH w/ caliper and log from PBTD back to surface. 9. PU 4 -1/2" liner (w/ centralizers), 5" x 7" Flex -lock liner hanger, 5" x 7" ZXP liner top packer, running tool, and RIH on drill pipe to PBTD. • • 30 -04 Rig Workover Pull 3-Y2" Completion, Cleanout to PBTD Install 4 1 /2" Scab Liner & Run 3 1 /2" Completion (PTD #: 188 -062) 10. RU SLB cementers, establish circulation rate, pump 10 bbl spacer followed by —29 bbls Class G cement, drop wiper plug and chase w/ KWF until plug bumps. Pressure up to 3500 psi to set liner hanger at —8,300' RKB. Slack off 50K lbs to check hanger is set. 11. PU to expose rotating dog sub and slack off 45K lbs. to set ZXP packer. Pick up and circulate cement out of the hole until clean fluid returns. WOC. 12. Swap the well over from 12.8 ppg mud to 9.8 ppg brine by reverse circulating at maximum rate. 13. POOH laying down drillpipe and liner running tools. 14. Single in w/ new 3 -1/2" tubing to just above the SBE. Sting into SBE, space out 7' from fully located, mark pipe and pull out of SBE. 15. Space out w/ pups, MU hanger. Load the IA with corrosion inhibited brine. Land the hanger, RILDS. 16. PT the tubing to 3,000 psi, bleed tubing to 2500 psi, PT the IA to 3,500 psi for 30 min and record. Bleed the tubing pressure to zero quickly to shear the SOV. 17. Pull the landing joint, install two -way check. 18. ND BOPE. NU tree and test. Pull BPV /dart. 19. Freeze protect through the SOV with diesel. Set BPV. 20. RDMO Post -Ri2 Work 1. Pull BPV 2. RU Slickline: a. Set a catcher sub b. Pull the SOV and replace with DV c. Pull catcher sub d. RDMO 3. Turn well over to operations • • Conoco Phillips Well: KRU 30 -04 Proposed Completion 1 )1Ds Id • 3- DS 2.875" Profile @ —500' MD 16" 62.5# H-40 to 115' MD 4 3 -'/2' 9.3 # /ft L -80 EUE 8rd -mod tubing 9 -5/8" 36# J -55 to 5,099' MD _ 4 3 -1/2" MMG GLM • 3 -1/2" MMG GLM 4 3 -1/2" MMG GLM • 3 -1/2" MMG GLM • 3 -1/2" MMG GLM os V • 3 -' /z" DS 2.813" Profile a Baker ZXP Liner Hanger /Liner Top Packer II.VEiEl Baker Seal Assembly Baker 80 -40 SBE 4 - 4-'/2" L -80 Scab Liner I t 7" 26# J -55 shoe at 8,961' MD KU P ID 30 -04 Conoc $ Well Attributes Max Angle & MD TD Alaska Inc, Wellbore APW WI Field Name Well Status Inc! ( °) MD (ftKB) Act Stn, (ftKB) 500292182600 KUPARU KRIVERUNIT PROD 51.60 2,600.00 8,984.0 • '"" Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date - - wau co, - - sno1zo131:aan PM SSSV:TRDP 150 1/16/2009 Last WO: 40.00 7/9/1988 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,668.0 9/8/2012 Rev Reason: WELL REVIEW osborl 5/20/2013 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 33 CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H - 40 Welded Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd - SURFACE 95/8 8.921 35.0 5,099.2 4,029.0 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 33.0 8,961.3 6,768.7 26.00 J -55 BTC CONDUCTOR, Tubing Strings 35-115 Tubing Description String 0... String ID ...Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING ( 3 1/2 2.99 33.0 8,548.6 6,466.2 9.30 I J -55 EUE 8rd MOD Completion Details Top Depth SAFETY VLV, (TVD) Top Inc! Nomi... 1,829 � - Top (ftKB) IRKS) (°) Item Description Comment ID (in) 33.0 33.0 0.18 HANGER CI W HANGER & 4' PUP 2.992 1,829.1 1,737.6 34.83 SAFETY VLV CAMCO TRDP SAFETY VALVE 2.812 GAS LI,070 FT, 8,463.2 6,404.0 43.42 LOCATOR AVA LOCATOR SUB 3.000 3 8,463.7 6,404,4 43.42 PBR AVA HYDRAULIC RELEASE PBR 3.000 8,476.8 6,413.9 43.36 PACKER AVA 'RHS' RETRIEVABLE PACKER 3.000 8,514.0 6,441.1 43.35 NIPPLE CAMCO D NIPPLE 2.750 8,547.9 6,465.7 43.27 SOS AVA SHEAR OUT SUB - TTL ELMD 8531' ON SWS LOG 7/8/1998 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) SURFACE, Top Depth 35 -5,099 (TVD) Top Inc! Top(ftKB) (RKB) (°) Description Comment Run Date ID(in) GAS LIFT, 8,514.0 6,441.1 43.35 PLUG 2.75" CA -2 PLUG 9/14/2012 0.000 5,295 8,718.0 6,590.4 43.24 FISH 10 Fired Strip Left in Hole 5/6/1989 U Perforations & Slots GAS LIFT, Shot 6,587 Top (TVD) Btm (TVD) Dens ill Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (oh... Type Comment 8,622.0 8,640.0 6,519.7 6,532.9 C C - 1, UNIT 5/7/1989 12.0 IPERF 21/8" EnerJet, 60 deg. phasing GAS LIFT, B, 30 IC 7,205 8 ,6530 8,669.0 6 ,542.4 6,554.1 A -3, 30-04 5/7/1989 12.0 IPERF 2 1/8" EnerJet, 60 deg. phasing 8,675.0 8,698.0 6,558.5 6,575.3 A -2, 30-04 5/7/1989 12.0 IPERF 2 1/8" EnerJet, 60 deg. phasing GAS LIFT, - 8,710.0 8,730.0 6,584.6 6,599.1 A -1, 30-04 9/25/1988 8.0 IPERF 4 1/2" HSD Csg Gun, 45 deg. 7,634 phasing Notes: General & Safety GAS LIFT, End Date Annotation 6,026 - 7/10/1994 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 9/8/2003 NOTE: 31" Surf CSG Patch covering hole located 32' below OA valve. GAS LIFT, t - 5/18/2009 NOTE: View Schematic w/ Alaska Schematic9.0 8,422 t LOCATOR, 8,463 PBR, 8,464 PACKER, 8,477 III y a NI PPLE, ry/ / S PLUG, 11,: �� / /J SOS, 8,548 IPERF, 8,622-8,640 IPERF, I 8,653 -8,889 IPERF, 6,675 -8,698 Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run N... Top (ftKB) (ftKB) 1 Make Model On) Sery Type Ty 1 (psi) Run Date Corn... IPERF, 1 3,070.0 2,579.9 45.35 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/10/2012 8,710 -8,730 2 5,295.3 4,170.3 44.06 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/10/2012 FISH, 8,718 3 6,586.9 5,074.6 46.08 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/10/2012 4 7,205.3 5,513.7 45.44 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 7/112012 5 7,633.9 5,814.5 45.24 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 10/5/2003 6 8,027.5 6,091.7 44.99 MMH FMH0 1 GAS LIFT DMY BK 0.000 0.0 10/3/2003 7 8,421.6 6,373.8 43.62 OTIS LBX 1 12 GAS LIFT DMY RM 0.000 0.0 8/12/1997 PRODUCTION, 33-8,961 A • TO, 8,984 Ferguson, Victoria L (DOA) From: Chan, Paul (Petrotechnical Resources of Alaska) < Paul. Chan ©contractor.conocophillips.com> Sent: Monday, June 10, 2013 8:52 AM To: Ferguson, Victoria L (DOA) Subject: RE: 30- 04(PTD 188 -062, Sundry 313 -274) Victoria Yes, the well will be perforated and fracture stimulated. The Sundry for that operation will be submitted separately. Thanks Paul Chan Workover Engineer ConocoPhillips Alaska (907) 263 -4759 (907) 444 -2881 (c) From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson @alaska.gov] Sent: Thursday, June 06, 2013 2:30 PM To: Chan, Paul (Petrotechnical Resources of Alaska) Subject: [EXTERNAL]30- 04(PTD 188 -062, Sundry 313 -274) Paul, After you run and cement the 4 -1/2" liner across the Kuparuk sands do you plan to perforate? Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferqusonCa)alaska.gov 1 • • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] r e f6 [21/0 Sent: Monday, December 27, 2010 4:27 PM I ` f To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 30 -04 (PTD 188 -062) Report of suspect TxIA communication Attachments: 30 -04 schematic.pdf Tom, Jim, Guy Kuparuk gas lifted producer 30 -04 (PTD 188 -062) has suspected TxIA communication as indicated by the well pressure trends. Currently the well is SI and is to remain SI while awaiting a RWO. The plan forward is to troubleshoot the GLV's to restore integrity. If that is unsuccessful, ewell will be secured with a TTP. Attached is a schematic and a 90 day TIO plot. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 4 , ¢a 2.0V+ 12/28/2010 KRU 30 -04 PTD 1880620 12 -27 -10 TIO Pressures Plot TRN_ANNL ANNULUS PRESSURE TRENDS TRtLANNI -INIT 500' SC WELL NAME WLRRU30 -04 f1111 3000 200. ; 3000. 2700 mar lir 3000 „ °3000. 3000. 2400 3000. I 2100 - • AAAAA AA4 1800 .. i 1500 1200 ,, 900 - = t� _ Vitt 600 _ ,- 1► .- 1A ..' ' - r� AA1 O. AAA ' llill #A 1 1► ► /11 /1' ifs- '�'4-k / 111 ►/ 300 \ ♦[ :________ r11 /1a r Y/1 L • •111 n 0 " PLOT START TIME MINOR TIME PLOT DURATION PLOT END TIME 28- SEP -10 16:00 MAJOR TIME WEER_'' i «? HRS ' PICK TIRE: 7 - DEC 10 15:46:52 7D •011 • SC TAG HAKE DESCRIPTION P- -VALUE LATEST - WL30 -04 -CHOKE FLOW TUBING CHOKE 7777777 PREY WELL DRILLSITE WELL IIII SCRATCH 34 FLOW TUBING PRESSURE 7777 ?7? 30 ` 0 4 IN SCRATCH_34 FLOW TUBING TEMP 7777777 NEXT WELL III AI- P305002 -04 GL CASING PRESSURE 7777777 - 7777777 ENTRY TYPE OPERATOR - 7777777 ME OPERATOR VERIFIED iii SCRATCH_34 INNER ANNULUS PRES 7777777 PRR SYSTEM AUTO ENTRY III SCRATCH_34 OUTER ANNULUS PRES 7777777 FIR BOTH KUP 30 04 /^ ry � a oPhi ps WeICJt trlb� P4-- ,, . , MaxAngle 8i ML1 r 7 . Alas" I Weltbore APIIUWI Fi eld Name Well Status Inca (°) MD (ftKB) Act Bt. (ftKB) caac eisps 500292182600 KUPARUK RIVER UNIT PROD 51.60 2,600.00 8,984.0 r Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date well conng: - 30 - 94 n9/3912919 a33.*8 PM SSSV:TRDP 150 1/16/2009 Last WO: 40.00 7/9/1988 = Sehem t :- Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,640.0 10/13/2010 Rev Reason: TAG Imosbor 10/30/2010 ,� "" Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt . Sring ... Sving Top Thrd HANGER. 3a CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 Welded g o Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 35.0 5,099.2 4,029.0 36.00 J - 55 BTC : Casing Description Sting 0... Stning ID ... Top (ftKB) Set Depth (f... Set Depth (WD(... String Wt... String ... string Top Thrd - PRODUCTION 7 6.151 33.0 8,961.3 6,768.7 26.00 J -55 BTC 'Cubing Strings j i,+ ,,,'- ,` CONDU OR, ' - ar ` " Tubing Description St ing 0... String ID ... Top (91(8) Set Depth (f... Set Depth (TVD) ... String Wt... St g .. String Top Thrd TUBING 3 1/2 2.992 33.0 8,548.6 6,466.2 9.30 J-55 EUE 8rd MOD tra }mpletion " ta` s ; . , - _ , pi 7: T p Depth SAFETY VLV, �'✓ (TVD) Top Intl Nomi... 1,829 1 / Top (ftKB) OMB) r) Item Description Comment ID Un) 33.0 33.0 0.18 HANGER CIW Hanger & 4' Pup 2.992 1,829.1 1,737.6 34.83 SAFETY VLV CAMCO TROP SSSV - 2.812" ID 2.812 GAS LIF,970 T, 6,463.2 6,404.0 43.42 LOCATOR AVA Locator Sub 3.000 3 0 8,463.7 6,404.4 43.42 PBR AVA Hydraulic Release PBR 3.000 8,476.8 6,413.9 43.36 PACKER AVA 'RHS' Retrievable Packer 3.000 8,514.0 6,441.1 43.35 NIPPLE CAMCO 'D' Nipple 2.750" ID 2.750 8,547.9 6,465.7 43.27 SOS AVA Ball Seat Shear Out Sub - TTL ELMD 8531' ON SWS LOG 2.992 7/8/1998 Otherin Hole ° reline retrievab a plug& va s h, ets = ' , SURFACE, ° 35.5,099:- Top Depth (WO) Top In el GAS LIFT, Top (ftKB) (ft(B) V) Description Comment Run Date ID (In) 5,295 8,718.0 6,590.4 43.24 FISH 10' Fired Strip Left in Hole 5/6/1989 GAS LIFT, Shot 6,587 Top (TVD) Btm (TVD) Dena Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (e Type Comment 8,622.0 8,640.0 6,519.7 6,532.9 C-4, C -1, UNIT 5/7/1989 12.0 IPERF 2 1/8" EnerJet, 60 deg. phasing B, 30 -04 GAS LIFT 4 6,554.1 A-3, 30-04 5/7/1989 12.0 IPERF 2 1/8" EnerJet, 60 deg. phasing 7.205 8 , 653 .0 8,669.0 6,542. 6,55 9 g 8,675.0 8,698.0 6,558.5 6,575.3 A -2, 30 -04 5/7/1989 12.0 IPERF 2 1/8" EnerJet, 60 deg. phasing GAS LIFT, 8,710 8,730.0 6,584.6 6,599.1 A -1, 30 -04 9/25/1988 8.0 IPERF 4 1/2" HSD Csg Gun, 45 deg. 7,634 - phasing Notes: General Safety i End Date Annotation 6,028 GAS LIFT, e- 7/10/1994 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 9/8/2003 NOTE: 31" Surf CSG Patch covering hole located 32" below OA valve. 5/18/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, 1 8,422 f LOCATOR, I I la , 8,463 PBR, 8,464 PACKER, 8.477 NIPPLE, 8,514 '® SOB, 8.548 SO IPERF, 8,622 -8,640 IPERF, 8,653 -8,669 PERF, 8,675-8,898 1.'':. _ a " S ' Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run ® ' >LL _ Stn Top (ftKB) (ftKB) r) Make Model (in) Sery Type Type (in) (psi) Run Date Com... IPERF, 1 3,070.0 2,579.9 45.35 McMu... FMHO 1 GAS LIFT GLV BK 0.125 1,296.0 1/3/2004 8,710 - $730 . 2 5,295.3 4,170.3 44.06 McMu_. FMHO 1 GAS LIFT GLV BK 0.188 1,371.0 1/3/2004 FISH, 8,718 3 6,586.9 5,074.6 46.08 McMu... FMHO 1 GAS LIFT GLV BK 0.250 1,476.0 1/3/2004 � 4 7,205.3 5,513.7 45.44 McMu... FMHO 1 GAS LIFT OV BK 0.188 0.0 1/2/2005 5 7,633.9 5,814.5 45.24 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 10/5/2003 € 6 8,027.5 6,091.7 44.99 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 10/3/2003 7 8,421.6 6,373.8 43.62 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 8/12/1997 PRODUCTION, 33 -8,961 TD, 8,984 C~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Down Hole Video: 30-04 Run Date: 3/13/2010 • March 18, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 30-04 Digital Video File (AVI) 50-029-21862-00 1 DVD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax:907-273-3535 rafael.barreto ~ ~ ; ~~ Date: ~~AR ~. ~) 2010 ~~~ d ' G/ ~~ ! l Signed: ~ ~ h°_~ t.' a opt ,~ . . ~ ~ _,.:, 1 ~ ~:.f _ __ ria. PreoAc~rive Diarinosrc S~es, livc. • • W~LL L~~ T'R~4/V5'lV1fTT.~4L To: A~C Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/ Mechanical Logs and /or Tubing fnspection(Caliper / MTT) The technica) data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 j Caliper Report 04-0ct-09 30-04 1 Report / EDE 50-029-21826-00 2) ~~-D~o ~ ~~~~.. h ~1°n :~ ~ v ~~~~ ~~s~+~~~~1 ~ ~~~s~ Signed : r Date : . . . Print Name: PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUtTE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-AMIL _.,._._. ~, _.~. r_ .- -_n.. ___~. WEBSITE : ~__ _ _._~ _._ _ __ . ____W C:`~.Dceimients and Settii~s\OwnerDesktop~'Cran~zuif_Conow.decx ~ ~ S Memory Mufti-Finger C~liper Log Results Summary Company: ConocoPhillips Qlaska, Inc. Well: 30-04 Log Date: October 4, 2p09 Field: Kuparak Log No. : 10596 State: Alaska Run No.: 1 API No.: 50-029-21826-00 Pipe1 Desc.: 3.5" 9.3 Ib. J-~5 EUE 8RD MOD Top Log Intvl1.: Surtace Pipe1 Use: Tubing Bot. Log Intvl1.: 8,548 Ft. (MD} Pipe2 Desc.: 7" 26 Ib. J-55 Top Log Intvi2.: 8,548 Ft. (MD) Pipe2 Use: Production Casing Bot. Log lntvl2.: 8,608 Ft. (MD) Inspection Type : Corrosive 8 Mechanical Damage lnspection ~ COMMENTS : ' This caliper data is tied into the AVA Shear Out Sub @ 8,548' (Qriller's Depth). This log was run to assess the condition af the tubing and production casing with respect ta corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing is in good to fair condition, with a ' maximum wall penetration of 25% recorded at an isolated pit in joint 242 (7,895'). Recorded damage appears as isolated pitting and shallow corrosion. No significant areas of cross-sectional wafl loss or I.D. restrictions are recorded. The caliper recordings indicate slight to moderate buckling, increasing in severity with depth, from -2,500' to -8,460'. ~ The caliper recordings indicate the 7" produc#ion casing logged is in poor condition with respect to corrosive and mechanical damage, with a maximum recorded wall penetration of 51% recorded at an isolated pit in joint 2(8,605'). Recorded damage appears as isolated pitting and general corrosion throughout the ~ production casing logged. No significant areas of cross-sectional wall loss or l.D. restrictions are recorded throughout the production easing logged. 3.5" TUBING - MAXIMUM RECCIRDED WALL PENETRATIONS: ' Isolated pitting ( 25%) Jt. 242 @ 7,895 Ft. (MD) Isolated pitting { 22%) Jt. 236 @ 7,670 Ft. (MD) Isolated pitting ( 20°/a) Jt. 233 ~ 7,594 Ft. (MD) ' No other significant wall penetrations (> 18%) are recorded. 3.5" TUBING - MAXIMUM RECORDED CROSS-SECTIUNAL METAL LOSS: No significant areas of cross-seetional wall loss (> 3%} are recorded. 3.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.D. restrictions are recc~rded. 7" PRODUCTION CASING - MAXIMUM RECC?RDED WALL PENETRATIONS: Isolated pitting ( 51%) Jt. 2 @ 8,605 Ft. (MD) Isolated pitting ( 42%) Jt. 1 ~ 8,575 Ft. (MD) 7" PRODUCTION CASING - MAXIMUM RECORDED CROSS-SEC'~ONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 11 %) are recorded throughout the production casing logged. f'roActive Diagnostic Services, Inc. ~` P.~. Box 1369, Staffor~i, TX 77497 Phone: (281) or (888} 565-9(785 Fax: (281) 565-1369 E-mail; PDS@memorylog.cam Prudhoe Bay Field {~ffice Phone: (907) 6Sg-230? Fax: (~07} 659-231 a ~~~ -v~a ~ ~ ~-~~ ' ~ • ' 7" PRODUCTION CASING - MAXIMUM RECORDED ID RESTRJCTiONS: ~ No significant I.D. restrictions are recorded throughout the production casing logged. ' ~ ~~ ~ ~~ ' Field Engineer. G. Etherton Analyst: C. Wa/drop Witness: C. Kennedy ProActive Diagnostic Services, Inc. ( P.O. Box 1369, Staffor~~, TX 7749? Phone: (281) or (888j 565-9Q85 Fax: (281) 565-1369 E-mai(: PDSCi~memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907} 659-2314 I ' ~ ~ ~ Correlation of Recorded Damage to Borehole Profile , Pipe 1 3.5 in (0.1' - 8551.2') Well: 30-04 Pipe 2 7. in (8551.2' - 8586.9') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: October 4, 2009 ^ A pprox. Tool D evia6on ^ A pprox. Boreho le Profil e 3 785 1598 2434 GLM 1 3248 0 < G 4058 .. ~ c . s - . a 4864 ~ GLM 2 5673 GLM 3 6482 GLM 4 7304 GLM 5 GLM 6 8129 GLM 7 2 8587 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degre es) Bottom of Survey = 2 1 25 50 75 .~. ~ ~ 100 ~ 125 ~ E ~ Z a 150 175 225 „_ ~ 250 _ 1 ~ ~ PDS Report Overview ~-1 ~,.. Body Region Analysis Well: 30-04 Survey Date: October 4, 2009 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Norn. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 EUE 8RD MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 250 2~~ 150 100 50 ~ 0 to 1 to 10 to 1%, 10% 20% ZO to 40 to over 40% 85% 85% Number of ~oints anal se d total = 263 pene loss . 0 210 51 225 38 0 2 0 0 0 0 0 Damage Configuration ( body ) 20 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of'oints dama ed total = 1$ 17 1 0 0 0 Damage Profile (% wall) ~ penetration body „u,,;k rnetal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 GlM 7 Bottom of Survey = 261.1 Analysis Overview page 2 ~ • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf )-55 EUE 8RD MOD Well: 30-04 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhiliips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 4, 2009 Joint No. Jt. Depth (Ft) Pt~n. lJEnc~i Iln~.) Pen. Body (Ins.) Pc~n. %> ~1rt,~l loss `;~, Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 0 0 0.02 9 t 2.95 PUP 1 3 (1 0.01 4 1 2,91 2 37 tt A 9 1 .9 3 70 u 0.01 (~ I 2.90 4 102 U 0.01 t~ 1 2.90 5 135 O 0.0 ~3 I .90 6 168 ~~ 0.01 4 1 2.91 7 200 ~~ 0.02 7 1 2.91 8 233 U 0.01 ~1 U 1 9 2 5 l~ 0.02 ~a 1 2.91 10 298 u 0.03 li1 I 2.91 11 330 ~) 0.02 f~ I .91 12 363 i> A '1 I .9 13 396 i~ 0.01 b U 292 14 428 ~~ 0.01 -1 I 2.91 5 461 t~ 0.01 5 1 2 90 6 493 U 0.01 ~~ ~ ~ .9 U 526 U 0.01 5 I 2.91 18 558 i~ 0.01 5 I .91 19 590 c~ 0.01 ~ I 2.91 20 62 ~~ 0.02 ~~ I 2.91 21 655 U 0.01 i I 2.92 22 688 t~ 0.01 5 ' 2.92 23 720 U 0.02 - 1 2.91 4 7 3 n OA 9 I 9 25 785 ~~ 0.01 4 I 2.91 2 818 U . 1 5 1 .91 2 7 850 U 0.01 4 1 2.91 28 883 ~) 0.01 4 I 2.91 29 915 ~~ 0.01 4 I 2.91 30 948 ~ ~ 0.02 ~~ 1 .90 31 981 i~ 0.01 ~i I 2.91 32 1013 u 0.03 11 ' 2. 1 3 1046 t 1 0.01 (~ I 2.91 34 1078 (1 0.02 7 3 2.92 35 1111 t) 0.01 4 ~3 2.92 36 1143 U 0.02 (3 I 'L.91 37 1176 u 0.02 7 I .93 38 120 ~~ 0.0 ~) I .91 39 1241 ~~ OA ~) 1 2.92 40 1 73 t~ 0.02 ti I .91 41 1305 ~) 0.03 1 Z ' 2.90 42 1 38 U 0.02 8 ' .90 43 1370 u 0.01 a ~ 2.92 44 1403 l1 0.03 1 U 1 91 45 1435 ~~ 0.01 6 1 2.91 46 1468 U 0.01 (i 1 .91 47 1501 ~? 0.01 b I 2.91 48 1533 0.02 `~ I .91 49 1566 0.02 ts I 2.91 Penetration Body ~ Metal Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEEf Pipe: 3.5 in 9.3 ppf J-SS EUE 8RD MOD Well: 30-04 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 4, 2009 Joint No. Jt. Depth (Ft.) I'en. I lF,~~~t (In..) Pen. Body (Ins.) Nc~n. °4, ti1c~t,il I r~s. ~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 50 1598 t~ 0.02 t~ I 2.90 51 1631 t t 0.02 '~ 1 2.90 52 1663 O 0.01 i U 2.92 53 1696 ~~ 0.02 t3 ~~ 2.92 54 172 8 ~~ 0.02 ~? 2.91 55 1761 !~ 0.01 ~1 1 2.93 55.1 1793 ~~ 0.01 -1 i; 2.96 PUP 55.2 1804 ~~ 0 l1 !~ 2.£31 Camco TRDP SSSV 56 1815 t? 0.02 ~~ I 2.41 57 1848 U 0.03 1 U U 2.91 58 1881 t ~ 0.01 6 ~~ 2.90 59 1913 ~~ 0.01 5 ~) 2.91 60 1946 ~? 0.02 ~~ I 2.89 61 1978 !~ 0.0 t~ I 2.91 62 2011 t) 0.01 5 I 2.90 63 2043 ~~ 0.03 1 1 ! .88 64 2076 U 0.0 7 i .90 6 2108 U Q03 1 U I 2.91 66 141 O 0.03 11 I 2.90 67 217 ~ 1 0.01 5 1 2.91 68 2206 U 0.02 8 1 2. 0 69 2239 ~~ 0.02 8 I 2.90 70 2271 ~? 0. 1 4 ~J 2.90 71 2304 u 0.01 5 I 2.90 72 ` 3" 6 ~', 0.01 t~ I "2.90 73 2369 ~~ 0.02 - I 2.90 74 2402 i~ 0.02 ti I 2.92 75 2434 !) 0.01 5 1 2.89 76 2466 c? 0 02 t~ I 2.91 77 2500 tl 0.02 9 1 2.94 Sli ht BucMin . 78 531 U 0.03 12 1 2.88 79 2563 ~? 0.02 7 1 2.92 80 2596 ~~ 0.03 12 1 2.87 81 2629 u 0.02 8 U 2.91 82 2661 O 0.02 ~) U 2.90 83 2694 ~) 0.02 £3 I 2.93 Sli ht Bucklin . 8 2726 U 0.02 t~ I 2.91 $ 2759 U 0.02 9 I 2.88 86 2792 i~ 0.02 £3 1 2.92 87 2823 U 0.02 9 (1 2.89 88 2854 U 0.01 4 u 2.90 89 2887 ~~ 0.02 9 ? 2.87 Sli ht Bucklin . 90 2919 ~~ D.O1 5 ' 2. 9 91 2952 ~~ 0.02 t3 ' 2.89 92 2984 !~ 0.02 9 I 2.90 93 3017 ~? 0.02 S I 2.88 93.1 3050 U 0 0 U N A GLM 1 Latch ~ 1030 94 3056 U 0.03 1 Z 1 2.87 95 3089 U 0.01 5 3 2.88 Sli ht Bucklin . 96 3121 tl 0.04 1~ I 2.89 Shallow ittin . Penetration Body Metal Loss Body Page 2 ' ~ ~ PDS REPORT )OINT TABULATION SHEET Pipe: 3.5 in 93 ppf )-55 EUE SRD MOD Well: 30-04 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Norninal I.D.: 2.992 in Country: USA Survey Date: October 4, 2009 Joint No. Jt Depth (Ft.) f'c~n. i Jp,~~i Iln..~ Pen. Body (Ins.) Pen. %, 'vlc~ial I oss °~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 97 3154 ! a 0.02 8 I 2 88 98 3186 c~ 0.02 9 1 2.88 99 3215 ~) O.D1 i t) 2.89 100 3248 ~' 0.02 ~~ ~ ~ 2.89 101 3281 ~~ 0.02 t; I 2.87 102 3312 t~ 0.02 ~J 1 2.90 Sli ht Bucklin . 103 3345 ~} 0.01 5 1 2.87 104 3377 U 0.03 1 U 1 2.87 105 3410 ~~ 0.02 9 I 2.88 106 3443 ~~ 0.01 6 ~ ~ 2.88 107 3475 ~~ 0.02 7 i ~ 2.89 108 3508 ~~ 0.02 fs I 2.90 Sli ht t3uckli 109 3540 ~~ 0.02 t3 I 2.88 110 3573 ~~ 0.02 ~~ u 2.88 111 3605 i~ 0.01 5 I 2.88 112 3638 t~ 0.03 11 1 2.87 113 3670 U 0.03 11 I 2.87 1 14 3703 U 0.02 ~ 1 2.88 Sli ht Buc.Min . 115 3735 c? .02 ~~ 1 2.88 116 3768 t? 0.02 ~3 1 2.91 117 3799 ~~ 0.02 7 1 2.87 118 3832 U 0.03 Il~ I 2.88 119 3865 U 0.02 ~1 1 2.87 Sli ht B cklin . 120 3897 ~~ 0.02 '~ 1 2.87 121 3930 ~~ 0.02 £3 1 2.86 122 3961 t 1 0.02 i I1 2.88 123 3993 U 0.02 i 1 2.88 124 4025 O 0.02 i 1 2.89 Sli ht Bucklin . 125 4058 U 0.03 1 1 i~ 2.86 126 4090 tl 0.01 i 1 2.88 127 41 3 t) 0.02 ~) I 2.87 128 4154 l~ 0.02 I 2.86 129 4186 t~ 0.02 `~ ~~ 2.88 Bucklin . 130 4219 ~ 1 0.02 7 I 2.88 131 4250 t~ 0.03 1 Z I 2.87 132 4283 ~) 0.02 7 i 1 2.89 133 4316 t~ 0.01 (i (1 .88 134 4348 O 0.03 10 I) 2.88 135 4381 t~ 0.03 11 I 2.87 Bucklin . 136 4413 ~~ 0.02 ~ 1 2.87 137 4444 ~~ 0.02 ~~ I 2.87 138 4476 ~~ 0.02 ~~ I 2.86 139 4509 ~! .02 ~) I 2.86 140 4542 ~~ 0.02 i I 2.88 Bucklin . 141 4574 ~~ 0.03 11 I 2.87 142 4607 ~) 0.02 7 ~~ 2.86 143 4639 ~~ 0.02 tS I 2,86 144 4672 ~! 0.03 1 1 ~~ 2.87 145 4704 0.03 1' I 2.8 Bucklin . 146 473 7 0.02 '~ I 2.87 F' Penetration Body Metal Loss Body Page 3 ~ PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf )-55 EUE SRD MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Cornpany: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 30-04 Kuparuk ConocoPhillips Alaska, Inc. USA October 4, 2009 )oint No. Jt. Depth (Ft.) I'~~n. U~~~c~t (In~.) Pen. Body (Ins.) I'en. % Yic~t,il I oss ",'<~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 147 4769 U 0.02 ~) I 2.86 148 4799 ~) 0. 2 ~? 1 2.88 149 4831 U 0.03 1( ) (~ 2.86 150 4864 U 0.02 '~ I 2.87 151 4896 cl 0.02 '~ I 2.86 Bucklin . 152 492 8 ~~ 0.0 ~l t~ 2.86 153 4959 ~~ 0.02 7 ~~ 2.88 154 4992 (~ O.U2 ~) I .87 155 5025 U OA2 ') 1 2.8 Lt. e osits. 156 5057 U 0.02 ~? I 2.88 157 5090 ~ ~ 0.03 1 U I 2.86 Bucklin . 158 5122 ~) 0.02 ~~ ~ ~ 2.86 159 5155 ~~ 0.03 I 1 ~ i 2.86 160 5185 ~~ 0.02 ~) ~ 1 2.85 161 5218 ~~ 0.03 1 1 I 2.87 162 5250 ~~ 0.02 ~) 1 .89 Bucklin . 162.1 5283 t~ 0 U (1 N A GLM 2 Latch @ 11:30 16 5290 ~~ 0.03 1 1 1 .88 164 532' u .02 ~) I 2.86 165 5355 O 0.02 ~i I .87 166 5386 O 0.03 1O I 2.89 ucklin . 167 5419 U 0.03 1 U I 2.86 Lt. De osi . 168 5452 u 0.02 ~) U 2.86 169 5482 O 0.03 12 1 2.86 170 5514 n 0 03 1(1 u 2.87 171 5544 ~~ 0.02 9 1 2.86 172 5577 t~ 0.02 f3 l~ 2.87 Buc lin . 173 5607 U 0.02 f~ 1) 2.87 174 5640 ~~ 0.01 6 I 2.88 175 5673 t~ 0.02 ~~ ~i 2.89 176 5705 u 0.01 ~ I .87 177 5738 t~ 0.03 1 I i~ 2.87 Lt. De osits. 178 5770 ~~ 0.02 i I 2.87 [3ucklin . 179 5803 (~ 0.02 ~) ~~ 2.87 Lt. De osits. 180 5835 ~~ 0.02 ~~ I 2.87 181 5866 u 0.03 1 U U 2.87 182 5$97 U 0.03 11 I 2.86 183 5929 U 0.02 ~? I 2.87 184 5962 U 0.01 ~~ i~ 2.87 cklin . 185 5994 ~1 0.02 ~~ I 2.88 186 602 7 t) 0.02 ~) U 2.88 187 6058 U 0.02 ~) u 2.87 1 SS 6091 (~ 0.02 7 I 2.88 189 6124 u 0.02 ~~ I 2.87 90 6156 U 0.02 8 ~. ~ 2.90 Buc (in . 191 6189 i~ 0.02 I 2.87 192 6221 ~> 0.02 ~i ~. i 2.86 193 6254 ~ 1 0.02 9 ~~ 2.85 194 6286 i~ 0.01 6 I 2.85 195 6319 ~ ~ 0.02 7 ~~ 2.86 Penetration Body ~~letal Loss Body Page 4 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE SRD MOD Weil: 30-04 6ody Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Corr~any: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 4, 2009 Joint No. Jt. Depth (Ft.) I'f•n. l l~~sc~i flns.) Pen. Body (Ins.) Pe>n. °io 1Actal I c~s5 °~~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 19 351 ~~ 0.02 ~3 I 2.86 Buc lin . 197 6384 ~) ~ 0.03 1Z 1 .85 198 6417 ~ ~ 0.02 7 ~~ .86 199 6449 c~ 0.02 ~) I .87 2 0 64 2 t~ 0.02 7 ~) .86 01 6514 l~ 0.05 1 tt 1 .87 Shallow itti . 02 6547 U 0.0 5 _' 2.86 Bucklin . 0.1 6579 t~ 0 U ~1 N A GLM 3 Latch ~ 830 03 6586 t~ 0.02 9 ~) 2.87 04 6619 u .01 5 1 2.87 205 6651 l) 0.02 9 I 2.87 LE. De o'ts. 06 668 U 0.02 ~~ ~~ 2.87 207 716 (~ 0. 2 I 2.88 Bucklin . 08 6749 ~~ 0.02 ~~ ~~ 2.89 209 6780 l1 0.02 t3 1 2. 8 210 6813 i~ 0.02 ' ' 2.90 211 6846 r i 0.01 ~ ~~ 2.88 1 6875 ~~ 0.03 11 i~ 2.86 Bucklin . 213 6909 (~ 0.02 9 U 2.88 Lt. De osits. 14 6941 U 0.02 7 ~~ .89 21 6971 l) 0.03 1~~ U 2.87 Lt. De osi . 216 7004 U OA2 9 1 2.90 217 7037 U 0.01 (~ 1 .86 ucklin . 218 7069 i) 0.03 1 1 ~~ 2.85 " 19 71 2 i) 0. ~ 2 ~> I .86 Lt ~ e osi . 220 7135 U 0.03 11 U 2.86 221 7167 i~ 0.02 ~) 1 2.82 ucklin . 221.1 7200 U 0 (1 l) N A GLM 4 Latch ~ 730 222 7207 t) 0.03 l:i ! 2.87 St allow i tin . 223 7239 ~) 0.03 lI I 2.87 224 7272 U 0.02 9 U 2.87 Lt. De osi . 225 7304 U 0.02 ~) Z 2.87 Bucklin . 2 6 7337 11 0.03 1' _' 2.88 Ll. osi . 227 7369 ~> 0.02 ~ ' 2.88 228 7402 ~) 0.04 1 ~ _' 2.84 Shallow ittin . 229 7434 O 0.01 5 ? 2.89 23 7467 l) . 1 5 ~' 2.88 231 7499 U 0.01 i, _' 2.90 Bucklin . 23 7531 (~ 0.0 lZ 2.88 233 7565 t) 0.05 ~'U I 2.90 Shallow ittin . 234 7598 t) 0.01 5 I 2.86 Lt. De osi . 234.1 7629 U 0 t~ ;~ N A GLM 5 Latch ~ 1:00 235 7637 t~ 0.03 13 .86 Shallow ittin . 236 7669 ~> 0.06 1~ i 2.85 Isolated ittin . 237 77 1 t~ 0.03 1 I I 2.87 t. De osits. 238 7734 t~ 0.03 1 U i~ 2.85 Bucklin . 239 7766 u 0.03 11 ' 2.84 240 7799 ~~ 0.04 14 3 2.86 Shallow 'tti . 41 7831 ~~ 0.04 15 ~~ .85 Shallow it in . 242 7864 ~~ 0.06 25 _' 2.83 Isolated ittin . Lt Ue osits. ~ Penetration Body Metal Loss Body Page 5 ~ • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 93 ppf J-55 EUE 8RD MOD Well: 30-04 l3ody Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 4, 2009 Joint No. Jt. Depth (Ft.) I'c•n. i l~~s~~~ Iln~.) Pen. Body (Ins.) f'en. % ~ic~t,al f c~ss °~;, Min. I.D. (Ins.) Comments Damage Profile (% waN) 0 50 100 243 7896 U 0.0 1~' ? 2.86 Bucklin . 244 79 8 u 0.03 13 U 2.87 Shallow ittin . 45 7961 U 0.04 16 _' 2.85 Shallow ittin . Lt. De its. 246 7993 !~ 0.04 1 t3 ' 2.83 Shallow ittin . Lt. De osits. 246.1 8026 U 0 U t ~ N A GLM 6 Latch @ 3:00 47 80 U .03 I I ~ i 2.85 Bucklin . 248 8064 ll .03 iZ I 2.87 Lt. De o its. 249 8097 U 0.05 18 1 2.87 Shallow ittin . t. De osits. 250 8129 l~ 0. 4 14 ~ 2.88 Shallow ittin . 251 8162 ~~ .03 10 _' 2.86 Bucklin . 2S2 $194 t~ 0.04 1' S 2.8b Shallow c.orrosion. 1_t. De osits. 253 8 26 l) 0.03 13 I 2.86 Shallow itti . Lt. e si . 254 8257 ~~ .03 t I ! 2.85 Lt. De osits. 255 290 t? 0.02 ~~ 2.87 . e osits. 256 8323 t i 0.03 1 1 1 2.88 Bucklin . Lt. De ~osits. 257 8355 U 0.0 9 ~ 2.89 Lt. De osits. 258 8388 c~ 0.02 9 ~' 2.87 t De osits. 258.1 8421 (~ 0 0 i~ N A GLM 7 Latch @ 7:30 259 84' 9 u 0.03 13 I 2.90 Buc.klin . Shallow itti . 259.1 846 i! 0 0 (1 3.00 AVA H dra lic Release PBR 59.2 8475 ti 0 t) ~) 3.00 AVA'RHS' Retriev ble Packer 260 8481 l~ 0.02 ~~ n 2.90 260.1 8514 u 0 U ~~ 2J5 Camco D-Ni le 261 8515 U 0.03 l l) _' 2.87 Lt De osits. 261.1 8548 u 0 U ~ ~ "2.99 AVA t3a11 Seat Shear Out Su _. Penetration Body Metal Loss Body Page 6 ~~ ~~ PDS Report Cross Sections Well: 30-04 Survey Date: October 4, 2009 Field: Kuparuk Tool Type: UW MfC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 3.5 ins 9.3 ppf _ J-55 EUE 8RD MOD Analyst: C. Waldrop Cross Section for Joint 242 at depth 7894.883 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 99 % Tool deviation = 49 ° Finger 5 Penetration = 0.063 ins Isolated pitting 0.06 ins = 25% Wali Penetration HIGH SIDE = UP ~ i Cross Sections page 1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ! ~ PDS Report Cross Sections ~ ~~ . Well: 30-04 Survey Date: October 4, 2009 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 p f -55 EUE SRD MOD Anal sr. C. Waldro Cross Section for Joint 236 at depth 7670.443 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 99 °/a Tool deviation = 43 ° Finger 11 Penetration = 0.057 ins Isolated pitting 0.06 ins = 22% Wall Penetration HIGH SiDE = UP i ~ Cross Sections page 2 i PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • -LATION SHEET 30-04 Kuparuk ConocoPhillips Alaska, Inc. USA October 4, 2009 Joint Jt. Depth I'~~n. Pen. Pen. Mc~t,il Min. Damage Profile No. (Ft.) UE„~~t Body `% I i~,s I.D. Comments (%wall) (In~ j (Ins.) ~ (Ins.) 0 50 100 1 8551 U 0.15 4'1 it 6.11 Isolated ittin . Corrosion. Lt. De sits. 2 8587 i~.!~~ 0.18 51 I I 6.12 Isolated ittin . Corrosion. Lt. De sits. ~ Penetration Body Metal Loss Body Page 1 ~ ! ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ! ~ ~ ~ PDS Report Cross Sections ~ ,. Wetl: 30-04 Survey Date: October 4, 2009 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, ~nc. Tool 5ize: 1.69 Country: USA No. of Fingers: 24 Tubin : 7 ins 26 f -55 Analvsr. C. Waldro Cross Section for Joint 2 at depth 8604.917 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 90 % Tool deviation = 47 ° Finger 17 Penetradon = 0.184 ins Isolated pitting 0.18 ins = 51% Wall Penetration HIGH SIDE = UP ~ ~ Cross Sections page 1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~ ~``~ „ Well: 30-04 5urvey Date: October 4, 2009 Field: Kuparuk Tool Type: UW MFC 24 bct No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA ~\'o. of Fingers: Z4 Tubing: 7 ins 26 ppf 1•55 Analvst: C. Waldrop Cross Section for )oint 1 at depth 8574.637 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 94 °/a Tool deviation = 47 ° Finger 15 Radius = 3.248 ins Isolated pitting 0.15 ins = 42% Wall Penetration HIGH SIDE = UP • • Cross Sections page 1 ~~~ KUP ~ 30-04 ConoCOPhiliips `~ en am~b~,c~ nn ie a ~ro ~n _.... ,. I ~ a ore ela N.ne 500292182600 KUPARUK RIVER UNIT tl~ ann a(~ PROD 51 60 2,600.Q0 ne ~ 8,984.0 ... ommert H35~ppn SSSV:TRDP 275 DMe 1/612008 /Urntatlon Last WO: tlD~e KB Qq 40.00 g elease 7/911988 M~odtlon Oeptli En Dae M~olatlon La y B~d e IasiTag:SLM 7.042.0 5114l2f~9 RevReason~.UPDATET09.0 knosbor 5/1&2009 Casin Strfn aanp wlptlon CONDUCTOR ~1n9 .. 16 . ~B -~ 15.062 a W 0.0 ~ K... 115.0 set uepm ( ... 115.0 .. 62.50 ... H-00 st op mra Ceepg n SURFACE 0. 9518 . ._ 8.765 uP 35.0 0-~ 5.099.2 ( )-~ 4.029.0 - J6.00 J-55 aP HANGER.33 ~ Slryj OII PRODUCTION lMlp .. 7 . 1_. 6.151 TOp 33.0 P~ ... 8,961.3 S![ ( )... 6,768.7 YYL.. 26.OD ... J-55 7M0 Tubin Strin s CoNOUCroa. 7LGIrg Deurlplon 9trMp 0... Ytrhp D._ TuV fl~81 Set Deplh (f.- Set DeP~ (~1-. CtMg _ Shing ... SbMB Top Md TUBING 31/2 2.992 33.0 8.548.6 6.4662 9.30 J-55 EUESrdMOD a„s I ~fon DatBflS T ptlCB) oa ph 1*wl (~0) rop Na (') R emOetc m Cm~neM iDPM 33.0 33.0 0.18 GER CI Harger 8 4' Pup 2.992 sssv,i,eze Gs 1,829.1 1,737.6 34.8~ S SSV CAMCOTRDPSSSV - 2.812"ID 2.872 8,463.2 6,404.0 43.42 L OCATOR AVA Lotaior Sub 3.000 ~; 8,463.7 6,404.4 43.42 AVA HyMa~Aic Release P8R 3. ~~~~~ 'r 8,476.8 6.413-9 43.36P ACKER AVA'RHS' etrievablePadcer 3.000 s.o~o g,514.0 6.447.1 43.35 N IPPLE CAMCO'd Nipple 2J50" ID 2J50 8,547.9 6,465J 43.27 S OS AVA BaM Seat SAear Out Sub 2.992 ~" 5 S~os~ Other I n Hole I Mreline rotrie~rabl e s valves um s fish otc. op ptl~ T'~ cns uFr, T ~tl(a ) ( 1~1 Toplna fl oescnpnon Cam~vt ~hn wte m Ihd 52ss 13 13.0 0.16 P ATCH LDED 31' PATCH ON SURFACE 9 5I8' CASING O CWFA HOLE 32" BELOW OA VALVE 9n/2003 8,718 6,590.4 4324 F ISH 10' Fired Sap Lefl in Fble 5/6/1989 G"^'s sa PYIfOfe tlOns i SIo1s T A~W shnl~l Top~TVq 1~01 BUn~TVD) 1~~1 zone oeu ~ D~~ (+~- cmmr» c~ ~i~. ~ ~os 8.622 8.6t0 6,519.7 6.532.9 C e 4. C-1. UNR , ao-0a 5!1/1989 12.0 IPERF 2 7/8" EnerJel, 60 deg. phasing 8.653 8.669 6 542 4 6.554.1 A -3. 30-04 5l7/1988 12.0 IPERF 2 118' Ene1JeL 60 deg. phas6ig 8. 5 8,698 6.558. 6,575.3 A -2, 30-04 5l7/1989 12.0 IPER 2 1I8' EnerJet, 60 deg. phasing ~~ ~~FT ).636 8,770 8,730 6.584.6 6,599.1 A -7, 30-04 912511988 8.0 IPERF 4 7!2" NSD Csp G~n, 45 deg. pha511Kf Notes: Gene rai 8 H1tl Ye AIt~Dhtlon ~^~~~FT 8.028 7/10/1994 NOTE:WAIVEREDWELL:IAxOACOMMUNICATION 5/18/2009 NOTE: VIEW SCHEMATIC w/Naska Schemalit9.0 ~~ ~iFt, e 4z~ ~ocnroR. 8 063 PBR.8466 PAGI~R.8477 NIPPLE,8514 I SOS.BSdB IPERf, 8,B2I-0 840 . i Ma ndrel D etalls j ipp2F, I e.653~.66e I BGl T 6 Top Dep1~ (Nq ~B) Top Ind (') ~~ rypdy OD pn) 8erv Valve ~yPe Letc~ ~YPe rt 81ze P^) 7RORU~ (ptq RwDtie Com._ I 1 3,070.0 2,5 9.9 45.35 McMu_. FMHO 1 G4S LI GLV BK 0.125 .2 .0 1l312 '~ I i~tF 2 5,295.3 4,1 0.3 44.06 McMu... MHO 1 GAS LIFT GW BK 0.188 1.371.0 1/32004 il s.sisa,ssa 3 6, 6.9 6,074.6 46.0 M1AcMu... FMHO 1 GAS LIFT GLV BK 025 1,476.0 1/32004 ~, 4 7,206.3 5,513.7 45.44 NkMu... F H 1 GAS LI OV 8K 0.188 0.0 1/?J2005 I 5 7,633.9 5. 14S 4514 McMu... FMH 1 ~1S LIFT DNTf B O.U00 0.0 10/52003 ~~ ' 6 8.027. 6,091J 44.99 McMu... FMHO 1 G4S UFT DWY K 0.000 0.0 10/3/2003 ' w~RF, I 8,770~.~30 7 g,421.6 6,3 3.8 43.62 OTIS LBX 1 12 GP~S LIFT D RM O.OpO 0.0 8/12/1997 ii FISH,8,11B I PROWGTION. 33-B,961 TD,8,984 . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 September 29,2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 30-04 (188-062). The report records the addition of inhibited casing v filler in the conductor top. Please call Jerry Dethlefs or me at 659-7043 or Marie McConnell or Perry Klein at 659- 7224 if you hav.e any questions. S~o//~~ MJ Loveland Problem Well Supervisor Attachments . . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION RECEIVED OCT 0 3 2U06 REPORT OF SUNDRY WELL OPERA TIO I". na 2. C..... ('n,H.' ('/\""mìf,'~ion 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate D Other AnCho~e . ¡I-.JJ Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension 1;;;Y~. Change Approved Program D Ope rat. ShutdownD Perforate D Re-enter Suspended Well D .£D ro';~ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Numblr: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 188-062 1 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21826-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 59' 30-04 . 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unti ¡<pI... t.{"f;/3 ß 10. ¡ .01. Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8984' , feet true vertical 6785' . feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SUR. CASING 5040' 9-5/8" 5099' 4029' PROD. CASING 8902' 7" 8961' 6783' Perforation depth: Measured depth: 8622-8640,8653-8669,8675-8698,8711-8731' true vertical depth: 6519-6532,6541-6553,6557-6575,6584-6599' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 8549' MD. Packers & SSSV (type & measured depth) pkr= AVA 'RHS' pkr= 8477' SSSV= SSSV SSSV= 1829' 12. Stimulation or cement squeeze summary: NA Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation NA Subsequent to operation NA 14. Attachments 15. Well Clas~> after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: NA Contact Jerry Detl1leWMJ L~ Printed Name MJ ,je!: '}l Title Wells Integrity Proj Supv ~ Signature l1'Y\. LrP. Phone 659-7043 ~:::red bv s9ß..tD'a~6~12 I Form 10-404 Revised 04/2004 RBDMS BFl €I ·4 2006 k ~ð't4Ø6 \0 I š'c.bmit ~/ônIY ~ /ò·3·~ /" , '"""--- ~ . 30-04 . DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary ¡/ 9/11/2006 Topped off conductor 2" from top with RG-2401 casing sealant. TII/O=180/960/800. Top of gravel in conductor @ 1'. Attempted to vac out gravel with very little success. Poured in 4 gals. of RG-2401 casing sealant into conductor which topped off conductor 2" from the top. Final T/I/O=180/960/800. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 1,2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7m Avenue, Suite 100 Anchorage, AK 99501 RECEIVED Ala ka Oil & Gas Con$. An 0r Dear Mr. Maunder: Enclosed please find 1.0-404 Sundry Notices for ConocoPhillips Alaska, Inc., wells IA-13 (PTD 18.1-195), IH-07 (PTD 182-084), and 30-04 (PTD 188-(i)62). The Sundry Notices regard tubing patches run to fix tubing leaks in IA-13 and IH-07. IH-07's Sundry is a repeat notice as the patch was recently pulled and re mn to access the C sand. 30-04. Sundry Notice is for an OA casing patch repair. Please call Nina Woods, Jerry Dethlefs or rne at 907-659-7224 if you have any questions. Sincerely, MJ ConocoPhillips Problem Well Supervisor Attachments STATE OF ALASKA ASKA OIL AND GAS CONSERVATION COMMI ,_,,,aN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r-~ Suspend r-'] Operation Shutdown D Perforate [~] Variance D Annular Disp. Alter Casing [--] Repair Well [~] Plug Perforations D Stimulate D Time Extension [-"1 Other [] Change Approved Program [] Pull Tubing D Perforate New Pool ['-'] Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development m)[~] Exploratory [] 188-062 / 3. Address: Stratigraphic [~] Service [--] 6. APl Number: P. O. Box I O036O 50-029-21826-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 59' 3O-O4 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8984'. feet true vertical 6785' feet Plugs (measured) Effective Depth measured 8878 feet Junk (measured) true vertical 6707 feet . Casing Length Size MD TVD Burst ., Collapse Structural CONDUCTOR 115' 16" 115' 115' SUR. CASING 5040' 9-5/8" 5099' 4029' PROD. CASING 8902' 7" 8961' 6783' Perforation depth: Measured depth: 8622-8640, 8653-8669, 8675-8698, 8711-8731' true vertical depth: 6519-6532, 6541-6553, 6557-6575, 6584-6599' Tubing (size, grade, and measured depth) 3-1/2", J-55, 8549' MD. Packers & SSSV (type & measured depth) pkr= AVA 'RHS' pkr= 8477' ~0j~; ~,,0~/~- SSSV= SSSV SSSV= 1829' ,, 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: ,, , 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casin..q Pressure Tubing Pressure Prior to well operation 300 135 440 1398 175 , , Subsequent to operation 300 135 440 1398 175 , 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory r-~ Development [~] Service [-~ Daily Report of Well Operations __X 16. Well Status after proposed work: Oi1['~1 GasE~ WAG r-] GINJE~ WINJ [] WDSPLr-'] ,, , ..... 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: 303-200 Contact MJ Loveland/Nina Woods Printed Name MJ Lovelan,~¢ / ~,-,I~' Problem Well Supervisor signature ~',,~ /~/~~/.~.~~- Phone: 659-7224 Date ~/'/,/~. ~ Form 10-4 ised 2/2003 SUBMIT IN DUPLICATE 30-04 ~" dESCRIPTION OF WORK COMPLETED - SUMMARY Date Event Summary 9/7/2003lipatchPurge onlA the & OA9 5/8wit"h oANitr°genjust belowf°r outer the startingCaSing patchhead, weld. Successfully welded 10 3/4" x 32" 9/8/20031MIT OA to 1800 PSI 9/23/20031Purged OA with N2, while Anodes welded to outer casing, Then Welded new conductor Isection around OA 9/28/20031 Replaced excavated material around well head and returned to operations Re: 3F-17 and 30-04 Subject: Re: 3F-17 and 30-04 Date: Mon, 21 Jul 2003 16:41:04 -0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: I will attempt to answer your questions in order. Also, you will be getting a couple more Sundrys for OA cement jobs, so the following statement applies to them as well. 3F-17: I have not yet completed the procedures for the actual cement pumping yet. But based on experience (some bad) we plan for a minimum of 500' cement column in the OA. We then mix and pump 100-120% excess to account for the amount that goes past the shoe. If the reservoir does not take any cement we may end up with a 1000' column. From experience we found it will probably take quite a lot. If we do not get a pressure bump we will shut down pumping with the calculated 500' column. The displacement fluid is 5 bbls water spacer to clean lines followed by diesel. There will not be any "Arctic Pack" pumped. The cement blend is recommended by Dowell for this purpose. An MITOA will be done a couple days after the job to test for integrity. 30-04: In preparation for attempting a SealTite repair on this well a couple months ago, we drilled and tapped a 3/4" hole in the conductor. The vendors needed a leak rate through the surface casing into the conductor to plan their sealant repair. When the hole was drilled it was obvious there was cement in the conductor, since the hole drilled straight into cement. However, we were able to establish a leak path from the surface casing out our hole in the conductor. Just by luck the hole we drilled in the conductor is fairly close to where we identified the leak with the boroscope. As we pumped diesel to get the leak rate, chunks of cement came out with the diesel and the leak rate increased up to 10 gpm, which is the maximum rate our pump would put out. That high of leak rate is not suitable for a SealTite repair, so we did not follow-up on that option. We expect there is a distinct possibility of hydrocarbon contaminated cement in the conductor. Since the void area should mostly be cement, we expect very little accumulated fluid. The Welding Foreman wants holes drilled top and bottom prior to cutting the window to verify that condition. I am unclear about your statement about cutting the window--the procedure starts with the major steps only. All the safeout steps and nitrogen purging are to be done prior to and in conjunction with cutting the window AND the casing repair. There will be nitrogen purging on the conductor, OA and IA during all the hotwork. After looking at the boroscope picture again, I suspect there is a split in either the surface casing mandrel or the pup joint immediately below it. Cutting the conductor window should make that clear. We can keep you posted as to what we find--I think it will take at least a few days or more after cutting the window before we attempt the repair. There are lots of approvals internally that will need to be obtained. I will be leaving the slope Tuesday and Nina will be here for another week. Please let us know if you want more information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska Tom Maunder <tom_maunder@admin.state.ak.us> 1 of 2 ~(,~!i~~p JJL © ~O ~.L~U.,'~ 7/22/2003 7:30 AM Re: 3F-17 and 30-04 07/21/2003 12:17 PM To: Jerry C Dethlefs/PPCO@Phillips, NSK Problem Well Supv/PPCO@Phillips cc: Michael B Mooney/PPCO@Phillips Subject: 3F-17 and 30-04 Jerry, MJ or Nina, I was looking at the sundries for these wells and had a few questions. 3F-17--What cement volume is proposed?? Will the displacement fluid be diesel?? 30-04--In the Job Procedure, step 2, it is noted that N2 should leak through the surface casing hole and provide purge for cutting the conductor window. With all the other gas checks planned, it seems strange that there are no similar plans for the conductor x OA. --Is the fluid level in the conductor x OA below the split?? --What fluid is present in the conductor x OA?? --Where is the cement level in the conductor x OA?? --Prior to cutting will the atmosphere in the conductor x OA be checked?? --Is it planned to attempt to keep water in the conductor x OA while the cutting is performed to allow steam to develop and prevent formation of an explosive mixture?? Thanks for you attention to these questions. Tom Maunder, PE AOGCC (See attached file: tom_maunder.vcf) Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 7/22/2003 7:30 AM ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 18.2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Sundry Notice for ConocoPhiilips Alaska, Inc., well 30-04 (PTD 1880620. The Sundry Notice regards a repair to the surface casing. Please call Nina Woods, MJ Loveland, or me at 907-659-7224 or 7043 if you have any questions. Sincerely, Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. Attachments ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 2O AAC 25.28O 1. Type of Request: Abandon Alter casing Change approved program Suspend FI Operation Shutdown I~l Repair well [] Plug Perforations FI Pull Tubing FI Perforate New Pool FI Perforate FI Vadance FI Stimulate [~ Time Extension Re-enter Suspended Well FI Annular Disp. FI Other FI 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development _ [] Exploratory Stratigraphic FI Service 5. Permit to Drill Number: 188-062 ~' 6. APl Number: 50-029-21826-00 7. KB Elevation (ft): RKB 59' 8. Property Designation: Kuparuk River Unit 9. Well Name and Number: 30-O4 10. Field/Pool(s): Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 8984' 6785' 8878 6707 Casing Length Size MD TVD CONDUCTOR 115' 16" 115' 115 S U R. CAS I N G 5040' 9-5/8" 5099' 4029 PROD. CASING 8902' 7" 8961' 6783 Perforation Depth MD (ft): 8622-8640, 8653-8669, 8675-8698, 8711-8731' Perforation Depth TVD (ft): 6519-6532, 6541-6553, 6557-6575, 6584-6599' Tubing Size: 3-1/2" Junk (measured): Burst Collapse Tubing Grade: Tubing MD (ft): J-55 8549' Packers and SSSV Type: pkr= AVA 'RHS' SSSV: SSSV 12. Attachments: Description Summary of Proposal ~-~ Detailed Operations Program [~ BOP Sketch E~] 14. Estimated Date for Commencing Operations: July 23, 2003 16. Verbal Approval: Date: Packers and SSSV MD (ft) pkr= 8477' SSSV= 1829' 13. Well Class after proposed work: Exploratory FI Development ~-~ 15. Well Status after proposed work: Oil ~ Gas E~ Plugged WAG E~ GINJ FI WINJ Service [] Abandoned r"-I WDSPL E~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jerry Dethlefs Printed Name,.-~ ~ ( 'h,=,_~/¢Jerry Dethlefs.~.. ~ . Title: Problem Well Supervisor Signature ~,,,Z,¢.¢.. ~/~' (--. ",._..-~~~ Phone 659-7224 Date 7/18/03 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I S und ry N u m be,~l~l~l~,~ ~ Plug Integrity r-'] BOP Test FI Mechanical Integrity Test FI Location Clea, rance., ', ",, ':; '":' '''','~ Other: Subsequent Form Required: Form 1 ~3R0~i'Se0 2/200a · - BY ORDER OF c~'i~l~Sl(~l~q k J A J THE COMMISSION Date: '~'~Z ~) ~,J I\ I U I I~/-tl-- SUBMIT IN DUPLICATE ) I ConocoPhillips Alaska, Inc. Kuparuk Well 30-04 (PTD 1880620) SUNDRY NOTICE 10-403 REPAIR REQUEST 7/18/03 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to repair the surface casing on Kuparuk producing well 30-04. 30-04 was drilled in 1988 and has been in production until 2002. There has been evidence of a gas leak in or near the wellhead assembly since 2000. The leak was eliminated by reducing the Outer Annulus (OA) pressure to below 500 psi (the well is gaslifted with up to 1400 psi on the Inner Annulus (IA)). In the fall of 2002 the well was shut-in due to the leak to atmosphere condition. The following are diagnostic notes regarding location of the leak: 4/24/01 MITOA failed. Casing leak started breaching to surface. 9/19/02 SL set plug in tubing for long term SI 5/20/03 T/I/O - 100/100/0. Initial OA FL @ surface. Started pumping down OA with Tri-plex, getting ~mmediate returns out of the Conductor of clean Diesel. OA slowly pressured up to 1600 psi, then the OA pressure dropped rapidly to 500 psi. Increased Tri-plex pump rate to approximately 10 gpm and pumped steadily for 2 bbls @ 850 psi. Taking equal returns per minute out of conductor. Upon completion of pumping the returns drum had cement sediment ~n bottom from Conductor. Final pressures; 100/100/0. 6/29/03 Boroscope Hole in OA - successful. Rig up tri-plex and visually inspect OA while purging diesel from OOA to OA. Identify split in OA at 32" below 2" annulus valve nipple. PROPOSED REPAIR PLAN (See attached detailed repair plan) ConocoPhillips proposes to use the following plan to repair the surface casing: 1. Excavate as needed around wellhead for working room; 2. Cut a window in the conductor to provide visual inspection of failed casing; 3. Prepare welding and/or patch plan by Facility Engineers; 4. Repair surface casing as per plan; 5. QA/QC repaired area and MITOA to verify integrity; 6. Replace excavated material around wellhead if necessary; 7. Return well to production. NSK Problem Well Supervisor 07/18/03 ConocoPhillips Alaska, Inc. 30-04 SURFACE CASING REPAIR PROCEDURE Surface Casing Leak Repair Objective Repair the leak in the surface casing. The leak is known to be approximately 32" below the surface casing annular valve. The extent of damage is unknown; the conductor casing will require partial removal to expose the damaged surface casing. Excavation around the wellhead may be necessary to provide adequate workroom. Major Steps 1. Excavate around wellhead as needed to provide workroom. Will require As-built review for buried lines or utilities. 2. Cut window in conductor to expose surface casing. Remove cement sheath from surface casing. 3. Inspect surface casing for damage and/or leak path. Identify failed component for repair, either mandrel hanger or casing pup joint. Prepare welding repair plan as needed (seal weld, patch, or other). 4. Repair casing, QA/QC. 5. Replace excavated gravel and cellar box as needed. General 1. Network number: 10028677 Activity code: ZX12 2. The surface casing mandrel hanger is made by FMC (PN 12-130-379) and is made of 4140 steel alloys. The mandrel is screwed into a 9-5/8" J-55 36# casing pup-joint. 3. Well is an oil producer. The safe-out procedure includes displacing the tubing and inner annulus with water and a diesel cap for freeze-protection. A tubing tail plug will be installed to secure the well from the formation. The well will be isolated from the facility by closed wing and lateral valves. Energy isolation lockout & tag-out procedures apply. A nitrogen purge will be maintained on the inner annulus (IA) and outer annulus (OA) during the repair operation with continuous monitoring of 02 and LEL levels. 4. Wellhouse flooring and beams have been partially removed to gain access to the wellhead. 5. On-site personnel should be limited to only those with activities and responsibilities associated with the job. 6. Any on-site personnel have the authority to stop or suspend the job should any safe-out or procedural conditions become suspect. Safety is everyone's responsibility. Repair Preparation: 1. Prepare In-Service package for cutting and welding. (WG, ENG) 2. Develop JHA package. (APC and APC Supt.) 3. Shut-in and secure well. Set tubing tail plug and dummy gaslift valves. Displace tubing and IA with seawater. Leave diesel freeze-protection fluids on tubing and IA to 2000'. (WG) 4. Bleed tubing, IA (3-1/2" x 7") and OA (7" x 9-5/8") to zero psi. Verify flow is zero; inability to maintain zero psi prior or during job will cancel the welding operation. (APC & WG) 30-04 Weld Proc 07-18-03.doc ! NSK Problem Well Supervisor 5. Prep 9-5/8" casing head: Pull VR plug and install opposing valve on casing head for N2 purge. (WG & Valve Shop) 6. Prep 7" casing head: Pull VR plug and install opposing valve on casing head for N2 purge. (WG & Valve Shop) 7. Verify OA fluid level is below repair point; remove fluid via suction hose as needed. (AP(;;; & WG) 8. Clean wellhead of dirt and hydrocarbons. Remove contaminated gravel from the wellhouse. (APC) 9. Install purge lines from N2 bottle rack to IA / OA, and from IA / OA to slop trailer. Discharge will be monitored for LEL and 02 levels and must be accessible. Position slop trailer downwind and as far from wellhouse as is practical. (APC) 10. Disconnect CAT wellhouse heater gas supply line (if applicable). (DSO) 11. Station Fire truck outside wellhouse, and several hand-held extinguishers in and around wellhouse. (APC & WG) 12. Inspect and remove any combustibles in accordance with Hot Work standard. (APC) 13. Install welding blankets to cover cellar and ground around wellhead. (APC) 14. Hold pre-job safety meeting and ensure all permitting is in order. (WG) Job Procedure 1. Safety department will check entire well area before Hot Work commences. Sniff entire piping layout in wellhouse to check for any potential flammable material sources. (APC and/or CPA) 2. Purge the IA and OA with nitrogen, venting outside to slop trailer. Purged gas is to be monitored throughout job for LEL and 02 levels. Target 02 level is < 5%. The heating / cutting operation may commence after target 02 level is reached. (WG) (APC Safety) Note: Nitrogen purge into OA will leak through surface casing hole, providing purge for cutting conductor window. 3. Establish fire watch and begin hot work, including prepping surface with torch, brushes, grinding or buffing as required. (APC) 4. Cut window in conductor to expose surface casing and cement. 5. Chip out and remove cement sheath from surface casing for inspection. 6. Cut additional window area as needed to fully expose damaged area of casing. 7. Stop N2 purge and remove Iow-pressure equipment from well. 8. Inspect casing damage and acquire data to formulate a welding and/or patch plan. 9. Pick up all trash and debris for disposal. Please leave a clean location! (ALL) Repair Plan Procedure 1. Prepare welding/repair plan as per Facility Engineer recommendations. 2. Repeat Job Procedure steps for purging and energy isolation as described above. 3. Repair surface casing as per Facility Engineer plans. 4. Note: The need to replace the conductor-casing window will be determined after the repair is done and QA/QC is complete. 30-04 Weld Proc 07-18-03.doc 2 NSK Problem Well Supervisor Post Weldinq Plan 1. QA/QC repair. 2. Remove the additional annular valves on IA and OA. (WG & Valve Shop) 3. MITOA to 1800 psi to check for any external leaks in wellhead connections. (WG) 4. Replace conductor casing window if necessary (weld). 5. Replace excavated gravel and cellar box as needed. 6. Return well to production. Monitor 9-5/8" annular pressure and welded area for 30 days. (DSO) 30-04 Weld Proc 07-18-03.doc 3 NSK Problem Well Supervisor ~~ ConocoPhillips Alaska, Inc. 30-04 (1829-1830, 0D:3.500) PBR (8464-8465, 0D:3.500) PKR (8477-8478, 0D:6.151) PLUG (8514-8515, 0D:2 750) TUBING (0-8549. OD:3.500, ID:2.992) Per[ (8622-8640) Per[ (8653-8669) Per[ (8675-8698) Per[ (8710-8730) KRU 30-04 APl:1500292182600 SSSV Type:[TRDP Annular Fluid:I Reference Log:I Last Tag:18695 Last Tag Date:] 5/15/2003 Casing String - ALL STRINGS Description CONDUCTOR SUE. CASING PROD. CASING rubing String - TUBING Size i Top 3.500 0 Perforations Summary Interval TVD 8622-8640 6520-6533 8653-8669 6542-6554 8675-8698 6559-6575 8710-8730 6584-6599 Gas Lift Mandrels/Valves Well Type:I PROD Orig 17/9/1988 Completion:I Last W/O: I Ref Log Date:I TD:18984 ftKB Max Hole Angle:152 deg ~ 2600 Size Top 16.000 0 9.625 0 7.000 0 Angle ~ TS:143 deg @ 8619 Angle @ TD:I43 deg @ 8984 I Rev Reason :l Set Plucj Last Update:15/30/2003 Boffom TVD 115 115 5099 4029 8961 6768 Wt Grade 62.50 I H-40 36.00 I J-55 26.00 I J-55 J Bottom J TVD J Wt' i'G'rade I Thread 8549 6466 I 9.30 J J-55 I EUE 8RD MOD Thread / Zone /'statuslFt ISPFI Date J Type '1 Comment F-4,c-i,UNqi 18 i 12 i 5/7/1989 I IPERF 121/8" EnerJet, 60 deg. / B / I I I I 1phasing / A-3/ 11611215/7/198911PERF 12l/8"EnerJet, G0deg. / / I I I I Iphasing / A-2/ I 23 I 12 I 5/7/1989 I IPERF 12 1/8"EnerJet, 60 deg. / / I I I I Iphasing / A-1/ J20 I 8 J9/25/1988J IPERFI41/2"HSDCsgGun, 45 / / I I I I Ideg. phasing St I MD I TVDI Man I Man I V Mfr Iv Type Iv OD I Latchl Port I TRO I Date Vlv Mfr Type Run 1 I 30701 25801MMH I FMHO I I GLV J 1.0 I BK 10.125 1129018/18/199' Cmnt 2152951 41701 MUll I FMHO I I G,V 11.0 I BE 10.188 1136618/18/199- 3165871 50751 MUll I FMHO I I GLV 11.0 I BE 10.188 1135718/18/199. 4172051 55131 MMH I FUHO I I DMY 11.0 I BE 10.0001 0 18/11/199. 5176341 58141 MMH I FMHO I I GLV I 1.0 I BE 10.250 1145418/18/199' 6180271 60911 MMH I FMHO I I ov I1'° I BK IO.25Ol 0 18/18/199' 7 I 84221 63741Otis I LBX I I DUY I 1.5 I RU 10.0001 0 18/12/199' Other (PlUgSi:;eqaiPii etc~;; :JEWELRY;: : ; ;: :; :: :~ ::;: :;: : ;;: ;;: :::; ::;; :: ;; ;;;: ;;; Depth lTVD I Type Description ID 1829 I 1737 I SSSV Camco'TRDP' 2.812 8464 16405 I PER AVA 3.000 8477 16414 I PKR AVA'RES' 3.000 8514 I 6441 I NIP Camco 'D' Nipple NO GO 2.750 8514 I 6441 I PLUG 2.75" A-2 PLUG SET 5/29/2003 0.000 8548 16466 1 sos AVA 2.992 8549 I 6466 I TTL 2.992 FiSh,FISH : : : : :: ::.:::: .: Depth Description I Comment 8718 10 Fired Strip I Left in Hole Date /Note 12/16/1999 CT FCO to 8840' corrected to RKB MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: DATE: Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector January 26, 2001 Safety Valve Tests KUparuk River Unit 30 Pad Friday, Janua~ 26, 200!: I traveled to the Kuparuk River Field and witnessed the 90-day retest of the safety valve systems on 30 Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Low pressure pilot on WAG injector 30-05 tripped below the required set point. This pilot was retested and passed at the the time of this test. Eamie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary:.. I witnessed the 90-day SVS testing at 30 Pad in the Kuparuk River Field. KRU 30 Pad, 12 wells, 24 components, 1 failure 4.1% failure rate 12 wellhouse inspections Attachment: SVS KRU 30 Pad 1-26-01 CS X Unclassified Confidential (Unclassified if doc. Removed) ,,, SVS KRU 30 Pad 1-26-01CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Earnie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Kuparuk / KRU / 30 Separator psi: LPS 67 Date: 1/26/01 HPS ..... i i ii i i ii i i i ........... ''"' '' '- ....... I' I ' il ' II '11' Illll I I I I ~ I I" Il '1' ill Well Pemit Separ Set L/P Test Test Test Date Oil, WAG, GI~J, Number Number. , pSI .... PSI Trip Code Code Code Passed GAS or CYCLE 30.-0i' i 1880730 , ,67. 70 80: P ' P ....... , .... ' 'OI.L 30-02 1880740 67 70 60 P P OIL 30-03 1880750 67 ' ~0 ' 601' ' P 1~' ' ' ' OIL 30-'04 1880~20 ' 67 ' 70 65 P 'P ....... 0IL 30-06 1880600 30-08 ' 18~06401 '67 70 7.,0. P' P ....... 0IL 30-09 1880610 67 70 40 P P OIL 30-11 1880420! 6) ' 70 ' 60 P .... P ...... OiL 30-13 1880400 67 70 60 P P OIL , 30-14' 1880390'. .................. 30-15 "' 1880310 ' "67! ' "70 7 .... 70 'P P ' ' 'OIL' 30'-'18 1 t~02~0 6)! 70 " 55 P P ...... OIL 30-20 i970450 '" 67I~'' 70 60 P P ........ OIL . 30-05 18'807ij0 3750:'' ~000 1100 ' "3 ..... P" 1/26/01 wAG Wells: .... !2,, Components: , , ,24 Failures:, , , ! Failure Rate: 4.17% /390 oar Remarks: ~il0t 9.n, WAG injector 30-05 tripped ~10w.,req,.ui~.ed set pressure. Pilot was retested and passed this date. RJF 1/16/01 Page 1 ofl SVS KRU 30 Pad 1-26-01 CS.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Operation Shutdown__ Stimulate X Alter casing Repair well 5. Type of Well: I Development ._X IExploratory I Stratigraphic __ 99510 I Service Plugging __ 4. Location of well at surface 789' FNL, 1879' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1278' FSL, 2400' FEL, Sec. 16, T13N, At effective depth 1306' FSL, 2200' FEL, Sec. 16, T13N, At total depth 1337' FSL, 2156' FEL, Sec. 16, T13N, R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 8984' feet true vertical 6785' feet Plugs (measured) Perforate Other 6. Datum elevation (DF or KB) 59' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 30-04 9. Permit number/approval number 88-62 10. APl number 50-029-21862 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 8878' feet true vertical 6707' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 115' 16" 5099' 9 5/8" Cemented 199SxAS III 1200 Sx AS III & 375 Sx Class G 8961' 7" 300SxClassG& 175 Sx AS 1 measured 8622'-8640', 8653'-8669', 8675 '-8698' true vertical 651 9'-6532', 6541 '-6553', 6557'-6575' Tubing (size, grade, and measured depth) 2 7/8" 6.5# J-55, EUE 8 RD, ABMOD, 8548' Packers and SSSV (type and measured depth) SSSV: Camco TRDP, 1829', Packer: AVA "RHS", 8477' Measured depth 115' 5099' True vertical depth 115' 4029' 8961' 6783' 8711'-8731' 6584'-6599' RECEJVF,-D 13. Stimulation or cement squeeze summary Intervals treated (measured) S~ ~ '~997 Perforated interval, 8/14/97 Treatment description including volumes used and final pressure "A" sand REFRAC completed. Screened out, injected 237000 lbs of prop in the-fe~~_~;r~e# PPA of #12/18 @ the Perfs. Maximum pressure 7900 psi & F.G. (.77). 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 940 400 - 0 - 1200 1 09 Subsequent to operation 2800 1 170 1 4 125 155 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations 16. Status of well classification as: Water Injector ~ Oil X Gas Suspended Service 17. I here/~ertify that the foregoing is true and correct to the best of my knowledge. (.2 ISigned Title Wells Superintendent Form/40d F~.e,,¢',~~-0 ' L SUBMIT IN DUPLICATE~...~ ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~ K1(30-04(W4-6)) WELL JOB SCOPE JOB NUMBER 30-04 FRAC, FRAC SUPPORT 0810971842.6 DATE DAILY WORK UNIT NUMBER 08~14/97 "A" SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON 'SUPERVISOR 2 (~) Yes (~ NoI ® Yes O No DS-YOAKUM CHAN)EY , FIELD AFC_.,~ CC~ DAILYOOST AOOUMCOST si~ne~ ~ /r ESTIMATE KD1434 230DS36OL $145,501 $154,087 :.::' ~1~ :_...~ Initial Tb~ Press Final Tb~ Press Initial Inner Ann Final Inner Ann ~ Initial Outer Ann Final Outer A~ 850 PSI 500 PSI 500 PSI 500 PSIJ 600 PSI~PSI DALLY SUMMARY I THE PERF'S. MAXIMUM PRESSURE 7900 PSI & F.G. (.77). "A" SAND REFRAC COMPLETED. SCREENED OUT, INJECTED 237000 LBS OF PROP IN THE FORMATION W/10# PPA OF #12/18 @ TIME 06:30 07:45 08:30 09:00 10:00 12:30 13:30 14:30 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC VAC TRUCK, AND LRS HOT OIL UNIT. HELD SAFETY MEETING (14 ON LOCATION). PT'D BACKSIDE LINES TO 4000 PSI AND RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 10300 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 25 TO 15 BPM. VOLUME PUMPED 395 BBLS. USED 6830 LBS OF #20/40 PROP. MAXIMUM PRESSURE 7900 PSI ND ENDING PRESSURE 3400 PSI. S/D AND OBTAINED ISIP OF 2105 PSI W/F.G. @ (.77). STOOD-BY AND MONITORED WHTP. PULSED FOR CLOSURE. (CLOSURE TIME +-14 MINS @ 1680 PSI) PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 189 BBLS. MAXIMUM PRESSURE 4000 PSI AND ENDING PRESSURE 3350 PSI. S/D AND OBTAINED ISIP OF 2146 PSI W/F.G. @ (.77). STOOD-BY AND MONITORED WHTP FOR CLOSURE. (CLOSURE TIME +-14 MINS @ 1750 PSI). PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SCREENED OUT. PUMPED 262350 LBS OF PROP (24000 LBS OF #20/40, 230000 LBS OF #12/18, & 8350 LBS OF #10/14). INJECTED 237000 LBS OF PROP IN THE FORMATION W/ 10# PPA OF #12/18 @ THE PERF'S. LEFT 25350 LBS OF PROP IN THE WELLBORE. VOLUME PUMPED 2590 LBS. MAXIMUM AND ENDING PRESSURE 7900 PSI. STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL UNIT. REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETED AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY-SERVICE DAILY COST ACCUM TOTAL $0.00 $861.00 APC $5,800.00 $5,800.00 DIESEL $250.00 $250.00 ... DOWELL $137,692.00 $137,692.00 HALLIBURTON $0.00 $4,865.00 LITTLE RED $1,760.00 $4,620.00 TOTAL FIELD ESTIMATE $145,502.00 $154,088.00 STATE OF ALASKA AL..-~KA OIL AND GAS CONSERVATION coMMISSION ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~ GAS [~] SUSPENDED [--"J ABANDONED r'~ SERVICE r'-'] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 88-62 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21826 4 Location of well at surface i9 Unit or Lease Name 789' FNL, 1879' FWL, SEC 22, T13N, RDE UM, ~i" ' i LO~ATJC~ F KUPARUK RIVER UNIT 1278'FSL, 2400'FEL, SEC16, T13N, RDE UM ?~F~ ~ ~Jr~~ 30-4 At Total Depth :~,~.;.~.~:~:. ::~.~· ~. ~ ~ 11 Field a~ Pool 1337' FSL, 2156' FEL, SEC 16, T13N, RDE UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) ~ 6 L~se Designation and ~rial ~. KUPARUK RIVER OIL P~L RKB 59'~ ADL: 25513 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ~ 15 Water Dep~, if offshore ~16 No. of Completions JULY 2 1988 JULY 8 1988 ......~ NA feet MSLI 1 17 Total Dep~ (MD+~D) 18 Plug Back Depth (MD+TVD) 19 Directional Suwey ~20 ~pth where SSSV set J 21 Thickness of ~rmafrost 8984' MD & 6785' TVD 8878' MD & 6707' TVD YES ~ NO ~J 1829' f~t MD~ 1700' (approximate) 22 Ty~ El~tric or Other Logs Run DIL,SFL, GR,CAL,SP,FDC,CNL, CBL,GYRO 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP ~ HOLE SIZE CEME~ING RECORD AMOUNT PULLED 16" 62.5~ H-40 SURF 115' 24" 199 SX AS III 9 5/8" 36~ J-55 SURF 5099' 12-1/4" 1200 SX AS III & 375 SX C~SS G 7" 26~ J-55 SURF 8961' 8-1/2" 300 SX C~SS G & 175 SX AS 1 24 Pedorations open to Production (MD+~D of Top and BoEom and 25 TUBING RECORD intewal, size and number) SIZE DEPTH SET (MD) PACKER SET 8710'-8730' MD, 5" W/8 SPF 6583' - 6598' TVD 3-1/2", J-55 8549' 8477' 8765' - 8698' md, 2-7/8" w/12SPF 6558' - 6574' TVD 8653' - 8669' MD, 2-7/8" W/12SPF 6542' - 6553' TVD 26 ACID, FRACTURE, CEME~ SQUEEZE, FTC DEPTH I~ERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7872'- 7892' 45,727 lbs 16/20 CARBOLITE 27 PRODUCTION TEST Date First Production lMethod of Operation (Flowing, gas li~ etc.) I Date of Test HoursTest~ PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO i TEST PERIOD ~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAV~Y-API (corr) Press. 24-HOUR ~T[ ~ 28 CORE DATA Brief description of lithology, porosi~, fractures, apparent di~ and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEIDLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP KUPARUK C 8614' 6513' NA BOTTOM KUPARUK C 8628' 6523' TOP KUPARUK A 8641' :6533' BOTTOM KUPARUK A 8784' 6638' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed -'~z.~¢,~/- '~'"'~-~'~ _ Title /l~,,'t..~"//'--/~),,l///',,3- /-..~',-~,,' Date ~/~',,/'~'~-./ __ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pedinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL 30-4 2/09/89 Frac Kuparuk "A" sand perfs 8711'-8731' in six stages as follows. Stage 1: Pmp 150 bbls Gel Diesel @ 0-20 bpm 0-6700 psi Stage 2: Prop 600 bbls Gel Diesel pad @ 25 bpm 4960-4420 psi Stage 3:65 bbls Gel Diesel w/0-2.3 ppg 16/20 Carbolite. @ 25 bbm 4480 psi Stage 4:75 bbls Gel Diesel w/2.3-4.7 ppg 16/20 Carbolite @ 25 bpm 4300 psi Stage 5:85 bbls Gel Diesel w/4.7-6.8 ppg 16/20 Carbolite @ 25 bpm 4200 psi Stage 6 27 bbls Gel Diesel w/6.8-8.3 ppg 16/20 Carbolite @ 25 bpm 4200-7500 psi Screen out with pressure spike w/8.3 ppg prop @ well head & 34 bbls of 6 ppg stage thru per Breakdown and pad contained 40 pptg Silica flour. Fluid to recover: 925 bbls Sand in zone: +-22000 lbs Sand in csg: +-17000 lbs Avg pressure: - psi Drilli~upervisor Date August 18, 1988 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re- Our Boss Gyroscopic Survey Job No. AK-BO-80081 Well: 3-o-4 Field: Kuparuk Survey Date: August 3, 1988 Operator: T. McGuire Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our BoSs Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Enclosure Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager NL Sperry-Sun/NL Industries, Inc. RO. Box 231649, Anchorage, Alaska 99523-1649 Tel. (907) 522-1737 ARCO ALASKA 3-0-4 KUPARUK ALASKA INC. .:,F ERRY-.:,JN WELL .:,URVEY I Nu. CC!MF.'A_N__Y ANL. HuRAL' E ALASKA DATE OF SURVEY AUGUST._-, ''~', 1'~,:,,:,-'~'"' F:OMPUI'AT l ON DATE AIJGI. I:_RT = .... '~-' ._,, 1988 JOB NUMBER AK-BU-oO~.~ 1 KELLY BIJc, HINU ELEV. = 59.00 FT. VERTICAL SECTION CALCULATED'ALONG CLOSURE TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION PC~'TH DEF'TH DEPTH DEG MIN 0 0.00 -59.00 0 0 100 100.00 41.00 0 15 200 200.00 141.00 0 21 300 300.00 241.00 0 21 400 399.99 340.99 0 24 500 499.99 440.99 0 23 600 599.99 540.99 0 20 650 649.97 590.97 I 55 700 699.92 640.92 3 25 750 749.76 690.76 5 27 800 799.46 740.46 7 0 850 848.93 789.93 9 27 900 898.11 839.11 11 18 950 946.96 887.96 13 10 1000 995.54 936.54 14 11 ~ 1¢)~0 1043 '-'= '~'~ '~'~ o._, ;o4 1~ 42 . -- . I m ~1._ 1100 10~1.75 1032.75 17 30 1150 1139.18 1080.18 19 23 1200 1186.13 1127.13 20 46 1250 1232.65 1173.65 22 15 1300 1278.66 1219.66 23 49 1350 1324.08 1265.08 25 34 1400 1368.94 130~.94 26 49 1450 1413.28 1354.28 28 12 1500 1457.10 1398.10 29 19 1550 1500.53 1441.53 30 5 1600 1543.72 1484.72 30 24 1650 1586.71 1527.71 31 1 1700 1629.44 1570.44 31 31 . 6._4 3:3: 46 1800 171:3 62 1 ~ .62 L. UURoE DOG-LEG D I RECT I ON SEVER I TY DEGREES BEG/1 O0 TOTAL RECTANC~ULAR C00RD I NATE:3 VERT I CAL NORTH/SOUTH EAST/WEST SECT I ON N O. 0 E S 61.39 E S 80.30 E N 83.50 E N 74.69 E N 54.10 E N 5.50 W N 5~?.10 W N 59.69 W N 61.50 W N 60.19 W N 60.39 W N61. OW N 62.60 W N62. OW N 61.69 W N 60. 0 W N 58.19 W N 55.30 W N 52.60 W N 51.10 W N51. OW N 50.89 W N 50.80 W N 51.60 W N54. OW N 56.60 W N 58.30 W N 60. 0 W N 61.30 W O. OO 0': O0 O. OO O. 00 o.25 o. 10 s 0.19 E -0.22 0.15 0.26 S 0,.6.? E -0.74 0.10 0.'-'° S~.~. 1.31 E -1.._C:l 0.08 0.15 ~ 1 '~= - .~.:, E -1. o._,'-'= O. 14 O. 14 N '-' 56 E -'2.'-" 0.37 0.6:3 N 2.81 E -2.33 3,50 1.21 N 2,07 E -1.43 :3 O0 2.40 N 0.06 E 0. 4.07 4. ~.'-,9 N 3.33 W 4.74 3.09 6.94 N 8.06 W 10.13 4.92 .... !.0,48 N . ~4,.~! W .1. 7,~4: o 71 14.89 N 22 14 W 26 20 ._m. . . 3.78 19.89 N 31.48 W 36.75 2. c)6 2~, '?'~ · -~ N 4!,'~.~ W 48,~4 3.04 31.47 N 53.32 W 61.38 3.73 38.44 N 65.80 W 75.59 3.40 56.00 N 93.71 W 108.14 ~.56 66.79 N 108.52 W 126.00 3.3~ ..... 7~,~ N ..!.~,89 W 144,~8 ~.50 92.01N 140.14 W 164.96 2.52 105.92 N 157.28 W 1'~'~.18 · ~.,76 !~0,.~! N ......... 175,!9 W 2.37 135.58 N 193.95 W 231.53 2.82 150.56 N ~13.69 W 255.55 2.70 1~4,89. N __ 234,.39 W _~80,~1 2.12 178 63 N 255 92 W o0._ 39 2.04 191.93. N 278.~0'-'~ W o._l'~q .11 2.35 218,35 N :~25,2~ W 384,72 ARCO ALASKA, 3-0-4 KUPARUK ALASKA INC. 'SPERRY-SUN WELL SURVEY]N!~i ANCHORAGE ALASKA VERTICAL SECTION CALCUL~TEKi"'ALONI3 P..LuoURE-'-'" COMPLITATION DATE ALUUoT 5, 1Po.=, DATE OF SURVEY AUGUST 3, 1988 dOB NUMBER AK-BO-80081 KELLY BUSHING ELEV. = 5'~.A0 FT. C! P E_R_.A_ T. g!B .- _M C__:_G !J. !R__E_E ...................... MEASURED ~']PTH 1900 2000 2050 2100 2150 2200 2250 2300 2350 2400 2500 2600 2700 2800 2'~00 3000 :3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 TRUE SUB-SEA C:OURSE VERT I CAL VERT I CAL I NCL I NAT I ON DEPTH DEPTH DEG M I N 1794.93 1735.93 37 24 1872.20 1813.20 41 22 1909.38 1850.38 42 32 1945.82 1886.82 43 52 1781.44 1922.44 45 15 2016.13 1957.13 46 51 2049.74 1990.74 48 38 2082.38 2023.38 49 49 2114.41 2055.41 50 30 2146.04 2087.04 51 0 2208.77 2149.77 51 18 2271.08 2212.08 51 36 2333.25 2274.25 51 30 23~6.3~ 2337.39 50 10 2462.26 2403.26 47 24 2530.68 2471.68 46 14 2600.63 2541.63 44 58 2671.59 2612.59 44 37 2742.74 2683.74 44 39 2813.87 2754.87 44 39 2885.08 2826.08 44 31 2956.14 2897.14 44 56 3026.81 2967.81 45 7 3098.02 3039.02 44 3 3170.14 3111.14 43 38 3242.81 3183.81 43 8 3316.02 3257.02 42 43 338~.5~ 3330.59 42 32 3462.92 3403.92 43 7 3534.41 3475.41 45 34 COLIRSE DOG-LEG DIRECTION SEVERITY DEGREES DEG/100 TOTAL RECTANGLILAR COORD I NATES VERT I CAL NORTH/SOUTH EAST/WEST SECT I ON 61.1'~) W 3. 60 60 W '-' 61.10 W 2. · o~ W 3. 60.17~ W 2. 60 '"" . .o0 W 3 60.5"~ . .-,~ W 3 60 '-" . .,:,0 W 2 60.10 W 1. 60. 0 W 0. 5'~. :3'~W 0. 5~. 10 W 0, ~'~ /-,9 . · _,.=,._. W 0 57.80 W 1. 59.10 W 58.69 W 1. 61.30 W 2. 61.19 W ....... ~.~ 60.69 W :::::0. 60.3~ W 60.50 W 5?0:, 64.6~ W :-'2. 65.80 W .... 0. 66.8'~ W N 67. OW 0. 66.30 W (), 66. 0 W ........ N Z-M 6'P W 0 66. C) ~ C), 64 98 43 14 79 31 . 58 36 73 56 33 5O 21 25 35 21 80 3~ 42 46 28 62 55 246.34 N o76.~4 W 277.21 N 431.67 W ~ ~:_~. 49 N 460 '~' .06 W 310. '-'= .:,~, N 490.65 W 327.87 N 521. t._, W ~,4._,. 59 N oY W '- '-" 62 t~6 .... N .Jo~. 71 W 382.06 N 617.78 W 401, O0 N 420.33 N 684.73 W 4._, ~. 63 N 751 . ?~7 W 540.07 N 886.26 W 580.87 N ~5~.~.19 W 657.~1 N 1078.73 W ~._~.64 N 1140.58 W 761.65 N 1263.79 W 796.21 N 1325.00 W 8~0,¢4_N 138~.07 W 863.20 N 1448.53 W 892.82 N 1512.78 W ~20.~8 ~ ..... I~ZZ..Q8 W 948.11N 1640.82 W 975.33 N 1703.88 W 1002.87. N 1766,18 W 1030.58 N 1827.99 W 1058.40 N 18~0.03 W 1087.39 N 19~8,62 W 442.61 505,70 538,94 572.95 607.78 680.35 718.00 75~,1~ 794.5~ 871.84 ..... ~4~...~ 1026.89 1103.52 1177.'~. 1250.11 1321.01 ........ 1~1.._1.3 1461.01 1530.86 1600.~0 1670.74 1741.46 1811.~5 1880.92 194~.62 2017,73 2085.45 2153.42 ~,. ARCO ALASKA, .5:-0-4 KUPARUK ALASKA INC. VERTICAL SECTION CALCULATED~ALONG L. LOoLRE~' -'-' ~ , :=,FERR ~'-.:.LN WELL._,URVEYING COMPANY PAGE ANCHORAGE ALA.=.KA - ,- DATE OF SURVEY AUGUST ~, 1.~,~, AI.IL. iL.:,T 5 1 ~,:,,:, dOB NUMBER AK-BO-80081 KELLY BUSHING ELEV. = 59.00 FT. MEASURED r']PTH 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 ~; I -'~ TRUE ... L B ~ EA COLIRSE VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEG M I N 3604.27 3545.27 45 46 3674.01 3615.01 45 46 3743.93 3684.93 45 30 3814.50 3755.50 44 43 3885.61 3826.61 44 37 3957.12 3898.12 44 4 4029.10 3970.10 43 51 4101.21 4042.21 43 50 4173.20 4114.20 44 4 4244.94 4185.94 44 15 4316.43 4257.43 44 28 4387.53 4328.53 44 54 4457.50 4398.50 46 1~ 4526.65 4467.65 46 10 4595.92 4536.92 46 8 4665.36 4606.36 45 52 4734.79 4675.79 46 10 4804.15 4745.15 45 59 4873.63 4814.63 45 59 4943.24 4884.24 45 46 5013.21 4954.21 45 24 5083.06 5024.06 45 58 5153.07 5094.07 45 8 5223.62 5164.62 45 6 5294.21 5235.21 45 4 5365.33 5306.33 44 15 5436.98 5377.98 44 13 5508.60 5449.60 44 18 5579.44 5520.44 45 28 5649.54 5590.54 45 30 _.ULRoE DOG-LEG DIRECTION SEVERITY DEGREES DEG/100 N 64.89 W N 65.19 W N 65.30 W N 64.50 W N 64.19 W N 63.89 W N 63.19 W N 63.10 W N 62.89 W N 63.10 W N 63.10 W N 66.80 W N 71.50 W N 71.60 W N 71.89 W N 71.89 W N 72.30 W N 72.50 W N 72.69 W N73. OW N 73.50 W N 74. OW N 74.30 W N 74.60 W N 74.80 W N 71.39 W N 70.69 W N 71.19 W N 72.39 W N 72.80 W TOTAL RECTANGULAR L. UL RD I NATEo VERT I L. AL NORTH/SOUTH EAST/WEST SECTION 0.21 0 '-"'- . ....4 0.96 0.60 0.53 0.07 O. 27 0.24 0.21 2. ~,4 o, 64 0.17 0, 0.27 O. 42 0.14 O. 30 0.51 0.67 O. 86 O, 22 0.1~ 2.53 ....... _0.49 O. 36 1.45 0.29 1117.69'N ,=01 :_~. 44''W 147.92 N 2083.41 W 177. '-= 21 :~._, N 48. W .................... t,:'4 , 207.90 N 1'--"-'"',-._-,o. :3:3 N ~..- .-. 84 N '~33~. ~3 N 362.64 N 394.27 N ~4~._,.9~ N 2294. '7'.-? · .o66.41 24:37 ,~o 2212 · ;..,0 W 250:=-:. 67 ~.,'.,.. ,:,o W ..'._,7o. 91 2338.7:':: W 2648:.._72 2400 89 W 271~ cz 2462.69 W 2787.14 ~..,~6.62 W 2925_. o..~'-'¢ 2648.97 W 2995 ' = ~455,.6Z N .... 2.7!2,67. W 1481.06 N 2779.43 W 1503.~1 N 2847.94 W 1~26,5Q N .... 2~16..~4..W 1548.86 N 2984.83 W 1570.98 N 3053.32 W 306~,?1 3137.28 320~.28 ~281,16 3352.84 3424.52 1614.27 N 3190.62 W 3567.81 1635.44 N 3259.22 W 3639.23 __16~6,03 N. ~27.63 W ~710.24 1676.05 N 3396.33 W 3781.31 1695.55 N 3465.02 W 3852.15 !7!4,~ N ~,29 W 3922,42 1733.24 N 3601.61 W 3992.60 1753.65 N 3668.84 W 4062.47 !776,31 .N ~7~4,82 W 4132.0~ 1799.08 N 3800.79 W 4201.67 1821.12 N 3867.83 W 4271.99 1842.44 N 39~5.8~ N 4342.96 ARCO ALASKA 3-0-4 KUPARUK ALASKA INC. SPERRY-SUN WELL SURVEYIND. CDMPI~Y ............................................................................... E'AGE ANCHORAGE ALASKA DATE OF SURVEY AUGUST dOD NUMBER KELLY DUSH~NG ELE~. = ~" · _,:/. O0 FT. COMPUTATIQN DATE .... ALIUU~T ~ · ,r.~,=,,~ · -~, .I. :: ~.,,- VERTICAL SECTION C:AL,E:L~L~ATED" ALONG CLOSURE MEASURED P'=')F'TH 7500 7600 7700 7800 7900 :5:000 8100 8200 8300 8400 8500 8600 8700 8800 8856 ,:. ! 8984 HEiR TRUE SUB-SEA IL. uLIR.:,E VERTICAL VERTICAL INCLINATION DEPTH DEF'TH DEG M I N 5719.60 566,0.60 45 33 5789.83 5730.83 45 13 5860.23 5801.23 45 16 5930.50 5871.50 45 26 6000.86 5941.86 45 6 6071.46 6012.46 45 4 6142.27 6083.27 44 46 6213.55 6154.55 44 18 6285.30 6226.30 43 59 6357.41 6298.41 43 43 6429.96 6370.96 43 15 6502.86 6443.86 43 8 6575.99 6516.99 42 52 6649.28 6590.28 42 52 66,90.40 6631.40 42 37 6722.77 6663.77 42 2:7 6784.57 6725.57 42 37 IZONTAL DISF'LACEMENT = COURSE DOG-LEG DIRECTION SEVERITY DEGREES DEG/IO0 .... TOT.~L REc TANGULAR COORD I NATES VERT I C:AL NORTH/SOUTH EAST/WEST SECT I ON 7:'::. 0 W 0.15 1 :z¢'.--. ' ....::)' .... ( ,~, ~ o._',. 43 N 4U(: 4. 3o W 4413.9:3 73.6'.-.? W O. 5:~ 1883 '~"-' '- ' ':' , o~. N 4072. '...'~ W 44,_,4.68 73.F:9 W 0.15 190~,64 N .... ~.1~4Q, 48 W_ 74.39 W O. 40 1 ~''=''- . . '.-~.11~.07 N 4208 :-73 W 4625 80 74.60 W 0.37 1.942.06 N 4277.4(i) W 46.96.24 74.:::(-) W 0.15 1.960.75 N.. 43~,~.! W 476~,,42 75. :30 W 0.46 1.978..96 N 441'--:J. 93. W 4oL~6.33 7.5. :=:9 W 0.48 1996.70 N 4481.7.9 W 4.905.71 7.5 .=,(.) W 0.32 '-~" , 4 .. . W . _. ..-o 14.20 N 54'~, .~o 4974, . . ._ (.)4.:,. 0:~ 75 8..-.? W 0.3.9 2031 31 N 4616_-,.34 W ?,' '-' 76.10 W 0.48 2047...~6 N 4683.12 W 5111.05 . . · . - . .... '-' ...=,178, 76, 1.-.? W O. 14 ~.0~,4 ~_.N .~7..4L9.~:, W 76. :2:9 W 0.30 2080.50 N 4815.85 W 5245..94 7/.-,. 3'.-.-: W 0.00 20.96.50 N 4881..97 W 5313.05 '76. :2:0 W 0.44 2 ! 05.47 N 4'.~ 18. S~ 1 W 5350.5.~ 7/-,. 30 W 0.00 2112.53 N 4.947.86 W 5::-:79.97 76.30 W 0.00 .'-'126.00 N 5003.1'~._ W .=,4:-~6_ _ .11 54:36.11 FEET AT NORTH 66 DEG. THE C:ALC'LILATION PROCEDURES ARE BASED ON THE USE OF THREE DIM_EN~!ON~L F(ADIU$ OF_CURVATURE METHOD. ARCO ALASKA, 3-0-4 KUPARUK ALASKA INC. .:,FERRY-;:,_IN'" '- ' ' '"1 WELL .:,.IRVEYING'-'I ' .......................................................................................... !;;.!:~MPANY F'~I.C~E ~' .. ANCHORAGE ALA~. F.A DATE OF SURVEY AUGUST ;3, 1'- '-'' '~'~ ¢, o COMPUTATION DATE. AUGLIST._.=., 1988 ,JuB NUMBER AK-Bu-c~o(.:.31 KELLY BUSHING ELEV. = 59.00 FT. INTERPOLATED VALUES FOR EVEN 1(:)00 FEET OF MEASURED DEPTH TRLIE SUB-SEA M ,IE. ASURED VERT I C:AL VERT I CAL )F:'TH DEF'TH DEF'TH TOTAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL NORTH/SOUTH EAST/WEST DIFFERENCE . C:CmRRE...C.:T ! ON 0 0.0 0 - 5 9.0 0 ('). 0 0 0.0 0 0.0 0 ~,4 ?;.:, W 4 46 4 46 · . - · ; --', 6 · ~ 10 (.) 0 '::';'~'; ~ 54 '--;'-' '-".=; '~' · .:,.-. N 41 '-= OF)(') 1:_::72 2c') 1 o 1':' 2(.) 277.21 N 4:31 /_-.7 W 127 :BO 12:3:34 # # # ,_I ~ m · · · i_l ..... · ~ . 1 N 1(.)7,:. .... :30C)0 25:::(') 6:3 2471 6,:--: 6._7 9 ' '-' 7:3 W 469:32 341 52 ,."/ · -.,.-.~ .-], ,.~ .'j~ ,-,.-~ 40C)0 ..,.. 4... ,_ 1 1 I .-. 7._ :33 N 170:3 °-"~" ,--,,~ W 757 1:~ 287.87 · _, ,_-',.-,. iD · . · · '-'~= '-"--"-"~" 73 W 1042.88 285.69 5000 .:, .... ,7.12 ~::;:'~:'::: 1 ']' 12A::~ '~2 N .... · .~. . . · . .~ ._',._-, ,=i · /.:,000 ~/. z S .-, · .=,,~o ,-,/. '-"--'-~"' d._': W 13'::34 64 291 76 -. ~-,o._ :'~/-, 4606 ._',6 '-'- . _ _ . · ,--, i], N --'-~ 7000 ':'-" .'=, :'::3 17._ ._-,./_-,.5 N ::~/-,A8 ~--,4 W 163:4.67 ~300. OC-~ · ..~.z. o,., _ ?, :':: (') /', ":' '';" .~'-' -- -- . _ · ._I._l _ _ . · 8C)00 6071.46 6012.46 1 '.-.-/6C), 7.5 N 4:345.71 W 1928 · 54 29:3.6:,7 ~ /.-7--.,~ 57 212/_-. C)(-.) N ~ (.) F) :':: . 1 '-~' '-' .) - :E: 'F; .'E: 4 67:34 · ._ 7 .... ~. ........ ,:~ W :21 .c;.c;. 4:3 ,..7(-. THE CALCULATION PROCEDURES ARE BASED I_-IN THE LISE OF THREE DIMENSIONAL RADIus OF cuRVATURE METHOD. ARCO ALASKA, 3-0-4 KUPARUK ALASKA tw=ASLIRED ( .PTH 0 59 159 259 359 459 559 659 759 860 962 1065 1171 1278 1388 15£)2 1617 1734 1855 I NC:. SPERRY-:_:;LIN WELL SLIRVEYIN.Q g;OMPAN¥ ....... ANCHORAGE ALASKA COMPUTATION DATE AL;GUST 5, 1988 DATE OF SURVEY AUGUST 3, 1988 dOB NUMBER AK-BO-80081 KELLY BUSHING ELEV. = .OR£RfiTORrHGGUIRE_ ~,y. 00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE VERTICAL DEPTH · . _ SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENt[ VERTICAL 0.00 59.00 159.00 259.00 359.00 459.00 559.00 659.00 759.00 859.00 ~59.00 1059.00 1159.00 1259.00 1359.00 1459.00 1559.00 1659.00 1759.00 -59.00 0.00 0. O0 O. O0 0.00 0.02 S 0.04 E 0.00 100.00 0.2'2 S 0.44 E 0.00 200.00 0.31 S 1.06 E 0.00 · :,0.) 00 0 '-"- . . ..,:..:: S 1 67 E 0 O1 400.00 0.02 .=,'-' .,.'-'.._:~":' E..,, 0.01 500.00 0 ""'- N 0.01 ._-~ :.,' '-., 600.00 1.37 N 1.81 E 0.0:3 700.00 4.71 N 4.10 W O. 800.00 11.31 N 15.74 W 1.21 900.00 21.19 N "~"-'.:,.:~. '..-79 W 10 0 0.0 0 '-"-' ~']':' · :,.:,....._, N 57. 11 W 6.76 11 O0. O0 ._,=C.), 33 N o'-' -'=._,. 33 W 12.04 · -.00 O0 7:_'-:.46 N 117 16 W o--! - . · _-, 00 00 102 7..5 N 1 ='-' '-"- . ._~._-,.._-,,_-I W ~.'7"'~ 1400.00 136.24 N 194.7:-': W 1 c - - · :,00 00 169 '-' '~' . . ,=,.:, N 241 1600 O0 201 O0 N '-"~ . . . ..'.-.~...,. 91 W 1700. O0 ~:,.-.:-,'--"~- '-'. 51 N ._.' -~ =:. ':'... ..- , 88 W O. 00 O. O0 0., O0 O. O0 0. O0 0.,:-,..">"=' O. 92 3.39 5.28 86 10.34 43.17 13.31 75.68 16.96 96.26 20.58 ARCO ALASKA, 3-0-4 KUPARUK ALASKA '. =F'TH 1982 2118 2264 2420 2580 2741 2895 3040 3182 3322 3463 3604 3745 3884 4022 4158 4294 4435 4578 I NC:. 'SF'ERRY-SUN WELL '-'_ 'YING COMF'ANY ANF:HORAGE ALA._ KA C:OMPIJTATION DATE AUGUST 5, 1988 .... EtA, GE . 7 DATE OF SUR~EY AUGUST 3~ 1988 KELLY BLISHINA ELEV. =._,y='-.00 FT. OF'ERATOR-MC:E~LI I RE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MD-TVD VERT I CAL DIFFERENCE C.C!RR_E.I_::I'_II_-.!N TRUE VERT I CAL DEF'TH ._,LIB ~,EA VERTICAL DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 1859.00 1959.00 2059.00 2159.00 2259.00 2359.00 2459.00 2559.00 2659.00 2759.00 2859.00 2959.00 3059.00 3159.00 3259.00 3359.00 3459.00 3559.00 3659.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 271.59 N 421.68 W ._t~1.6.- W 316.71 N .~' '-' '--"/'---' ~':','":' '-? 3 W · :, =,o. 75 N 428. :_-':4N ,".~,'~.~8.5'.:'," W 491.7::: N A06.10 W 556.:$:9 N 913.90 W 61:=:. 4A_ . N 101'--'._~..~'-"'--'.= W 673. '25 N 1104.00 W 721 .=; 9 .._4 N 11 1.47 W 769.52 N 1277.80 W "" 74 W ,=,. 21 N 1 ":'/- ":' ._l _i,_l · 864.4.'.--:N 14.51.11 W tV06.01 N 1542 .~.~.'-.' ''~ W c ":' '.'76 163 04 /4 .... 1",4 1. W "..-'?:--:1.43 N 1717.78 W 1019.03 N 1c,'"O'-'. ,.-. -,," ,.,,', 105/_-,. 90 N 1 :::86.67 1-c,-, cJ :-]~. 00 N 1 '.-776.._ 6 1141.45 N ...-,U,6Y. 41 ,,,. 123.52 27.25 159,28 35,77 205.04 45.75 261.59 56.55 321.55 59,~ _ . 382.35 60.81 436.16 53.81 481.94 45.78 523.31 41.37 563.86 40.55 604,42 40,~6 645.04 40.62 686.58 41.54 725,~0 ......... 3~,03 763.19 37.58 W 799.48 36 · 29 N .............. ~;~_~6;i .......................... 3..6..,._1.5 ............................................. W 876.14 40· 51 W .g 19.47 43.34 ARCO ALASKA, 3-0-4 KUPARUK ALASKA ~mASLIRED ( .PTH 4721 4862 5002 5141 5280 5419 5559 5702 5846 5990 6134 6278 6422 6565 6708 6850 6991 7130 7270 INC. ¢ ..... c. SURVEYING COMPANY ._.FERRY ._,LIN WELL ANCHORAGE ALASi<A C:OMPUTATION DATE AUGUST 5, 1988 RAGE DATE OF SURVEY AUGUST dOB NUMBER AK-BO-80081 KELLY BUSHING ELEV. = D~EF~TOR.~;OL!IRE 1988 59.00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE VERTICAL DEPTH SUB-SEA TOTAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD DEPTH NORTH/SOUTH EAST/WE~:;T DIFFERENCE VERTICAL t--;QRRECT I ON 3759.00 3859.00 3959.00 4059.00 4159.00 4259.00 4359.00 4459.00 4559.00 4659.00 4759.00 4859.00 4959.00 5059.00 5159.00 5259.00 5359.00 5459.00 5559.00 3700.00 1184.26 N 2162.27 W 3800.00 1226.90 N 2252.22 W 3900.00 1269.72 N 2340.36 W 4000.00 1312.80 N 2426.53 W 4100.00 1356.38 N 2512.30 W 4200.00 1400.47 N 2598.84 W 4300.00 1444.17 N 2686.76 W 4400.00 1481.56 N' 2780.92 W 4500.00 1514.54 N 2879.92 W 4600.00 1546.82 N 2978.60 W 4700.00 1578.65 N 3077.35 W 4800.00 1609.76 N 3176.16 W 4900.00 1640.17 N 3274.71W 5000.00 1669.19 N 3372.40 W 5100.00 1697.17 N 3470.76 W 5200.00 1723.97 N 3567.54 W 5300.00 1751.68 N 3663.00 5400.00 1783.39 N 3755.05 5500.00 1814.83 N 3848.02 962.50 43.co 1003, 60 1043.61 40.01 1 ' L--, '--.~ ~--~ C~c,~.. 47 38.06 1 _l 21.2:3 1160.63 39.40 1200 .' 79 40.15 1243.18 42.39 1287.71 44.54 1331 '~'~ · .c,., 44 15 !375,96 ......... 44. ,10 1419.94 43.98 1463.60 43.66 1549, 41 43, 04 1591,13 41,72 W 1671.73 39.57 W 1711.85 40.12 ARCO ALASKA 3-0-4 KUPARUK ALASKA I NC:. SPERRY-F;UN WELL SLIRVEYIN~ ¢:OMFLAN_Y ANC:HORAGE ALASKA COMPLITATION DATE ALIGLIST 5, 1988 DATE OF SURVEY AUGUST 3, Jo~'-NO~B~R--'AK-BO- 80081 KELLY BUSHING ELEV. = ~PER~TOR-MC:GUIRE 59.00 FT. MEASURED ( PTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL VERT I _.AL VERT I CAL RECTANGULAR COORD I NATES MD-TVD DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL C0RRE~:T_ION ...... 7413 5659.00 5600.00 1845.29 N 3945.07 W 1754.49 7556 5759.00 5700.00 1875.08 N 4042.44 W 1797.21 7698 5859.00 5800.00 1903.29 N 4139.29 W 1839.25 7840 5959.00 5900.00 1930.85 N 4236.82 W 1881.63 7982 6059.00 6000.00 1957.47 N 4333.66 W 1923.36 8123 6159.00 6100.00 1983.18 N 4429.99 W 1964.57 8263 6259.00 6200.00 2007.84 N 4524.62 W 2004.44 8402 6359.00 6300.00 2031.68 N 4617.81W 2043.20 8539 6459.00 6400.00 2054.53 N 4709.64 W 2080.87 8676 6559.00 6500.00 2076.7? N 4800.52 W 2117.81 8813 6659.00 6600.00 2098.62 !'~ 4890.74 W 2154.2~ 8949 6759.00 6700.00 2120.43 ~ 4980.26 W 2190.24 8980 6781.63 6722.63 2125.36 ~. 5000.50 W 2198.37 42.64 42.72 _ . 42.04 42.38 .41.73 41.21 o~.87 38.76 37 /v-' :36.94 :~/_;,, 45 :35.98 :3.1o-. THE CALCULATION F'ROC:EDURES USE A L. INEAR INTERFLLATIUN BETWEEN THE NEAREST '-'C ' ~ '-' · .-) FOOT MD (FROM PA[ILl._-, OF F:URVATURE) POINTS ARCO ALASKA, INC. 3-0-4 KUPARUK ALASKA · ':;PERRY-L:;UN WELL '.3URVEY INO COiF'ANY ........................................... PAGE iD'. ANCHORAGE ALASKA DATE OF SURVEY AUGUST 3, 1.986: C:OMPUTATION DATE AUGUST 5, 1'~88 dOB NUMBER AK-BO-80081 KELLY BUSHING ELEV. = 59.00 FT. . OPE~T_OR_-_I~LC'GU.I.E:E .. MEASURED ( PTH INTERPOLATED VALUES FOR SPEC:IAL SURVEY POINTS TRUE SuB-SEA TOTAL VERT I C:AL VERT I CAL REC:TANGULAR COORD I NATEs--: DEPTH DEPTH NORTH/SOLITH EAST/WEST MARKER 8614 6513.08 6454.08 2066.63 N 4758.88 W 8628 6523.29 6464.29 2068.92 N 4768.18 W 8641 6532.78 6473.78 2071.04 N 4776.81 W 8784 6637.55 6578.55 2093.94 N 4871.39 W 8856 6690.40 '6631.40 2105.47 N 4918.91 W 8878 6706.59 6647.59 2109.00 N 4933.39 W 8984 6784.57 6725.57 2126.00 N 5003.13 W TOP KUPARUK C BASE KUPARUK C: TOP KUPARUK A BASE KUPARUK A SURVEY DEPTH PBTD TD ARCO ALAoKA· INC' 3-0-4 STRAT I GRAPH! C. ~UMMARY DERIVED USING DIL DEPTHS AND SPERRY :-] SURVEY DATA ._ LIN ' BKB -TVD BKB SUB-SEA TOP KUPARUK C 8614 6513.08 6454.08 BASE KUPARUK C 8628 6523.29 6464.29 TOP KUPARUK A 8641 6532.78 6473.78 BASE KUPARLIK A 8784 6637.55 6578.55 PBTD 8878 6706.59 6647.59 TD 8984 6784.57 6725.57 COORD I N~TE~ THIF:KNESS ......... WITH REF. TO WELLHEAD VERTICAL (ORIGIN- 78'~FNL 187';-~FWL) .............. SEC 22 T13N RO?~ 2066.63N 2068.~2N 2071.04N ~.*~o.~4N 210~.~ON 2126.00N 4758.88W 4768.18W 4776.81W 4871.39W 4~33.3~W 5003.13W 1) FROM LINEAR EXTRAPOLATION BELOW [EEFEoT STATION 2) COMPUTER PROGRAM - SPERRY'"~UN THREE DIMENSIONAL RAEIdo' ~ I~' OF CURVATURE. DATA CALCLILATION AND INTERPELLATION BY RADIUS OF CLIRVATURE COMPUTATION DATE AUGUST..,M 1988 ,_lOB NUMBER AK-BO-80081 KELLY ..B.U:~H!.NG ELEV. = ~_'?,,0~;:~ FT. SPERRY -SUN f ---6000.00 INCH TO lO00. O0 / lO00. O KUPRRUK RRCO RLRSKR. INC. $CRLE :- 1 5-0-4 RUGUST 5. !988 .- RK-BO-80081 ' ~' TRdE NORTH 89,84 -5000. O0 -4000. C~ -~COO. O0 -2000. CO SPESR¥ -SUN 0.00 ~500.00 ~O00. CO 45C0. CO 6000.00 /SCC. C6 r SCALE :- 1 INCH TO 1500.00 / 1500.0 KUPRRUK ARCO ALASKA, INC. 3 -0 -4 AUGUST 3, 1988 qK-BO-BOOBt S784. 07 ~8984 I I I PROJEC-F i ON STATE OF ALASKA ALASKA OIL AND ~ CONSERVATION COMMISo~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown .__ Pull tubing Alter casing 2. Name of Operator ARCO Alaska. Inc. 3, Address P. O. Box 1003.60, Anchorage, AK 4, Location of well at surface 99510 Stimulate X Repair well 5. Type of Well: Development ~ Exploratory _ I Stratigraphic _ Sent~ce ~ 789' FNL, 1879' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1278' FSL, 2400' FEL, Sec. 16, T13N, R9E, UM At effective depth 1306' FSL, 2200' FEL, Sec. 16, T13N, R9E, UM At total depth 1337' FSL~ 2156' FEL~ Sec. 16~ T13Nr R9Er UM 12. Present well condition summery Total Depth: measured 8 9 8 4' feet true vertical 6785' feet Plugging Perforate Other 6. Datum elevation (DF or KB) Plugs (measured) 59' RKB 7. Unit or Property name feet Effective depth: measured 8 8 78' feet true vertical 6707' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 115' 16" 5099' 9 5/8" 8961' 7" measur~ 8622'-8640', true vertical 6519'-6532', Cemented 199 Sx AS III 1200 Sx AS III & 375 Sx Class G 300 Sx Class G & 175 Sx AS 1 8653'-8669', 6541'-6553', Tubing (size, grade, and measured depth) 2 7/8" 6.5# J-55, EUE 8 RD, ABMOD, 8548' Packers and SSSV (type and measured depth) 8675'-8698', 6557'-6575', Kuparuk River Unit 8. Well number 30-O4 9, Permit number/approval number 88-62 10. APl number .~r 50-029-218~ 11. Field/Pool Kuparuk River Oil Pool Measured depth 115' 5099' 8961' SSSV: Camco TRDP ~ 1829'r Packer: AVA "RHS"r 8477' 13, Stimulation or cement squeeze summary 14. Intervals treated (measured) Perforated interval. Treatment description including volumes used and final pressure True vertical depth 115' 4029' 6783' 8711 '-8731' 6584'-6599' Refractured A Sand w/104 M LBS proppant & 1700 BBL gelled sea water. Final pressure 5400 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 940 400 - 0 - I 200 I 09 2800 j 1170 /'~ 14 f 125 155 16. Status of well classification as: Water Injector__ Oil ~ Gas Suspended Service Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Operations Engineer Date SUBMIT IN DUPLICATE Form 10-404 Rev 09/12/90 ARCO Alaska, Inc.-~, Subsicfiary of Atlantic Richfi®lcl Company WELL SERVICE REPORT WELL j PBDT 30-~/ 9'¢75 IFIELD- DISTRICT- STATE OPERATION AT REPORT TIME dTRACTOR , 'l ~ l l t 'b u.r.to ,~ - ?'.13. REMARKS JDAY? IDATE I ~/,~/~ ~ 0700 ,r--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport~l!Temp' °F !Chill Factor. F Visibility miles jlWind VoL REMARKS CONTINUED: DESCRIPTION CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision L,i-/-/-i, £~ d Pre-,Job Safety Meeting AFE TOTAL FIELD ESTIMATE DAILY -lC-(~- O- - ACCUM. TOTAL I ClT,qo q , 757 c~t c~c) 1/.,5o0 I 7?,57(-/ :[ :12: mRU.,' C I/'NU/":DR ! LL I NI3 AIL WELLS lOCATED IN SEC. 22 T. 13 N,, la,. 9E., UMIAT MERIDIAN. TEL NO:9~?-265-~Zl~ im i mmm __ VICIN. ITY MAP ~ 6~z 2 MIKES NOTES I. N.A, COORDINATES ARE A.$.P., ZONE 4. 2. ALL DISTANCES ~HOWN ARE TRUF, 3, ELEVATIONS ARE B.P.M,~,L 4, REFER. FIELD 8gX)K LoBB-~, ~-$S. 5. 0.~ ELEVATIONS FROM CED-RIXX-$365A 6, HORIZONTAl.. POSITION BASED ON ~) CONTROl. MONUMENTS ~ I,OUN~BURY & &agog. ................... O~ST. OiST. o.~. Wej. I Y ASPs X LATITUDE LONGITUDE: ._. , ....... ,1., ,J~ 6,022,073.~ 525 ~490.94 7Oe~' 17. 128" 149047'30.5~'' 745' 1855' I ,7, 23.5; 6,OZ2,030,~ 525,5~5.58 ~28, ~&~ ,, f49°41, Z9.8~. 6~02~8.~ 525 ~528.58 7~Z8, t49e 47, 29.4~. 8l I, 1092, 18, I 2~6 ,,021,987, 12 5Z5,5~,73 ~' 1~5,, ' 1~2~. 149047, ~,071. 032, 19~ ? 6~021,965,~ 5~5 ~555.~ 1~059 14~47 28,G~. 05~ 1917, 18.2, 2~1 ' ~5,~", ets: ~e. 3, 9 6,0~ I ,~Z~. IZ ~ ,575.z7 i5.6~2' 149047 27,974 897 1941 18.4 23.2 I0 6~021 t84~ 525 ~62~,6l . ~28' 14,~3" 149047'26.6~'' 975' 1986' Il 6,021,822.~ 525 ~655.7t ~.' 14.651" 149e4T'Z6.~5" ~7' 1998' 18.0' 23.5' l~ 6,021,8~.87 525,648.~ 7~26',' 14,4~7" 149~47',~.9~ 1019' 2011' 18.8' ;3 6,O21,779. 16 525,66i .~ ~9~ 14,223" 149°47,25.~. 1041' ZOZ4', 18.9', 2~.0, ~.~5 14ge47 24. a~ 2048, ,735, li~ 6,021,714. 15 5Z5,6~. t7 ~e2B' 13.~3" 14go47'Z4.4~" 6,0Zl ~69~ 5~5,710.85 ~' !3.36~" t4~e47'Z4.0~' t 12~ 2073 Ig.O' 2[~' t8 6,02 1,670. 97 525 ~1~3.~ ~29' t3. 157" 149047'Z3,733" 1149' 2085' 19.0' 23.3' I HE~E~W' CERTIFY THAT t AM PI~OPERI,¥ ~CE ~ND 3URGING tN ~A~ ~ A~3KA AND ~AT P~AT REPRESENT~ A 4~ATION SU~EY ~ ~ UE ~ ~DER. ~ ~PERViSlON, ~D ~AT DIMEN~IO~ ~ ~ ~E C~RECT ~ ~ % . ............ ,_ _ Atas a ,4?' D.S. 3.0 WELL coNDUCTOR AS-BUILT LOUNSBURY Associates ANCHORAGE .............. D,,,. bT' MO'D "ALASKA. ! ~,,h,k ~' AJR ARCO Alaska, Inc. Date: July 7, 1989 Transmittal #: 7505 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H -0 2 Kuparuk Fluid Level Report 6 - 2 1 - 8 9 Casing 30-04 Kuparuk Fluid Level Report 6 - 2 1 - 8 9 Casing 3 J - 0 6 Kuparuk Fluid Level Report 6 - 2 1 - 8 9 Casing 3 A-0 5 Kuparuk Fluid Level Report 6 - 2 1 - 8 9 Casing I E-20 Kupaurk Fluid Level Report 6-28-89 Tubing I E- 2 0 Kuparuk Fluid Level Report 6 - 2 8 - 8 9 Casing Receipt Acknowledged: ' Jbr' ! 0 0ii & Gas Cons. ........................... Date' - ........... DISTRIBUTION: BP Chevron Unocal Mobil State of Alaska D&M CC: DS Engr. NSK Files OP Engrg. Files Prod. Foreman sssv GLM DV or GLV Fluid Level Found @ ~,3~Ft KUPARUK FLUID LEVEL REPORT Fluid Level Shot Down: ~CSG Press During Shot= Tubing TBG Press During Shot = Reason For S~L: ~o Determine Operating Valve Well Status: On Continuous GL Operating CSG Press = __ GL Rate (If Available)= On Intermittent GL On Time=__ Min. Off Time = Hr. Min. .... Delta Time From End Of On Cycle No GL # MCFD Min. Comments: ARCO Alaska, Inc. Date: June 23, 1989 Transmittal #: 7498 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and retdrn one signed copy of this transmittal. 30-11 Kuparuk Well Pressure Report 3 - 1 3 - 89 Sand 'A' 30-04 Kuparuk Well Pressure Report 4-09-89 Sand'A' 30-04 Bottom Hole Pressure Survey 4-09-89 #963284 3 O- 11 Bottom Hole Pressure Survey 3 - 1 3 - 89 # 862980 30-03 Kuparuk Fluid Level Report 6-1 5-89 Casing 1 G- 11 Kuparuk Fluid Level Report 6 - 1 5 - 89 Casing Receipt Acknowledged' 2 6 19 9 ........................... Date' - ........... DISTRIBUTION; BP Mobil Chevron Unocal State of Alaska D&M Telecopy No. (907) 276-7542 December 2, 1988 J B Kewin Regional Drlg Eng ARCO Alaska, Inc P O Box 100360 Anchorage, AK 99510-0360 Re: API number - Kuparuk well 30-4 Dear Mr Kewin: On your copy of the original "Permit to Drill" form 10-401, the AP1 number is wrong. The correct number is 50-029-21826. Please make this change in your records. - Sincerely, Blair E WondzelP~ Sr Petr Engineer jo/A.BEW. 128 "'"" STATE OF ALASKA ALA,. .,A OIL AND GAS CONSERVATION COMMIS,. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown m Stimulate __ Plugging __ Pedorate __ 'X Pull tubing __ Alter casing __ Repair well __ Pull tubing __ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well: '~ Development ~..~_ Exploratory Stratigraphic Service 4. Location of well at surface COHPLETE 6. Datum elevation(DForKB) RKB 59' 7. Unit or Property name Kuparuk River Unit 8. Well number 789' FNL, 1879' FWL, 5ec.22, T13N, RgE, UM At top of productive interval 1278' FSL, 2400' FWL, 5ec.16, T13N', RgE, UM At effective depth 1320' FSL, 2226' FWL, Sec.16, T13N, R9E, UN At total depth 1337' FSL, 2156' FWL, Sec.16, T13N, R9E, UM 30-4 9. Permit number/approval number 88-62/8-594 10. APl number 50-- 029-244~2 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 8984'MD 6785'TVD feet Plugs (measured) feet None Effective depth: measured true vertical 8878'MD 6707'TVD Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 5064' 8928' Size 16" 9-5/8" 7" measured 8710'-8730'MD true vertical 6583 ' -6598 'TVD Tubing (size, grade, and measured depth) feet Junk (measured) None feet Cemented Measured depth True vertical depth 199 sx AS II 115'MD 1200 sx AS Ill & 5099'MD 375 sx Class G - Top Job w/150 sx AS I 300 sx Class G & 8961'MD 175 sx AS I 115'TVD 4028'TVD 6768'TVD 3-1/2", J-55- ~bg w/t.ail ~ 8549' Packersand SSSV(typeana measured depth) AVA 'RHS' pkr ~ 8477'; Camco 'TRDP' SSSV ~ 1829' 13. Stimulation or cement squeeze summary I n~e/rAvals treated (measured) Treatment description including volumes used and final pressure 14. N/A RepresentatiVe Daily Average Production or I niection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run"~__ Gyro Daily Report of Well Operations _~_ 16. Status of well classification as: Oil ~ Gas__ Suspended __ 17. I hereby ce~rtify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 ~ (Dani) SW03/045 *NOTE: Completion Well History Service Date SUBMITIN DUPLICATE _~-- ARCO Oil and Gas Company ~, Well History - Initial Report - Daily instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. ARCO Alaska, Inc. NORTH SLOPE - KUPARUK District ICounty, parish or borough KUPARUK RIVER FIELD I ADL.' 25513 Field J Lease or Unit AK2963 J COMPI'.ETE Auth. or W.O. no. JTitle J API.' 50-029-21862 Istate IWell no, ARCO Operator ACCF--?T Spudded or W.O. begun IARCO W.I. Date and depth as of 8:00 a.m09/26/88 ( ?B: 8878 SUPV: MDD 09/25/88 1430 HRS Complete record for each day reported 9) DROP STANDING VALVE 7"~ 8961' MW:10.0 N~CL ACCEPT RIG @ 1430 HRS 9/25/88. NU BOPE AND TEST SAME. PERF 8710'-8730' W/ 8 ~PF, 45 DEGREE PHASING. RIH W/3-1/2" COMPL. DROP BALL. ATTEMPT TO SET PKR SHEAR OUT SUB BLEW ~ 1800 PSI. DROP STANDING VALVE. DAILY: $33,033 CUM: $825,743 ETD:S825, 743 EFC.' $1,350,000 The above i,~.~rrect -- For fd}'m~preparatigJ~ar~' distribution~....~ see Procedures WanJJal, Section 10, Drilling, Pages 8~d 87. I Date / TitleR O ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ARCO Alaska, Inc. IIC°unty°Nl~["]l SLOPE - KUPARUK Stat~K Field KUPARUK RIVER FIELD Lease or~LI~L'- 2~13 30-4 Well no. Auth. or W.O.A~g{5;~ ITitle CO I API: Operat.or ARCO Spudded or Date and depth as of 8:00 a.m. 09/27/88 TD: 8984 Date OglZb/t~l~ Complete re(N~[~,~,l'~lact'].day reported RIG RELEASED WO STANDING VALVE TO FALL. Iotal number of wells (active or inactive) on this, Dst center prior to plugging and I bandonment of this well ourl4~O HRS [Prior atatus if a W.O. 7"~ 6961' MW:IO.O NACL SET PKR. REL PBR. LAND TBG. PB: 8878 SUPV:MDD HGR, TEST TBG, ANN AND SSSV - OK. ND BOPE. NU TREE AND TEST SAME. DISPL WELL W/DIESEL. RR g 1415 HRS, 9-26-88. DAILY:S149,251 CUM:$974,994 ETD:S974,994 EFC:$1,350,000 NOTE: CAMCO 'TRDP' SSSV @ 1829', AVA 'RHS' PKR ~ 8477', & TT ~ 8549'. Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data New TD Date IPB Depth Kind of rig IType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The abov~[.~ correct ]Date . TI For form prepa ;nd d~stribution,¢~'~ a ' se. soction ,o., 0 Drilling, Pages 86 and 87. ARCO Alaska, Inc. Date' August 26, 1988 Transmittal #: 7276 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 O- 0 6 Cement Bond Log 8 - 0 2 - 8 8 5 1 8 7 - 8 0 5 2 3 O- 0 8 . Cement Bond Log 8 - 0 1 - 8 8 3 0 8 5 - 7 6 4 8 3 O- 0 4 Cement Bond Log 8 - 0 3 - 8 8 6 9 8 0 - 8 8 6 6 3 O- 0 7 Cement Bond Log 8 o 0 2 - 8 8 6 4 5 7 - 8 0 2 4 Receipt Acknowledged: DISTRIBUTION; NSK Drilling Chevron(+sepia) State of Alaska(+sepia) SAPC(+sepia) Unocal(+sepia) Mobil(+sepia) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ~ Operation Shutdown ~ Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 5. Datum elevation (DF or KB) RKB 59 ' 6. Unit or Property name Kuparuk River Unit 4. Location of well at surface 7. 789' FNL, 1879' FWL, Sec. 22, T13N, R9E, UM 30 At top of productive interval 8. Well number -4 Permit number 1:~20' FSL, 2398' FWL, Sec. 16, T13N, RgE, UM (appz:o×) 88-62 At effective depth 9. APl number ~/~ ~, 1:~66' FSL, 2236' FWL, Sec. 16, T13N, RgE, UM (appro×) 50-- 029-'~21862- At total depth 10. Pool 1~84' FSL, 2168' FWL, Sec. 16, T13N, R9E~UM (appro×) Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8984 'MD feet Plugs (measured) None 6788 ' TVD feet 8878 ' MD feet Junk (measured) No ne 671 0 ' T V D feet Casing Length Size Conductor 80' 16" Surface 5064' 9-5/8" Production 8928' 7" Cemented Measured depth 199 sx AS II 115'MD 1200 sx AS III 5099'MD & 375 sx Class G Top job w/150 sx AS I 300 sx Class G 8961'MD Rue Verticaldepth 115'TVD 4029'TVD 6771'TVD Perforation depth: measured None true vertical Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None None 12.Attachments Description summary ofproposal [] WELl HISTORY 13. Estimated dateforcommencing operation September~ 1~8~ Detailed operations program BOP sketch 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed &~J~x ~¢[J.C~ Title Associate Engineer Date Commission Use Only (5A3/0023) (Dani) Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy oArPmP r~)(~3b~~, ~~ Returped Commissioner J Approval No. ~")'" ~7 ¢ the commission Date Su'bmj4 in triplicate ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK RIVER FIELD Auth, or W.O. no, AK2963 ICounty, parish or borough NORTH SLOPE - KUPARUK Lease or Unit ADL: 25513 Title DRILL State 30-4 no, API: 50-029-21862 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 07/03/88 ( TD: 1539' ( 1: SUPV:SLC 07/04/88 ( ' TD: 4293' ( 2' SUPV:SLC 07/05/88 ( TD: 5120'( SUPV:SLC 07/06/88 ( TD: 5989'( SUPV:SLC 07/07/88 ( TD: 8334' ( 2: SUPV:JPS 07/08/88 ( TD: 8943'( SUPV:JPS 07/09/88 ( TD: 8984'( SUPV:JPS Date 07/02/88 ]Hour Complete record for each day reported DOYON 14 IARCO Wrl, 56.0000 Prior status if a W.O. 1700 HRS ) ,39) ) 54) ) ~27) :) :69) ) 45) ) 09) ) 41) DRLG 16"@ 115' MW: 9.1 VIS: 56 NU 20" ANNULAR AND DIVERTER. CUT DRILL LINE. PU BHA. TEST DIVERTER. SPUDDED WELL @ 1700 HRS, 7/2/88. DRLD TO 1539' DAILY:S55,226 CUM:$55,226 ETD:S55,226 EFC:$1,350,000 DRLG 16"@ 115' MW: 9.2 VIS: 64 DRLD TO 4293'. DAILY:S43,668 CUM:$98,894 ETD:S98,894 EFC:$1,350,000 RUN 9-5/8" CASING 9-5/8"@ 5099' MW: 9.7 VIS: 44 DRLD TO 5120'. SHORT TRIP. POOH. LD BHA. RAN 9-5/8", 36.0#, J-55, BTC CASING W/ FS @ 5099', & FC @ 5016'. DAILY:S127,329 CUM:$226,223 ETD:S226,223 EFC:$1,350,000 DRLG 9-5/8"@ 5099' MW: 8.6 VIS:331 CMT CSG W/ 1200 SX OF AS III AND 375 SX OF CLASS G. CIP AT 1130 HRS, 7/5/88. TOP JOB W/150 SX AS I. NU BOPE AND TEST SAME. PU BHA AND RIH. DRLD CMT. TEST CSG. DISP MUD. TEST FORM TO 12.5 PPG EMW. DRLD TO 5989'. DAILY:S133,391 CUM:$359,614 ETD:S359,614 EFC:$1,350,000 DRLG AHEAD AT 8334' 9-5/8"@ 5099' MW:10.0 VIS: 39 DRILLED AND SURVEYED FROM 5989' TO 8334'. DAILY:S54,224 CUM:$413,838 ETD:S413,838 EFC:$1,350,000 RIH FOR LOGS 9-5/8"@ 5099' MW:10.0 VIS: 39 DRLD TO 8943'. SURV. CIRC. DRY JOB. SHORT TRIP TO SHOE. CUT DRILL LINE. RIH. CIRC 700 BBLS. SS SURVEY. SPOT DIESEL PILL. POOH. LD BHA. RU SOS AND RUN DIL/SFL/GR/SP/FDC/CNL/CAL. DAILY:S53,143 CUM:$466,981 ETD:S466,981 EFC:$1,350,000 RUNNING CASING AT 6700'. 7"@ 8961' MW: 9.9 VIS: 39 FINISH LOGGING OPEN HOLE. 2ND PASS DIL/SFL/GR/FCD/CNL/CAL. DRILL 8-1/2" HOLE TO 8984'. CIRC. SPOT DIESEL PILL. POOH LDDP. RU AND RIH WITH 7" CASING. DAILY:S118,524 CUM:$585,505 ETD:S585,505 EFC:$1,350,000 The above is correct For form preparation an~distribution, see Procedures Manual[.Section 10, Drilling, Pages 86 and 87. Date Tit,e ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, repod completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. ARCO Alaska, Inc. District Field Accounting cost center code State KUPARUK RIVER FIELD Auth. or W.O. no. AK2963 Operator ARCO ICounty or Parish NORTH SLOPE - KUPARUK Lease or Unit Title ADT,: 25513 30-4 DRILL API: 50-029-21862 IWell no. Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m, 07/10/88 ( TD: 8984 PB: SUPV:JPS IA.R.Co. W.I. 56.0000 IDate 07/02/88 Complete record for each day reported DOYON 14 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our j Prior status If a W.O, 1 1700 HRS RIG RELEASED 7"@ 8961' MW: 0.0 FINISH RUNNING 7" CASING. RAN 224 JTS 7", 26.0#, J-55, BTC CASING. FS @ 8961'. CEMENTED CASING WITH 100 SX 50/50 POZ LEAD, FOLLOWED BY 200 SX CLASS G TAIL. CI? @ 1445 HRS 7/9/88. ND BOPE. NU TUBING HEAD. RELEASE RIG @ 2030 HRS 7/9/88. DAILY:S207,205 CUM:$792,710 ETD:S792,710 EFC:$1,350,000 Old TD Released rig New TD Date Classifications (oil, gas, etc.) J Type completion (single, dual, etc.) I Producing method J Official reservoir name(s) I Potential test data JPB Depth Kind of rig Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day , Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature -- For, rm re ~'atilo~n aJ~n/~.n o p ~lCa~at' d dist 'bution, see Procedu~.~ Manual, Section 10, Drilling, Page'{ 86 and 87. JDate JTitle AGGO~ATE ENGINEER ARCO Alaska, Inc. Date: July 22, 1988 Transmittal #: 7228 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 O- 04 OH LIS Tape and Listing 7-17-88 988.50-8965.19 Receipt Acknowledged: DISTRIBUTION: ........................... Dat State of Alaska Lynn Goettinger ARCO Alaska, Inc. Date: July 15, 1988 Transmittal #: 7227 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-04 2" Dual Induction 7-08-88 1000-8932 30-04 5" Dula Induction 7-08-88 1000-8932 30-04 2"& 5" Porosity FDC 7-08-88 8300-8906 30-04 2" & 5" Raw FDC 7-08-88 8300-8906 30-04 Cyberlook 7-08-88 8400-8830 Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION: NSK Drilling Franzen D&M State of Alaska(+sepia) L. Johnston(vendor package) June 9, 1988 Telecopy: (907)276-7542 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska', Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 30-4 ARCO Alaska, Inc. Permit No. 88-62 Sur. Loc. 78.9'FNL, 1879'FWL, Sec. 22, T13N, RgE, UM. Btmhole Loc. 1399'FSL, 2220'FWL, Sec. 16, T13N, RgE, UM. Dear Mr. Kewin: Ea~closed is the approved application for permit to drill the above referenced well. The permit to drill does not inden~lify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment insta].lation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ~ ? ~ /~V ~ ,~ ..'~ ~,~.~ ..-~- / .... C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Con~ission BY ORDER OF THE CO~,~fISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. STATE OF ALASKA ALASK,, OIL AND GAS CONSERVATION _ ,.)MMISSION PERMIT TO DRILL 20 AAC 25.005 i la. Type of work Drill [] Redrill E31 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenE]I Service E3 Developement Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 59' , PAD 24'GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oi 1 Po P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25513V'ALK 2554 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 789'FNL,1879'FWL,Sec.22,T13N,R9E,UM Kuparuk River Unit Statewide At top of productive interval(@ target) 8. Well nu.mber Number 1320 ' FSL, 2398 ' FWL,Sec . 1 6 ,T13N ,R9E ,UM 30-4 #8088-26-27 At total depth 9. Approximate spud date Amount 1399 ' FSL, 2220 ' FWL,Sec . 1 6, T1 3N ,R9E ,UM 07/13/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line DS 30-6 8889' 2200 ' (~ TD feet 50 ' (~ surface feet 2560 6709 ' ~'¢/) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 600 feet Maximum hole angle 450 Maximum surface 2382 psig At total depth (TVD) 3154 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" ~2.5# H-40 Weld 80 35' 35 115 115' +200 cf 12-1/4" 9-5/8" 36.0# J-55 BTC 5023' 35' 35 5058 4024' 1800 sx AS Ill & i F-ERW 370 sx Class G 8-1/2" 7" 26.0# J-55 BTC 8855' 34' 34 8889 6709' 100 sx 50/50 Poz Lea t F-ERW 200 sx Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations.r, up ru'T'OPa'°-fkG 500' above Present well condition summary Total depth: measured feet Plugs (measured) '. true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural GonductorRE[EIVED Surface Intermediate JUN 0 .t; Production Liner /~~& ~~ Perforation depth: measured ,l~lC~10r~.,9 true vertical 20. Attachments Filing fee ti~ Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program 5( Drilling fluid program 1~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby~ that the f~,~oing~ true and correct to the best of my knowledge Commission Us~ Only (IE~) PIP3/7/5, ~ -6°~ 50-- O~9 ' ~I3 ~> 0 6/0 9 / 88 for other requirements Conditions of approval Samples required [] Yes 1~ No Mud log required ~ Yes ~ No Hydrogen sulfide measures [] _Yes '58 No Directional survey required t~'Yes [] No Required working ~e forl~PE /;~"2~; [~L3M; . [] 5M; [] 10M; [] 15M Other: ~/~ /I/ (// /~~-'~k-~c~-~-- by order of Approved by ~,,,~ ,., // ,, ~.¢' ~ ~'/~ Commissioner the commission Date Subr~it triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to loggi'ng point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing,. Pressure test to 3500 psig. 11) Downsqueeze Arctic pack' and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. DEGASSER MUD CLEANER SHALE SHAKERS STI STIR STIR MUD CLEANER CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids i0± 4-7 9-12 Drilling Fluid System: - Triple'Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser -. Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack Upon completion of the fluid disposal. R~CE~VE~" LWK5 / ih 20' DIVERTER SCHEHATIC DESCRIPTION I. 16' C0NOUCT(:IR 2. FlOC SLIP-ON ~ STARTIN~ 3. FI'lC DIVERTT. q AS~]"I~.Y WITH ~ 2-I/ 20O0 PSI BALL VN. VE3- 4. 20' 2000 I~113e. JLLIl~ ~ ~tltO' ~UTI/T~ 5. 10" ~ BAIJ, VALVF,3W/IO" D~ A $1H~L[ VALV~ ~ ~I'ICAU,¥ UI~ I~]'tOI"ELY Ci~NTIN~J,~D DIVEI~SI(:IN. 6. 20" 2000 PSI ~ ~ 4 ARCO ALA~I<A, INC., REOI~$1~ OF THIS DIVERT~ SYSTEI"I AS A VARIANCE FR0tq 20AAC25.035(b) r'!,~INTENANCE & OPERATION 2 UPON INITIAL INSTALLATION, CLOSF.. PI~VENTER VERIFY THAT VALVE 0I:~F.,NS CLOSE ANNULAR PREVENTER ANO BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOUR~. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN iNFLUX OF WELLBORE FLUIDS OR GAS IS DETEC TED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNW~NO DIVERSION. DO NOT .~HUT IN WELL UNDER ANY CIRCUMSTANCES 7 6 ACO,,MA.AT~ CAPACITY, TEST :1, O-ECK ~ FILL ACO. M.LATC~ R~SE~VOIR TO ~ LEVEL WITH HYORAU. IC FLUID. 2. ASSLI~ THAT ACCLM.LATCR ~ IS ~000 PSI WITH 1,500 PSI DOVe~T~.AM CF T~E ~EGLLATC~. 5. (~SERNE TIb~_. TFEN CLOSE AU. UI~TS 5IMJLT~AEOUSLY A/~ RE~ THE TII~: ~ ~ REI~INING AFTER ALL Led/TS AI~ CLOSED WZTH CHARGING PLM:~ CFF. 4. RECORD 0N N~tDC ~:~RTo TI~ ACCEPT~ L(]~R LIMIT IS 45 SE~ CLCSINS TIldE N~ 1200 PSI RE)4~]NING L J 5 4 , > 3 2 ICL II. 12. 13. 13-5/8" BCP STACK TEST I. FILL ~ STAG( AN:) CHI:]<E IvRNIF~ WITH ~IC DIESEL. 2. C3-E~ THAT ALL Lt33( DO~ ~ IN N~l. Ll-E~ ARE FLLLY I~TRACTED. SEAT TEST PLUG IN I~LLI..E/~ ~TH ~t.N~ING JT ~ ~ IN L(:X:XI:X311~ SCRE~ 5. CLOSE ~ PI~-VENTER AN3 LIllE VALVES ADJA~ TO B~P STACK. ALL. OTI-ER 4. F~ESSLRE UP TO ~30 PSI ~ HOLD F~R IO MIN. IN- ~ PRE~LRE TO ~ PSI /t~l) H~LD FCR IO MIN. ~_FED P;E~ TO 0 PSI. OPEN ~ PREVE~ AN3 ~ Kill A~ CHCKE LI~E VALVE~ CLOSE ?CP PIPE RAM~ AN3 HCR VALVES CN Kill ~ CHC~E LI~ES. 6. TEST TO 250 P~I ~ 5(3130 PSI A~ IN STEP 4. ?. CCNTIN. E TESTING ALL ~T ~T~PI~~ ~0 ~ ~I ~~~I. ~N ~T~ PI~ ~ ~I. ~E~D ~ LI~ ~ ~UI~ ~T ~L V~ IN ~I~I~ ~ITI~ PI~ ~ETY V~ ~ I~I~ ~ ~I. ~ SI~ ~ ~ ~0 ~ILLI~ ~VI~. ~E~Y ~~ E~I~Y ~. Pa'd ::30, i ~el I No=_ 4 Propoeed . Kupaeuk Fleld,i North elope, Aleeka .. '~~ . KOP: .... TVD,6OO'TMD"600 DEP-O' 3 : i : ~33. B/ pERMAFROST TVD-171g THO-1796 DEP-362 ..... :.! .......... 200o_~EOC.. TVD'lg62 THD-21.!Z DEP-ST1 ....... ~ .... : ................. : .....~ ~ T/ UGNU SNDS TVD-26zg TfiD-3139 DE~1301. ' . ~ K-12 TVD-3824 THD-4ZZ3 DEP-2466 ~..~ 4000 ...... " . ~ 9 5/8" C~O PT ~ . . ~TVD-4024 T,D-5058 DEP-266g ' :'AvERAOE ANGLE ' : T/ ZONE A TVD"B46Z T~D"8544 DEP"5155 ....... TARGET O~TR TVD"6518- T~"SB16 DEP"520Z- ';' B/ KUP SNDS TVD"BsBg T~D.sBsg DEP"525g ' TD (LO~ P.T) TVD"6zog T~-888g DEP"5402 ................. 7000 , 2000 'i 3000 VERTICAE SECTION. , , 4000. i .. 5000 6000 I ~ 0 , 1 000 : , HORIZONTAL SCALE 1 IN. PROJECTION - 1000 FEET '~co ALASKA, ~. · Ped ~0, Well No~ 4 Kuperuk Field, North Propoeed ' I~ elope. Aleeke 3000 20oo.. . i, ! O0 !c: ..... 10oo _ sooo 5ooo WEST-EAST 4000 :3000 2000 1 000 000 I TO iLl)CAT [ ON. 13g~' F~I.. 2220' FI/L SEC. 18. TI3N. RGE 15207' (TO 6 HIN W TARGET) ,1 80~:' ,1 850 900- 1 950'~ 2000~ 2050i 2100 95Q_ _ 1000 _ 10SQ. i~.,~4oo ~ ~ ~oa ' '",4,300_ ...... I ~,r~ Io~,o' 4000 ................ ~- ............. / t'3-900 I I i 1 ! ..- 80O-: .- 850- ! i8oo llSQ. ~8~o, 1 O0 ............... [ ....................... ;. I 1 go0. 2000 I ~' 600 ~' 4800 ~[cC~jVt.:~ · -Z~o,k-. . , ......... JUN 0 ).lgBB ~ ./ s°°~2oo J ~ ~ & ~s ~n~ Comm;~s:,..~ / [ 26~0 ~uuI ~chom"~ ' ' V 5200 ~/' ~ I ' · / 2700 %1400 ',.. ~ ~ · ~s~oo ~o~- J / 550O ! 1 950 301 600' ' rT'OO_ . ! _ 1 001 _ 105r _.110 _1.15 2050 .. 21 O0 -- --3'100 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) (8) (3) Admin ~ ~ 9. (9 thru 13) 10. (10 and 13) 12. 13. *' -?-$3 (4) C as g /~.(. :.~M, ~ (14 thru 22) (5) (23 thru 28) (6) OTHER (29 thru 31) (6) Add: '~,.~f~f g-?-F~ Company ~~(%> Lease & Well No. YES NO Is the permit fee attached ........................................... ~ , ,, 2. Is well to be located in a defined pool ............................. ,~ 3. Is well located proper distance from property line .................. ~_ 4. Is well located proper distance from other wells .................... a~ 5. Is sufficient undedicated acreage available in this pool ............ ~_ 6. Is well to be deviated and is wellbore plat included ................ _~ 7. Is operator the only affected party ................................. ~ --_ 8. Can permit be approved before fifteen-day wait ...................... ~_ Does operator have a bond in force .................................. ~ Is.a conservation, order needed ...................................... ,, ~ Is administrative approval needed ................................... ~ Is the lease number appropriate ..................................... .~ -- Does the well have a unique name and number ......................... ~ _ 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ ~ Will surface casing protect fresh water zones ....................... ~ Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... /z~ Will cement cover all known productive horizons ..................... /'~4 Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. /~ ,, Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~'~ __ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... ///~ Is the drilling fluid program schematic and list of equipment adequate/z~f Are necessary diagrams and descriptions of diverter and BOPE attached.~z~. Does BOPE have sufficient pressure rating - Test to ,~Od)O psig .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ............. · .................... . For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones .... 31 If an offshore loc., are survey results of seabed conditions pr=s 32, Additional requirements ............................................. ~Z Geology: Engi.n.ee. ring: LCS ~ BEW .~"'" rev: 02/17/88 6.011 IN ITIAL GEO. i UN IT ON / OFF POOL CLASS STATUS AREA NO. SHORE ,,~?oI~o DE~/-[ OCL ~c)co i(1'~0 Oh; Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. VERIFICATfON LISTING ~R bVP OlO,M02 VE.IFICATION LISTING PAGE TAP CON EADER /07/~? ** tEDIT 846 LI:S,ARCO KUPARUK 3 0-4,API ~ 50-029'21862 :R ** IEDIT 7 # :01 ~IOUS TAPE fENT$ :EDIT LIS,ARCO KUPARUK ] O-4,API # 50-029-21862 EOF ** FI. bE HEADER ** FILE NAME :EDIT S~RV~CE NAM~ : VERSION # : DATE : ~AXlMU~ bENGTH PREVIOUS FIbE ,001 1024 ** INFORMATION RECORDS ** MNEN CONTENTS CN I ARCO ALASKA, INC, WN : 3 0 - 4 FN { KUPARUK RANGI 9E TOWN: N~RTH SLOPE SECTI COUN: S A ALASKA C~RT: Y: USA MNEN CONTENTS UNIT TYPE CATE SIZE CODE 000 000 018 065 000 000 008 065 000 000 008 065 000 000 002 065 000 000 004 065 000 000 002 065 000 000 0!2 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 001 065 COMMENTS ** ******************************************************************************** bVP 010,H02 VERIFfCATION LIS?I.G PAGE COMPANY = ARCO ALASKA ZNC = 3 0-4 = 50-029-21862 = KUPARUK = ~OR?H SbOPg BOROUGH STATE = ALASKA ; CE~TE~ * ******************************************* NUI~BER AT AKCCl 72846 DATE LOGGEDI08" JUL',.,88. R]:CK KRUWEbL = 9.625" ~ 5099' ' BIT SIZE = 8,5" TO 8943' DRILLER = LSND POLYMER , 10 LB/G R~ · 4.78 ~ 61 DF R39 $ R~F a 5'47 ~ 66 DF = 9,0 R~C ,2.35 ~ 63 DF =4 2. C3 R~ AT' BHT = 2,~i~ ~ 1.47 ~F CENTER REM]ARKSl I,)FILE EDIT,O0i CONTAINS DATA OF DUAL INDUCTION (,Vlb)~ FORMATION DENSITY LVP 010,M02 VERIFICATION LISTING PAGE 3 (.FDC). COMPENSATED NEUTRON (,CNL)~ AND GAMMA RAY THRU CASING SAMPLED ~ ,5~ )FILE EDiT,O02 CONTAINS~ ~I RE~ FORmATiON' DENSITY (,FDH), COMPENSATED NEUTRON (;CNH) SAMPLED 1,.5" STANDgFF AND 2' HOLE FI DER U.SED ON DUAL DENSITY ~2.65 GIC3. FLUID DENSITY ~ I G/C~. HOLE CORRECTION = CALIPER. ~UDCAKE IS CAUSE KUP~OK * SCHLUMBERGER LOGS INCLUDED wITH THIS MAGNETIC TAPE: * DUAL INDUCTION SPHERICALLY FOCUSED bOG C DIb) * DATA AVAIbABbE~ 8932' TO 5094' ' * FORMATION' DENSITY COMPENSATED LOG (.FDC) * DATA AVAI~ABbEI 8906' TO 8296' * COMPENSATED NEUTRON LOG C CN ~ · * DATA AVAIbABbE~, ~89 TO 8296 * GAMMA RAY THRU CASING (,CSG) LVP 010,H02 VERIFICATION LISTING PAGE 4 DATA AVAIbABbE~ 51.58' TO 990' FORMATION DENSITY COMPENSATED bOG HI RES DATA AVA~bABbEl 8906' TO ~295' COMPENSATED NEUTRON bOG HIRES DATA AVAILABLEI 8891' TO 82,95 ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 ~ 66 0 4 1 66 8 4 73 60 9 4 65 ,lin ~ 66 0 66 0 ~ATU. SPECIFICATION BLOCKS MNE~ SERVICE SERVICE UNIT API Al'I API AP1 FILE SIZE SPb REPR PROCESS ID ORDER ~ LOG TYI CLASS MOD NO, O:TAL) FT O0 0 O0 0 4 68 0000000 0 0000 DEPT ~. p~ o.~ oo ~oo,o o ~ ~ ~. oooooooooooooo x~.~ o..~ oo ~o~ o o ~ ~ ~. oooooooooooooo D ~, o..~ oo~4o o ~ ~ s. oooooooooooooo ~o ~P DIB NV O0 0:0 01 0 0 4 ! 68 00000000000000 0 0 0 4 I 68 oo~ooooooooooo 1 68 00000000000000 ~ ~Dc SAPI O0 ~=~ ~= 0 0 4 ~, ~8 00000000000000 ?f~S ~pC ~S O0 0 0 4 t eS 00000000000000 CA~Z ~PC ~ O0 0 O~ 0 0 4 ~ ~S O0~OO!O0000000 RHOB FD¢ G/C3 O0 0 02 0 0 4 1 68 OOuuO0 00000000 DRHO ~C ¢/C3 O0 ~S O~ 0 0 4 t 68 00000000000000 FDC PU O0 890 O0 0 0 4 ! 68 00000000000000 DPHI NFDC FDC CPS O0 ~54 O! 0 0 4 ~ ~8 00000000009000 FFgC FDC CPS O0 ~54 02 0 0 4 1 68 00000000000000 TNRA tnb 00 420 01 0 0 4 1 ~8 00000000000000 ~TN~ C~b O0 000 O0 0 0 4 1 68 00000000000000 NPHI CHh PU O0 890 O0 0 0 4 1 68 00000000000000 ~CNr C~ CPS O0 000 O0 0 0 4 ~ ~! 00000000000000 RCr~ C~U CPS O0 000 O0 0 0 ~ 1.o 00000000000000 Cr?C C~ CPS O0 000 O0 0 0 4 ~ S8 00000000000000 CNTC CN~ CPS O0 000 O0 0 0 4 ~ S8 00000000000000 rE"S C~L bB O0 SiS ~t 0 0 4 ~ S8 00000000000000 ~R C~U GA~I O0 ~10 Oi 0 0 4 ~ S~ 00000000000000 G~ CS~ ~API O0 IlO O~ 0 0 4 t 68 00000000000000 LVP 010.H02 VfRIFICATION LISTING PAGE 5 TENS bB O0 6]5 21 0 DATA -999 0000 3:906 NPHf CNTC 2500 TENS =999 ~49 ~25 ~9 2500 ,,.999 SF/,U GR 0000 CAbI 9162 NFDC 8707 NPH! 8556 CNTC 2500 TENS 8 664 .208 -999 RHOB FFDC TENS ,500 R 8800 78~2 , -999 0000 srbu 0313 GR 0000 CAL! 4586 NFDC 292 NPHX 533 CNTC 2500 TENS 8;3203 RHOB 619,$000 FrDC 42;3964 R~NT 999,2500 DEPT SP RTNR CFTC GR 700,0000 -37,4688 7440;0000 14~3857 2,7 8 -999, ~00 SFLU GR CALl NFDC NPHI CNTC TENS 593 31 2402 -999 640 750~ !875 RHOB 0000 rrOC 18RCNT 61~ TEN8 25OO DEPT TENS DPH! RTNR CFTC 8600 7992 10 -999 0000 SFLU 0313 GR 0000 CALl 6121 NFDC 2561 NPH! 4553 CNTC 2500 TENS 3,5790 XLD 119'8750 TENS 8'8047 RHOB 586.0000 FFDC '4839 RCNT ,2627 TENS DEPT DPHX RTNR CFTC 8500 0000 SFLU '36 7813 GR 7320 0000 CAb! 15 4688 afDC 3 703I NPH! 520 7000 CNTC -999 2500 TENS 374 ILD 1'~750 130, TENS 8.~9 RHOB 606, 0 FFDC 46,8647 RCNT !832, 7 TENS 999,~3 0 500 DEPT 8400,0000 SFLU 2.3421 XbD 4 1 68 00000000000000 R. HO 3 4006 111 0 Iii 25 IbM G~ DRHO TNRA RCFT GR 9 664 97 789~ 9779 IbM 0000 GR 4446 DRHO RCFT 3 98 0 6682 ILN oooo 4128 HO 0000 TNRA 7588 RCFT 0000 GR 10, i271 79;0~500 2~80 79.7500 799~:4362 XbN 0000 GR 4750 DRHO sO:Isoo 7992'0 GR 119 ° 0 1 0484 0809 8750 2 547 9440 IbM 0000 GR 3949 DRHO 5000 TNRA 5884 RCFT 0000 GR 1,9970 130,3750 130,37 1,8919 1,9994 5VP OIO,H02 YE IFICATION hISTING PAGE' 6 Sp 7~39:4063 GR 44 )000 CAb! I8 .~479 NFDC '999 2500 TENS 3 549 -999 SFbU CAb! NFDC 2500 TENS 6oeo ~ ]bo TENS RHOB FFDC 0950 ~NT 3013 TENS 2500 GR 'T -999 000 ooo i FDC 2500 NP I 2500 CN~C 2500 TENS -999 -999 -999 2500 RHOB 2'500 FFDC 2500 RCNT 2500 EPT P ENS RTNR GR 8100 0000 SFLU 68 0000 OR NFDC :500 NPHI ~500 CNTC -999 2500 TENS 2,1764 IbD .268,0000 TENS ,999,2500 RHOB :999,2500 FFDC ~999,2500 RCNT -999,2500 TENS -999,2500 DEPT OPHI RTNR CFTC 8000 .999 -999 -999 -999 O0 93~GRSFbU 2500 CAbI NFDC 0 NPH.! 2~00 CNTC O6 TENS 4 0868 ZbD 124 3750 TENS :999 2500 ~HOB 999 2500 FFDC -999 2500 RCNT -999 DEPT TE~S DPH! CFTC 7900 0000 SFbU '70 8750 GR -999 500 CAb! -999 500 NFDC :999 2500 999 2500 C~?C -999 2500 TENS 2,8540 IbD !09,2500 TENS -999,2500 RHOB :999,2500 FFDC .999,2500 RCNT .999,2500 TENS 999.2500 DEPT RTNR CFTC G~ 7800,0000 SFL, U "66,)750 GR -999,2500 CAb! '999'2500 NFDC -999,2500 NPH! '999,2500 CNTC -999.2500 TENS -999 -999 -999 -999 2318 IbD 56~5 TENS 25 0 RHOB 2500 FFDC 2500 RCNT 2500 TENS 2500 GR RCFT GR 3220 0000 GR RS00 TaRA 2500 RCFT 2500 GR -999 -999 1480 0000 GR 2500 DRHO 2500 2500 RCFT 2500 GR 4,2756 7140,0000 -999.2500 ~HO -999.2500 TNRA -999.2500 RCFT -999,2500 GR 2 9970 ~944 0000 GR 999 !500 DRHO :99' ~0 TNRA ggg 0 RCFT -999 2500 GR 2,4236 ,2500 ORHO -99~e2500 TNRA "999,2500 RCFT '999,2500 GR 113 -0 i 3 I -999 -ggg O0 -99~ O0 -99 ~00 -999 ~0 iO0 -999 -999 2500 0507 -999 , oo ~999 2500 "999, -999, LVP 010,H02 VERIFICATION LISTING PAGE 7 PT R R R DEPT SP RTNR D~PT ~TNR GR DEPT OPH! RTNR GR D£PT SP TENS DPH! RTNR 7700,00~0 '76:,93 5 : 9*.tsoo 999. 500 NPHI CNTC TENS AbI FD¢ TENS I RFbo 2500 CAb! 2500 NFDC 2500 NPHI 2500 CNTC 2500 TENS 4375 -999 250o 7300 000o -99? 2500 -999 2500 -999 2500 -999 2500 IFLU NPHI CN?¢ TENS CALl NFDC NPHI CNTC TENS 7200 -38 -999 -999 -999 -999 0000 SFLU 2187 GR 2500 CALl 500 NFDC 500 NPH! 500 CNTC 500 TENS 1 10~,0000 SFLU -4 ,1875 GR 99 ,2500 CAbI 999,2500 NFDC 999,2500 NPHI bD HOB FDC O0 4 -999 -999 -999 500 RHOB FFDC RCNT TENS -999;2500 RHOB 2500 FFDC '999'25~-999. RCNT -999, .999 999 -999 -999 -999 -999 9 -999 -999 17 2500 RHOB ,35~0 FFDC 25 0 RCNT 2500 TEN& 2500 RHDB i500 ~DC 500 RCNT 500 TENS 5OO 2, 260 ILD 10i,~750 TENS -999,1500 RHOB '999, 00 RCNT -999, ~00 FFDC -999,2500 TENS -999,2500 3,2666 lbo .106,5000 TENS 999,2500 RHOB .,999,2500 FFDC 999,2500 RCNT 999; DRHO "999, TNRA -999, ~500 RCFT '9:99,2500 GR' HO '999 642 -999 -999 -999 -999 2 -999 .62443 999 -99~ ,9583 bM ;0000 ,.!500 DRHO O0 RCFT , 500 GR 000o ~ 2500 'DRHO '0o ~C~T t 66 TNA ~500 GR 0 DRHO 500 TNRA O0 GR 9~0 GR 0 TNRA 2500 GR 550 IbM 000 GR 500 DRHO 500 ?NRA 500 RCFT 3 4 -999 -999 -999 -999 -999 r3 2 0060 I!I°° - O0 -999 5 0 -9 2500 · O0 '"'999 2500 .,,i it 'oo -999 500 -999 2 8306 -999 -999 -999 2500 3,1930 -999_, 1500 -999. 500 -.999, 500 999; 500 LVP OIO,H02 VERIFICATION bi. STING PAGE 8 R PT ~TNR CFTC G~ DEPT DEPI TENS DPH! RTNR DEPT '999.2500 CNTC -999.2500 TENS 7{ -999 500 'N -999 TENS 6800,0000 -4, 9375 . -999'2500 NPHI TENS 6700,0000 -¢6;oooo -999,2500 "999'2500 .999.2500 '999,2500 -999.2500 6600.0000 .-57.4375 999.2500 -999.2500 -999;2500 -999.2500 -999.2500 6500,0000 "57,3750 -999~2500 -999,2500 -999,2500 -999,2500 -999,2500 6400,0000 '61,8437 '999,2500 SFLU NrDC NPH! NTC SFbU GR ALI FDC NPHI CNTC TENS SrbU CALl NFDC NPHI CNTC TENS SFSU CAbI -999.2500 -999,2500 -999 -999 99! 2500 25:00 -999 2500 ...999 -999 -999 !500 0390 - 2500 -999 2500 ,44~7 ,2500 -999,25§0 ~999;25 0 ,2500 -999 500 -999 O0 -999 ~500 -999 250O ~ 2083 8 7500 -999 2500 -999 2500 -999 2500 "9992500 '999 2500 2, 7~8 86, -999, 500 TENS TENS RHOB FFDC RCNT TENS TENS TENI bD RCN TEN~ I.~D RHOB FFDC RCNT TENS EN$ RHOB RCNT TENS TENS RHOB rroc RCNT TENS RHOB -999o2500 GR [! RCFT 0968 0000 FT 3 6538 ~86,0 99 -99:~ -999 -99:9 7906 0000 2500 999 2500 -999 2500 -999 2500 RHO TNR A RCFT GR Ibl~ GR DRHO INRA CFT GR 578~:441~000 GRILH ~999,2500 ORHO -999.2500 TNRA :999,2500 RCFT 999.2500 GR 2,6221 Ib~ 5408,0000 GR -999.2500 DRHO -999,2500 TNRA '999,2500 RCFT "999.2500 GR 2,8728 Ibg 5552.0000 GR -999,2500 DRHO '999.2500 .9 I00 -9 -9 0 iO0 -999 -99~ 7695 ,~00 O0 "999 2600 '999 O0 -999; 2,4232 -999, 9,8420 -99 ,2500 -999,2500 [,VP 010,H02 VERIFICATION blSTING PAGE 9 DPH! -999, 2500 NFDC RTNR -999,2500 NPH! -999,2500 TENS SFLU -999,2500 O~PT 6200 0000 SFbU "68 50:00 GR :999 2500 CA[,I 999 2500 NFDC NPH! CNTC ~R -999 0 TENS PT FTC DEPT Sp TENS DPHI RTNR CFTC D£PT SP DPHI RTNR CFTC GE 0000 SFLU 9375 GR 2500 CALI 2500 NFDC CNTC 2500 TENS 6000 0000 '91 5000 -999 2500 -999 .2500 -999 2500 -999 2500 -999 2500 5900 0000 -36 1875 -999 2500 -999 2500 :999 2SO0 999 2500 -999 2500 5800.0000 ,2500 '2500 -999.2500 -999.2500 5700,0000 DEPT rbU R CAb! NFDC NPHI CNTC TENS SFLU GR CAb! NFDC NPHI CNTC TENS SFLU OR CALI NFDC NPHI CNTC TENS '9~. ,2500 '9~ ,2500 ,,99' ,2500 ,2500 3 79 -999 -999 -999 -999 -999 ~ 8540 8 50O0 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 9~ 0338 0625 -999 2500 -999 2500 -9 ~500 99 '999 500 '999 2500 i9876 9 0625 -99 2500 '999 2500 -999 2500 -999 2500 -999 2500 625 999, 500 .999,2500 999,2500 '999,2500 5O0 2500 -999'2500 -999.250o -999,2500 '999,2500 2,9724 FFDC TENS IbD TENS RHOB FFDC RCNT TENS RHOB FFDC RCNT TENS ENS RHOB FFDC RCrN~ TENS IbD TENS RHOB FFDC RCNT TENS IbD TENS RHOB FFDC RCNT TENS -999,2500 TNRA -999,2500 RCFT -999'2500 GE -999 )500 R DRHO TNRA RCFT .q GR DRHO ~500 2500 GE 4890 GR DRHO TNRA RCFT GR 1,9 852 IbM ,0000 GR 2500 DRHO -999:2500 TNRA :999'2500 RCFT 999,2500 GE '999 '999 -999 0 GR 2500 DRHO 2500 ~NRA 2500 RCFT 25OO GR 3,1752 4660'0000 GR -999,2500 DRHO -999,2500 TNRA -999,2500 RCFT -999,2500 GR 3.0223 '999,2500 -999'2500 '999,25 O0 ~0 ~9 15 O0 - O0 -999 '999 0 -999 2 9909 -999 ~500 -999 250O ~999 2500 -999 ,2933 -99 ,2500 -99 ,2500 -99 ,2500 -999,2500 '999,2500 3,1175 -999,2500 -999.2500 -999.~50~ -999, 50 -999,2500 2,9498 bVP OIO,H02 VERIFICATION LIST,lNG PAGg 110 R PT R O£PT R ,R D:PHiI RTNR CFTC GR DEPT TE~$ DPMI RTN~ CFTC GR DEPT sp ~E.S ~PHI RTNR DEPT RTH~ CFTC GR -4.3 -999 CN?C TENS -999 -999 -999 2500 2500 2500 A6I NPHI 5500,0000 -46,0625 ,2500 .2500 '2500 '2500 -999.2500 54 I 0000 6875 -9'I 2500 2500 2500 2!500 -999 2500 5300,0000 -27,1875 -999;2500 :999;2500 .999,2500 :999,2500 999,2500 5~00,000'0 . 29,8281 999.2500 -999,2500 -999, 00 169,1250 5~00,0000 49, ?5 '999'~00 '999, 0 '999,2500 95°0000 CALl NFDC NPHI CN?C TENS SFLU GR ~PHI CNTC TENS SFLU GR CALl NFDC NPHI TENS SFLU GR CALl NFDC NPH! CNTC TE~S GR CALl NFDC NPHI CN?C TENS 102 9~ -999 -999 -999 2 . 93 .999 -999 -999 -999 ~999 -999 -999 -999 -999 -999 1 98 :999 999 -999 -999 -999 -999 =999 -999 -999 4074 4 82 -999 -999 -999 -999 3960 2500 8806 2500 2500 2500 2500 2500 2500 9845 8750 2500 2500 2500 2500 2500 8602 ~$0o 25oo 25OO 250O 0151 7500 2500 2500 2500 2500 0000 2188 250 5O0 500 500 500 0000 ~RHOB FDC CNT TENS RH:OB FFDC ~C~T TENS RHOB FFDC TENS LD H. OB ?DC RCNT TENS ILD TENS RHOB FFDC ReNT TENS ILD TENS RHOB FFDC RCNT TENS IbD TENS RHOB FFDC RCNT TENS 4580 -999 -999 19 4 " )0 -99 -99 GR DRHO RCFT GR DRHO GR DRHO TNRA RCFT ~281,!402 I6~ '0000 GR 999'2500 DRHO -999;2500 TNRA -999,2500 RCFT -999,2500 GR ~ o0oo 2500 -999 2500 -999 2500 -999 2500 IbM INRA CF? GR 3,1589 IbM gg.oooo ,2500 DRHO '9 ,2500 RCFT ~999'2500 GR 3,1747 IbM 500 DRHO .999,2500 TNRA .999,2500 RCFT 999,2500 GR )0 )0 -9~. )0 '999 2500 -999 ~99.9 3 0322 ':999 2500 -9~ 2500 -9 2 ,oo 2500 -999 2500 2,5119 -999,2500 '999,2500 -999,2500 -999,2500 -999,2500 3,0551 -999"2500 -999,2500 -'",I'!! -999, ~ -999'25 3 7763 -999 O0 ~999 2500 -999 2500 -999 25OO bVP O10,H02 VERI¥ICATION LISTING PAGE 11 ~PT PT ~gPT ~P DPH! RTNR DEPT SP DPHI RTNR CFTC GR OEPT SP TENS OPH! RTNR CFTC EFT P I TNR 4~ 69 )0 ,875 GR -9 TENS RHOB FFDC NPHI 0 RCNT CNTC TENS TEN& 39i0,.0000 50 TENS -999 - 999 56 000 500 CAb! NFDC 2500 NPH! 2500 CNTC 1250 TEN& -999 -999 -999 ,~999 55 0000 SFbU 2500 GR 2500 CALI 2500 NFDC 2500 NPH! 2500 CNTC 7500 TENS 4'0 -999 -999 ,,999 0000 SFGU 2500 GR 2500 CAb! 2500 NFDC 2500 NPHI 2500 CNTC 1875 TENS 4500.0000 -999*2500 -999,2500 .999.2500 .999,2500 71.4375 SFbU GR CAb! NFDC NPHI CNTC TEN& 4400.0000 -999,2500 ~999'2500 "999.2500 -999,2500 SFbU GR CALl NFDC NPHI RHOB -9 9 ~'9~9 3900 ~000 . -999 3864 2500 ! D 2500 T~N$ 2500 RHOB 2:500 FFDC 2500 RCNT 2500 TENS 0000 -999 -:999 -999 -999 -999 -999 3720 500 Ib~ 500 500 ~HOB 2500 FFDC 2500 RCNT 2500 TENS 0000 -999 '999 -999 -999 *999 -999 3720 500 500 TEN& 2500 RHOB 2500 FFDC 2500 RCNT 2500 TENS 0000 -999 2500 -999 2500 TENS -999 2500 RHOB -999 2500 FFDC -999 2500 ReNT -999 2500 TENS 3644 0000 -999,2500 !Lb -999,2500 TENS -999,2500 RHOB '999.2500 FFDC =999'2500 RCNT -999 500 ILM -9 0 DRHO -999 -999 O0 '999 2500 GR G ~ DRHO GR - 9 .~9,2500 ,2500 GR -999,2500 DRHO '999,2500 ~999,2500 RCFI 9'99.2500 GR -999 2500 Ib~ -9 2500 DRHO -9~ 2500 Ge -999 2500 TNRA '999 2500 RCFT '999 2500 GR '999.2500 IbM '999'2500 GR '999,2500 DRHO "999' !500 TNRA -999, 500 RCFT "999. 500 GR =999 2500 -9992500 GR -999 2500 DRHO -999 2500 -999 2500 RCFT -999 0 ~9i99 -999 - 0 -9:99 -999 ~0 0 -999 O0 -999 -999 -999 :999 2500 O0 -999 ~999 2500 -999 2500 -999 2500 ~999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999,2500 -999,2500 -999.2500 -999,2500 -999~2500 bVP 010,H02 VERIFICA?I. 0 LISTING PAGE 12 CFTC -.999 C~TC ~0 TEN5 -999 '999 59 C~L,I NF DC TENS 625O SF6U ER A~ 'FDC NPHI CN?C TENS :PT 99 999 999 999 54 0000 500 5OO 1500 500500 4688 SFLU GR CALI NFDC NPHI C~TC TENS DEPT SP ' TENS DPH! RTNR CFTC GR 000,0000 999;2500 -2~2;25oo :999,2500 999,2:500 49,5000 SFLU GR CA6I NFDC NPHI CNTC TENS DEFT Sp DpH! RTNR CFTC ~900,0000 999;2500 '999, 500 '999'~500 '9~'5625 SF6U OR CAb! NFDC NPH! CNTC TENS EPT P DPH! RTNR CFTC GR ~800, 999' -999' -999 -999 -999. 26 0000 SFbU 2500 OR 2500 CALl 500 NFDC 500 NPHI 2500 CNTC 8594 TENS DEPT TE~S 3700,0000 SFbU -999.2500 GR -999,2500 CALI '999,2500 3540,0000 -999 '999 2500 2500 3524 0000 2500 2500 2500 2500 3404 !000 -999 2500 -999 2500 -999 2500 -999 2500 -999~2500 -999,2500 ]394 0000 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~2500 3274 0000 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 · 0000 -999 2500 '999 2500 '999 2500 '"999 2500 '999 2500 "9992500 3120 0000 -999,2500 -999,2500 '999,2500 RHOB FF:DC RCNT RHOI~ F'FDC RCNT TENS bD RHOB FFDC RCNT TENS RHOB FFDC RCNT TENS TENS RHOB FFDC RCNT TENS TENS RHOB FFDC RCNT TENS IbD TENS RHOB -99:9.2500 GR -9~ O0 ~500 DRHO A RCFT GR DRHO TNRA RCFT GR ~500 GR ~999 }0 DRHO 999 TNRA -999 2500 RCFT '999 2500 OR -999,2500 -999;2500 OR -999,2500 DRHO ;2500 ~NRA '"999t2500 GR -999 2500 '999 2500 :999 2500 999 2500 -999 2500 -999 2500 DRHO TNRA RCFT GR -999,ii00 '"999, O0 OR -999, O0 DRHO -99~'2500 TNRA -999,2500 RCFT '999,2500 GR -999 2500 I6M -999~2500 GR -999,2500 DRHO -999,2:500 O0 -999 -999 -999 )0 -999 iO0 '"999 -999 2500 -999 2500 -999 2500 -9~9 2500 -9 9 2500 -999 2500 -999 3500 '''' ]~ -999 ~ 2500 -999 2500 '999,2500 '"'99~, 2500 -99 , 2500 Lyp 010,H02 VERIF!CATIOM LISTING PAGE 13 R EPT PT PH! ENS DEPT TENS DPHI RTNR CFTC GR DEPT TENS D~! RTNR DEPT 0625 NFDC NPHI CN~C 3t 0000 2500 031.3 LU 0 CALl NFDC 0 MPH! C~TC 3 TENS 3400 -999 . : -999 -999 42 0000 SrbU 2500 GR 2500 CAbI 2:500 NFDC 2500 NPHI 2500 CNTC 9687 TENS 300 999 999 -999 -999 0000 SrbU 2500 GR 2500 CA[,I 2500 NFDC .2500 NPH! 2500 C~TC 6250 TENS 3200,0000 Sf l.,O -999,2500 OR -999,2500 CALI -999,2500 NFDC -999,2500 NPHI -9~:2500 CNTC 0313 TENS 100,0000 SFLU 999,2500 GR 999,2500 CALl -999,2500 NFDC "999,2500 NPH! '999'2500 CNTC 48,6250 TENS 3000,0000 SFLU '999,2500 -999,2500 "999,2500 3024,0000 2500 3500 2500 2500 2500 2500 0000 -999 -999 -999 2500 '999 2500 '999 2500 -999 ~$00 2874 000 -999 2500 '999 2500 '999 2500 "999 .2500 -999 2500 '999 2§00 288O 0000 -999 i500 -999 500 -999 i500 -999 500 -999 50O -999 50O 2724 ~000 FFDC RCNT TENS TENS RXOB FFDC RCNT TENS RHOB FFDC RCNT TENS TENS RHOB FFDC RCNT TENS ENS RHOB FFDC RCNT TENS -999,2500 IbP -997'2500 TENS -999,2500 RHOB -999, 500 FFDC -999' 500 RCNT '999,2500 TENS 2650,0000 -999,2500 ILO :999,2500 TENS .999.2500 EHOB .999'2500 FFDC .999,2500 RCNT 999,2500 TENS 2610'0000 '999,2500 ILD -999,2500 -999,2500 -999; 2500 2500 .! -999 TNRA RCFT GR ~HO RC GR GR -999 2500 -999~2500 GR 2500 DEHO -999 "999 ~0 TNRA :999 0 RCFT 999 GR -999 25OO '999 1 '999 ~ "999 500 -999 500 -999 500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 250o :999 2500 999 2500 -999 2500 TNRA RCFT GR IbM GR DRHO TNRA RCFT GR GR DRHO TNRA RCFT GR -999,2500 IL~ 5O -999 )0 -999 500 .I )0 2500 2500 500 500 -999 2500 -,,, -999 '"' -999 ) '999 2 O0 -999,2500 -999,;~500 -999,2500 '999,2500 '999,2500 :999,2500 999,!500 -999; 500 -999, 500 -999~2500 -999,2500 -999,2500 LVP 010,H02 VERIFICATION LISTING PAGE 14 R R :PT R DEPT SP DPH! RTNR DEPT SP T~NS DPH! CF?C D~T Sp TENS DpH! RTNR CFTC 2:500 GR 500 CALl 500 NFDC NPHI ~NTC 5938 .,ENS .28 42 700, 999:~ '999, -999' ~600, 999, '999, '999' -999, ~500 -999 -999 -999 47 2400 -99 -99 -999 0000 2500 500 500 25OO 2500 4375 0000 2500 2500 :2500 2500 2'500 6875 0000 2500 2500 2500 2500 2500 0000 0000 2500 500 50O 2500 2500 8750 0000 2500 2500 2500 2500 2500 7188 SFLU GR NFoc NPHi CNTC TENS SFLU GR CALI NFDC NPH! CNTC TENS SFLU GR CA~! NFDC NPHI CNTC TENS SFLU CALl NFDC NPHI CNTC TENS SFLU GR CALl NFDC NPHI CNTC TENS SFLU GR NFDC NPH! CNTC TENS -999 2500 2500 2500 2500 2:500 2540 0000 '999.2500 '999;2500 ,2500 ,2,500 ,2500 ;2500 2424,0000 -999 2500 -999 2500 -999 2500 -999 2500 2500 -999 -999 2500 225O 0000 '999,2500 '999,2500 '999.250 "999*2509 '999,!500 '999~00 2224;~00 -999 0 -999 i O0 -999 ~00 -999 50o -999 500 2124 0000 -999.2500 '999, O0 -999.) 5 5OO '999.2500 '999.~!00 "999. O0 2130, O0 -999 500 -999 500 -999 500 -999 500 "999 500 '999 :500 2000 0000 TENS FOC TENS ILD TENS RHOB FFDC RENT TENS IbD TENS RHOB FFDC RCNT TENS TENS RHOB FFDC RCNT TENS TENS RHOB FFDC RCNT TENS TENS RHOB FFDC RENT TENS IUD TENS RHOB FFDC RENT TENS -999 m -9! -999 500 -999 -999 -999 2500 250:0 ilgoo -999 2500 -,999 2500 -999 2500 -,,, -999 00 -999 2500 -999 2500 -999 2500 GR REFT GR DRHO RCFT GR DRHO TNRA ! . · IbM GR RHO NRA REFT GR XLM GR DRHO TNRA RCFT GR -999.2500 IbM -999.2500 GR -999,2500 DRHO -999~2500 TNRA -999.2500 RCFT -999e2500 GR i 99,2500 IbM 99;2500 GR 99,2500 DRHO 99~,2500 TNRA -99 ,2500 RCFT °999,2500 GR -99:9 -999 -999 -999 O0 -9 O0 -' -999 -999 -999 - 99 -999 2500 -9 2500 ' 9 -9 -99 iO0 '99~'i500 · -999, 900 -999, 500 -999, 500 -999, 500 '999,2500 '999,2500 '999,2500 '999,2500 -9:99,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999, O0 -9991, 00 -999, O0 ~VP OIO,H02 VERIFICATION LISTING PAGE 15 PT 46 R GR TENS RTNR DEPT RTNR GR DEPT TENS RTNR DEPT 8P TENS DPHI SFLU GR CAbI NFDC 2500 NPHZ 2500 C~TC 7188 TENS 21 0000 &FLU - 2500 GR -' 2500 CAb! " 2'500 aFDC -' 2500 NPHI -' 2500 CNTC 48 9375 TENS oo.ooo '999,250~ -999,2500 CALl -999,~500 NFDC -999, O0 NPH[ 813 TENS ~800. 999 -999 -999 -999 -999 44 0000 SrbO 250O GR 500 CALl 500 aFDC 500 NPH! 2500 CNTC 0313 TENS 1700 0000 SFLU -999 2500 GR -999 2500 CALl -999 2500 NFDC -999 2500 NPH! 2000 ~0 TENS RHOB RCNT TENS RHOB FFDC CNT 2025 -999 -999 -9 1940 RHOB FFDC 2500 RCNT 2500 TEN8 0000 -9 . 99 -999 -999 -999 -999 -999 1905 25 0 RHOB 2500 FFDC I~00 RCNT O0 TENS 0000 -999 -999 -999 -999 -999 -999 1890 TENS 2500 RHOB 2500 FFDC 500 RCNT 500 TENS 0000 ~999 999 -999 -999 -999 -999 1820 2500 ILD 2500 ~ENS 2500 RHOB 500 FFDC 500 RCNT 500 TENS 0000 -999,2500 .-999.2500 ,999,2500 999, O0 '999'~00 TENS RHOB FFDC RCNT O0 DRHO TNRA -99! 2500 RCFT -999 2500 GR 0 L~ ~RHO T:N:RA -' 2500 DRHO -' 2500 TaRA -999 2500 RCFT -999 2500 GR HO 25:00 TNRA 2500 RCFT 2500 GR -99 -999 ~999 00 Ibg O0 GR 2500 DRHO 2500 TNRA 2500 RCFT 2500 GR -999,2500 IbM -999,2500 GR -999,2500 DRHO -999'2500 TNRA '999,2500 RCFT "999,2500 GE -999 2500 IbM -999 2500 GR -999 2500 DRHO -999 2500 TNRA -999 2500 RCFT -999 ~00 )0 )0 -999, O0 -999,2500 -999,2500 -999,2500 -999,2500 -999 2500 -999 2500 -999 2500 ~ O0 11oo "99~ 2500 ,,999,2500 ..999,2500 -999;2500 -999.,2500 -999,2500 LVP OIO,H02 VERIFICATIEN LISTENS PAGE 16 PT DE~T R~NR DEPT RTNR CFTC GR DEPT TENS DPH! R?NR CFTC DEPT TENS -999.2500 CNTC 21.7500 TENS 999 -999 -999 -999 -999 47 2500 C~bZ 2'500 ~tVC CNTC 5625 TENS 2500 2500 4688 FLU R CAbI NFDC NPH! CNTC TENS 34, 625 rbu R CALI NrDC NPHI CNTC TENS 300,0000 999;2500 '999'2500 :999;2500 999,2500 6875 SFLU CALl NFDC NPH! CNTC TENS ~200,0000 2500 500 8t3 NFDC NPH! CNTC TENS 1100,0000 =999,2500 -999,2500 -999,2500 -999,2500 -999,2500 51,4688 SFLU GR CALI NFDC NPH! NTC 1000,0000 -999,2500 -999,2500 SFLU GR CALl -999 i805 -999 -999 =999 -999 -999 -999 I720 -999 -999 -999 -999 -999 -999 1625 -999 -999 -999 -999 -999 -999 1585 -999 -999 -999 -999 -999 -999 t515 -999 -999 -999 -999 "999 -999 1465 -999 -999 -999 -999 -999 -999 1395 ~999 .999 999 ,2500 ,0000 2500 2500 ~2500 ,2500 o000 ,25~0 ;2:50 ,2500 ,2500 ,2500 ;~2500 ,0000 2500 2500 2500 2500 2500 2500 0000 i500 50 · 50§ °° 5OO O0 0000 ,2500 2500 2500 2500 2500 2500 0000 500 500 500 2500 2500 2500 0000 ,2500 ,2500 ,2500 TENS TE RHOB FFDC RCNT TENS TENS RHOB FFDC RCNT TENS TENS RHOB FFDC RCNT TENS TENS RHOB FFDC RCNT TENS TENS RHOB FFDC RCNT TENS TENS RHOB FFDC RCNT TENS TENS RHOB -999,2500 GR -999,2500 '999,2500 OR -999,2500 ORBO -999~2500 TNRA -999'2500 RCFT -999;2:500 GR -999 . -9! -999 -999 -999 2500 Ib~ 2500 GR 2500 ORHO 2500 TNRA 2500 RCFT 2500 GR -999 '999 -999 -999 -999 -999 2500 2500 GR 2500 DRHO 500 ~NRA 500 RCFT 500 GR -999 '999 '999 ''999 '999 -999 2500 IL~ 500 GR 500 DRHO 500 TNRA 500 RCf'T 2500 GR -999.2500 IbM "9 GR .9~'2500 ;2500 DRHO '99~,2500 TNRA -99 RCFT .99~'2500 ,2500 GR -999,2500 lb~ '999,2500 GR '999,2500 DRHO -999.250'o ,,9' ~500 -999 500 -999 !500 '99:9 O0 -999 O0 0 0 -999 -999 ~500 '99~ )0 -99 -99 -999 ,0 -999 2500 ~999 2500 9 9 2500 '9~9 2500 -999 2500 -999 2500 '999,2500 '999, O0 -999, O0 -999,2500 -999,2500 !0 -999, 0 -99_9, ~00 -999, 500 "'99_9, 500 '999, 500 -999,2500 '999,2500 -999,2500 LVP 010,H02 VERIFICATION LISTING PAGE 17 GR -999 2500 NFDC · ' 9 NPHI TENS -999,2500 FFDC "999,2500 RCNT -999':2500 TEN5 1310,,0000 GR G.R 5625 'TENS -999 2500 -999 TENS RHOB FFDC 9! RCNT TENS 1300 0000 : l , soo ' '2500 OR -99! O0 '999,2500 ..99_9_, 2500 ,,999,2500 -999 500 -999 FiLE ?RAILER ** ;DIT ,001 ~ION # I : 1024 :XT FILE NAME : FILE HEADER ** AM4EDIT1 ,002 ON ~ ! MON LENGTH : 1024 TYPE t IOUS FILE : ** DATA FORMAT RECORD $* ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 4 1 66 1 8 4 73 12 9 4 65 ,lin 16 1 66 1 0 I 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT APl APl APl APl FILE SIZE SPb REPR PROCESS ID ORDER # ' LOG TYPE CLASS MOD NO, CODE FT O0000 O0 0 0 4 ! 68000000000000 O0 DEPT GR FUH ~PZ O0 ~!~ ot o o 4 t ee oooooooooooooo !ENS rD. L~ oo eJ~ ~l o o 4 t es ooooooooooo0oo cA~I rD. z~ oo 2so ot o o 4 , es oooooooooooooo R.OS FDH G/C3 O0 350 02 0 0 4 t eS 00000000000000 DR.O rDH GYC3 O0 356 01 0 0 4 I 68 00000000000000 LVP OIO,M02 VERIFICATION LISTING PAGE 18 FDH FDH DH CNH CNH R CNH DATA $* 89 DEPT FFDC RHOB FFDC RCNT ?ENS DEPT RHOB FFDC RCNT TENS DEP_T RHOB rroc RCNT TENS PU O0 890 OO 0 o CPS oo o o 0 oo o o O0 O0 0 0 U O0 890 O0 o 0 PS O0 000 O0 0 0 CPS O0 000 O0 0 0 CPS O0 000 O0 0 0 CPS OO OO0 O0 0 0 LB O0 635 21 0 0 GAPI O0 310 O1 0 0 84 O0 2 98 8 t 8;i 826 0000 8800 2988 51.20 4489 2500 1835 2527 8384 O000 2988 870~ 4352 501 5000 3784 o 7 000 G~ RHO NRA RCFT GR DRHO TNRA RCFT GR GR DRHO TNRA RCFT GR GR DRHD TNRA GR 988 GR 465 ~ TNRA ' oo 8500.23988 58 ~000 TNRA 1896, 044 RCFT 7784,0000 GR 840~,2988 GR ,3835 DRHO 1010 8125 0594 3 3496 60 4950 101 8125 104 3125 0 O57O 3 0730 5 2 94 04~3 6250 0 52~ 47 5 41.96 94 6250 119 5000 0 0209 3 1073 692 2141 119 5000 133 25O0 -0 O07 l 46~ 6301 7074 133 2500 5,~87 120. TENS DPH! RTNR CFTC TENS RTNR CFTC TENS DPHI RTNR CFTC TENS DPHI RTNR CFTC TENS RTNR CFTC TENS RTNR CFTC TEN& DPHI 4.668,0000 ,8020 8264,0000 72t0 ! ,1948 .8667 588;2916 79~,0000 ,0 67 8808,0000 1,1,2145 76~ ,2059 .6067 7784,0000 18,6628 52~ e6818 .2196 7449,0000 16,1608 68 00000000000000 68 6 68 0 0000000 0000 0000.00000~0000 CALl NFDC NPHI CNTC 8 6797 650 0 CALI NFDC NPHI CNTC CALl NFDC NPH! CNTC CALl NFDC NPH! CNTC CALl NFDC NPHI CNTC CALI NFDC NPH! CNTC CALl NFDC 8. 625, 0 21 2266 617~5000 8,1562 5~8,0000 24925 't662 ,9424 8,7578 581'5000 2253, 8,4063 583,5000 45'735! 1873,2075 8,4609 613,0000 / [~VP OlO,H02 VERiF"~CAT!ON LISTING R.~FT 2988 GR TNRA RCFT GR GR DRHO 1740 0747 RCFT 7]24,0000 GR 3,6502 RTNR 43i 4692 CFTC 12:6875 1270 6oe i27 8750 TENS O604 DPHI RTNR CFTC 111 3:750 TENS DPHI RTNR 429 CFTC ,002 [E NAME : :lqU~ bENGTH { 1024 TYPE { 3,3478 NPHI 511,1180 CNTC 7312, CALI 9, NFDC , NPHi 55 ,2628 CNTC 7:]2'4.0000 CALI 14, O] NFDC 1 ,51 CNTC PAGE 19 46,0202 1805,1365 8,5156 6~I'0000 ;998I 1888,2388 1801,4543 ~* T.A'PF TRAILER ~* ~E~VICEC NAME {EDIT ATE :88/07/17 TAPE NAME l CONTINUATION # 101 NEXT TAPE NAME I COMMENTS :EDIT bIS,ARC0 KUPARU~ 3 0-4,API # 50-029-21862 ** REEL TRAILER SERVICg NAME :EDIT DATE 188/07/17 ORIG~N { REEb_NAME :72846 CONTINUATION # 101 NEXT REEb NAME : COMMENTS {EDIT bIS,ARCO KUPARUK 30-4,AP! ~ 50-029.2~R62