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182-068
Carlisle, Samantha J (DOA) From: Haggerty-Sherrod,Ann (Northland Staffing Services) <Ann.Haggerty- Sherrod@contractor.conocophillips.com> Sent: Friday, November 18, 2016 7:01 AM To: Carlisle, Samantha J (DOA) Cc: Burke,Jason Subject: Sundry Withdrawal-1H-06 Good morning, This email is to officially request withdrawal of the following approved Sundry: 1H-06 approved Sundry#316-417 We are withdrawing this sundry because the job has been cancelled due to the failure of 1H-07 laterals. Thanks, Ann S%ANNE() APR 2 8 ? %'; 1 RBDMS t'L'J"," 2 6 2017 STATE OF ALASKA � 1i ALKA OIL AND GAS CONSERVATION COMMISSION i: _. • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations r Fracture Stimulate fl Pull Tubing F p ri4atdown E Performed: Suspend I— Perforate fl Other Stimulate n Alter Casing F Changepproved rogram F Plug for Redrill I— Perforate New Pool I— Repair Well F Re-enter Susp Well r Other: Run Casing Patch 17 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory f 182-068 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-20741-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25639 KRU 1H-06 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: • Total Depth measured 6964 feet Plugs(measured) None true vertical 6942 feet Junk(measured) 6650, 6728 Effective Depth measured 6634 feet Packer(measured) 6110,6226,6460,6554 true vertical 6812 feet (true vertical) 6088,6204,6438,6532 Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80 80 SURFACE 2166 10.75 2194 2194 PRODUCTION 1612 7 1636 1636 PRODUCTION 5264 7 6900 6878 Perforation depth: Measured depth: 6372-6400,6404-6410,6417-6428,6472-6496,6634-6641,6647-6656 True Vertical Depth: 6350-6378,6382-6388,6395-6406,6450-6474,6612-6619,6625-6634 Tubing(size,grade,MD,and TVD) 3 1/2 x 4 1/2, L-80 x J-55,6566 MD,and 6544 TVD Packers&SSSV(type,MD,and ND) PACKER-PACKER, BAKER,47B2 FHL(60K SHEAR RELEASE)@ 6110 MD and 6088 ND PACKER-BAKER HB-1 HYD PACKER @ 6226 MD and 6204 ND PACKER-PACKER HB-1 HYDSET PACKER @6460 MD and 6438 ND PACKER-BAKER 1B PERMANENT PACKER w/SBE XO to 2 7/8"@ 6554 MD,and 6532 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/AL3� �� t7 Z7,117, 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 Off-Line Subsequent to operation Off-Line 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory fl Development F Service E Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas E WDSPL E Printed and Electronic Fracture Stimulation Data E GSTOR E WINJ r WAG 1— 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: 316-378 Contact Danny Kane Ccs 265-6048 Email Daniel.Kane(a conocophillips.com Printed Name Daniel Kane Title Sr. Wells Engineer SignaturePhone:265-5048 Date Form 10 404 Revised 5/2015 tel' � ` x i2//1,- L L/ SEP - 1 2016 Submit Original Only RBDMS B • • Operations Summary (with Timelog Depths) Conoco hitiips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P T x Operation (fCKS)< End Depth(eKE) 7/9/2016 7/9/2016 0.50 MIRU MOVE RURD P Install blank flanges on the tree. 0.0 0.0 12:00 12:30 Cleanout the cellar box. Prep to move the rig. 7/9/2016 7/9/2016 0.75 MIRU MOVE MOB P Separate boiler,motor,pump,and pit 0.0 0.0 12:30 13:15 modules and stage on the pad. 7/9/2016 7/9/2016 2.75 MIRU MOVE MOB P Move satellite office,shop,boiler, 0.0 0.0 13:15 16:00 motor,pump,and pit modules from 2S to 2M pad. SimOps: PU and load out rig mats. Hook up the sow to the sub. 7/9/2016 7/9/2016 0.50 MIRU MOVE MOB P Pull the sub off well 2S-12 and stage 0.0 0.0 16:00 16:30 on the pad. 7/9/2016 7/9/2016 2.00 MIRU MOVE MOB P Move the sub,pipe shed,and rock 0.0 0.0 16:30 18:30 washer from 2S to 2M pad. 7/9/2016 7/10/2016 5.50 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 18:30 00:00 2S-14. SimOps: Remove rock washer drag chain. Disassemble mud cleaner and centrifuge. 7/10/2016 7/10/2016 6.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 00:00 06:00 2S-14. SimOps: Remove rock washer drag chain gear box. Disassemble mud cleaner and centrifuge. General maintenance and housekeeping. 7/10/2016 7/10/2016 6.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 06:00 12:00 2S-14. SimOps: Continue to remove rock washer drag chain gear box,drive sprocket,and bearings. Disassemble mud cleaner and centrifuge. RemoveGeneral maintenance and housekeeping. 7/10/2016 7/10/2016 6.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 12:00 18:00 2S-14. SimOps: RU air to the sub and conduct BWM on the BOP stack. Continue to change out the rock wash gear box. Disassemble 10"PVC line from the mud cleaner. Weld plates on the rig floor. Fill cracks from the rig floor to the mezzanine. Change out the pop offs replace flange gaskets on boiler#2. Change out main check valve on the steam line in the boiler room. 7/10/2016 7/10/2016 1.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 18:00 19:00 2S-14. SimOps: Safety stand down and 1 H- 06 pre spud meeting with rig crew. Page 1/23 Report Printed: 8/1/2016 • • Operations Summary (with Timelog Depths) 1H-06 ConocoPhltgps e.a Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Tithe End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/10/2016 7/11/2016 5.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 19:00 00:00 2S-14. SimOps: Continue to change out the rock wash gear box. Continue to change out main check valve on th? steam line in the boiler room. Clean mud out of the mud cleaner body. Install stairs on the sub. Clean under the pipe skate. 7/11/2016 7/11/2016 6.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 00:00 06:00 2S-14. SimOps: Repair rock washer heater plumbing. Repair hammer unions. Change out check valve on boiler#1. 7/11/2016 7/11/2016 6.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 06:00 12:00 2S-14. SimOps: Change out suction valves in the rock washer. Rebuild the rock washer drag chain gear box. Weld floor plates on the rig floor. Remove centrifuge,guards,and electric motor from the mud pits. Assist KDTH and Doyon 142 with laying out plywood on the road from 2L to 2S pad. 7/11/2016 7/11/2016 6.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 12:00 18:00 2S-14. SimOps: Change out butterfly valves in the rock washer. Clean and clear out parts from the centrifuge from the pits. Continue to weld floor plates on the rig floor. Clean dust out of the power factors. Assist KDTH and Doyon 142 with laying out plywood on the road from 2L to 2S pad. 7/11/2016 7/12/2016 6.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 18:00 00:00 2S-14. SimOps: Continue to disassemble centrifuge and mud cleaner feed/return lines. Clean double studded adaptor in the pipe shed. Change out skate hydraulic tank heater and filter the oil. Mobilize equipment from 1J pad to KIC pad. 7/12/2016 7/12/2016 6.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 00:00 06:00 2S-14. SimOps: General maintenance and housekeeping. Continue to repair hammer unions. Mobilize equipment from 1J pad to KIC pad. 1H-06 pre spud meeting with rig crew. Page 2/23 Report Printed: 8/1/2016 • S ' k Operations Summary (with Timelog Depths) 1H-06 44,4 ConocioPhiliips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKB) 7/12/2016 7/12/2016 6.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 06:00 12:00 2S-14. SimOps: Install drag chain in rock washer. Weld floor plates on the rig floor. Change out valve on the pipe skate. Continue to mobilize equipment from 1J to KIC pad. 7/12/2016 7/12/2016 6.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 12:00 18:00 2S-14. SimOps: Wire wheel primer off welds on the new choke manifold. Clean and restock bolt bin in the pump room. Change out hydraulic feed/return line on the iron roughneck. Replace hoist valve on the pipe skate. Change out belt on water pump#2. Service the dynamic brake. Change gear oil in the rotary table. Prep and assembly the mud pumps. 7/12/2016 7/13/2016 6.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 18:00 00:00 2S-14. SimOps: Continue to change out the hose on the iron roughneck. Continue to change gear oil in the rotary table. Assemble the mud pumps. • 7/13/2016 7/13/2016 2.00 MIRU MOVE WAIT T Waiting for Doyon 142 to move onto 0.0 0.0 00:00 02:00 2S-14. SimOps: Change out butterfly valves on the rock washer. Remove drilling line hatch for repair. 7/13/2016 7/13/2016 4.00 MIRU MOVE WAIT P Pick up mats,portable road,and 0.0 0.0 02:00 06:00 plywood from 2L to 2S. Lay out mat and portable road from 2M to 1H pad. SimOps: Continue to change out butterfly valves on the rock washer. Change out valve on the pipe skate. Repair hinges on the fast line hatch. Cap off 8"cone in the pits. Assist the KDTH pick up the portable road. 7/13/2016 7/13/2016 8.00 MIRU MOVE WAIT P Pick up mats,portable road,and 0.0 0.0 06:00 14:00 plywood from 2L to 2S. Lay out mat and portable road from 2M to 1H pad. SimOps: Cut off and weld new 8" flange on charge pump#2. Change cellar light to LED. Prep the sub and modules for moving. Load up the shop. 7/13/2016 7/13/2016 2.00 MIRU MOVE MOB P Move the shop,satellite office,boiler, 0.0 0.0 14:00 16:00 motor,pump,and pit modules from 2M to CPF2. 7/14/2016 7/14/2016 2.00 MIRU MOVE MOB P Move the shop,satellite office,boiler, 0.0 0.0 00:00 02:00 motor,pump,and pit modules from CPF2 to KKC/KOC. Page 3/23 Report Printed: 8/1/2016 �; S • '� ��� � Operations Summary (with Timelog Depths) n ,--' , IL,-,-,..( a 1H-06 ConotoPhillips rks Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Tirtie Cur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth(MKS) 7/14/2016 7/14/2016 3.00 MIRU MOVE WAIT P Lay out mats and portable road from 0.0 0.0 02:00 05:00 KCC to 1H pad. 7/14/2016 7/14/2016 1.25 MIRU MOVE WAIT P The road is ready. Wait for field crew 0.0 0.0 05:00 06:15 change. 7/14/2016 7/14/2016 1.75 MIRU MOVE MOB P Move the shop,satellite office,boiler, 0.0 0.0 06:15 08:00 motor,pump,and pit modules from KKC/KOC to 1H pad. 7/14/2016 7/14/2016 2.00 MIRU MOVE MOB P Stage the boiler,motor,pump,and pit 0.0 0.0 08:00 10:00 modules on 1H pad. Set the shop and satellite office. 7/14/2016 7/14/2016 5.00 MIRU MOVE MOB P Hook up the trucks to the sub and pipe 0.0 0.0 10:00 15:00 sheds. Move the pipe shed modules and sub from 2M to 1H pad. 7/14/2016 7/14/2016 1.00 MIRU MOVE RURD P Remove riding shacks and yolk from 0.0 0.0 15:00 16:00 the sub. 7/14/2016 7/14/2016 1.25 MIRU MOVE MOB P Spot the sub over well 1H-06. 0.0 0.0 16:00 17:15 7/14/2016 7/14/2016 2.50 MIRU MOVE MOB P Set mats. Spot pit,pump,motor,and 0.0 0.0 17:15 19:45 boiler modules. 7/14/2016 7/14/2016 1.00 MIRU MOVE MOB P Spot the pipe sheds to the sub. 0.0 0.0 19:45 20:45 On hi-line power at 20:00 hours. 7/14/2016 7/15/2016 3.25 MIRU MOVE RURD P Set mats and stairs. Turn on SCR 0.0 0.0 20:45 00:00 and air. Set the pipe skate. Set enviro vac. Test LEL and H2S alarms. Connect the high pressure mud lines. SimOps: Move the rock washer from 2M to 1H pad. 7/15/2016 7/15/2016 0.50 MIRU MOVE MOB P Spot the rock washer. 0.0 0.0 00:00 00:30 7/15/2016 7/15/2016 2.50 MIRU MOVE RURD P Set up berming around the rig. Hook 0.0 0.0 00:30 03:00 up the rock washer. Spot the choke house and kill tank. RU hard line from the cellar to the choke house and from the choke house to the kill tank. Clean pits. Work on rig acceptance checklist. 7/15/2016 7/15/2016 2.00 MIRU WELCTL RURD P Rig accepted at 03:00 hours. Start 0.0 0.0 03:00 05:00 loading the pits with seawater. RU circulating equipment for the well kill operation. PT lines with air(no leaks) and PT lines with fresh water to 2500 psi(good test). 7/15/2016 7/15/2016 2.75 MIRU WELCTL MPSP P PU and RU the lubricator. PT the 0.0 0.0 05:00 07:45 lubricator to 1000 psi(good test). Pull the 3"H BPV. RD the lubricator. • Tubing=480 psi and IA=1200 psi. Page 4/23 Report Printed: 8/1/2016 • S Operations Summary (with Timelog Depths) 1H-06 rat Conoc Phiiiips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) '; Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 7/15/2016 7/15/2016 4.25 MIRU WELCTL KLWL P PJSM. PT rig pump lines to 3000 psi 0.0 0.0 07:45 12:00 (good test). Pump 8.5 ppg seawater down tubing taking returns up the IA through the choke manifold to the kill tank. ICP at 1 BPM=450 psi for 66 bbls and staged up to 2 BPM=180 psi while maintaining back pressure at the choke manifold. Pumped 300 bbls of 8.5 ppg seawater and recovered 124.7 bbls at the kill tank before getting good 8.5 ppg seawater at surface. Shut in the well to monitor pressures. 7/15/2016 7/15/2016 0.75 MIRU WELCTL OWFF P Observe the well for flow for 30 0.0 0.0 12:00 12:45 minutes and the well is on a slight vac. 7/15/2016 7/15/2016 0.25 MIRU WELCTL RURD P Blow down and RD circulating lines. 0.0 0.0 12:45 13:00 7/15/2016 7/15/2016 0.25 MIRU WHDBOP MPSP P Install 3"HP BPV with dry rod. 0.0 0.0 13:00 13:15 7/15/2016 7/15/2016 1.75 MIRU WHDBOP NUND P PJSM. ND tree and tubing head 0.0 0.0 13:15 15:00 adapter. The lift threads on the tubing hanger looked good. Installed the blanking plug into the BPV. 7/15/2016 7/15/2016 2.00 MIRU WHDBOP NUND P Clean the API ring groove. NU the 0.0 0.0 15:00 17:00 DSA and spacer spool. 7/15/2016 7/15/2016 3.00 MIRU WHDBOP NUND P NU the BOP stack,NU the Dutch 0.0 0.0 17:00 20:00 riser,and NU the choke line. SimOps: Load,strap,and tally 200 joints of 4"XT 39 DP. 7/15/2016 7/15/2016 1.00 MIRU WHDBOP RURD P RU BOPE testing equipment. Fill the 0.0 0.0 20:00 21:00 BOP stack and choke manifold with fresh water. Shell test the BOP stack to 250/3000 psi(good test). 7/15/2016 7/16/2016 3.00 MIRU WHDBOP BOPE P Conduct initial BOPE test: test 2-7/8" 0.0 0.0 21:00 00:00 x 5"VBR's(upper pipe rams)to 250/3000 psi with 3-1/2"test joint. The states right to witness was waived by AOGCC inspector Guy Cook via email on 7/13/16 at 14:17 hours. Tests: 1) Upper pipe rams with 3-1/2"test joint,manual Kill,chokes 1, 12, 13,4 14(Passed) 2) Upper IBOP, HCR kill,chokes 9& 11 (Passed) 3) Lower IBOP,chokes 5,8,&10 (Passed) 4) Dart valve,chokes 4,6,&7 (Passed) 5) 4"XT39 TIW,choke 2(Passed) 6) HCR choke,4"Demco(Passed) 7) Manual Choke,HCR kill(Passed) 8) Annular with 3-1/2"test joint (Passed) Page 5/23 Report Printed: 8/1/2016 • aral"Pitt Operations Summary (with Timelog Depths) 1H-06 tAV COrlOCCehillipS Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Cade Activity Cade Time P-T-X Operation (ftKB)', End Depth MMKS), 7/16/2016 7/16/2016 1.50 MIRU WHDBOP BOPE P Continue to conduct initial BOPE test: 0.0 0.0 00:00 01:30 test 3-1/2"x 6"VBR's(lower pipe rams)to 250/3000 psi with 3-1/2"test joint;test annular to 250/3000 with 3- 1/2"test joint;conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Guy Cook via email on 7/13/16 at 14:17 hours. Tests: 9) Lower pipe rams with 3-1/2"test joint(Passed) 10)Blind rams,choke 3(Passed) 11)Super choke and manual adjustable choke(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=2950 psi Accumulator Pressure After Closer= 1800 psi Pressure Gain of 200 psi=51 seconds Full System=200 Seconds Average N2(5 Bottles)=1950 psi 7/16/2016 7/16/2016 1.00 MIRU WHDBOP RURD P Blow down and RD BOPE testing 0.0 0.0 01:30 02:30 equipment. 7/16/2016 7/16/2016 0.25 MIRU WHDBOP MPSP P Check for pressure under the BPV 0.0 0.0 11 02:30 02:45 and the well is on a slight vac. Pull the blanking plug and BPV with dry rod. 7/16/2016 7/16/2016 0.50 COMPZN RPCOMP RURD P Bring GBR power tubing tongs and 0.0 0.0 02:45 03:15 SLB control line spool to the rig floor and RU both. RU 4"DP elevators. 7/16/2016 7/16/2016 1.25 COMPZN RPCOMP PULL P MU the landing joint,BOLDS,unseat 5,680.0 5,651.0 03:15 04:30 the tubing hanger at 190K,and pull hanger to the rig floor(PU=90K and SO=67K). Lay down the tubing ' hanger. 7/16/2016 7/16/2016 3.50 COMPZN RPCOMP PULL P POOH laying down 3-1/2"tubing 5,651.0 3,901.0 04:30 08:00 spooling control line removing stainless steel bands to the SCSSSV. Lay down the SCSSSV. Control line parted 2 joints prior to SCSSSV. 7/16/2016 7/16/2016 0.50 COMPZN RPCOMP RURD P RD SLB control line spooler. 3,901.0 3,901.0 08:00 08:30 Recovered 27 of the 31 stainless steel bands. 7/16/2016 7/16/2016 3.50 COMPZN RPCOMP PULL P Continue POOH laying down 3-1/2" 3,901.0 0.0 08:30 12:00 tubing removing GLM's. Recovered 180 joints of 3-1/2"tubing,7 GLM's, and cut joint(length=15.86'and OD flared to 4"). Observed drag with the last 500'of tubing while POOH. 7/16/2016 7/16/2016 1.00 COMPZN RPCOMP RURD P RD GBR power tubing tongs. Clear 0.0 0.0 12:00 13:00 and clean the floor. 7/16/2016 7/16/2016 1.00 COMPZN RPCOMP BOPE P RU BOPE testing equipment. Install 0.0 0.0 13:00 14:00 the test plug. Page 6/23 Report Printed: 8/1/2016 • Operations Summary (with Timelog Depths) • frAp "16 11-4f 1H-06 ConocoPhillips ` Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB)< End Depth(ftKE); 7/16/2016 7/16/2016 1.00 COMPZN RPCOMP BOPE T MU the crossover to the test joint and 0.0 0.0 14:00 15:00 it was noticed that the crossover was to long and would not be able to test the lower pipe rams. Wait for correct length crossover to arrive. • SimOps: Lay down all 5"handling equipment. 7/16/2016 7/16/2016 1.75 COMPZN RPCOMP BOPE P BOPE test: test 2-7/8"x 5"VBR's 0.0 0.0 15:00 16:45 (upper pipe rams)to 250/3000 psi with 4"test joint;test 3-1/2"x 6"VBR's (lower pipe rams)to 250/3000 psi with 4"test joint;test annular to 250/3000 with 4"test joint. Tests: 1) Upper pipe rams with 4"test joint (Passed) 2) Annular with 4"test joint(Passed) 3) Lower pipe rams with 4"test joint (Passed) 7/16/2016 7/16/2016 0.25 COMPZN RPCOMP BOPE P RD BOPE testing equipment. 0.0 0.0 16:45 17:00 7/16/2016 7/16/2016 1.75 COMPZN RPCOMP BOPE T Attempted to pull the test plug but 0.0 0.0 17:00 18:45 unable to pull it with 25K over. Called Cameron rep to location and found out that incorrect test plug was used. Discussed options with town. Pulled test plug free with 45K over pull. 7/16/2016 7/16/2016 0.75 COMPZN RPCOMP RURD P MU wear ring setting tool,to a joint of 0.0 0.0 18:45 19:30 DP,install the wear ring,run in 2 LDS, and lay down the wear ring setting tool. 7/16/2016 7/16/2016 0.25 COMPZN RPCOMP RURD P Bring Baker fishing tools to the rig 0.0 0.0 19:30 19:45 floor. 7/16/2016 7/16/2016 1.50 COMPZN RPCOMP BHAH P PU and MU BHA#1 -overshot 0.0 0.0 19:45 21:15 assembly for 3-1/2"tubing. After MU the bumper sub and hydraulic jar attempted to RIH but tagged at 36' RKB. Used the elevators to make it down to 50'and tagged up with 5K down. Pull the BHA out of the well. 7/16/2016 7/16/2016 0.75 COMPZN RPCOMP WAIT X Call town engineer and discuss 0.0 0.0 21:15 22:00 options. Decided to attempt to run RBP in the well in order to stretch the casing. Notify Baker,PESI,and Cameron. 7/16/2016 7/16/2016 0.25 COMPZN RPCOMP BHAH X Lay down BHA#1. 53.0 0.0 22:00 22:15 7/16/2016 7/17/2016 1.75 COMPZN WELLPR PULD X PJSM. Single in the hole with 4"XT39 0.0 504.0 22:15 00:00 DP. At 110'MD starting taking weight. Work down to 120'MD and lost all SO weight. MU the top drive and RIH with 5-7K down to 504'MD(PU=55K and SO=OK). Page 7/23 Report Printed: 8/1/2016 • • sie �toaq Operations Summary (with Timelog Depths) 1H-06 +ConocoPhilltps Rig: DOYON 141 Job: RECOMPLETION Time Log • Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/17/2016 7/17/2016 2.75 COMPZN WELLPR PULD X Continue to single in the hole with 4" 504.0 1,421.0 00:00 02:45 XT39 DP from 504'to 1420.55'MD. Unable to get any SO weight;having to use the top drive to push the DP in the hole with 5-10K down. Note: Called for SLB E-line and Baker for 2!BP's. 7/17/2016 7/17/2016 1.00 COMPZN WELLPR TRIP X TOOH standing back 4"DP. 1,421.0 0.0 02:45 03:45 7/17/2016 7/17/2016 0.25 COMPZN WELLPR RURD X Clear and clean the rig floor. 0.0 0.0 03:45 04:00 7/17/2016 7/17/2016 1.75 PROD1 WELLPR WAIT X Wait on E-line. 0.0 0.0 04:00 05:45 SimOps: Work on MP2's. 7/17/2016 7/17/2016 1.25 PROD1 WELLPR ELNE X PJSM. Spot SLB E-line unit and bring 0.0 0.0 05:45 07:00 E-line equipment to the rig floor. 7/17/2016 7/17/2016 1.25 PROD1 WELLPR ELNE X Install the Dutch riser. 0.0 0.0 07:00 08:15 7/17/2016 7/17/2016 1.00 PROD1 WELLPR ELNE X RU E-line and PT the pack-off to 500 0.0 0.0 08:15 09:15 psi(good test). 7/17/2016 7/17/2016 0.75 PROD1 WELLPR ELNE X PU and MU Baker 3-3/8"IBP with 0.0 0.0 09:15 10:00 setting tool and CCL. 7/17/2016 7/17/2016 3.25 PROD1 WELLPR ELNE X RIH with 3-3/8"IBP,set at 3000'WLM 0.0 0.0 10:00 13:15 (center of element),and POOH with setting tool and CCL. Lay down E-line tools. 7/17/2016 7/17/2016 0.75 PROD1 WELLPR PRTS X RU pressure testing equipment. PT 0.0 0.0 13:15 14:00 the IBP to 1000 psi. The pressure bleed off to 600 psi in 20 minutes (leaking by the faulty IC secondary pack-off). 7/17/2016 7/17/2016 3.00 PROD1 WELLPR FLOG X MU 40 multi finger caliper,RIH to 0.0 0.0 14:00 17:00 2990'WLM,and log back to surface. Lay down caliper. 7/17/2016 7/17/2016 4.00 PROD1 WELLPR FLOG X MU SCMT(CBL),RIH to 2985'WLM, 0.0 0.0 17:00 21:00 and log back to surface. Lay down SCMT. 7/17/2016 7/17/2016 0.50 PROD1 WELLPR ELOG X RD SLB E-line(E-line crew timed out). 0.0 0.0 21:00 21:30 Leave SLB E-line unit spotted up for addition runs tomorrow. 7/17/2016 7/17/2016 0.50 PROD1 WELLPR FLOG X RD the Dutch riser. 0.0 0.0 21:30 22:00 7/17/2016 7/17/2016 1.25 PROD1 WELLPR OTHR X PU a joint of 4"DP,MU mule shoe to 0.0 0.0 22:00 23:15 the bottom,RIH,and set in the slips with a dog collar. Dump 1500 lbs of sand down the 7"casing;placing 65.55'of sand on top of the IBP. 7/17/2016 7/18/2016 0.75 PROD1 WELLPR WAIT X Allow the sand to settle. 0.0 0.0 23:15 00:00 SimOps: RU testing equipment to the IA and OA. 7/18/2016 7/18/2016 0.50 PROD1 WELLPR WAIT X Continue to allow the sand to settle. 0.0 0.0 00:00 00:30 7/18/2016 7/18/2016 1.00 PROD1 WELLPR PRTS X Pressure up the OA to 2500 psi with 0.0 0.0 00:30 01:30 the test pump. Pressure up on the 7" casing to 2500 psi to test the IBP for 15 minutes(good test). Page 8/23 Report Printed: 8/1/2016 • , ; Operations Summary (with Timelog Depths) sem.. Conocothiliips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB); 7/18/2016 7/18/2016 0.75 PROD1 WELLPR PRTS X Bleed the 7"casing to 0 psi and bleed 0.0 0.0 01:30 02:15 the OA to 0 psi. Blow down the kill and choke lines. 7/18/2016 7/18/2016 1.00 PROD1 WELLPR NUND X PJSM. ND the BOP stack and set 0.0 0.0 02:15 03:15 back on the stump. ND the 7-1/16"x 13-5/8"DSA. ND the IA flange. 7/18/2016 7/18/2016 1.00 PROD1 WELLPR NUND X PJSM. ND the annulus valve from the 0.0 0.0 03:15 04:15 tubing head. Remove every other bolt from the tubing head lower flange using the nut splitter. 7/18/2016 7/18/2016 0.75 PROD1 WELLPR NUND X Bleed off the void and BOLDS on the 0.0 0.0 04:15 05:00 casing head. 7/18/2016 7/18/2016 2.50 PROD1 WELLPR NUND X RU Hydratight and ND the tubing head 0.0 0.0 05:00 07:30 using Hydratight to control the casing growth(27"of growth). RD Hydratight. 7/18/2016 7/18/2016 0.50 PROD1 WELLPR RURD X PJSM. Bring 11"3M x 13-5/8"5M 0.0 0.0 07:30 08:00 spacer spool into the cellar. Gather equipment to Nipple back up BOPE. 7/18/2016 7/18/2016 2.75 PROD1 WELLPR NUND X NU the 11"3M x 13-5/8"5M spacer 0.0 0.0 08:00 10:45 spool and NU the 13-5/8"BOP stack. Change lower pipe rams(LPR)from 3 -1/2"x 6"VBR's to 7"solid body rams. 7/18/2016 7/18/2016 1.25 PROD1 WELLPR BOPE X RU BOPE testing equipment and 7" 0.0 0.0 10:45 12:00 donut test joint. 7/18/2016 7/18/2016 1.50 PROD1 WELLPR BOPE X Test LPR's and annular with 7"donut 0.0 0.0 12:00 13:30 test joint to 250/2500 psi(both tests passed). Note: The 2500 psi pressure limitation is due to 80%burst pressure of the 10 -3/4",45.5#K-55 surface casing. 7/18/2016 7/18/2016 0.50 PROD1 WELLPR BOPE X RD BOPE test equipment and lay 0.0 0.0 13:30 14:00 down 7"donut test joint. 7/18/2016 7/18/2016 1.00 PROD1 WELLPR SEQP X RU hard line from spacer spool to the 0.0 0.0 14:00 15:00 open top tank and PT line to 2500 psi with fresh water. 7/18/2016 7/18/2016 1.25 PROD1 CSGRCY ELNE X PJSM with rig crew and SLB E-line 0.0 0.0 15:00 16:15 crew. RU Dutch riser and SLB E-line. PT the pack-off to 500 psi(good test). 7/18/2016 7/18/2016 1.25 PROD1 CSGRCY ELNE X MU 5"chemical cutter assembly 0.0 0.0 16:15 17:30 7/18/2016 7/18/2016 1.00 PROD1 CSGRCY ELNE X RIH with 5"chemical cutter,correlate 0.0 0.0 17:30 18:30 to cutting depth with CCL,and cut the 7"casing at 1632'ORKB. 7/18/2016 7/18/2016 1.25 PROD1 CSGRCY ELNE XT Attempt to release the anchor but 0.0 0.0 18:30 19:45 unable to go up or down. Pressure up on the well to 500 psi twice to get the anchor to release but still unable to get free. Fire the E-line jars several time but unsuccessful. Pressure up on the well to 2500 psi(maximum pressure due to the 80%burst of the 10-3/4"casing)but still unable to pull free. Continue to attempt to free the anchor using the E-line jars but were unable to go up or down. Decided part the E-line at the weak point of the rope socket. Page 9/23 Report Printed: 8/1/2016 i • • o 0;;' , Operations Summary (with Timelog Depths) 1H-06 r«,o Mips .fit:Y.If::S Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time ..End Time Our(hr) Phase Op Code Activity Code Time P-T X Operation (RKB) End Depth(RKB) 7/18/2016 7/18/2016 0.25 PROD1 CSGRCY ELNE XT POOH with the parted E-line. 0.0 0.0 19:45 20:00 7/18/2016 7/18/2016 1.00 PROD1 CSGRCY ELNE XT RD SLB E-line and RD the Dutch 0.0 0.0 20:00 21:00 riser. Note: Called Baker for 4-11/16" overshot and grapples to fish the E- line tool string. 7/18/2016 7/18/2016 0.50 PROD1 CSGRCY WAIT XT Wait for Baker fishing tools to arrive. 0.0 0.0 21:00 21:30 SimOps: Work on MP2's. 7/18/2016 7/18/2016 1.50 PROD1 CSGRCY WAIT XT Wait for Baker fishing tools to arrive. 0.0 0.0 21:30 23:00 SimOps: Slip and cut 52'of drilling line. Service the top drive and draw works 7/18/2016 7/18/2016 0.50 PROD1 CSGRCY RURD XT Bring fishing tool to the rig floor. 0.0 0.0 23:00 23:30 7/18/2016 7/19/2016 0.50 PROD1 CSGRCY BHAH XT PU and MU BHA#2-overshot 0.0 27.0 23:30 00:00 assembly for E-line chemical cutter tool string. 7/19/2016 7/19/2016 0.50 PROD1 CSGRCY TRIP XT TIH with BHA#2-overshot assembly 27.0 0.0 00:00 00:30 for E-line chemical cutter tool string. Could not get past 130'MD. TOOH. 7/19/2016 7/19/2016 0.25 PROD1 CSGRCY BHAH XT Lay down the bumper sub and 27.0 8.0 00:30 00:45 hydraulic oil jar. 7/19/2016 7/19/2016 0.75 PROD1 CSGRCY TRIP XT TIH with BHA#3-overshot assembly 8.0 1,429.0 00:45 01:30 (without bumper sub&hydraulic oil jar)for E-line chemical cutter tool string to 1421'RKB. 7/19/2016 7/19/2016 0.25 PROD1 CSGRCY PULD XT Continue to RIH with BHA#3 with DP 1,429.0 1,591.0 01:30 01:45 from the pipe shed from 1429'to top of fish at 1591'RKB(PU=65K and SO= 40K). 7/19/2016 7/19/2016 0.75 PROD1 CSGRCY FISH XT Engage E-line fish with 10K,PU 10K 1,591.0 1,595.0 01:45 02:30 over but the grapple slipped off,rotate at 15 RPM=4-5K ft-lbs torque,SO to 1595',stalled out at 10K torque. PU to 45K over,and fish began to drag up hole with 5-15K drag. 7/19/2016 7/19/2016 1.00 PROD1 CSGRCY TRIP XT TOOH with BHA#3. 1,595.0 0.0 02:30 03:30 7/19/2016 7/19/2016 0.25 PROD1 CSGRCY BHAH XT Lay down BHA#3. Change out the 0.0 8.0 03:30 03:45 grapple to 1-5/8"and PU BHA#4- overshot assembly with 1-5/8"grapple for E-line fish. 7/19/2016 7/19/2016 1.25 PROD1 CSGRCY TRIP XT TIH with BHA#4 to 1618'RKB and the 8.0 1,618.0 03:45 05:00 fish is no longer there. 7/19/2016 7/19/2016 1.25 PROD1 CSGRCY PULD XT Continue to RIH with BHA#4 with 4" 1,618.0 2,902.0 05:00 06:15 DP from the pipe shed from 1618'to 2902' 7/19/2016 7/19/2016 2.00 PROD1 CSGRCY TRIP XT POOH f/2902'U surface 2,902.0 0.0 06:15 08:15 7/19/2016 7/19/2016 0.50 PROD1 CSGRCY BHAH XT L/D BHA#4 and 12'of fish(backed off 0.0 0.0 08:15 08:45 at the top the jars. 7/19/2016 7/19/2016 0.25 PROD1 CSGRCY BHAH XT M/U Fishing BHA#5 w/1-5/8"grapple 0.0 8.0 08:45 09:00 and plain control. Page 10/23 Report Printed: 8/1/2016 • • Operations Summary (with Timelog Depths) 1 H-06 ConocoPhiiiliips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr)' Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth(itKD) 7/19/2016 7/19/2016 1.50 PROD1 CSGRCY TRIP XT TIH f/8'to 2910'set down 10k,PU 8.0 2,910.0 09:00 10:30 and seen 15K overpull as tools pulled out of sand 2,935-ft. 7/19/2016 7/19/2016 1.50 PROD1 CSGRCY TRIP XT POOH f/2910'to 8'Observe chemical 2,910.0 127.0 10:30 12:00 cutter powder leaking from tools,RIH t/127'Notify Eline reps. 7/19/2016 7/19/2016 0.50 PROD1 CSGRCY SFTY XT PJSM with crews on handling ELine 127.0 127.0 12:00 12:30 tools and chemicals and fumes from eline tools. • 7/19/2016 7/19/2016 1.00 PROD1 CSGRCY BHAH XT L/D BHA as per E-line rep and Baker 127.0 0.0 12:30 13:30 Fishing reps. Found that cutter had not fired do to the rupture disk malfunction-this caused pressure to remain behind slips not allowing them to release-which resulted in pulling out of the rope socket. then dragging up hole when fished on drill pipe until breaking the slip insert. 7/19/2016 7/19/2016 1.00 PROD1 CSGRCY BHAH XT Clear BHA from Floor and Bring new 0.0 8.0 13:30 14:30 BHA to floor M/U Multi String Cutter Assy. 7/19/2016 7/19/2016 1.00 PROD1 CSGRCY TRIP XT TIH f/8'to 1615' 8.0 1,615.0 14:30 15:30 7/19/2016 7/19/2016 0.75 PROD1 CSGRCY CPBO XT Break circulation Locate collar @ 1,615.0 1,636.0 15:30 16:15 1651'pull up and make cut with multi string cutter @ 1636'.Observe pressure increase and flow increase through the cutter. 7/19/2016 7/19/2016 1.00 PROD1 CSGRCY CIRC X Close annular and divert artic pack to 1,636.0 1,636.0 16:15 17:15 tiger tank,pump 24 bbls fluid to tiger tank.shut down. No flow at the tiger tank,open annular and observe fluid 28-ft RKB(OA valve).Slight gas breaking out,Well Static. 7/19/2016 7/19/2016 1.25 PROD1 CSGRCY TRIP X P/U 5-ft on cutter and pressure up to 1,636.0 0.0 17:15 18:30 250 psi while slacking off and confirm cut depth of 1636',Bleed off pressure and POOH f/1636'U surface. Inspect knives-markings 1-1/2"from cutter body indicating good cut. 7/19/2016 7/19/2016 0.75 PROD1 CSGRCY BHAH X Clear Floor C/O BHA to spear Assy. 0.0 8.0 18:30 19:15 7/19/2016 7/19/2016 0.25 PROD1 CSGRCY FISH X Engage casing stump verify casing 8.0 1,636.0 19:15 19:30 free @70kPUW 7/19/2016 7/19/2016 0.50 PROD1 CSGRCY SFTY X Pre Job Safety Meeting w/rig crews 1,636.0 1,636.0 19:30 20:00 and truck drivers on displacing artic pack to tiger tank 7/19/2016 7/19/2016 1.00 PROD1 CSGRCY DISP X Displace Well w/120 bbls diesel 1,636.0 1,636.0 20:00 21:00 7/19/2016 7/19/2016 1.00 PROD1 CSGRCY OTHR X Let diesel soak on artic pack for 1 hr 1,636.0 1,636.0 21:00 22:00 7/19/2016 7/19/2016 1.75 PROD1 CSGRCY DISP X Displace diesel w/Heated Water to 1,636.0 1,636.0 22:00 23:45 tiger tank followed by seawater 7/19/2016 7/20/2016 0.25 PROD1 CSGRCY OWFF X Observe Well for flow well static 1,636.0 1,636.0 23:45 00:00 7/20/2016 7/20/2016 0.25 PROD1 CSGRCY OWFF X Observe Well for flow well static 1,636.0 1,636.0 00:00 00:15 7/20/2016 7/20/2016 0.50 PROD1 CSGRCY RURD X Relesase 7"casing spear and lay 1,636.0 1,636.0 00:15 00:45 down same. Page 11/23 Report Printed: 8/1/2016 . • • � _ ,q.�� Operations Summary (with Timelog Depths) •Ig 014 1H-06 ConocoPhiiiips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB)` End Depth(ftKB) 7/20/2016 7/20/2016 2.50 PROD1 CSGRCY PULL X Lay down 7"fluted hanger,40 joints of 1,636.0 0.0 00:45 03:15 7"26#,K-55,BTC and 25.30-ft of jt# 41 7/20/2016 7/20/2016 0.50 PROD1 CSGRCY RURD X Clean and clear rig floor • 0.0 0.0 03:15 03:45 7/20/2016 7/20/2016 0.50 PROD1 CASING BHAH X Bring BHA Handling equipment to 0.0 0.0 03:45 04:15 floor. 7/20/2016 7/20/2016 1.25 PROD1 CASING BHAH X M/U Scraper dress off BHA RIH 0.0 36.0 04:15 05:30 7/20/2016 7/20/2016 0.75 PROD1 CASING TRIP X RIH F/36'to 1551' 36.0 1,551.0 05:30 06:15 7/20/2016 7/20/2016 1.00 PROD1 CASING REAM X Ream down from 1551'to top of 7" 1,551.0 1,640.0 06:15 07:15 casing stub @ 1636'dress off casing stub to 1636.5',work over stub clean with out issues. 7/20/2016 7/20/2016 0.75 PROD1 CASING CIRC X Circulate bottoms up @ 10 bpm 300 1,640.0 1,636.0 07:15 08:00 psi 7/20/2016 7/20/2016 1.00 PROD1 CASING TRIP X POOH f/1636'to 36' 1,636.0 36.0 08:00 09:00 7/20/2016 7/20/2016 1.25 PROD1 CASING BHAH X L/D BHA scraper and dress off assy. 36.0 0.0 09:00 10:15 cllean and clear floor of BHA equipment. 7/20/2016 7/20/2016 1.25 PROD1 CASING RURD X R/U to run 7"Casing,bring 0.0 0.0 10:15 11:30 centralizers to floor,R/U tongs 7/20/2016 7/20/2016 1.00 PROD1 CASING SVRG P Service rig and top drive 0.0 0.0 11:30 12:30 7/20/2016 7/20/2016 0.50 PROD1 CASING SFTY X Pre Job safety meeting on running 0.0 0.0 12:30 13:00 casing with all parties involved 7/20/2016 7/20/2016 2.00 PROD1 CASING PUTB X RIH w/7"26#HYD 563 casing w/ 0.0 1,638.0 13:00 15:00 patch and HES cementer f/surface•to 1621'Latch up patch on 7"Csaing Stub @ 1636'2'of swallow t/1638'set in tension 125k hook load 7/20/2016 7/20/2016 2.00 PROD1 CEMENT RURD X R/U cement head load plugs R/U 1,638.0 1,638.0 15:00 17:00 surface circulating equipment 7/20/2016 7/20/2016 1.75 PROD1 CEMENT RURD X Spot SLB cementers R/U to pump 1,638.0 1,638.0 17:00 18:45 Cement 7/20/2016 7/20/2016 0.50 PROD1 CEMENT SFTY X PJSM with all parties involved on 1,638.0 1,638.0 18:45 19:15 pumping cement 7/20/2016 7/20/2016 3.00 PROD1 CEMENT CMNT X Cement as per SLB,PT lines to 4000 1,638.0 1,638.0 19:15 22:15 psi,Test casing patch to 2500 psi f/30 min,Pressure up to 3300 psi to shear open HES cementer,Circulate bottoms up 70 bbls seawater,chase w/10 bbls H2O,Pump 87 bbls 15.7ppg Cement,Drop plug,chase w/ 3 bbls cement,Chase w/63.5 bbls seawater Bump plug close HES cementer 2200 psi,hold pressure f/5 min,Bleed off check for flow well static CIP @ 2215hrs 11 bbls cement returned to tiger tank. 7/20/2016 7/20/2016 0.75 PROD1 CEMENT RURD X Blow Down Lines R/D SLB cementers, 1,638.0 0.0 22:15 23:00 Flush Stack w/Black Water,clean cement valves. 7/20/2016 7/21/2016 1.00 PROD1 WELLPR NUND X N/D BOP stack and prep f/setting • 0.0 0.0 23:00 00:00 emergency slips. 7/21/2016 7/21/2016 0.75 PROD1 WELLPR CPBO X Set Emergency slips w/110k Hook 0.0 0.0 00:00 00:45 Load Page 12/23 Report Printed: 8/1/2016 �. • 0 "' ,-"? , Operations Summary (with Timelog Depths) 1H-06 ConotmPhitiips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth start Irma End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(MICE) 7/21/2016 7/21/2016 1.25 PROD1 WELLPR CPBO X Cut 7"Casing w/WACHS Cutter as 0.0 0.0 00:45 02:00 per Cameron Rep 7/21/2016 7/21/2016 0.50 PROD1 WELLPR NUND X Nipple Down Adaptor Flange 0.0 0.0 02:00 02:30 7/21/2016 7/21/2016 5.25 PROD1 WELLPR NUND X N/U C-Bowl Tubing head Test Breaks 0.0 0.0 02:30 07:45 250/4300 Leaking,Pull tubing head change out pack off seals and API Ring,N/U tubing Head and test t/ 250/4300 psi good test. 7/21/2016 7/21/2016 1.00 PROD1 WELLPR NUND X N/U BOP Stack 0.0 0.0 07:45 08:45 7/21/2016 7/21/2016 0.75 PROD1 WELLPR 'BOPE X Change out Bottom Rams to 3.5 x 6 0.0 0.0 08:45 09:30 VBR 7/21/2016 7/21/2016 0.50 PROD1 WELLPR BOPE X R/U t/test breaks and lower rams 0.0 0.0 09:30 10:00 7/21/2016 7/21/2016 2.00 PROD1 WELCTL BOPE X Test BOPE Breaks choke line and 0.0 0.0 10:00 12:00 bottom rams w/3.5"and 4"test jtoints to 250/3000 psi 7/21/2016 7/21/2016 0.75 PROD1 WELLPR RURD X Set Wear ring 6 3/8 0.0 0.0 12:00 12:45 7/21/2016 7/21/2016 1.50 PROD1 WELLPR BHAH X M/U clean Out BHA RIH t/218' 0.0 218.0 12:45 14:15 7/21/2016 7/21/2016 0.75 PROD1 WELLPR TRIP X RIH w/Clean Out BHA f/218'to 1608' 218.0 1,558.0 14:15 15:00 7/21/2016 7/21/2016 2.25 PROD1 WELLPR DRLG X Establish Parameters Wash Down f/ 1,558.0 1,728.0 15:00 17:15 1558'Tag Cement @ 1620'Drill Cement and Plug f/1620'to 1624' Clean Out to 1728' 7/21/2016 7/21/2016 0.75 PROD1 WELLPR PRTS X Test casing to 2500 psif/10 min good 1,728.0 1,728.0 17:15 18:00 test 7/21/2016 7/21/2016 1.00 PROD1 WELLPR TRIP X RIH f/1728't/2865' 1,728.0 2,865.0 18:00 19:00 7/21/2016 7/21/2016 0.75 PROD1 WELLPR 'REAM X Ream Down f/2865'to 2923' 2,865.0 2,923.0 19:00 19:45 7/21/2016 7/21/2016 0.75 PROD1 WELLPR CIRC X Circulate Bottoms up 200 gpm 600 psi 2,963.0 2,963.0 19:45 20:30 7/21/2016 7/21/2016 0.25 PROD1 WELLPR DRLG X Drill Hard Cement and Junk f/2963'to 2,963.0 2,938.0 20:30 20:45 2927'Broke through wash down t/ 2938' 7/21/2016 7/21/2016 0.75 PROD1 WELLPR CIRC X P/U t/2918'Increase pumps t/8 bpm 2,938.0 2,938.0 20:45 21:30 600 psi Mix and pump hi vis sweep around,Shut down pumps and rotary tag bottom @ 2938' 7/21/2016 7/21/2016 1.00 PROD1 WELLPR TRIP X •POOH f/2938'to 218' 2,938.0 218.0 21:30 22:30 7/21/2016 7/21/2016 0.50 PROD1 WELLPR BHAH X Stand Back and L/D BHA 2#of metal 218.0 0.0 22:30 23:00 debris and 2 chunks of aluminum recovered from boot baskets. 7/21/2016 7/22/2016 1.00 PROD1 WELLPR BHAH X Clean and Clear rig floor M/U Reverse 0.0 238.0 23:00 00:00 junk basket BHA U 238 7/22/2016 7/22/2016 1.00 PROD1 WELLPR TRIP X RIH f/238't/2794' 238.0 2,794.0 00:00 01:00 7/22/2016 7/22/2016 0.50 PROD1 WELLPR WASH X Establish Circulation 6 bpm 580 psi 2,794.0 2,889.0 01:00 01:30 Wash down f/2794'to 2889' 7/22/2016 7/22/2016 0.50 PROD1 WELLPR WASH X Drop Ball pump down 4 bpm 280 psi 2,889.0 2,938.0 01:30 02:00 observe pressure increase to 380 psi up pump rate to 8 bpm 1400 psi Continue washing town to topof sand @ 2938' Page 13/23 Report Printed: 8/1/2016 • I Operations Summary (with Timelog Depths)• 1H-06 CcxnocoPhitltps`p Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(ftKB) 7/22/2016 7/22/2016 2.75 PROD1 WELLPR REAM X Ream down through sand f/2938'to 2,938.0 2,940.0 02:00 04:45 2939'50 rpm hit junk ream to 2940' stopped drilling off work string with out rotary got hung up,pull 50k over to get free estaqblish rotation work back to bottom no head way 7/22/2016 7/22/2016 1.25 PROD1 WELLPR TRIP X POOH f/2940'to 283' 2,940.0 283.0 04:45 06:00 7/22/2016 7/22/2016 1.00 PROD1 WELLPR BHAH XT Stand Back and L/D BHA Missing 283.0 0.0 06:00 07:00 bottom 6"of Reverse junk basket (crown) 7/22/2016 7/22/2016 1.00 PROD1 WELLPR BHAH XT Clear Rig floor UD BHA Components 0.0 0.0 07:00 08:00 &P/U BHA components 7/22/2016 7/22/2016 0.75 PROD1 WELLPR BHAH XT M/U Fishing BHA#11 RIH t/234' 0.0 234.0 08:00 08:45 7/22/2016 7/22/2016 0.75 PROD1 WELLPR TRIP XT RIH w/Fishing BHA#11 f/234'to 234.0 2,885.0 08:45 09:30 2885' 7/22/2016 7/22/2016 0.25 PROD1 WELLPR FISH XT Slack Off f/2885't/2940'set down 2,885.0 2,940.0 09:30 09:45 20k P/U rotate half turn set down 40k, P/U rotate half turn set down 20k Rotate 5 turns observe torque P/U no over pull 7/22/2016 7/22/2016 1.50 PROD1 WELLPR TRIP XT POOH f/2940'to 234' 2,940.0 234.0 09:45 11:15 7/22/2016 7/22/2016 0.75 PROD1 WELLPR BHAH XT Stand abck and L/D BHA as per Baker 234.0 0.0 11:15 12:00 hand,No fish 7/22/2016 7/22/2016 0.75 PROD1 WELLPR BHAH XT M/U BHA#12 RIH t/212' 0.0 212.0 12:00 12:45 7/22/2016 7/22/2016 1.00 PROD1 WELLPR TRIP XT RIH f/212'to 2940' 212.0 2,940.0 12:45 13:45 7/22/2016 7/22/2016 0.25 PROD1 WELLPR FISH XT Dry tag fish setting down 5k P/U 2,940.0 2,940.0 13:45 14:00 engage rotary 30 rpm and pump 8 bpm 1800 psi set down 15k twice shut down rotary and pump set down 15k 7/22/2016 7/22/2016 1.00 PROD1 WELLPR TRIP XT POOH f/2940'to 212' 2,940.0 212.0 14:00 15:00 7/22/2016 7/22/2016 0.75 PROD1 WELLPR BHAH XT Stand Back and UD BHA no fish 212.0 0.0 15:00 15:45 discuss options w/town 7/22/2016 7/22/2016 0.50 PROD1 WELLPR BHAH XT M/U BHA 13 Taper Box Tap 0.0 208.0 15:45 16:15 7/22/2016 7/22/2016 1.00 PROD1 WELLPR TRIP XT RIH f/224't/2386' 208.0 2,386.0 16:15 17:15 7/22/2016 7/22/2016 0.50 PROD1 WELLPR SVRG P Service rig and top drive 2,386.0 2,386.0 17:15 17:45 7/22/2016 7/22/2016 0.25 PROD1 WELLPR TRIP XT Continue RIH f/2386't/2859' 2,386.0 2,859.0 17:45 18:00 7/22/2016 7/22/2016 0.50 PROD1 WELLPR FISH XT Establish Parameters wash down to 2,859.0 2,940.0 18:00 18:30 2940'set down twice 15k 15 rpm 1k tq no excess torque. 7/22/2016 7/22/2016 2.00 PROD1 WELLPR TRIP XT POOH f/2940't/208' 2,940.0 208.0 18:30 20:30 7/22/2016 7/22/2016 0.50 PROD1 WELLPR BHAH XT Stand Back and UD BHA components 208.0 0.0 20:30 21:00 no fish flat markings on taper tap face 7/22/2016 7/22/2016 0.50 PROD1 WELLPR BHAH XT M/U BHA#14 Packer Mill Assy. 0.0 0.0 21:00 21:30 Page 14/23 Report Printed: 8/1/2016 • . • Operations Summary (with Timelog Depths) 1H-06 CanocoPhi€lips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/22/2016 7/22/2016 1.00 PROD1 WELLPR TRIP XT RIH f/228'to 2879' 0.0 2,879.0 21:30 22:30 7/22/2016 7/23/2016 1.50 PROD1 WELLPR MILL XT Establish parameters 50 rpm 1k tq 8 2,879.0 2,942.0 22:30 00:00 bpm 1700 psi Wash down t/2940'mill t/2941.5' 7/23/2016 7/23/2016 1.50 PROD1 WELLPR TRIP XT POOH f/2942't/228' 2,942.0 228.0 00:00 01:30 7/23/2016 7/23/2016 1.00 PROD1 WELLPR BHAH XT Stand Back and L/D BHA#14 228.0 0.0 01:30 02:30 7/23/2016 7/23/2016 0.50 PROD1 WELLPR BHAH XT M/U BHA#15 Grapple RIH 0.0 212.0 02:30 03:00 7/23/2016 7/23/2016 0.75 PROD1 WELLPR TRIP XT RIH f/212'U 2863' 212.0 2,863.0 03:00 03:45 7/23/2016 7/23/2016 0.50 PROD1 WELLPR REAM XT Ream down f/2863'U 2940'set down 2,863.0 2,940.0 03:45 04:15 10k X3 Rotate 1/2 turn set down 10-12 K X2 7/23/2016 7/23/2016 1.00 PROD1 WELLPR TRIP XT POOH f/2940'to 212 2,940.0 212.0 04:15 05:15 7/23/2016 7/23/2016 1.00 PROD1 WELLPR BHAH XT Stand Back and L/D BHA Simops 212.0 0.0 05:15 06:15 Load shed w/HWDP 7/23/2016 7/23/2016 1.00 PROD1 WELLPR BHAH XT M/U BHA#16 Tapered Mill BHA RIH 0.0 586.0 06:15 07:15 HWDP f/Shed 7/23/2016 7/23/2016 0.75 PROD1 WELLPR TRIP XT RIH f/586'U 2859' 586.0 2,859.0 07:15 08:00 7/23/2016 7/23/2016 1.25 PROD1 WELLPR WASH XT Wash down f/2859'U 2940'Slack off 2,859.0 2,941.0 08:00 09:15 20k P/U Engage rotary set 5k down ream through fish stall out tq 8 k Set down friction bite fish 20k Pulled up bleed jars came free repeat process 7 times U 2941' 7/23/2016 7/23/2016 1.00 PROD1 WELLPR TRIP XT POOH f/2941'to 586' 2,941.0 586.0 09:15 10:15 7/23/2016 7/23/2016 0.75 PROD1 WELLPR BHAH XT Stand Back and L/D BHA#16 586.0 0.0 10:15 11:00 7/23/2016 7/23/2016 0.75 PROD1 WELLPR BHAH XT M/U BHA#17 Tapered Tap RIH 0.0 574.0 11:00 11:45 7/23/2016 7/23/2016 0.75 PROD1 WELLPR TRIP XT RIH f/574'U 2938' 574.0 2,938.0 11:45 12:30 7/23/2016 7/23/2016 1.00 PROD1 WELLPR REAM XT Ream down U fish 20 rpm stab into 2,938.0 2,941.0 12:30 13:30 fish w/4k down stall out @ 10 k tq, repeat 2 times,Pull 10k over pull fish appeared to move up hole 4'5k drag then came free 7/23/2016 7/23/2016 1.50 PROD1 WELLPR TRIP XT POOHf/2941'to 574' 2,941.0 574.0 13:30 15:00 7/23/2016 7/23/2016 0.50 PROD1 WELLPR BHAH XT Stand Back and L/D BHA No Fish 574.0 0.0 15:00 15:30 7/23/2016 7/23/2016 0.50 PROD1 WELLPR BHAH XT M/U BHA#18 Spear BHA 0.0 578.0 15:30 16:00 7/23/2016 7/23/2016 0.75 PROD1 WELLPR TRIP XT RIH f/578'to 2938' 578.0 2,398.0 16:00 16:45 7/23/2016 7/23/2016 0.25 PROD1 WELLPR FISH XT Establish Circ Slack off to top of fish 2,938.0 2,957.0 16:45 17:00 @ 2941'Break free chase fish U 2957' 7/23/2016 7/23/2016 1.00 PROD1 WELLPR TRIP XT POOH f/2957'U 578' 2,957.0 578.0 17:00 18:00 7/23/2016 7/23/2016 0.50 PROD1 WELLPR BHAH XT Stand Back and L/D BHA No Fish 578.0 0.0 18:00 18:30 Page 15/23 Report Printed: 8/1/2016 • 3a Operations Summary (with Timelog Depths) 1H-06 Con000t hiliips • Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftKB) 7/23/2016 7/23/2016 1.00 PROD1 WELLPR BHAH XT M/U BHA#19 Reverse Junk Basket 0.0 600.0 18:30 19:30 7/23/2016 7/23/2016 1.00 PROD1 WELLPR TRIP XT RIH f/600't/2889' 600.0 2,889.0 19:30 20:30 7/23/2016 7/23/2016 1.00 PROD1 WELLPR REAM XT Ream down w/pumps 7.5 bpm 1270 2,889.0 2,958.0 20:30 21:30 psi 40 rpm tag fish @ 2957'set light weight on fish wash t/2958' 7/23/2016 7/23/2016 0.50 PROD1 WELLPR CIRC XT Circulate Bottoms Up 7.5 bpm 1270 2,958.0 2,958.0 21:30 22:00 psi 7/23/2016 7/23/2016 1.00 PROD1 WELLPR TRIP XT POOH f/2958't/600' 2,958.0 600.0 22:00 23:00 7/23/2016 7/24/2016 1.00 PROD1 WELLPR BHAH XT Stand Back and L/D BHA chucks of 600.0 0.0 23:00 00:00 fish on magnets and in Junk Basket 1" by 1"4 chunks 7/24/2016 7/24/2016 0.50 PROD1 WELLPR BHAH XT PJSM on laying down Reverse 0.0 0.0 00:00 00:30 circulating junk basket as per Baker Fishing Rep 7/24/2016 7/24/2016 0.50 PROD1 WELLPR BHAH XT M/U 4.01"Grapple on spear and RIH 0.0 578.0 00:30 01:00 w/2-stds of 4-3/4 DC's and 4-stds of 4"HWDP 7/24/2016 7/24/2016 0.75 PROD1 WELLPR TRIP XT RIH from 578-ft to 2,945-ft. UP WT 578.0 2,945.0 01:00 01:45 80K,DN WT 80K 7/24/2016 7/24/2016 0.50 PROD1 WELLPR FISH XT P/U working single and break 2,945.0 2,966.0 01:45 02:15 circulation at 3 bpm at 280 psi. with 18%return flow. Slack off to 2,966-ft and set down 5k. P/U 15-ft and tag up at 2,958-ft stacked 10k dn. Pick back and slack off going past to 2,966-ft Set down 15K twice at same depth. 7/24/2016 7/24/2016 1.25 PROD1 WELLPR TRIP XT POOH from 2,966-ft to 578-ft 2,966.0 578.0 02:15 03:30 7/24/2016 7/24/2016 1.00 PROD1 WELLPR BHAH XT POOH and Lay down BHA#20- 578.0 0.0 03:30 04:30 Nothing recovered. 7/24/2016 7/24/2016 0.75 PROD1 WELLPR BHAH XT PU,MU and RIH w/ BHA#21 Fishing 0.0 594.0 04:30 05:15 magnet assembly to 594-ft 7/24/2016 7/24/2016 0.50 PROD1 WELLPR TRIP XT RIH w/BHA#21 from 594-ft to 2,899- 594.0 2,899.0 05:15 05:45 ft UP WT 80K, DN WT 80K 7/24/2016 7/24/2016 2.50 PROD1 WELLPR FISH XT Break circulation at 3 bpm at 140 psi 2,899.0 2,972.0 05:45 08:15 w/18%return flow. Shut down pump, slack off tagging up at 2,957-ft,set 5k down. Cycle charge pump,fell off immediately and regained string wt, SO to 2,969-ft. Cycle charge pump, fell off immediately and regained string wt,SO to 2,969-ft, Cycle charge pump,fell off immediately and regained string wt,SO to 2,972-ft and set down 15k.Cycle charge pump,fell off immediately and regained string wt, 7/24/2016 7/24/2016 1.25 PROD1 WELLPR TRIP XT POOH from 2,972-ft to 594-ft 2,972.0 594.0 08:15 09:30 7/24/2016 7/24/2016 0.25 PROD1 WELLPR BHAH XT POOH and Lay down BHA#21 - 594.0 0.0 09:30 09:45 Recovered misc material along with one piece 3.25"x 5". Offload tools from rig floor to allow room for slick line. 7/24/2016 7/24/2016 0.50 PROD1 WELLPR RURD XT Install Dutch riser and close annular 0.0 0.0 09:45 10:15 Page 16/23 Report Printed: 8/1/2016 41) 4 rat ,:h ,� � :moo Operations Summary (with Timelog Depths) r�r 1H-06 ConocoPhi lips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr)', Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKE), 7/24/2016 7/24/2016 1.75 PROD1 WELLPR SLKL XT PJSM,RU slick line. 0.0 0.0 10:15 12:00 7/24/2016 7/24/2016 1.50 PROD1 WELLPR SLKL XT MU 3"magnet,RIH to 2,959-ft SLM 0.0 0.0 12:00 13:30 and tagged up. POOH and recover' small amount of metal. 7/24/2016 7/24/2016 1.50 PROD1 WELLPR SLKL XT RIH w/3"x 5-ft Drive down bailer to 0.0 0.0 13:30 15:00 2,959-ft and drive down 2,960.5-ft Recovered 1/2 gallon of sand. Lay down bailer. 7/24/2016 7/24/2016 2.00 PROD1 WELLPR SLKL XT MU 3"Plunger bailer set down on 0.0 0.0 15:00 17:00 DSA,POOh and remove shoe,Cut mule shoe and MU to bailer RIH and set down on DSA. Drain stack Pull Dutch riser and visually guide bailer past DSA. Lower bailer past wellhead then lowered Dutch riser and install lock downs. RIH to 2,957-ft and stroke bailer seen over pull.POOH and dump bailer-recovered 7/24/2016 7/24/2016 2.50 PROD1 WELLPR SLKL XT MU 3"Fishing Magnet with bow spring 0.0 0.0 17:00 19:30 centralizer in string. RIH 2959'WLM POOH 2 small chunks of metal 1/4" size 7/24/2016 7/24/2016 1.50 PROD1 WELLPR SLKL XT M/Uum bailer and RIH t/2959' 0.0 0.0 p p 19:30 21:00 work bailer to 2961'WLM POOH No sand Recovered. 7/24/2016 7/24/2016 1.50 PROD1 WELLPR SLKL XT M/U 6"Magnet on slick line tools RIH 0.0 0.0 21:00 22:30 t/2958'POOH Recover no metal chunks just shavings. 7/24/2016 7/24/2016 1.00 PROD1 WELLPR SLKL XT M/U Pump Bailer RIH t/2959'set 0.0 0.0 22:30 23:30 down work tool no progress,POOH 1/2 gal of sand 7/24/2016 7/25/2016 0.50 PROD1 WELLPR SLKL XT R/D Slick Line 0.0 0.0 23:30 00:00 7/25/2016 7/25/2016 1.50 PROD1 WELLPR SLPC P PJSM,Slip and cut 59-ft of 1.25"Drill 00:00 01:30 line 7/25/2016 7/25/2016 0.50 PROD1 WELLPR SVRG P Service rig,Top drive and crown 01:30 02:00 7/25/2016 7/25/2016 1.00 PROD1 WELLPR BHAH XT PJSM,MU Reverse circulating junk 0.0 601.0 02:00 03:00 basket and RIH to 601-ft. 7/25/2016 7/25/2016 0.75 PROD1 WELLPR TRIP XT RIH f/601't/2905' 601.0 2,905.0 03:00 03:45 7/25/2016 7/25/2016 0.75 PROD1 WELLPR WASH XT Wash Down f/2905'to 2969'Work 2,905.0 2,969.0 03:45 04:30 RCJB to bottom stack weight ramp up pumps t/9 bpm 1600 psi wash down 3'P/U over pull observed,Repeat process 5 times until no overpull observed. 7/25/2016 7/25/2016 0.50 PROD1 WELLPR CIRC XT Circulate bottoms up @ 9 bpm 1600 2,969.0 0.0 04:30 05:00 psi shut down pumps dry tag fill @ 2972' 7/25/2016 7/25/2016 0.75 PROD1 WELLPR TRIP XT POOH f/2972'U 600' 0.0 600.0 05:00 05:45 7/25/2016 7/25/2016 0.50 PROD1 WELLPR BHAH XT Stand Back and L/D BHA RCJB 600.0 0.0 05:45 06:15 7/25/2016 7/25/2016 0.50 PROD1 WELLPR BHAH XT M/U BHA#23 Magnet RIH U 594' 0.0 594.0 06:15 06:45 7/25/2016 7/25/2016 0.75 PROD1 WELLPR TRIP XT RIH f/594'U 2899' 594.0 2,899.0 06:45 07:30 Page 17/23 Report Printed: 8/1/2016 • • )p ' Operations Summary (with TimelogDepths) gifn .�'. - 1H-06 ConocoPhifps Rig: DOYON 141 Job: RECOMPLETION Time Log ' Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ft03) End Depth(ftKD), 7/25/2016 7/25/2016 0.25 PROD1 WELLPR WASH XT Slack of f/2899'U 2970'Turn on 2,899.0 2,972.0 07:30 07:45 charge pump wash U 2972' 7/25/2016 7/25/2016 2.50 PROD1 WELLPR TRIP XT POOH f/2972'U 594' 2,972.0 594.0 07:45 10:15 7/25/2016 7/25/2016 0.25 PROD1 WELLPR BHAH XT Stand back HWDP and Collars Bring 594.0 0.0 10:15 10:30 BHA to floor Clean large chucks of metal from magnet. 7/25/2016 7/25/2016 0.25 PROD1 WELLPR BHAH XT Re run same BHA t 594' 0.0 594.0 10:30 10:45 7/25/2016 7/25/2016 0.50 PROD1 WELLPR TRIP XT RIH f/594'U 2899' 594.0 2,899.0 10:45 11:15 7/25/2016 7/25/2016 0.50 PROD1 WELLPR WASH XT Slack off f/2899'tag top of sand @ 2,899.0 2,974.0 11:15 11:45 2970'turn charge pumps on and wash U 2974' 7/25/2016 7/25/2016 2.25 PROD1 WELLPR TRIP XT POOH f/2974'U 594' 2,974.0 594.0 11:45 14:00 7/25/2016 7/25/2016 1.00 PROD1 WELLPR BHAH XT Stand back and L/D BHA large chunk 594.0 0.0 14:00 15:00 of medal and smaller chunks recovered 7/25/2016 7/25/2016 0.50 PROD1 WELLPR SVRG P Service rig and top drive 0.0 0.0 15:00 15:30 7/25/2016 7/25/2016 1.00 PROD1 WELLPR BHAH XT M/U BHA#25 RCJB RIH U 600' 0.0 600.0 15:30 16:30 7/25/2016 7/25/2016 1.00 PROD1 WELLPR TRIP XT RIH f/600'U 2905' • 600.0 2,905.0 16:30 17:30 7/25/2016 7/25/2016 0.50 PROD1 WELLPR WASH XT Wash down f/2905'U top of sand 2,905.0 2,978.0 17:30 18:00 2970'wash down U 2978'pumps 8 bpm 1350 psi 7/25/2016 7/25/2016 1.00 PROD1 WELLPR TRIP XT POOH f/2978'U 600' 2,978.0 600.0 18:00 19:00 7/25/2016 7/25/2016 0.50 PROD1 WELLPR BHAH XT Stand Back and L/D BHA Nothing in 600.0 0.0 19:00 19:30 reverse basket 7/25/2016 7/25/2016 0.50 PROD1 WELLPR BHAH XT M/U BHA#26 Plug retrieval tool U 0.0 569.0 19:30 20:00 569' 7/25/2016 7/25/2016 1.00 PROD1 WELLPR TRIP XT RIH f/569'U 2937' 569.0 2,937.0 20:00 21:00 7/25/2016 7/25/2016 1.00 PROD1 WELLPR FISH XT Wash down to top of Fish and engage 2,937.0 2,997.0 21:00 22:00 fish @ 2993' P/U release IBP Drop dart to open Pump out sub Slack off 4' past set depth U 2997' 7/25/2016 7/25/2016 1.00 PROD1 WELLPR CIRC XT Pump Hi Vis snot pill Losses 60 bph 2,997.0 2,997.0 22:00 23:00 spot snot pill out side pipe. 7/25/2016 7/26/2016 1.00 PROD1 WELLPR TRIP XT POOH f/2997'U 1800' 2,997.0 1,800.0 23:00 00:00 7/26/2016 7/26/2016 0.50 PROD1 WELLPR TRIP X POOH V 1800'U 569' 1,800.0 569.0 00:00 00:30 7/26/2016 7/26/2016 1.00 PROD1 WELLPR BHAH X L/D BHA and Plug 569.0 0.0 00:30 01:30 7/26/2016 7/26/2016 0.75 PROD1 WELLPR BHAH X Clean and Clear Rig Floor 0.0 0.0 01:30 02:15 7/26/2016 7/26/2016 1.00 COMPZN RPCOMP BHAH P M/U Rattler BHA RIH U 249' 0.0 249.0 02:15 03:15 7/26/2016 7/26/2016 3.00 COMPZN RPCOMP TRIP P RIH f/249'U 5610'P/U singles f/3088' 249.0 5,610.0 03:15 06:15 to 5610' Page 18/23 Report Printed: 8/1/2016 Operations Summary (with Timelog Depths) � ,. 1 H-06 ConocoPhillips pt Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/26/2016 7/26/2016 2.50 COMPZN RPCOMP FISH P Establish Parameters Ream down f/ 5,610.0 5,681.0 06:15 08:45 5610'U 5672'Top of fish,Dress off stub,work grapple over fish swallow U 5681',Pump 2 bpm P/U fire jars @ 45k over pull,rattler started working, rattle f/25k to 40k over pull f/1 hr, Stop rattling cock jars,over pull 45k fire jars,cock jars and fire again w/ 50k over pull,fish came free dragging 5-10k over Puw 125k-130k 7/26/2016 7/26/2016 1.00 COMPZN RPCOMP CIRC P L/D 2 Singles,U 5621 Circulate 5,681.0 5,621.0 08:45 09:45 bottoms up @ 2 bpm 1200-1600 psi 7/26/2016 7/26/2016 0.25 COMPZN RPCOMP OWFF P Observe Well for Flow Well Static 5,621.0 5,621.0 09:45 10:00 7/26/2016 7/26/2016 2.50 COMPZN RPCOMP TRIP P POOH f/5621'U 247' 5,621.0 247.0 10:00 12:30 7/26/2016 7/26/2016 0.50 COMPZN RPCOMP BHAH P L/D Fishing BHA R/U Simops,Power 247.0 0.0 12:30 13:00 tongs 7/26/2016 7/26/2016 1.00 COMPZN RPCOMP PULL P L/D Fish 14 jts 3.5"tubing,2 GLM's 0.0 0.0 13:00 14:00 Tubing patch,Seal Assy.and Cut Joint. 7/26/2016 7/26/2016 1.50 COMPZN RPCOMP RURD P R/D Tubing Equipment,clear floor of 0.0 0.0 14:00 15:30 tools and equpiment. 7/26/2016 7/26/2016 1.00 PROD1 WELLPR BHAH P M/U BHA Clean Out Run#28 U 255' 0.0 255.0 15:30 16:30 7/26/2016 7/26/2016 2.00 PROD1 WELLPR TRIP P RIH f/255'U 6120' P/U 21 jts of DP 255.0 6,210.0 16:30 18:30 from Shed. 7/26/2016 7/26/2016 1.50 PROD1 WELLPR CIRC P Wash down observe pressure 6,210.0 6,220.0 18:30 20:00 increase seals in PBR Top of PBR @ 6206'Stinger @ 2620'P/U 1' Circulate bottoms up @ 10 bpm pump Hi Vis Sweep 7/26/2016 7/26/2016 1.00 PROD1 WELLPR PRTS P Stab Seals to No Go test Casing to 6,220.0 0.0 20:00 21:00 2500 psi Test Failed,Unable to get to desired Pressure 1100 psi injection rate @ 1.5 bpm Test Surface Equipment test good. 7/26/2016 7/26/2016 2.00 PROD1 WELLPR TRIP X POOH f/6224'U 255' 6,224.0 255.0 21:00 23:00 7/26/2016 7/27/2016 1.00 PROD1 WELLPR BHAH X L/D BHA 255.0 0.0 23:00 00:00 7/27/2016 7/27/2016 1.00 PROD1 WELLPR BHAH X L/D BHA#28 Clean Out Assy.Clear 0.0 0.0 00:00 01:00 Floor 7/27/2016 7/27/2016 0.50 PROD1 WELLPR BHAH X M/U test Packer BHA RIH U 201' 0.0 201.0 01:00 01:30 • 7/27/2016 7/27/2016 0.50 PROD1 WELLPR TRIP X RIH f/201'to 1143' 201.0 1,143.0 01:30 02:00 7/27/2016 7/27/2016 0.25 PROD1 WELLPR PRTS X Test casing U 2500 psi f/5 min Test 1,143.0 1,143.0 02:00 02:15 good. 7/27/2016 7/27/2016 1.00 PROD1 WELLPR TRIP X RIH f/1143'U 3504' 1,143.0 3,504.0 02:15 03:15 7/27/2016 7/27/2016 2.00 PROD1 WELLPR PRTS X Test Csaing @ 3504'Test failed,P/U 3,504.0 2,945.0 03:15 05:15 U 3031'Test Failed,P/U U 2935'test passed U 2500 psi f/10 min,Slack off U 2961'Test failed,P/U U 2953'test failed, P/U U 2945'Test failed 7/27/2016 7/27/2016 0.75 PROD1 WELLPR TRIP X POOH f/2945'U 201' 2,945.0 201.0 05:15 06:00 Page 19/23 Report Printed: 8/1/2016 • = 3 Operations Summary (with Timelog Depths) t kcy�Y 1H-06 Corso iflips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Ttme End Time Dur(hr) Phase Op Cede Activity CodeTime P-T-X Operation (ftKB) End Depth MKS)' 7/27/2016 7/27/2016 0.25 PROD1 WELLPR OWFF X Observe Well f/flow 201.0 201.0 06:00 06:15 7/27/2016 7/27/2016 0.50 PROD1 WELLPR BHAH X L/D BHA and Blow down Lines 201.0 0.0 06:15 06:45 7/27/2016 7/27/2016 0.50 PROD1 WELLPR SVRG X Service Rig and Top Drive 0.0 0.0 06:45 07:15 7/27/2016 7/27/2016 1.00 PROD1 WELLPR BHAH X M/U BHA as per Baker G-Lock Plug 0.0 204.0 07:15 08:15 RIH t 204' 7/27/2016 7/27/2016 2.50 PROD1 WELLPR TRIP X RIH f/204'U 6184' 204.0 6,184.0 08:15 10:45 7/27/2016 7/27/2016 0.25 PROD1 WELLPR MPSP X Set G-Lock Plug as per baker plug 6,184.0 6,184.0 10:45 11:00 7/27/2016 7/27/2016 0.50 PROD1 WELLPR OWFF X Observe well for flow well static 6,184.0 6,184.0 11:00 11:30 7/27/2016 7/27/2016 2.00 PROD1 WELLPR TRIP X POOH f/6184'U 204' 6,184.0 204.0 11:30 13:30 7/27/2016 7/27/2016 0.50 PROD1 WELLPR BHAH X L/D BHA running tool 204.0 0.0 13:30 14:00 7/27/2016 7/27/2016 1.00 PROD1 WELLPR BHAH X M/U test Packer and retrieval tool 0.0 212.0 14:00 15:00 7/27/2016 7/27/2016 1.00 PROD1 WELLPR TRIP X RIH f/212't/2956' 212.0 2,956.0 15:00 16:00 7/27/2016 7/27/2016 1.50 PROD1 WELLPR PRTS X Set te4st packer and test casing U 2,956.0 2,956.0 16:00 17:30 2500 psi f/10 min,bleed off,release packer blow down lines 7/27/2016 7/27/2016 1.50 PROD1 WELLPR TRIP X RIH f/2956'U 6171' 2,956.0 6,171.0 17:30 19:00 7/27/2016 7/27/2016 0.50 PROD1 WELLPR MPSP X Pull G-Plug as per Baker Rep. 6,171.0 6,177.0 19:00 19:30 7/27/2016 7/27/2016 1.50 PROD1 WELLPR CIRC X Circulate bottoms up 3 bpm 140 psi 6,177.0 6,177.0 19:30 21:00 7/27/2016 7/27/2016 2.00 PROD1 WELLPR TRIP X POOH f/6173'U 212' 6,177.0 212.0 21:00 23:00 7/27/2016 7/27/2016 0.50 PROD1 WELLPR BHAH X L/D BHA as per baker Rep 212.0 0.0 23:00 23:30 7/27/2016 7/28/2016 0.50 PROD1 WELLPR ELNE X R/U Eline,Spot Unit bring tools to floor 0.0 0.0 23:30 00:00 7/28/2016 7/28/2016 2.00 PROD1 WELLPR ELNE X R/U ELine Equipment 0.0 0.0 00:00 02:00 • 7/28/2016 7/28/2016 3.25 PROD1 WELLPR ELNE X RIH w/40 Arm Caliper Log 3500' 0.0 0.0 02:00 05:15 Locate Leak @ 2938'WLM 7/28/2016 7/28/2016 0.50 PROD1 WELLPR ELNE X R/D ELine Equipment 0.0 0.0 05:15 05:45 7/28/2016 7/28/2016 0.50 PROD1 WELLPR RURD X R/D Dutch Riser 0.0 0.0 05:45 06:15 7/28/2016 7/28/2016 0.50 PROD1 WELLPR RURD X Flush Stack&Ram Cavities 0.0 0.0 06:15 06:45 7/28/2016 7/28/2016 2.25 PROD1 WELLPR SEQP XT Pull Wear Bushing,Unable to pull 0.0 0.0 06:45 09:00 wear Bushing due to Metal Debris blocking J slot. 7/28/2016 7/28/2016 1.00 PROD1 WELLPR BHAH XT M/U 6"Fishing magnet,String magnet 0.0 45.0 09:00 10:00 and Boot Baskets. 7/28/2016 7/28/2016 0.25 PROD1 WELLPR FISH XT Work down past wear ring 45.0 45.0 10:00 10:15 7/28/2016 7/28/2016 0.25 PROD1 WELLPR BHAH XT POOH UD Fishing BHA 45.0 0.0 10:15 10:30 7/28/2016 7/28/2016 0.75 PROD1 WELLPR SEQP X Pull wear ring,rotating handling ring 0.0 0.0 10:30 11:15 and pulling 10k over Page 20/23 Report Printed: 8/1/2016 Y • 0 - s.. Operations Summary (with Timelog Depths) N_s, 1H-06 at Conocont tlips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth StartTame End Time 0(2'00 Phase Op Code Activity CodeTime P-T-X Operation (5KB) End depth(ItKB) 7/28/2016 7/28/2016 1.25 PROD1 WHDBOP RURD P R/U t/test BOPE 0.0 0.0 11:15 12:30 7/28/2016 7/28/2016 5.50 PROD1 WHDBOP BOPE P Test BOPE w/3.5"and 4"test Jts,test 0.0 0.0 12:30 18:00 choke vales 1-14 Auto and Man!BOP, HCR and Man Choke and Kill,TIW& Dart,4"Demco kill line,Upper Lower and Blind Rams,test annular all tests t/250/3000 psi Accumulator Test,Test Witness waived by state Inspector. Bob Noble 7/28/2016 7/28/2016 0.50 PROD1 WHDBOP RURD P R/D Test Equipment 0.0 0.0 18:00 18:30 7/28/2016 7/28/2016 0.50 PROD1 WELLPR SEQP XT Install New Wear Ring 0.0 0.0 18:30 19:00 7/28/2016 7/28/2016 1.00 PROD1 WELLPR BHAH XT M/U Clean Out BHA RIH t/249' 0.0 249.0 19:00 20:00 7/28/2016 7/28/2016 1.50 PROD1 WELLPR TRIP XT RIH f/249't/6145' 249.0 6,145.0 20:00 21:30 7/28/2016 7/28/2016 2.00 PROD1 WELLPR CIRC XT Establish circ. 10 bpm 1040 psi Wash 6,145.0 6,214.0 21:30 23:30 into pbr @ 6206'four times,Circulate Hi Vis Sweep around,shut down confirm PBR entry pumps two times with out pumps 7/28/2016 7/29/2016 0.50 PROD1 WELLPR SLPC P Slip and Cut Drilling line 9 wraps 6,214.0 6,154.0 23:30 00:00 7/29/2016 7/29/2016 0.50 PROD1 WELLPR SLPC P Slip and Cut Drilling line 6,154.0 6,154.0 00:00 00:30 7/29/2016 7/29/2016 0.50 PROD1 WELLPR SVRG P Service Top Drive and Draworks 6,154.0 6,154.0 00:30 01:00 7/29/2016 7/29/2016 3.25 PROD1 WELLPR TRIP X POOH f/6113't/249' 6,154.0 249.0 01:00 04:15 7/29/2016 7/29/2016 0.50 PROD1 WELLPR OWFF X Observe well for flow well static 249.0 249.0 04:15 04:45 7/29/2016 7/29/2016 0.75 PROD1 WELLPR BHAH X L/D BHA as per Baker rep clear floor 249.0 0.0 04:45 05:30 of BHA equipment. 7/29/2016 7/29/2016 1.75 COMPZN RPCOMP RURD P R/U t/run lower completion as per 0.0 0.0 05:30 07:15 detail 7/29/2016 7/29/2016 3.75 COMPZN RPCOMP PULD P RIH w/Completion f/surface t/159' 0.0 6,208.0 07:15 11:00 crossover t/4"DP RIH t/6208'Locate out on PBR. 7/29/2016 7/29/2016 1.00 COMPZN RPCOMP CIRC P Spot 15 bbls CI Brine Around Seals 6,208.0 6,208.0 11:00 12:00 sting into PBR. 7/29/2016 7/29/2016 1.50 COMPZN RPCOMP PACK P Set baker FHL Packer as per Baker 6,208.0 6,050.0 12:00 13:30 Rep,Shear off Packer w/30k over pull top of packer 6080' P/U and set test packer Test packer top t/2500 psi f/ 30 min.Good test 7/29/2016 7/29/2016 2.00 COMPZN RPCOMP PULD P L/D DP f/6050't/3187' 6,050.0 3,187.0 13:30 15:30 7/29/2016 7/29/2016 1.00 COMPZN RPCOMP TRIP P POOH f/3187't/159' 3,187.0 159.0 15:30 16:30 7/29/2016 7/29/2016 1.00 COMPZN RPCOMP BHAH P L/D BHA 159.0 0.0 16:30 17:30 7/29/2016 7/29/2016 0.50 COMPZN RPCOMP BHAH P M/U BHA Large OD String Mill 6.213 0.0 239.0 17:30 18:00 7/29/2016 7/29/2016 1.00 COMPZN RPCOMP TRIP P RIH f/239't/1615' 239.0 1,615.0 18:00 19:00 Page 21/23 Report Printed: 8/1/2016 • S ` rApip Operations Summary (with Timelog Depths) 1H-06 C.onocoPhiii ps Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Cede Activity Code Time P-T-X Operation (ftKB) Erb Depth(ftKB) 7/29/2016 7/29/2016 2.00 COMPZN RPCOMP REAM P Dress off f/1621'to 1625'Through 1,615.0 1,625.0 19:00 21:00 HES cementer,40 rpm 8 bpm 310 psi until clean. 7/29/2016 7/29/2016 1.00 COMPZN RPCOMP TRIP P RIH f/1625'U 2795' 1,625.0 2,795.0 21:00 22:00 7/29/2016 7/30/2016 2.00 COMPZN RPCOMP REAM P Ream f/2866'U 3010'60 rpm 8 bpm 2,795.0 3,010.0 22:00 00:00 Work area uintil clean no issues observed,Pump Hi vis sweep around 10 bpm 630 psi 7/30/2016 7/30/2016 2.75 COMPZN RPCOMP TRIP P POOH f/3010'U 240' 3,010.0 240.0 00:00 02:45 7/30/2016 7/30/2016 1.75 COMPZN RPCOMP BHAH P Clean magnets L/D BHA as per Baker 240.0 0.0 02:45 04:30 Rep.Clear floor of BHA components 7/30/2016 7/30/2016 4.50 COMPZN RPCOMP RURD P R/U for Metal skin casing patch BHA 0.0 0.0 04:30 09:00 and components,strap and prep 7/30/2016 7/30/2016 5.00 COMPZN RPCOMP BHAH P M/U Weatherford metal skin casing 0.0 159.0 09:00 14:00 patch, M/U inner string and L/D,M/U Outer Patch Assy.and torque turn, P/U Inner String and RIH U 40',M/U Hydraulic setting tool RIH U 159' 7/30/2016 7/30/2016 2.00 COMPZN RPCOMP TRIP P RIH w/Casing patch f/159'U 2938' 159.0 2,938.0 14:00 16:00 7/30/2016 7/30/2016 1.50 COMPZN RPCOMP OTHR P P/U single,spot casing patch on depth 2,938.0 2,904.0 16:00 17:30 and set patch as per WTF rep.f/2920' to 2959'w/over pull of 60-170k, release hydraulic running tool,drop bar to shear drain sub. 7/30/2016 7/30/2016 1.00 COMPZN RPCOMP PRTS P Test casing to 2500 psi f/15 min good 2,904.0 2,904.0 17:30 18:30 test,blow down lines,R/D • 7/30/2016 7/30/2016 2.00 COMPZN RPCOMP TRIP P POOH f/2904'U 159' 2,904.0 159.0 18:30 20:30 7/30/2016 7/30/2016 2.00 COMPZN RPCOMP BHAH P 'L/D BHA as per Weatherford Rep UD 159.0 0.0 20:30 22:30 and clear floor 7/30/2016 7/30/2016 0.50 COMPZN RPCOMP SEQP P Remove wear ring 0.0 0.0 22:30 23:00 7/30/2016 7/31/2016 1.00 COMPZN RPCOMP RURD P R/U U run upper completion,R/U GBR 0.0 0.0 23:00 00:00 7/31/2016 7/31/2016 9.25 COMPZN RPCOMP RCST P RIH w/3.5"Upper completion as per 0.0 6,082.0 00:00 09:15 detail U 6082' 7/31/2016 7/31/2016 0.50 COMPZN RPCOMP RCST P Pump down tubing 1 bpm 60 psi 6,082.0 6,108.0 09:15 09:45 locate liner top @ 6086'slack off to no go @ 6108' 7/31/2016 7/31/2016 1.25 COMPZN RPCOMP RCST P L/D 3 jts make up space out pups,and 6,050.0 6,050.0 09:45 11:00 1 jt,hanger w/pup,M/U landing jt to hanger. 7/31/2016 7/31/2016 0.50 COMPZN RPCOMP RCST P Drain Stack Land tubing on hanger@ 6,050.0 6,076.0 11:00 11:30 6102',P/U and check hanger seals 7/31/2016 7/31/2016 1.00 COMPZN RPCOMP CIRC P Break circulation pump CI Brine 5 bpm 6,076.0 6,076.0 11:30 12:30 480 psi 197 bbls total pumped,chase w/30 bbls clean seawater. 7/31/2016 7/31/2016 1.00 COMPZN RPCOMP HOSO P Drain stack Land on Hanger @ 6102' 6,076.0 6,102.0 12:30 13:30 RILDS 7/31/2016 7/31/2016 1.50 COMPZN RPCOMP PRTS P Pressure up on tubing to 3000 psi f/ 6,102.0 6,102.0 13:30 15:00 15 min,bleed tubing U 1800 psi shut in,pressure up on IA U 2500 psi f/30 min,Shear SOV @ 2400 psi pump 1 bpm 130 psi through SOV Page 22/23 Report Printed: 8/1/2016 • • Operations Summary (with Timelog Depths) tif 111`1' 1H-06 CxxxxoPhillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity CodeTime P-T-X Operation (ftKB) End Depth(ftKB) 7/31/2016 7/31/2016 0.50 COMPZN RPCOMP OWFF P Observe well for flow well static. 6,102.0 6,102.0 15:00 15:30 7/31/2016 7/31/2016 0.50 COMPZN RPCOMP SEQP P Set BPV test in direction of flow t/ 6,102.0 6,102.0 15:30 16:00 1000 psi f/10 min 7/31/2016 7/31/2016 1.00 COMPZN RPCOMP GLEN P Drain and blow down surface lines 0.0 0.0 16:00 17:00 Suck out stack and clean drip pan. 7/31/2016 7/31/2016 1.00 COMPZN WHDBOP NUND P N/D BOP stack 0.0 0.0 17:00 18:00 7/31/2016 7/31/2016 3.00 COMPZN WHDBOP NUND P N/U adaptor flange and tree,test tree 0.0 0.0 18:00 21:00 and void to 5000 psi 7/31/2016 7/31/2016 0.75 COMPZN WHDBOP SEQP P R/U test equipment, Pull BPV as per 0.0 0.0 21:00 21:45 Cameron rep. 7/31/2016 7/31/2016 0.50 COMPZN WELLPR RURD P R/U to freeze protect well 0.0 0.0 21:45 22:15 7/31/2016 8/1/2016 1.75 COMPZN WELLPR FRZP P Freeze protect well w/75 bbls diesel, 0.0 0.0 22:15 00:00 as per LRS, Put tubing into communication with IA Allow to utube Rig Released @ 2359 Hrs • • Page 23/23 Report Printed: 8/1/2016 A; KUPOD 1H-06 Con©coPhilips Well Attrib Max Angle MD TD Alaska IN:, Wellbore APVUWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) hhps 500292074100 KUPARUK RIVER UNIT PROD 8.85 3,500.00 6,964.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date 1H-06,8/30/2016 7 15 11 AM SSSV:NONE 75 11/5/2014 Last WO: 8/1/2016 29.50 6/3/1982 Vertical schematic(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,240 7iSt��all Last Tag:SLM 6,634.0 4/22/2015 Rev Reason:REMOVED WAIVERED pproven 8/18/2016 Casing Strings ._, 4F. ait5r..Casing Description _OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 30.0 80.0 80.0 65.00 H-40 WELDED '''' ''''.....Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread I. SURFACE 10 3/4 9.950 28.5 2,194.0 2,193.7 45.50 K-55 BTC Casing Description SOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR;30,080.0 7 6.276 24.4 1,636.0 1,635.9 26.00 L-80 TSH 563 WORKOVER 2016 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 1,635.9 6,900.0 6,878.0 26.00 K-55 BTC Tubing Strings PRODUCTION WORKOVER Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection zots;2a.a1,636.o RWO2016UPPER 31/2 2.992 24.0 6,102.0 6,060.4 9.30E-80 EUE Brd Mod COMPLETION l • Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) SURFACE;28.5-2,194.0 24.0 24.0 0.20 HANGER Hanger,Cameron,CXS,7-1/16"x 3-1/2"EUE 8rd Box x 2.992 Box,3"H BPVG GAS LIFT,2,519.3 j: :" 6,079.3 6,057.7 2.18 LOCATOR Locator Sub,Baker,GBH-22(bottom of locator spaced 2.992 out 6.09') 6,080.3• 6,058.7 2.18 SEAL ASSY Seal Assembly,Baker,80-40(total seal area length= 2.992 Patch;2,919.0 [ 11.94) Tubing Description String Ma...ID(in) Top(ftKB) 'Set Depth(k..{Set Depth(ND)(...Wt(1b/ft) Grade Top Connection GAS LIFT;3,727.9IP- RWSTA216 20 D PACKER I 3 1/21 2.9921 6,086.5 6,220.81 6,199.1 9.301 L-80 I EUE 8rd Mod Completion Details Nominal ID GAS LIFT;4,651.9 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Cam (in) Irt 6,086.5 6,064.8 2.16 PBR 20'PBR,Baker,80-40 2.980 6,109.6 6,087.9 2.11 PACKER Packer,Baker,4762 FHL(60K shear release) 2.990 GAS LIFT;5,293.8 6,162.9 6,141.2 2.01 NIPPLE Nipple,Camco,2.813"DS,SN:3651-20(RHC plug body 2.813 installed) 6,209.9 6,188.2 1.92 LOCATOR Original Locator Sub,Brown Oil Tools(bottom of locator 2.992 spaced out 1') GAS LIFT;5,740.0 r 6,211.2 6,189.5 1.91 SEAL ASSY Original Seal Assembly,Brown Oil Tools OA Length 9.60' 2.992 Tubing Description String Ma...ID)in) Top(ftKB) SeIDepth(5 5et Depth(ND)(...Wt(Ib8t) Grade Top Connection GAS LIFT;6,023.1id-( LOWER TUBING 41/2 2.867 6,210.0 6,565.8 6,543.9 9.20 J-55 BTC AB-MOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Corn (in) 6,210.0 6,188.3 1.92 PBR BAKER G PBR 2.937 LOCATOR;8,078.3 6,225.5 6,203.7 1.89 PACKER BAKER HB-1 HYD PACKER 2.890 SEAL ASSY;6,080.3iimE 6,374.6 6,352.8 1.88 BLAST CARBIDE BLAST RINGS 2.867 PBR;6,086.4 RINGS PACKER;0.109.6 6,459.7 6,437.9 1.83 PACKER BAKER HB-1 HYDSET PACKER 2.867 6,474.3 6,452.4 1.81 BLAST CARBIDE BLAST RINGS 2.867 RINGS • • NIPPLE;6,162.9 6,545.1 6,523.2 1.59 NIPPLE AVA BPL PORTED NIPPLE 2.750 II 6,552.1 6,530.2 1.57 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 ila 6,553.6 6,531.7 1.56 PACKER BAKER'18'PERMANENT PACKER w/SBE XO TO 2 3.250 LOCATOR;6,209.9` II 7/8" SEAL ASSY;6,211.2 ,' _ PBR;6,210.0 ) Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) C-_ Top(ND) TopInc! PACKER;8,225.5 nc Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) PRODUCTION;6,263.3 `; 2,919.0 2,916.6 6.57 Patch WFT MetalSkin Patch-Across partial accidental 7/26/2016 5.488 casing cut PRODUCTION;6,334.5 6,545.1 6,523.2 1.59 SLEEVE-C AVA 2.75"BPI 3/31/2003 2.320 I 6,650.0 6,628.1 1.37 FISH NIPPLE/SOS/TBG/STANDING VLV IN TUBING (GAL=11') 8/2/2004 0.000 IPERF;6,372.08,400.0 6,728.0 6,706.1 1.35 FISH '1 JDC DOGS Downhole,PIECE OF SLIP 11/18/1986 0.000 IPERF,6,404.08,410.0 '' Perforations&Slots IPERF;6,4170-6,428.0 Shot FIT Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com PRODUCTION,8,450.6 I. 6,372.0 6,400.0 6,350.2' 6,378.2 C-4,1H-06 6/1/1982 8.0 IPERF 90 deg Ph,4"HyperJet II PACKER;6,459.7 1 APERF;6472.06,496.0 6,404.0 6,410.0 6,382.2 6,388.2 C-4,1H-06 6/1/1982 8.0 IPERF 90 deg Ph,4"HyperJet II 6,417.0 6,428.0 6,395.2 6,406.2 C-3,1H-06 6/1/1982 8.0 IPERF 90 deg Ph,4"HyperJet II PRODUCTION;6,508.4 SLEEVE-C;8,545.1 6,472.0 6,496.0 6,450.2 6,474.1 C-1,UNIT B, 7/27/1986 12.0 APERF 120 deg Ph,5"Csg Gun 1H-06 NIPPLE;6,545.1 6,634.0 6,641.0 6,612.1 6,619.1 A-5,1H-06 6/1/1982 8.0 IPERF 90 deg Ph,4"HyperJet II SEAL ASSY;6,552.1 PACKER;8,553.8 6,647.0 6,656.0 6,625.1 6,634.1 A-4,1 H-06 6/1/1982 8.0 IPERF 90 deg Ph,4"HyperJet II -FISH @ 6650-6662 IPERF,6,634.0-6,641.0 Mandrel Inserts St ati IPERF;6,647.0-6,656.0 on Top(ND) Valve Latch Port Size TRO Run • FISH;6,8500 N Top(ftKB) (ftKB) Make Model OD(In) Sere T - ype Type (in) (psi) Run Date Com 1 2,519.3 2,518.6 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/31/2016 FISH;s,7zeo .0, 2 3,727.9 3,717.1 Camco KBMG 1 GAS LIFT DMY 'BK 0.000 0.0 7/31/2016 Q 3 4,651.9 4,634.8 Camco SDCK2 ' 1 GAS LIFT SOV •SBEK 0.000 0.0 7/31/2016 4' 5,293.8 5,274.1 Camco -KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/31/2016 5 5,740.0 5,718.8 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/31/2016 PRODUCTION;1,6360-6,900.0 KUP 1100 • 1 H-06 ConocoPhillips Alaska Inc. I CwcoPhiilips 1 W ...•• 1 H-06,8130/2016 7:15:11 AM Vertical schemata(actugi HANGER 240 II -,t:•8 Mandrel Inserts 1, st 4 ati on Top(ND) Valve Latch Port Size TRO Run N Top(BOB) MKS) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com W 6,023.1 6,001.5 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/31/2016 CONDUCTOR;30.0430.0 .."-A-1".'7 6,263.3 6,241.6 OTIS LBX 1 1/2 PROD DMY RM 0.000 0.0 4/27/1996 CLO SED 8 6,334.5 6,312.8 OTIS LBX 11/2 PROD DMY RM 0.000 0.0 2/3/1999 CLO j SED 9 6,450.6 6,428.7 OTIS LBX 11/2 PROD DMY RM 0.000 0.0 2/3/1999 CLO SED PRODUCTION WORKOVER 2016;244-1,636 0 1 6,508.4 6,486.5 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 11/20/1993 CLO 0 SED Notes:General&Safety End Date Annotation 9/23/2010 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE;28.5-2,194.0 8/11/2016 NOTE:Upper Completion is a mix of 3 1/2"9.3#L-80 EUE-8RD AB-Mod 8 3 1/2"9.2#L-80 IBT-M tubing. IIE GAS LIFT;2,519 3 T - Patch;2,919.0 GAS LIFT;3,727.9 M GAS LIFT;4,651 9 ,. illi GAS LIFT,5,2938 It GAS LIFT,5,740.0 I . II In GAS LIFT;6,023.1 1'-. iii LOCATOR;6,079 3 SEAL ASSY,6,080.3` U_.: A PBR,6086.4 r� PACKER;6,109.6 -- NIPPLE 6162.9 r = LOCATOR;6,209.9 SEAL A=12111620 SSY;6,217.2 llI __ P06.6,210.0 e: / lIMN PACKER;6,225.5 PRODUCTION;6,263.3 l.• PRODUCTION;6,334.5 ' l IPERF;6,372.06,400.0 ((Pre IPERF;6,404.06,410.0 ° • IPERF;6,417 0-6428.0 1I ME PRODUCTION.6,450.6 ?Mr PACKER;6,459.7 4.a.'.. APERF;6,47206,496.0--e PRODUCTION,6,508.4 11 SLEEVE-C;6,545.1, y—-p NIPPLE;6,545.1 ga SEAL ASSY;6,552.1. PACKER;6,5536 IPERF;6,034.0-6641 0 IPERF;6,647 06,656.0 FISH,6,650.0 FISH;6,7280 .. PRODUCTION,1,636.0-69000 • - • • OF T4 o\l///THs THE STATE Alaska Oil and Gas ®f L sKA Conservation Commission 333 West Seventh Avenue r Anchorage, Alaska 99501-3572 jolly GOVERNOR BILL WALKER g 0 p. ....-.....�_� .,,.,,. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke CTD Coordinator ConocoPhillips Alaska, Inc. %O n JAN 2 4 2[17 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1H-06 Permit to Drill Number: 182-068 Sundry Number: 316-417 Dear Mr. Burke: 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, Cathy . Foerster Chair DATED this lay of August, 2016. RBDMS t ' ANS L S ZU16 0 STATE OF ALASKA 0 • ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 1 0/0I"' '"' , rs S. PPLI 9/�� A CATION FOR SUNDRY APPROVALS {'�. 20 AAC 25.280 AO'er:C 1.Type of Request: Abandon El Plug Perforations Fracture Stimulate El Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill Q Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑✓ 182-068 t 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service PO Box 100360,Anchorage AK 99510 50-029-20741-00 . 7. If perforating: POs 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA- ❑ KRU 1H-06 - Will planned perforations require a spacing exception? Yes ❑ No 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25639 P6 Kuparuk River Field/Kuparuk 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): 6964' 6942' 6813' 6793'• 2817 psi N/A 6650'MD Fish Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 80' 80' 1640 psi 630 psi Surface 2194' 10-3/4" 2194' 2193' 3580 psi 2090 psi Intermediate Production 6900' 7" 6900' 6878' 4980 psi 4330 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6372'-6556' " 6350'-6625' 3-1/2" J-55 6565' Packers and SSSV Type: SSSV:None Packers and SSSV MD(ft)and TVD(ft): . FHL Packer:6109'MD&6087'TVD Packers:Baker FHL Packer,Baker HB Packer, • HB Packer:6227'MD&6204'TVD Baker HB Packer • HB Packer:6461'MD&6439'TVD 12.Attachments: Proposal Summary Q Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Q� 12/1/2016 ❑ WINJ ❑ WDSPL ❑ Suspended • 41�(C" Commencing Operations: OIL 16.Verbal Approval: Date: GAS ❑ WAG El GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown El Abandoned 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jason Burke Email Jason.Burke@cop.com Printed Name Jason Burke Title CTD Coordinator Signature Phone 265-6097 Date 494//b COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance El Other: 500 51 l3aA ti✓5t ��r�55�r� t-0 3 ,-h0vl(Av prcventtr tt5f 17,-- 55-uv-4 fa 25-00 p51^5 • 1 A- 6tc-rnyuc t-c Pl , Pd7 cr»L"wt a-1210lovz;d per 2-O�}�-C Z5 • I "(t Post Initial Injection MIT Req'd? Yes ❑ No // ,t gl l 1(\to Spacing Exception Required? Yes ❑ No � 4 Subsequent Form Required: 1 9 — RBDMS LAI Q'I' 2 5 2016 Approved by: COMMISSIONER THE COMMISSION Date: 8-(1_4 `� <<� APPROVED BY Submit Form and Form 10-403 ivised 1 /2015 �itN'At ' for 12 months from the date of approval. Attachments in Duplicate � droll 4471'44 111 RECEIVE! ConocoPhillips p AUG 10 2016 Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ,. C August 2, 2016 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 applications to abandon the KRU 1 H-06 by cementing up the perforations and isolating the A-sand with a CIBP with cement on top in order to set up to for CTD operations to drill a single lateral out of the KRU 1 H-06 using the coiled tubing drilling rig, Nabors CDR2-AC. A sundry application is attached to plug the KRU 1H-06 (182-068) perfs to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the NC-sand perfs in 1 H-06. Attached to this application are the following documents: — 10-403 Sundry Application to Abandon KRU 1 H-06 (182-068) — Operations Summary in support of the 10-403 sundry application — Proposed CTD Schematic — Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-265-6097. Sincerely, Jason Burke ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • KRU 1H-06 CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU well 1 H-06 is a Kuparuk NC-sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize a single lateral to target the A4 sand to the north of the 1 H-06. The lateral will target oil on the other side of a major fault. Prior to CTD operations the existing C-sand perforations will be squeezed with cement and a CIBP will be set above the 2-7/8" tubing tail with cement dumped on top to abandon the A- sand perforations. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A/C-sand perforations in this manner. Following the cement squeeze Nabors CDR2-AC will exit the casing at 6520' MD via a mechanical whip-stock. The single lateral will be completed with 2-3/8" slotted liner from TD to inside the mother-bore. The completion will include a swell packer and a liner top packer to isolate a swept zone near the mother-bore. Using the maximum formation pressure in the area of 3480 psi in 1 H-07, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 2817 psi. '-- CTD Drill and Complete 1H-06 Laterals: December 2016 Pre-CTD Work 1. RU Slickline: Dummy off gas lift mandrels, pull production mandrels and AVA nipple sleeve; obtain a SBHP and drift tubing 2. RU E-line: Set CBP at 6549' MD 3. RU Pumping: Swap hole over to diesel and perform injectivity test 4. RU Service Coil: Lay in cement plug and squeeze off the C-sand perforations. Let cement harden, pressure test cement and mill cement out to CBP. Mill CBP and push down into the tubing tail and out into the 7" casing if possible. 5. RU E-line: Set CIBP just above the AVA nipple at 6544' MD 6. RU Slick-line: Dump bail 10' of cement on top of CIBP; dummy whip-stock drift 7. RU E-line: Set whip-stock at 6520' MD 8. Prep site for Nabors CDR2-AC and set BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1 H-06A Sidetrack (A4 sand - North) a. Mill 2.80" window at 6520' MD. b. Drill 3" bi-center lateral to TD of 10300' MD. c. Run 2%" slotted liner with a swell sacker and 6' • - •' ►i B. 3. reeze protect, se : `T, • BSPE, and RDMO Nabors CRD2-AC. t � pbtprfaAK`w/11 Post-Rig Work Cd��h Conk✓(• 7� • fro ' ,An9 lair e<rft1 1. Pull BPV W� ,4t c i0u1I 0� Co/►t?' 1/ �✓'P 2. Obtain SBHP Well �orc a"� r w¢lI �3 �odvciny. � ir� 3. Set linera ntcesfory 4. top packer tyre t. (66-43 rib) Install to production no fefervef f'vi'a''� if 5. Return Page 1 of 1 8/8/2016 • • • Loepp, Victoria T (DOA) From: Burke,Jason <Jason.Burke@conocophillips.com> Sent: Tuesday,August 16, 2016 2:29 PM To: Loepp,Victoria T(DOA) Subject: BOP test pressures 1H-06&1B-18 1B-18:4200 psi 1H-06:3500 psi ConocoPhil lips Jason Burke Coiled?ubing Drilling Coordinator (0) 907-265-6097 (SM) 907-231-4568 • • LoN W (C) m N 0 Q (o * 'O co co cm N Lr) o2S 0 c O F: - 0 -073 0) CON cO N Cr) Co N G U) 0 Q 0 co co 0) 0 (f) CN _ C 0 F2 V' z- M cis N 2_ O o of N Z m - ❑ ❑2 o N- Q a) m = 2 LU -o (� ❑ ❑ E )n co m .-E, c a) w m 2 o , in m ❑ o 0 cc F-. E o ».. - (o F-N CC0 C Z N C 0 V (6 E - ED g -0 @ O CO 0 (O O CO 73 0 in V N O (O .0 Or9 C u) 2 (D O. w to �` J (S3 (0 Q E N ,„1° CO LU .C- a) W d V Cr 4) d Y O Y (- a) a) f6 (0 (0 i ❑' Y Q O O) O O f0 O_ N 0 (0 (:,),_ 2 .O- } V) Y .f co 0D E o O_ U z x Q Y c o o m 9 -(..:.5 . J —, m O m O..-. �k O CO m i) m E (.) pmn •� C Cr) co LL Ol S •— I N 0 - N i 0 Q N O N M N 4) O aa)) \ \ m as _1 (00 \ m \ > m m 0 ~ Z co co m CO 0 CO co CO Co < « CO CO X N A iii III I C __Al 3 lamas O ,./„A.,‘,... J 0_ 11 114 1 o 1,1I! I III m ❑ c a# rf 00 a) O f0 0 O. CO O U 2 u) O � V 0 N C U � - N 0) V N Q(9 N -a N V N- co ❑ V' N VI 0 h. N N co rn (O � 25U MM V 0 O U) v) aOQ (O ) io 0 0 .0 (o 0 0 0 _ _ O Y U U w �� • McEvoy Gen I/C-Bowl(5M) .KRU 1 H_06 7'/tfi'x3'/:"EUETbgHgr ConocoPhillips 1 ( P - Kuparuk A-&C-Sand Producer 2016 Post RWO—Subsidence& Casing Patch Repair 16"62.58#H-40 WLD,110'MD--III.- - I CIW C-Bowl Tubing Head Retrofit Surface Casing Primary Cement 342 bbls 12.2 ppg Arctic Set III ! 7"26#L-80 TSH563 Casing Tieback 42 bbls 15.2 ppg Arctic Set II 1618'MD,HES Type H ES Cementer OA Shoe Squeeze Q __.,0.41-- �_1631'MD,Bowen Casing Overshot Patch Measured TOC 1690'MD jI 1 1632'MD,Existing 7"Production Casing Cut 41.4 bbls 15.2 ppg Arctic Set II I Surface to 2536'MD 98 bbls 7.3 ppg Arctic Pack 3-"A"9.3#L-80 EUE-8RD AB-Mod R2 Tubing 2536'to Seal Assembly 3'/:"9.2#L-80 IBTM R2 Tubing w/EUE-8RD 10-%"45.5#K-55 BTC,2193'MD-111.-L i' I � SCC on GLMs(Clearance thru Csg Patch) 11 � 2519'MD,Camco 3'/z"x 1"KBMG,DV 7"Casing Leak,-2939'MD-0.- Bt .1--2920'-2959'MD WFT MetalSkin Casing Patch 4 3727'MD,Camco 3-W'x 1"KBMG,DV .0 4651'MD,Camco 3-'A"x 1"KBMG,SOV iSheared SO V - 5293'MD,Camco 3'1/2"x 1"KBMG,DV IllUi 5739'MD,Camco 3-%"x 1"KBMG,DV iiii 6023'MD,Camco 3'/z"x 1"KBMG,DV t I 4 6086'MD,Baker 20'80-40 PBR Seal Assembly Sheared,Space-Out Seals 6' Drilling Mud/Spacer f Lead Cement 1, 4 r'-411- -6109'MD,Baker 7"x 3'/"FHL Packer Pin for 60 klbs Shear Release Arctic Pack �' 6162'MD Camco 2.813"DS Landing Nipple w/RHC Plug Body Installed for Ball 8 Rodd Diesel " 4 i 6211'MD,BOT Original Seal Assembly t'Space-Out Kill Weight Fluid f 4 6212'MD,BOT 10'PBR Unknown/Form Fluid f-6227'MD,BOT 7"x 3'1"HB Packer 56 klb Straight-Pull Shear or Rotational Release -4 6265'MD,Otis 3-1/2"x 1-1/2"LBX GLM(DV) II 6336'MD,Otis 3'/"x 1'1/2"LBX GLM(DV) - 6367'-6433'MD,Carbide Blast Rings On 3-%"9 2#J-55 BTCM Tubing Kuparuk C-Sand Perforations 1 6452'MD,Otis 3-1/2"x 1-1/2"LBX GLM(DV) C-4,1982-6372'-6400'MD 1 C-4,1982-6404'-6410'MD C-3,1982-6417'-6428'MD '1 6461'MD,Baker 7"x 3-'A"HB Packer C-1,1986-6472'-6496'MD I ' 56 klb Straight-Pull Shear or Rotational Release 41--6467-6501'MD,Carbide Blast Rings $ On 3-Y"9.2#J-55 BTCM Tubing ti I@ -4I6510'MD,Camco 3'/"x 1"KBUG GLM(DV) I ,( • A 6547'MD,Camco AVA BPL Nipple Isolation Sleeve Installed o -411--6554'MD,BOT Seal Assembly(1'Space-Out) 6555'MD,7"x 3-1/2"BOT 1B Packer w/5'SBE 6565'MD,Jet-Cut 2-%"Tubing Stub Kuparuk A-Sand Perforations A-5,1982-6634'-6641'MD A-4,1982-6647'-6656'MD Production Casing Primary Cement -11'Tubing Tail Fish,6650'MD -IP- TOC-4860'MD(CBL 31-May-1982) 133 bbls 11.4 ppg Columbia Class'G'Lead 82 bbls 15.8 ppg Columbia Class`G'Tail 7"26#J-55 BTC,6900'MD ► Date: 08-Aug-2016 I Draw"By: Danny Kane • S r Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the"Abandon"or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist / work)the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the"Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. S 411/ Icu o m ,-,:, _ a) 41 r, Q X . Q -. 3 O ❑ 1111 O � H V coO U vi > Em O� nW QT Q c p -O0 4 0 10 Q (moo co co co co co co }o o v y m E 0 Q . o E O) 6 6 6 6 O) L OC +' Vl Ct. �"`, W a a a Q a a E "6 N Q N G Z:'., ~Q N O 00 O M N N C m 3 �, Z 4:,.. O O -O s_ O >, cu u +.. H ❑ ❑ p ❑ ❑ ❑ to • G) u s O' } W W W W W W W ..- .bp O CO Q O - H LL LL LL LL LL LL LL N w E - . 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Z c4 03 — OMch c co it > W O U H ;48%VI Idl .44.4W xcecccecectce s.: CU W W W W W W W �p W > > > > > > > v z Y Y Y Y Y Y Y > > > > > > > O 1411 o a Q Q a Q Q Q a U a; a. n. d 0. d d 0- 0 'n 0 Y Y Y Y Y Y Y C T W 0N G > W (0 V M N O COW 0u ;;._) ® Ce O O O O O O O Q�E,AC 0 0 0 0 0 0 0 O rcs ___ ^{ W O O O O O O O '-- FJ i r...1V co F F F H F 00 E W!` ❑ ❑ ❑ ❑ p (0 p c N; to CC p 0 0 0 0 O V lD} O 0 0 0 O O O in _ _ \ ▪ O) N CO M M M by E N- (O CO0 0 N VI' V N 0 O N O N N N N N N N N N N V N O) O O M (3) O) O) 0 CD N N N 0 N N N L N v O O O O O O N 17 O O O O O O O L 1.0 in ID LO N N p) co ec r al E E I - p1 fp N 01 ( N > N W a CE phi d Q co a v a op v v ra a L 3 aL v A pJ i z O h- O N N E (n m F- d Q N w = f`a'') O M el E Z v • y Y co .: `7 I ^ f6 .EU fp C/� 3d� l Ca_ a Q, • OF Tk ��1 //7, s THE STATE Alaska Oil and Gas of Conservation Commission Ott — 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501 3572 'T Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Daniel Kane Sr. Wells EngineerCT 1B, ConocoPhillips Alaska, Inc. P.O. Box 100360 SCANS Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1H-06 Permit to Drill Number: 182-068 Sundry Number: 316-378 Dear Mr. Kane: 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, Daniel T. Seamount, Jr. Commissioner frkv DATED this 2,day of July, 2016. RBDMS /V JUL 2 9 2016 • • RECEIVED STATE OF ALASKA JUL 2 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 ` Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q , Change Approved Program Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑J - Other: rvr G 4 3 t we- ��afieV 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. / Exploratory ❑ Development Q. 182-068 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-20741-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1H-06 " Will planned perforations require a spacing exception? Yes ❑ No @ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025639 ' Kuparuk River Field/Kuparuk 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): - 6964' ' 6942' k 6634' " 6612' 2043 none 6650' Casing Length Size MD TVD Burst Collapse Structural Conductor 50' 16" 80' 80' Surface 2159' 10.75" 2192' 2192' Intermediate Production 6870' 7" 6898' 6876' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6372'-6400' , 6350'-6378' 3.5" J-55 6566' 6404'-6410' - 6382'-6388' 6417'-6428' i 6395-6406' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV: CAMCO TRDP-1A-SSA SAFETY VALVE(LOCKED OUT 6/21/2016) MD=1776 TVD=1776. PACKER-BAKER HB-1 HYD PACKER MD=6226 TVD=6204 . 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development . Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 7/15/2016 OIL Q - WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 7/19/2016 GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: Victoria Loepp GINJ 0 Op Shutdown ❑ Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Daniel Kane @ 265-6048 Email Daniel.Kane@conocophillips.com Printed Name Daniel Kane 265-6048 Title Sr.Wells Engineer Phone 4 --C;Cc—•^%._____ SignatureDate 1 % "S(..)L--Z 151 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _ kl_it Plug Integrity ❑ BOP Test II Mechanical Integrity Test ❑ Location Clearance 0 Other: Bd Pin n V I A ✓ YJ✓> ✓C fr.,' ✓r_I- -,-5 J to 05-°v p S L Post Initialcf Injection MIT Req'd? Yes ❑ NoA Spacing Exception Required? Yes El No Subsequent Form Required: JO - 4-1)4 APPROVED BY J Approved by: 0 /2. 1 COMMISSIONER THE COMMISSION Date: 7- Submit Form and Form 10-403 Revised 11/20150 �1ppCQvricajiorLis valid for 12 months from the date of approval. Attachments in Duplicate II ((VV�� A L RBDMS 07 JUL 2 9 2016 • • Nov RECEIVED ConocoPhillips JUL 2 2 2016 Alaska /(^'' P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 July 19th,2016 Cathy Foerster 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 workover Kuparuk Producer KRU 1H-06(PTD# 182-068). Well 1H-06 was spudded and completed in 1982 as a comingled Kuparuk A-& C-sand producer. In 1986 a work- over was performed to upgrade the wellhead and to replace the original completion with a single dual-selective completion to produce from three different intervals. In 2002,IA x OA communication was first noticed and the well was waivered for IA x OA communication in 2005. In 2004,a tubing leak was discovered across GLM#8 and was patched successfully. The patch started leaking and was replaced in 2011. While preparing the well for a CTD development project,the well failed a TIFL and all attempts to pull the existing retrievable tubing patch were unsuccessful. The well was then added to the rig work-over list to pull&replace the Upper Completion(to remove the tubing patch restriction)as well as to replace the leaking I.C. secondary pack-off Doyon 141 moved on KRU 1H-06 15-Jul-2016&while performing the rig work-over,severely subsidence-induced 7"production casing buckling was discovered and was severe enough to prevent the original work-over scope from being completed. A plan was put together to restore full-bore drift access to the tubing stub that involved cutting& replacing the 7" production casing from the top of cement within the surface casing and then cementing this new casing tieback string to surface. This plan was forwarded to the AOGCC for approval on 18-Jul-2016&permission was granted to proceed ahead 19-Jul-2016(attached email). This Sundry is intended to document the proposed remaining work on KRU 1H-06 because of the intent to repair the well,pull tubing, alter the casing,&change approved program as well as to request approval to workover this well. If you have any questions or require any further information, please call me at 265-6048 or email me at danny.kane@conocophillips.com. conocophillips.com. Sincerely, Danny Kane Wells Engineer CPAI Drilling and Wells • s KRU 1H-06 Proposed Rig Workover ConocoPhil lips CTD Set-Up—Subsidence Repair During RWO Alaska Original PTD#:182-068 CURRENT STATUS: KRU 1H-06,a Kuparuk A-&C-sand Dual Selective Single Completion gas-lifted producer, is currently being worked- over after being shut-in because of a failed TIFL&stuck tubing patch encountered while attempting to set the well up for a CTD development project. In order for the CTD project to proceed, a planned capital rig work-over was started to restore the lost tubing integrity,remove the tubing patch (ID restriction), &replace a failing I.C. secondary pack-off. During the course of the workover,subsidence-induced damage of the 7" production casing was discovered that required the replacement of the damaged 7"production casing in order to regain full-bore drift access. Please see below for a history of the well&annuli integrity diagnostics: - 1982—KRU 1H-06 was drilled&completed in the Kuparuk A-5/A-4&C-4/C-3 sands as a gas-lifted producer with a Single Completion (comingled production). - 1986—RWO#1 performed to fix a troublesome SSSV&convert the well to a Dual-Selective Single Completion gas-lifted producer. o The entire original 1982 completion was pulled and the C-1 sands were also perforated. The McEvoy Gen I 3M wellhead was retrofitted to a McEvoy Gen III 5M top(tubing head& tubing head adapter)—the 7" production casing mandrel hanger was left in place. o The A-sand was fracture-stimulated(6.9 klbs 20/40 proppant). Equipment problems led to possible screen-out&leaving most of the proppant in the tubing. - 1994—Fracture-stimulated the A-sand(105 klbs 16/20& 12/18 proppant). - 2002—Start bleeding OA for building pressure. First evidence of IA x OA communication. - 2004—AnnComm continues to investigate IA x OA communication&discovers/patches tubing leak. o January—Re-energize I.C.secondary pack-off&obtain passing I.C. POT/PPPOT. • IA x OA communication continues. o February—Passing MIT-OA to 1,800 psig. TIFL fails&find leak in 5851' MD GLM#8. Pull DV &find packing in good shape but valve flow-cut. Hole in side of GLM#8. o March—Holefinder slips fall out&get lodged next to fishing neck of CA-2 plug in 2-7/8' D Nipple at 6567' MD. Unable to fish CA-2 plug. o August—Jet cut 2%8"tubing tail at 6565.8'MD(middle of 2-%8"tubing pup beneath BOT 1B permanent packer). Top of tubing tail fish at 6,650'MD. o October—Set WFT Eclipse retrievable patch 5,844'—5,864' MD across leaking GLM#8. o December—Re-energize I.C.secondary pack-off&monitor I.C. pack-off test void pressures along with IA x OA pressures. Confirm slow IA x OA leak is not at the wellhead(I.C. PO test void did not track IA/OA pressures). Suspect thread leak at 7"BTC casing above the top of the OA shoe(2,000'MD)caused by subsidence-induced compression. • O.C. LDS were re-torqued to re-energize O.C. primary pack-off seal. - 2005—Well waivered for IA x OA communication,start additional annual monitoring&I.C. pack-off maintenance schedule as part of waiver. - 2010—Well fails TIFL in December. - 2011—Leak discovered at existing tubing patch across GLM#8. Fished&replaced w/new patch. o March—CTU had to fish tubing patch with Bakke hammer(scale). o April—Set WFT Eclipse retrievable patch 5,834'—5,865'MD across GLM#8. • CMIT-TxIA to 2,500 psig passed using test tool in Lower Patch packer at 5,865' MD. - 2015—Pre-CTD TIFL fails&unable to fish existing tubing patch. Well headed to Pre-CTD RWO. o Nov—Pre-CTD work TIFL fails. SL&CTU unable to fish patch. Well headed to RWO. - 2016—I.C.secondary pack-off difficult to re-energize(5 days to re-energize after being re-energized only 10 days earlier). Severe subsidence-induced buckling discovered during RWO. o While performing the planned RWO,severe subsidence-induced buckling of the 7" production casing was discovered that inhibited full-bore access for the fishing tools required to complete the original scope of the RWO. Page 1 of 4 tr s KRU 1H-06 Proposed Rig Workover ConocoPhillips CTDSet-Up—Subsidence Repair During RWO Alaska Original PTD #:182-068 SCOPE OF WORK: The original objectives of the proposed KRU 1H-06 RWO were to remove the tubing patch from the well, restore tubing integrity,&replace the failing I.C.secondary pack-off which didn't require a work-over sundry application. With the subsidence-induced casing damage discovered while performing the above work-over scope,the new scope requires replacing the damaged 7"production casing and requires sundry approval. The subsidence repair will consist of cutting the 7" production casing above the TOC, pulling the damaged 7"casing, running a new 7" casing tieback string with a stage cementer&casing overshot patch,and drilling out the stage tool to bring the work-over back to the originally planned scope. Well Type: Kuparuk A-&C-sand Producer. MPSP: 2,106 psig using MPSP=(PP-(0.1*TVD)), or dry gas gradient to surface. 2,106 psig=(2,768 psig—(0.1 psig/ft*6,623'TVD)) Reservoir Pressure/TVD: Kuparuk A-Sand Mid-Perfs—2,768 psig/6,623'TVD(8.1 ppg EMW) Using last recorded shut-in tubing pressure&known fluid column. Kuparuk C-Sand Mid-Perfs—Unknown(selective shut-in since 2011). Wellhead Type: McEvoy Gen I/Gen III (5M Tubing Head) BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams BOP Test Pressure 250/3,000 psig(Rams&Annular) 1 , Integrity Results: TIFL Failed 02-Nov-2014 (Last Passing CMIT-TxIA 12-May-2011) CMIT-TxIA Passed 12-May-2011 (Well waivered for IA x OA communication) MIT-OA Passed 11-Jun-2016 Earliest Start Date: RWO Rig Accepted 15-Jul-2016 Production Engineers: John Cookson 1H DPE/Steve Gieryic 1H Development Engineer Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com SUMMARY OF COMPLETED&PROPOSED RWO PROCEDURE: Completed Pre-Rig Work: 1. Function-tested all LDS. Performed passing T POT& PPPOT. Reenergized I.C.secondary pack-off&performed passing I.C. POT& PPPOT. Reenergized O.C.secondary pack-off&performed passing O.C. POT&PPPOT. 2. Dummy off GLMs#1-6. Pulled GLM#7 OV&left pocket open for RWO well kill. 3. Chemical cut 3-1/2"tubing at 5,680' MD(above stuck tubing patch). 4. Lock-out SSSV. 5. Set BPV. Completed Rig Workover Procedure: 1. MIRU, R/U surface equipment for well kill. 2. Pulled BPV. 3. Killed well with 8.5 ppg seawater. Well killed,slight vacuum, passing no-flow test. 4. Install BPV. ND Tree/NU BOPE. 5. Conduct BOPE test(AOGCC Field Inspector waived witness)to 250/3000 psig(pipe rams&annular). Page 2 of 4 • • KRU 1H-06 Proposed Rig Workover ConocoPhillips CTD Set-Up—Subsidence Repair During RWO Original PTD #:182-068 Alaska a. NOTE:AOGCC Field Inspector informed that because of tight tolerances between the Lower Pipe Ram &the tubing hanger neck,the rams would be tested on the 4"test joint(for the drill pipe)after pulling the 3-%2"tubing. 6. Unseated tubing hanger and pulled &LID 3-%2"tubing to pre-rig tubing cut at 5,680' MD. a. NOTE: Issues encountered while TOH where slack-off weight lost&tubing cut showed indications of having been performed in high compression. 7. Finished BOPE test w/4"test joint to 250/3000 psig. 8. TIH w/ 3%2" tubing stub fishing assembly (to go after the remaining Upper Completion tubing to the Seal Assembly)&lost slack-off weight at 36' MD. Attempt to push down,stop at 50' MD w/5klbs top drive weight. 9. Decision made to Grow/Stretch 7" Production Casing (wellhead work intended to be performed after Upper Completion was out of the hole). 10. TIH w/4" drill pipe to 1420' MD to hang-off below storm packer to use as barrier—having to push drill pipe down at 1420' MD w/10 klbs top drive weight, never able to freely slack-off. Decision made to TOH, R/B drill pipe,&call-out E-Line. 11. R/U Dutch Riser&E-Line,Set IBP at 2,990'WLM. Log Multi-Finger Caliper&Cement Bond Log from above IBP to surface(surface casing shoe 2,194' MD). a. Caliper showed severely buckled tubing from surface to TOC(OA squeeze performed in 1982)at 1,690' MD. Processed caliper results returned 18-Jul-2016. b. RWO Officially Turned into Subsidence RWO at this time. c. Set Aside E-Line& R/D Dutch Riser(Crew Timed Out) 12. 55'of sand dumped on top of IBP. Combo IA x OA pressure test to 2,500 psig performed to test IBP from above (IA x OA communication through wellhead pack-offs). Good test. 13. N/D BOPE stack. 14. Used Hydratight to grow the 7" production casing (27" of growth, 61" of documented wellhead subsidence prior to RWO). 15. N/U BOPE stack,changed Lower Pipe Rams to 7"solid body rams,test the break, Lower Pipe Rams,&annular w/7"test joint to 250/2,500 psig(reduced test pressure because of 10-3/4" burst rating). Proposed Rig Workover Procedure: 16. N/U Dutch Riser, R/U E-Line, Chemical Cut 7" Production Casing at 1,632' MD (OA Squeeze TOC logged at 1,690' MD). R/D Dutch Riser&E-Line 17. Spear 7" Production Casing Hanger, P/U, Close Rams Around the 7" Production Casing to divert fluids, and circulate out Arctic Pack in OA to Kill Tanks with hot diesel &water. 18. TOH&L/D 7"Casing to Chemical Cut at 1,632' MD. 19. Drift 10-3/4"Casing&Dress-Off 7"Casing Stub at 1,632' MD. a. If drift issues are encountered, mill 10-3/4" surface casing as needed to obtain drift access for the new 7"production casing string. 20. Run new 7" 26# L-80 Hydril 563 production casing w/ casing overshot patch & Halliburton Type H ES stage cementer,engage, &latch-on to 7"casing stub. Install cementing head. 21. Pressure-test 7"casing to 2,000 psig to verify casing overshot integrity(pressuring-up against IBP set at 2,990' WLM). 22. Pressure-up on 7" casing to open stage cementer(target 2,500 psig opening pressure), circulate to clean OA, close rams. Page 3 of 4 • • KRU 1H-06 Proposed Rig Workover ConocoPhillips CTD Set-Up—Subsidence Repair During RWO Alaska Original PTD#:182-068 23. Pressure-test to IA x OA 2,500 psig to verify casing overshot integrity to full IA test pressure. 24. Pump cement OA to surface, bump plug in stage cementer. a. Stage Cementer to be within 100' MD of the existing TOC, plan to cement entire annulus from existing OA TOC at 1,690' MD to surface. 25. ND cement head&WOC to achieve 500 psig compressive strength. 26. Once 500 psig compressive strength achieved, monitor production casing&OA for flow. 27. N/D BOPE stack, land casing in slips. Cut excess casing. Install pack-offs & new tubing head. Pressure-test pack-off to 4,300 psig. Shell-test BOP stack&all breaks to 250/3,000 psig. 28. TIH w/Clean-Out Assembly to Drill-Out stage cementer. 29. TIH w/Clean-Out Assembly to clean-out debris on top of sand above IBP. Clean-out sand. 30. Retrieve IBP. a. Resume original work-over scope: 31. MU & TIH while picking-up drill pipe with the tubing stub fishing assembly, engage the tubing stub, & pull tubing free to the seal assembly in the BOT PBR at 6,212' MD. TOH racking pipe, L/D assembly, &L/D fish. 32. MU &TIH w/ racked back pipe & casing scraper/PBR clean-out assembly. Clean-out to the PBR & obtain IA pressure-test w/clean-out stinger in PBR. 33. MU & TIH with the new 3-%" Stacked Packer Upper Completion. Using the old seal assembly stripped of packing as WLEG into the existing PBR,tag,fully-locate, &space-out 1'from fully-located. 34. Spot C.I. brine pill,drop ball&rod, &set FHL packer. Pressure-test IA to 2,500 psig to confirm packer has set. Shear seal assembly from PBR. 35. Slack-off to tag seal assembly on PBR,space-out seal assembly into PBR,mark-pipe at surface,&lay-down two joints. Space-out with tubing pups, M/U tubing hanger, M/U landing joint. 36. Displace IA to C.I. brine,stab seals, land hanger,&RILDS. 37. Pressure-test tubing to 3,000 psig&IA to 2,500 psig. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV. 38. Back-out landing joint&install BPV. 39. ND BOPE, make-up Plug-Off tool to the BPV, NU tree,&pressure test tree. Remove Plug-Off tool&BPV. 40. Freeze protect well through SOV. Set BPV. 41. RDMO Doyon 141. Proposed Post-Rig Work 1. Pull BPV. 2. Pull the ball &rod from the RHC plug body set within the 2.813" DS Landing Nipple. 3. Set a catcher sub&install the GLD as planned. Pull the catcher sub. 4. Pull the RHC plug body set within the 2.813" DS Landing Nipple. 5. Reset well house(s)&re-attach flow line(s). 6. Turn well over to operations. Page 4 of 4 • • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday,July 27, 2016 9:42 AM To: 'Kane, Danny' Subject: RE: [EXTERNAL]RE: KRU 1H-06-Change of Scope w/Casing Leak(PTD 182-068, Sundry 316-378) Change of Approved Program Danny, Thanx, Danny, I will add this change of scope to the Sundry. Approval is granted for the plan forward to repair the PC leak as outlined below. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp at7.alaska.gov CONFIDENTIALIIYNOTICE: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.Loepo@alaska.gov From: Kane, Danny [mailto:Danny.KaneOconocophillips.com] Sent: Wednesday, July 27, 2016 9:33 AM To: Loepp, Victoria T(DOA) Subject: Re: [EXTERNAL]RE: KRU 1H-06 -Change of Scope w/Casing Leak(PTD 182-068) Victoria, This was originally a non-Sundry workover. This is the same well that I talked with you about a week and a half ago where we had to do a subsidence repair. I have already submitted a Sundry already for the subsidence scope change. This casing leak is in addition to the subsidence work we performed. I'll forward you the subsidence scope change email with the requested information. Regards, Danny Danny Kane Senior Wells Engineer-GKA ConocoPhillips Alaska, Inc. +1(907) 265-6048-Office 1 • +1 (907)227-6037-Mobile • danny.kane@conocophillips.com On Jul 27,2016,at 09:30, Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>wrote: Danny, Was this a non-Sundry workover for the original work? If so,you will need to prepare a sundry for the new work scope which should be completed as soon as possible. Please provide the MPSP and the BOP test pressure. Thanx, Victoria From: Kane, Danny [mailto:Danny.Kane@conocophillips.com] Sent: Wednesday,July 27, 2016 7:09 AM To: Loepp, Victoria T(DOA) Subject: KRU 1H-06 -Change of Scope w/Casing Leak(PTD 182-068) Victoria, I wanted to let you know that we have found a leak in our 7" production casing at 2940' MD. We successfully completed the subsidence repair earlier and were able to fish the remainder of our Upper Completion to the seal assembly. Yesterday we performed a clean-out run of our 7" production casing above the PBR at 6212' MD and as part of the clean-out,we stabbed a set of seals into the PBR to pressure-test the casing(last pressure-tested in 2011 other than the subsidence repair interval which was tested post-repair). This pressure test failed. Using a test packer we found a casing leak from 2935' to 2945' MD which correlates to an interval where we broke a junk basket&had to mill up the junk basket fish. This is our current plan forward: • TOH with the Test Packer • P/U&TIH with a RBP,set above the PBR at 6212' MD. TOH w/drill pipe. • P/U&TIH with a test packer&confirm casing integrity below the casing leak found at^'2940' MD to the PBR. • TIH further with test packer, retrieve RBP,TOH,& L/D the test packer&RBP. Assuming we have the one casing leak: • R/U E-Line&perform caliper survey of casing leak interval. • Run Stacked Packer on drill pipe with a test packer. Set stacked packer as originally planned. • Use test packer to confirm stacked packer set properly. • TOH w/Test Packer. • Install Weatherford Metalskin Casing Patch(dressed for 7"26#casing)across casing leak(^'40' patch for single leak). • Pressure-test casing to confirm production casing integrity from surface to the stacked packer. • Run new Upper Completion tying into Stacked Packer. I have attached a PDF schematic of what the work-over will look like assuming the one leak. If we discover additional production casing leaks,we will re-evaluate our repair options. 2 • • Does the AOGCC have any questions regarding our plan forward? If wedetermine that there are no other casing leaks,does the AOGCC approve of our plan forward? Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 3 ye KUP PROD • 1H-06 ConocoPhillips S Well Attributes Max Angle&MD TD Alaska,Inc. " Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) r Onodi lips 500292074100 KUPARUK RIVER UNIT PROD 8.85 3,500.00 6,964.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1H-06,4/23/20153:13'.57 PM SSSV:TRDP 75 11/5/2014 Last WO: 7/22/1986 29.51 6/3/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ................. _.._. '-`. Last Tag:SLM 6,634.0 4/22/2015 Rev Reason:TAG lehallf 4/23/2015 HANGER 21.4 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 30.0 80.0 80.0 65.00 H-40 WELDED ICooIngDescrl tion ODin ID In ToSet De th ftKB Set Depth D...WULen I...Grade Top Thread p ( 1 1 p(EBB) p (ftKB) 219 SURFACE 103/4 9.950 28.5 2,194.0 2,193.7 45.50 K-55 BTC Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WVLen(I...Grade Tap Thread PRODUCTION 7 6.276 28.8 6,900.0 6,878.0 26.00 K-55 BTC -.i ti CONDUCTOR;30.0$0.0 a.. I■J■ Tubing Strings - Tubing Description 'String Malin 'Top(ftKB) /Set Depth(ft..]Set Depth(1601(...I Wt(Ib/k) (Grade /Top Connection SAFETY VLV;1,775.7 TUBING Il 31/2 2.992 21.4 6,565.81 6,5439 9.20 J-55 BTC AB-MOD Completion Details 1 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 21.4 21.4 0.17 HANGER MCEVOY GEN II HANGER 3.500 SURFACE;28.5-2,194.0- 4 1,775.7 1,775.6 0.85 SAFETY VLV CAMCO TRDP-IA-SSA SAFETY VALVE 2.813 6,210.0 6,188.3 1.92 PBR BAKER G PBR 2.937 GAS LIFT;2,216.2 ®. 6,225.5 6,203.7 1.89 PACKER BAKER HB-1 HYD PACKER 2.890 GAS LIFT;3,579.9 _ 6,374.6 6,352.8 1.88 BLAST RINGS CARBIDE BLAST RINGS 2.867 6. 6,459.7 6,437.9 1.83 PACKER BAKER HB-1 HYDSET PACKER 2.867 GAS LIFT;4,324.9 6,474.3 6,452.4 1,81 BLAST RINGS CARBIDE BLAST RINGS • 2.867 GAS LIFT;4,670.3 ®. 6,545.1 6,523.2 1.59 NIPPLE AVA BPL PORTED NIPPLE ' 2.750 7 6,552.1 6,530.2 1.57 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;4,956.4 - 6,553.6 6,531.7 1.56 PACKER BAKER'1B'PERMANENT PACKER w/SBE X0 TO 2 7/8" 3.250 GAS LIFT;5,275.7 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 11 Top(ND) Top Incl' GAS LIFT;5,563.4 ' Top(ftKB) (ftKB) (°) Des Corn Run Date ID(In) 5,834.5 5,813.2 3.56 PACKER UPPER ER PACKER 5/14/2011 1.800 PACKER;5,834.5 = (. 5,836.8 5,815.5 3.55'PATCH SET SPACER PIPE 8 SNAP LATCH SEAL 5/14/2011 1.750 ASSEMBLY,OAL=31.2 PATCH;5.836.8, II. 5,864.1 5,842.7 3.38 PACKER LOWER WEATHERFORD ER PACKER 4/27/2011 1.800 GAS LIFT;5,849.0 -� 6,545.1 6,523.2 1.59•SLEEVE-C AVA 2.75"BPI 3/31/2003 2.320 PACKER;5,864.1 _ 6,650.0 ' 6,628.1 1.37 FISH NIPPLE/SOS/TBG/STANDING VLV IN TUBING 8/2/2004 0.000 (OAL=11') 6.728.0 6.706.1 1.35 FISH 1 JDC DOGS Downhole,PIECE OF SLIP 11/18/1986 0.000 GAS LIFT;6,189.3 Perforations&Slots Shat Dens PBR;6.210.0 / f,, Top(ND) Btm(TVD) (shots/f PACKER;6,225.5 AN Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,372.0 6,400.0 6,350.2 6,378.2 C-4,1H-06 6/1/1982 8.0 IPERF 90 deg Ph,4"HyperJet II IF PRODUCTION;6,263.3 6,404.0 6,410.0 6,382.2 6,388.2 C-4,1H-06 6/1/1982 8.0 IPERF 90 deg Ph,4"HyperJet II PRODUCTION;6,334. . 6,417.0 6,428.0 6,395.2 6,406.2 C-3,1H-06 '6/1/1982 8.0 IPERF 90 deg Ph,4"HyperJet II 6,472.0 6,496.0 6,450.2 6,474.1 C-1,UNIT B, 7/27/1986 12.0 APERF 120 deg Ph,5"Csg Gun (PERF;6,372.0.4,400.0 • 1H-06 6,634.0 6,641.0 6,612.1 6,619.1 A-5,1 H-06 6/1/1982 8.0 IPERF 90 deg Ph,4"HyperJet II IPERF;6,404.0-6410.0 • 6,647.0 6,656.0• 6,625.1. 6,634.1 A-4,1H-06 6/1/1982 8.0 IPERF 90 deg Ph,4"HyperJet II -FISH @ 6650-6662 IPERF;6,417.0-6,428.0 Mandrel Inserts I st ® ti on Top(TVD) Valve Latch Port Size TRO Run PRODUCTION;6,450.6III Nr Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com PACKER;6,459.7 ?)f3"r l 2,216.2 2,215.9 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,295.0 12/24/2005 t APERF;8,472.0-6,496.0- 2 3,579.9 3,570.6 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,325.0 12/24/2005 3 4,324.9 4,309.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/22/2004 4 4,670.3 4,653.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.250 1,465.0 12/24/2005 PRODUCTION;6,508.4 5 4,956.4 4,938.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/22/2004 6 5,275.7 5,256.0 CAMCO KBUG 1 GAS LIFT GLV 'BK 0.250 1,455.0 12/24/2005 SLEEVE-C;6,545.1,1I ,�. NIPPLE;6,545.1 7 5,563.4 5,542.8 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 12/31/2010 SEAL ASSY;6,552.1 '-'-11 ,` 8 5,849.0 5,827.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/25/2004 PACKER;6.553.6 9 6,169.3 6,147.6 OTIS LBX 11/2 GAS LIFT DMY RM 0.000 0.0 9/7/2004 1 6,263.3 6,241.6 OTIS LBX 11/2 PROD DMY RM 0.000 0.0 4/27/1996 Close 0 d 1 6,334.5 6,312.8 OTIS LBX 11/2 PROD DMY RM 0.000 0.0 2/3/1999 Close IPERF;6,634.0.6,641.0 1 1 6,450.6 6,428.7 OTIS LBX 11/2 PROD DMY RM 0.000 0.0 2/3/1999 Close 2 d IPERF;8,647.08,856.0 1 6,508.4 6,486.5 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 11/20/1993 Close FISH;6,650.0 11.4 3 410 Notes:General&Safety End Date Annotation FISH;6,728.0 - 1/6/2005 NOTE:WAIVERED WELL: IA x OA COMMUNICATION 9/23/2010 NOTE;Mandrel @ 5851-Suspect hole in mandrel-dmy pulled 2/25/04,Bowcut but pkg in good condition 9/23/2010 NOTE:View Schematic w/Alaska Schematic9.0 PRODUCTION;28.8.6,900.0 • • McEvoy Gen I/III(5M) 11/..."' KRU 1 H-06 � • � 7-'/�fi'x 3-V EUE Tbg Hgr ConocoPhilhps Kuparuk A-&C-Sand Producer ' [___, Current Status—30-Jun-2016 16"62.58#H-40 WLD,128'MD Surface Casing Primary Cement 342 bbls 12.2 ppg Arctic Set III 42 bbls 15.2 ppg Arctic Set II OA Shoe Squeeze ! 1777'MD,Camco 3 W'TRDP-IA-SSA SSSV Est TOC 2000'MD 31 Stainless Steel Bands 41.4 bbls 15.2 ppg Arctic Set 1I 98 bbls 7.3 ppg Arctic Pack 4 3-Y2"9.2#J-55 IPC BTCM 10-%"45.5#K-55 BTC,2193'MD—111.--L r 2218'MD,Camco 3-1/2"x 1"KBUG,DV Drilling Mud/Spacer .�--r—3582'MD,Camco 3-1/2"x 1"KBUG,DV Lead Cement -414327'MD,Camco 3-1/2"x 1"KBUG,DV r' u� °t" 1 4672'MD,Camco 3-1/2"x 1"KBUG,DV Arctic Pack Diesel - 4958'MD,Camco 3-1/2"x 1"KBUG,DV Kill Weight Fluid 5277'MD,Camco 3'/:"x 1"KBUG,DV Unknown/Form Fluid _ =-. 5565'MD,Camco 3'/:"x 1"KBUG,OPEN 5680'MD-Pre-Rig Tubing Cut - - OV pulled&pocket left open during pre-rig work. WFT ER Upper Patch Packer,5834'MD ►''l i Spacer Tube Threaded to Packer 5851'MD,Otis 3-1/2"x 1-V LBX GLM,DV WFT ER Lower Patch Packer,5865'MD rl ri?' Leak in side of GLM#8 6171'MD,Otis 3 W'x 1 W'LBX GLM,DV �-6212'MD,BOT 10'PBR&Seal Assembly 1 6�- 4 6227'MD,BOT 7"x 3-1/2"HB Packer 56 klb Straight-Pull Shear or Rotational Release 6265'MD,Otis 3-1/2"x 1-1/2"LBX GLM(DV) _- 6336'MD,Otis 3 V x 1-V LBX GLM(DV) I6367'-6433'MD,Carbide Blast Rings I On 3-16"9.2#J-55 BTCM Tubing Kuparuk C-Sand Perforations 4 6452'MD,Otis 3-1/2"x 1-1/2"LBX GLM(DV) C-4,1982-6372'-6400'MD H- 11-Th C-4,1982-6404'-6410'MD C-3,1982-6417'-6428'MD -41, 6461'MD,Baker 7"x 3:1/2"HB Packer 56 klb Straight-Pull Shear or Rotational Release C-1,1986-6472'-6496'MD _ ' � R f—6467-6501'MD,Carbide Blast Rings On 3-1c 9.2#J-55 BTCM Tubing t 6510'MD,Camco 3'1/2"x 1"KBUG GLM(DV) 6547'MD,Camco AVA BPL Nipple Isolation Sleeve Installed f-6554'MD,BOT Seal Assembly(1'Space-Out) I i . f6555'MD,7"x 3-1/2"BOT 1B Packer w/5'SBE i 6565'MD,Jet-Cut 2-1/2"Tubing Stub Kuparuk A-Sand Perforations A-5,1982-6634'-6641'MD A-4,1982-6647'-6656'MD Production Casing Primary Cement -11'Tubing Tail Fish,6650'MD -114.- TOC 4860'MD(CBL 31-May-1982) 133 bbls 11.4 ppg Columbia Class'G'Lead 82 bbls 15.8 ppg Columbia Class'G'Tail 7"26#J-55 BTC,6900'MD--114.L -' Date: 30-Jun-2016 I Drawn By: Danny Kane • • McEvoy Gen I/UE owlTbg(5MHgr KRU 1 H-06 � � 7-1/1fi'x 3-V EUE Tbg Hgr ConocoPhillips j I Kuparuk A-&C-Sand Producer i 1 2016 Proposed Subsidence RWO 16"62.58#H-40 WLD,110'MD I ---' I Replace I.C.Pack-Offs,Retrofit to C-Bowl Surface Casing Primary Cement ! Tubing Head 342 bbls 12.2 ppg Arctic Set III i HES Type H ES Cementer-1618'MD 42 bbls 15.2 ppg Arctic Set 11 j 7"Production Casing Cut 1632'MD --Casing Overshot Patch Tie-In OA Shoe Squeeze _ ''' 7"26#L-80 TSH563 Casing String Measured TOC 1690'MD OA Cemented to Surface 41.4 bbls 15.2 ppg Arctic Set 11 98 bbls 7.3 ppg Arctic Pack t ) 3-'A"9.3#L-80 EUE-8RD AB-Mod R2 Tubing 1 10-%"45.5#K-55 BTC,2193'MD-110.-- 1 t adar 2502'MD,Camco 3'1/2"x 1'/2"MMG,DV Drilling Mud/Spacer t 3710'MD,Camco 3 W'x 1-1/2"MMG,DV Lead Cement 1 3 4617'MD,Camco 3-1/2"x 1-1/2"MMG,SOV Arctic Pack SOV Pinned 2000 psig IA4 T Shear Diesel -I 11 5270'MD,Camco 3-1/2"x 1-1/2"MMG,DV Kill Weight Fluid5720'MD,Camco 3-1/2"x 1-1/2"MMG,DV rata I 6011'MD,Camco 3-1/2"x 1- "MMG,DV Unknown/Form Fluid ?-� 6077'MD,Baker 20'80-40 PBR Pin for 40 klbs Shear Release,Space-Out Seals 7' 6100'MD,Baker 7"x 3-%"FHL Packer .- Pin for 60 klbs Shear Release 6158'MD Camco 2.813"DS Landing Nipple ;...�� �:. w/RHC Plug Body Installed for Ball 6 Rod 6211'MD,BOT Stripped Seal WLEG 6212 St'rip pacg from existing seal assembly,1'Space-Out MD,BOTkin10'PBR . a f-6227'MD,BOT 7"x 3-1/2"HB Packer �� 56 klb Straight-Pull Shear or Rotational Release 6265'MD,Otis 3-1/2"x 1-1/2"LBX GLM(DV) �, Wit-6336'MD,Otis 3-1/2"x 1-1/2"LBX GLM(DV) c 1. -4 6367'-6433'MD,Carbide Blast Rings On 3-Ya 9.2#J-55 BTCM Tubing Kuparuk C-Sand Perforations f-I 6452'MD,Otis 3'/2"x 1-1/2"LBX GLM(DV) C-4,1982-6372'-6400'MD C-4,1982-6404'-6410'MD C-3,1982-6417'-6428'MD -6461'MD,Baker 7"x 3-1/2"HB Packer 56 klb Straight-Pull Shear or Rotational Release C-1,1986-6472'-6496'MD 6467-6501'MD,Carbide Blast Rings On 3-W 9.2#J-55 BTCM Tubing r t 6510'MD,Camco 3-1/2"x 1"KBUG GLM(DV) -4-6547'MD,Camco AVA BPL Nipple Isolation Sleeve Installed r .#01-F-6554'MD,BOT Seal Assembly(1'Space-Out) t 6555'MD,7"x 3'1/2"BOT 1B Packer w/5'SBE f 1 .40 6565'MD,Jet-Cut 2-%"Tubing Stub Kuparuk A-Sand Perforations A-5,1982-6634'-6641'MD A-4,1982-6647'-6656'MD Production Casing Primary Cement -11'Tubing Tail Fish,6650'MD ] TOC-4860'MD(CBL 31-May-1982) 133 bbls 11.4 ppg Columbia Class'G'Lead 82 bbls 15.8 ppg Columbia Class'G'Tail 7"26#J-55 BTC,6900'MD-11.-L ' I Date. 19Ju1-2016 j Drawn By: Danny Kane • Kane, Danny From: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Sent: Tuesday,July 19,2016 8:35 AM To: Kane,Danny Subject: [EXTERNAL]RE:KRU 1H-06-Change of RWO Scope Requiring Altering Production Casing Categories: 1H-06 Danny, Approval is granted to proceed with this alternative procedure as written. Please submit a change of approved program as soon as possible. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepoaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.aov From: Kane, Danny [mailto:Danny.Kane@conocophillips.com] Sent: Monday,July 18, 2016 4:19 PM To: Loepp, Victoria T(DOA) Subject: KRU 1H-06 - Change of RWO Scope Requiring Altering Production Casing Importance: High Victoria, ConocoPhillips is currently working over the shut-in producer KRU 1H-06 in preparation for CTD development and encountered subsidence-induced damage of the 7" production casing that requires us to perform work on the 7" production casing as well as possibly on the 10-%"surface casing. Can you please review below and advise if the AOGCC is OK with ConocoPhillips to proceed ahead with our plan forward? I have attached the Pre-RWO schematic and the planned RWO schematic(I have not updated it yet to show the subsidence repair). A brief history: The well was added to the work-over schedule earlier this year when attempts to pull a retrievable tubing patch (above the production packer)were unsuccessful. With coil drilling unable to drift the patch,the well went to RWO for the following scope: • Pull& Replace the 3-%2" Upper Completion to remove the tubing patch restriction. • Swap the Inner Casing Secondary Pack-Off(bad test history). • A pre-rig tubing chemical cut was performed at 5,680' MD (above the tubing patch). 1 • • Doyon 141 moved on KRU 1H-06&accepted on 03:00 15-Jul-2016. The following has occurred: • MIRU, R/U surface equipment for well kill. • Pulled BPV. • Kill well with 8.5 ppg seawater. Well killed,slight vacuum, passing no-flow test. o Prognosed Reservoir Pressure: The well is open to the A-sand, but shut-off from the C-sand. ■ Kuparuk A-Sand Perforations at 6645' MD/6623'TVD:2768 psig/8.1 ppg EMW ■ Kuparuk C-Sand Perforations: Unknown, modeling shows<seawater gradient, C-sand selective shut-in since 2011. • Install BPV. ND Tree/NU BOPE. • Conduct BOPE test(AOGCC Field Inspector waived witness)to 250/3000 psig(pipe rams&annular). o Prognosed MPSP w/2768 psig reservoir pressure =2768 psig—(0.1*6623'TVD) =2106 psig o NOTE:AOGCC Field Inspector informed that because of tight tolerances between the Lower Pipe Ram & the tubing hanger neck,the rams would be tested on the 4"test joint (for the drill pipe) after pulling the 3-Y2"tubing. • Unseated tubing hanger and pulled & L/D 3-%2"tubing to pre-rig tubing cut at 5,680' MD. o NOTE: Issues encountered while TOH where slack-off weight lost &tubing cut showed indications of having been performed in high compression. • Finished BOPE test w/4"test joint to 250/3000 psig. • TIH w/3%"tubing stub fishing assembly(to go after the remaining Upper Completion tubing to the Seal Assembly) & lost slack-off weight at 36' MD. Attempt to push down, stop at 50' MD w/5klbs top drive weight. • Decision made to Grow/Stretch 7" Production Casing(wellhead work intended to be performed after Upper Completion was out of the hole). • TIH w/4" drill pipe to 1420' MD to hang-off below storm packer to use as barrier—having to push drill pipe down at 1420' MD w/ 10 klbs top drive weight, never able to freely slack-off. Decision made to TOH, R/B drill pipe, &call-out E-Line. • R/U Dutch Riser& E-Line,Set IBP at 2,990' WLM. Log Multi-Finger Caliper&Cement Bond Log from above IBP to surface (surface casing shoe 2,194' MD). o Caliper showed severely buckled tubing from surface to TOC(OA squeeze performed in 1982) at^'1,690' MD. Processed caliper results returned in the morning(18-Jul-2016) o RWO Officially Turned into Subsidence RWO at this time. o Set Aside E-Line& R/D Dutch Riser(Crew Timed Out) • 55' of sand dumped on top of IBP. Combo IA x OA pressure test to 2,500 psig performed to test IBP from above (IA x OA communication through wellhead pack-offs). Good test. • N/D BOPE stack. • Used Hydratight to grow the 7" production casing(27" of growth, 61" of documented wellhead subsidence prior to RWO). • N/U BOPE stack, changed Lower Pipe Rams to 7"solid body rams,test the break, Lower Pipe Rams, &annular w/7"test joint to 250/2,500 psig (reduced test pressure because of 10-3/4" burst rating). • Currently R/U E-Line. Plan Forward: • N/U Dutch Riser, R/U E-Line, Chemical Cut 7" Production Casing at"'1,632' MD(OA Squeeze TOC logged at 1,690' MD). R/D Dutch Riser& E-Line o 5" Extended Reach for 7" Casing • Spear 7" Production Casing Hanger, P/U, Close Rams Around the 7" Production Casing to divert fluids, and circulate out Arctic Pack in OA to Kill Tanks with hot diesel &water. • TOH & L/D 7" Casing to Chemical Cut at 1,632' MD. • Drift 10-3/4" Casing& Dress-Off 7" Casing Stub at 1,632' MD. 2 • • o If drift issues are encountered, mill 10-%"surface casing as needed to obtain drift access for the new 7" production casing string. • Run new 7" 26#L-80 Hydril 563 production casing w/casing overshot patch & Halliburton Type H ES stage cementer, engage, & latch-on to 7" casing stub. Install cementing head. • Pressure-test 7" casing to 2,000 psig to verify casing overshot integrity (pressuring-up against IBP set at 2,990' WLM). • Pressure-up on 7" casing to open stage cementer(target 2,500 psig opening pressure), circulate to clean OA, close rams. • Pressure-test to IA x OA 2,500 psig to verify casing overshot integrity to full IA test pressure. • Pump cement OA to surface, bump plug in stage cementer. o Stage Cementer to be within 100' MD of the existing TOC, plan to cement entire annulus from existing OA TOC at 1,690' MD to surface. • ND cement head &WOC to achieve 500 psig compressive strength. • Once 500 psig compressive strength achieved, monitor production casing&OA for flow. • N/D BOPE stack, land casing in slips. Cut excess casing. Install pack-offs & new tubing head. Pressure-test pack-off to 4,300 psig. Shell-test BOP stack&all breaks to 250/3,000 psig. • TIH w/Clean-Out Assembly to Drill-Out stage cementer. • TIH w/Clean-Out Assembly to clean-out debris on top of sand above IBP. Clean-out sand. • Retrieve IBP. • Resume original work-over scope: o MU &TIH while picking-up drill pipe with the tubing stub fishing assembly, engage the tubing stub, & pull tubing free to the seal assembly in the BOT PBR at 6,212' MD. TOH racking pipe, L/D assembly, & L/D fish. o MU &TIH w/racked back pipe&casing scraper/PBR clean-out assembly. Clean-out to the PBR& obtain IA pressure-test w/clean-out stinger in PBR. o MU &TIH with the new 3-Y2"Stacked Packer Upper Completion. Using the old seal assembly stripped of packing as WLEG into the existing PBR,tag,fully-locate, &space-out 1'from fully-located. o Spot C.I. brine pill, drop ball & rod, &set FHL packer. Pressure-test IA to 2,500 psig to confirm packer has set. Shear seal assembly from PBR. o Slack-off to tag seal assembly on PBR, space-out seal assembly into PBR, mark-pipe at surface, & lay-down two joints. Space-out with tubing pups, M/U tubing hanger, M/U landing joint. o Displace IA to C.I. brine, stab seals, land hanger, & RILDS. o Pressure-test tubing to 3,000 psig& IA to 2,500 psig. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV. o Back-out landing joint & install BPV. o ND BOPE, make-up Plug-Off tool to the BPV, NU tree, & pressure test tree. Remove Plug-Off tool& BPV. o Freeze protect well through SOV. Set BPV. o RDMO Doyon 141. Please advise if you are OK with our plan forward and if we need to submit any additional paperwork to the state. Please call me at 907-227-6037 if you have any questions. 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Can you please review below and advise if the AOGCC is OK with ConocoPhillips to proceed ahead with our plan forward? I have attached the Pre-RWO schematic and the planned RWO schematic(I have not updated it yet to show the subsidence repair). A brief history: The well was added to the work-over schedule earlier this year when attempts to pull a retrievable tubing patch (above the production packer)were unsuccessful. With coil drilling unable to drift the patch,the well went to RWO for the following scope: • Pull & Replace the 3-Y2" Upper Completion to remove the tubing patch restriction. • Swap the Inner Casing Secondary Pack-Off(bad test history). • A pre-rig tubing chemical cut was performed at 5,680' MD(above the tubing patch). Doyon 141 moved on KRU 1H-06&accepted on 03:00 15-Jul-2016. The following has occurred: • MIRU, R/U surface equipment for well kill. • Pulled BPV. • Kill well with 8.5 ppg seawater. Well killed, slight vacuum, passing no-flow test. o Prognosed Reservoir Pressure: The well is open to the A-sand, but shut-off from the C-sand. • Kuparuk A-Sand Perforations at 6645' MD/6623'ND:2768 psig/8.1 ppg EMW • Kuparuk C-Sand Perforations: Unknown, modeling shows<seawater gradient, C-sand selective shut-in since 2011. • Install BPV. ND Tree/NU BOPE. • Conduct BOPE test(AOGCC Field Inspector waived witness)to 250/3000 psig(pipe rams&annular). o Prognosed MPSP w/2768 psig reservoir pressure=2768 psig—(0.1*6623'ND) =2106 psig o NOTE:AOGCC Field Inspector informed that because of tight tolerances between the Lower Pipe Ram & the tubing hanger neck,the rams would be tested on the 4"test joint(for the drill pipe) after pulling the 3-%Z"tubing. • Unseated tubing hanger and pulled & L/D 3-Y2"tubing to pre-rig tubing cut at 5,680' MD. o NOTE: Issues encountered while TOH where slack-off weight lost&tubing cut showed indications of having been performed in high compression. • Finished BOPE test w/4"test joint to 250/3000 psig. 1 • TIH w/3-1/2"tubing stub fishing assembly(to go after the remaining Upper Completion tubing to the Seal Assembly)& lost slack-off weight at 36' MD. Attempt to push down,stop at 50' MD w/5klbs top drive weight. • Decision made to Grow/Stretch 7" Production Casing(wellhead work intended to be performed after Upper Completion was out of the hole). • TIH w/4" drill pipe to 1420' MD to hang-off below storm packer to use as barrier—having to push drill pipe down at 1420' MD w/10 klbs top drive weight, never able to freely slack-off. Decision made to TOH, R/B drill pipe, &call-out E-Line. • R/U Dutch Riser& E-Line,Set IBP at 2,990'WLM. Log Multi-Finger Caliper&Cement Bond Log from above IBP to surface (surface casing shoe 2,194' MD). o Caliper showed severely buckled tubing from surface to TOC(OA squeeze performed in 1982)at 1,690' MD. Processed caliper results returned in the morning(18-Jul-2016) o RWO Officially Turned into Subsidence RWO at this time. o Set Aside E-Line& R/D Dutch Riser(Crew Timed Out) • 55'of sand dumped on top of IBP. Combo IA x OA pressure test to 2,500 psig performed to test IBP from above (IA x OA communication through wellhead pack-offs). Good test. • N/D BOPE stack. • Used Hydratight to grow the 7" production casing(27" of growth,61" of documented wellhead subsidence prior to RWO). • N/U BOPE stack,changed Lower Pipe Rams to 7" solid body rams,test the break, Lower Pipe Rams, &annular w/7"test joint to 250/2,500 psig(reduced test pressure because of 10-%" burst rating). • Currently R/U E-Line. Plan Forward: • N/U Dutch Riser, R/U E-Line,Chemical Cut 7" Production Casing at 1,632' MD (OA Squeeze TOC logged at 1,690' MD). R/D Dutch Riser& E-Line o 5" Extended Reach for 7" Casing • Spear 7" Production Casing Hanger, P/U,Close Rams Around the 7" Production Casing to divert fluids,and circulate out Arctic Pack in OA to Kill Tanks with hot diesel &water. • TOH & L/D 7"Casing to Chemical Cut at 1,632' MD. • Drift 10-W' Casing& Dress-Off 7" Casing Stub at 1,632' MD. o If drift issues are encountered, mill 10-%" surface casing as needed to obtain drift access for the new 7" production casing string. • Run new 7" 26# L-80 Hydril 563 production casing w/casing overshot patch & Halliburton Type H ES stage cementer,engage, & latch-on to 7" casing stub. Install cementing head. • Pressure-test 7" casing to 2,000 psig to verify casing overshot integrity(pressuring-up against IBP set at 2,990' WLM). • Pressure-up on 7" casing to open stage cementer(target 2,500 psig opening pressure),circulate to clean OA, close rams. • Pressure-test to IA x OA 2,500 psig to verify casing overshot integrity to full IA test pressure. • Pump cement OA to surface, bump plug in stage cementer. o Stage Cementer to be within 100' MD of the existing TOC, plan to cement entire annulus from existing OA TOC at 1,690' MD to surface. • ND cement head &WOC to achieve 500 psig compressive strength. • Once 500 psig compressive strength achieved, monitor production casing&OA for flow. • N/D BOPE stack, land casing in slips. Cut excess casing. Install pack-offs& new tubing head. Pressure-test pack-off to 4,300 psig. Shell-test BOP stack&all breaks to 250/3,000 psig. • TIH w/Clean-Out Assembly to Drill-Out stage cementer. • TIH w/Clean-Out Assembly to clean-out debris on top of sand above IBP. Clean-out sand. • Retrieve IBP. • Resume original work-over scope: 2 o MU &TIH while picking-up drill pipe with the tubing stub fishing assembly,engage the tubing stub, & pull tubing free to the seal assembly in the BOT PBR at 6,212' MD. TOH racking pipe, L/D assembly,& L/D fish. o MU &TIH w/racked back pipe&casing scraper/PBR clean-out assembly. Clean-out to the PBR&obtain IA pressure-test w/clean-out stinger in PBR. o MU &TIH with the new 3%"Stacked Packer Upper Completion. Using the old seal assembly stripped of packing as WLEG into the existing PBR,tag,fully-locate, &space-out 1'from fully-located. o Spot C.I. brine pill, drop ball & rod, &set FHL packer. Pressure-test IA to 2,500 psig to confirm packer has set. Shear seal assembly from PBR. o Slack-off to tag seal assembly on PBR,space-out seal assembly into PBR, mark-pipe at surface,& lay-down two joints. Space-out with tubing pups, M/U tubing hanger, M/U landing joint. o Displace IA to C.I. brine,stab seals, land hanger, & RILDS. o Pressure-test tubing to 3,000 psig& IA to 2,500 psig. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV. o Back-out landing joint&install BPV. o ND BOPE, make-up Plug-Off tool to the BPV, NU tree, &pressure test tree. Remove Plug-Off tool & BPV. o Freeze protect well through SOV. Set BPV. o RDMO Doyon 141. Please advise if you are OK with our plan forward and if we need to submit any additional paperwork to the state. Please call me at 907-227-6037 if you have any questions. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 3 McEvoy Gen I/ (5M) KRU 1H-06 ConocoPhillips 7'1,6"x3'/z"EUETbgHgr Hgr 4 Kuparuk A-&C-Sand Producer Proposed 2016 RWO 16"62.58#H-40 WLD,128'MD--11P- --, Replace I.C.Secondary Pack-Offs,Retrofit tr. Surface Casing Primary Cement C-Bowl Tubing Head 342 bbls 12.2 ppg Arctic Set III 42 bbls 15.2 ppg Arctic Set 1I OA Shoe Squeeze Est TOC 2000'MD 41.4 bbls 15.2 ppg Arctic Set 11 98 bbls 7.3 ppg Arctic Pack --3-1/2"9.3#L-80 EUE-BRD AB-Mod R2 Tubing 10'/1"45.5#K-55 BTC,2193'MD—.-110-4 4 . 2502'MD,Camco 31/2'x 1-Y."MMG,DV Drilling Mud/Spacer - I 3710'MD,Camco 3-W'x 1-1/2"MMG,DV Lead Cement Tail Cement —4617'MD,Camco 3-1/2"x 1-1/2"MMG,SOV Arctic Pack SOV Pinned 2000 psig IA-1 T Shear Diesel II —5270'MD,Camco 3'/z"x 1-1/2"MMG,DV Kill Weight Fluid II —5720'MD,Camco 3-1/2"x 1-Y2"MMG,DV Unknown/Form Fluid 6011'MD,Camco 3'1/2"x 1-1/2"MMG,DV o - —6077'MD,Baker 20'80-40 PBR Pin for 40 klbs Shear Release,Space-Out Seals 7 Or ° --6100'MD,Baker 7"x 3-1/2"FHL Packer a Pin for 60 klbs Shear Re/ease 6158'MD Camco 2.813"DS Landing Nipple w/RHC Plug Body Installed for Ball&Rod 6211'MD,BOT Stripped Seal WLEG Strip packing from ex r seal assembly,1'Space-Ow 6212'MD,BOT 10'PBR I __ 6227'MD,BOT 7"x 3'/z"HB Packer • '='""-- 56 klb Straight-Pull Shear or Rotational Release 1 I 6265'MD,Otis 3'/2"x 1-1/2"LBX GLM(DV) iii If6336'MD,Otis 3'/z"x 1-1/2"LBX GLM(DV) = r 't• 6367'4433'MD,Carbide Blast Rings On 3-W 9.2#J-55 BTCM Tubing Kuparuk C-Sand Perforations _ flir 4 6452'MD,Otis 3'1/2"x 1-1/2"LBX GLM(DV) C-4,1982-6372'-6400'MD C-4,1982-6404'-6410'MD 41 6461'MD,Baker 7"x 3-1/2"HB Packer C-3,1982—6412'-6428'MD --- 56 klb Straight-Pull Shear or Rotational Release C-1,1986-6472'-6496'MD 1 r 1 40—6467-6501'MD,Carbide Blast Rings IOn 3-M•"9.2#J-55 BTCM Tubing 6510'MD,Camco 3-1/2"x 1"KBUG GLM(DV) I / 6547'MD,Camco AVA BPL Nipple Isolation Sleeve Installed i Io f•+--6554'MD,BOT Seal Assembly(1'Space-Out) 11- I. E 4 6555'MD,7"x 3-Y2"BOT 1B Packer wl 5'SBE — h 4 6565'MD,Jet-Cut 2-1/2"Tubing Stub Kuparuk A-Sand Perforations A-5,1982-6634'-6641'MD A-4,1982-6647'-6656'MD Production Casing Primary Cement -11'Tubing Tail Fish,6650'MD —► c TOC-4860'MD(CBL 31-May-1982) 14� 133 bbls 11.4 ppg Columbia Class'G'Lead 82 bbls 15.8 ppg Columbia Class`G'Tail 7"26#J-55 BTC,6900'MD---110-L I Date: 30-Jun-2016 1 Drawn By: Denny Kane McEvoy Gen 1/III 7't�e'x3'/:"EUETbgHr gKRU 1H-06 ConocoPhillips Kuparuk A-&C-Sand Producer L. Current Status-30-Jun-2016 16"62.58#H-40 WLD,128'MD Surface Casing Primary Cement 342 bbls 12.2 ppg Arctic Set Ill 42 bbls 15.2 ppg Arctic Set 11 OA Shoe Squeeze 1Gs I f----I 1777'MD,Camco 3-16"TRDP-IA-SSA SSSV Est TOC 2000'MD 31 Stainless Steel Bands 41.4 bbls 15.2 ppg Arctic Set it 98 bbls 7.3 ppg Arctic Pack 3-Y2"9.2#J-55 IPC BTCM 10-1/2"45.5#K-55 BTC,2193'MD�♦► - i --�—2218'MD,Camco 3'/:"x 1"KBUG,DV I) Drilling Mud/Spacer .--I 3582'MD,Camco 3-1"x 1"KBUG,DV Lead Cement ■� -4 4327'MD,Camco 3'/2"x 1"KBUG,DV Tail Cement •I --- —4672'MD,Camco 3-1/2"x 1"KBUG,DV Arctic Pack Diesel �+---4958'MD,Camco 3-Y2"x 1"KBUG,DV Kill Weight Fluid 4 5277'MD,Camco 3'/2"x 1"KBUG,DV Unknown/Form Fluid f—,--5565'MD,Camco 3'/2"x 1"KBUG,OPEN 5680'MD— ig Tubing Cut— OV pulled&pocket left open during pre-hg work. WFT ER tipper Patch Packer,5834'MD ►��} �.I Spacer Tube Threaded to Packer 4 5851'MD,OtiS 3'/2"x 1'/a"LBX GLM,DV WFT ER Lower Patch Packer,5865'MD rI Leak in side of GLM 88 �1■�--I 6171'MD,Otis 3'/2"x 1-1/2"LBX GLM,DV Mt - F 6212'MD,BOT 10'PBR&Seal Assembly to 6227'MD,BOT 7"x 3-'4"HB Packer 56 klb Straight-Pull Shear or Rotational Release Iwo 4 6265'MD,Otis 3'/2"x 1'/a"LBX GLM(DV) (, 1110■ 4 6336'MD,Otis 3'/2"x 1-1/2"LBX GLM(DV) �----6367'-6433'MD,Carbide Blast Rings On 3-W 9.26 J-55 BTCM Tubing Kuparuk C-Sand Perforations Na 4 6452'MD,Otis 3'/2"x 1'/2"LBX GLM(DV) C-4,1982-6372'-6400'MD C-4,1982-6404'-6410'MD 6461'MD,Baker 7"x 3-1/2"HB Packer C-3,1982—641 T-6428'MD 56 klb Straight-Pull Shear or Rotational Release C-1,1986-6472'-6496'MD �—64674501'MD,Carbide Blast Rings On 3-ic 9.28 J-55 BTCM Tubing 6510'MD,Camco 3-1/2"x 1"KBUG GLM(DV) I_ I 1 - 4 6547'MD,Camco AVA BPL Nipple Isolation Sleeve Installed m- u 4 6554'MD,BOT Seal Assembly(1'Space-Out) 6555'MD,7"x 3'1/2'BOT 1B Packer w/5'SBE i 6565'MD,Jet-Cut 2-1/2'Tubing Stub Kuparuk A-Sand Perforations A-5,1982-6634'-6641'MD A-4,1982-6647'-6656'MD Production Casing Primary Cement -11'Tubing Tail Fish,6650'MD �. TOC-4860'MD(CBL 31-May-1982) 133 bbls 11.4 ppg Columbia Class'G'Lead 82 bbls 15.8 ppg Columbia Class'G'Tail 7"26#J-55 BTC,6900'MD—OL Date: sD 1un-2Dis F Drawn By: Danny Kane Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Wednesday,July 20, 2016 4:41 PM To: Loepp,Victoria T(DOA) Subject: RE: KRU 1H-06 - Change of RWO Scope Requiring Altering Production Casing (PTD 182-068) Follow Up Flag: Follow up Flag Status: Flagged Victoria, I wanted to provide an update to the subsidence repair being performed on KRU 1H-06. We were able to cut the 7" production casing at 1,636' MD&successfully retrieve the damaged casing to surface. We made a drift run with a casing stub dress-off assembly with no issues and were able to dress-off the casing stub to prepare it for the Bowen casing overshot patch. This afternoon we were able to run the new 7"casing tieback string(with stage cementer&overshot) and we are currently engaging the overshot to tie the new casing into the existing casing stub. I will have the Sundry as requested submitted tomorrow. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.govj Sent:Tuesday,July 19,2016 8:35 AM To: Kane, Danny<Danny.Kane@conocophillips.com> Subject: [EXTERNAL]RE: KRU 1H-06-Change of RWO Scope Requiring Altering Production Casing Danny, Approval is granted to proceed with this alternative procedure as written. Please submit a change of approved program as soon as possible. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 1 Victoria.Loepp(cilalaska.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.Loepo@alaska.gov From: Kane, Danny[mailto:Dannv.KaneOconocophillios.com] Sent: Monday,July 18, 2016 4:19 PM To: Loepp, Victoria T(DOA) Subject: KRU 1H-06-Change of RWO Scope Requiring Altering Production Casing Importance: High Victoria, ConocoPhillips is currently working over the shut-in producer KRU 1H-06 in preparation for CTD development and encountered subsidence-induced damage of the 7" production casing that requires us to perform work on the 7" production casing as well as possibly on the 10-3"surface casing. Can you please review below and advise if the AOGCC is OK with ConocoPhillips to proceed ahead with our plan forward? I have attached the Pre-RWO schematic and the planned RWO schematic(I have not updated it yet to show the subsidence repair). A brief history: The well was added to the work-over schedule earlier this year when attempts to pull a retrievable tubing patch(above the production packer)were unsuccessful. With coil drilling unable to drift the patch,the well went to RWO for the following scope: • Pull& Replace the 3-'A" Upper Completion to remove the tubing patch restriction. • Swap the Inner Casing Secondary Pack-Off(bad test history). • A pre-rig tubing chemical cut was performed at 5,680' MD(above the tubing patch). Doyon 141 moved on KRU 1H-06&accepted on 03:00 15-Jul-2016. The following has occurred: • MIRU, R/U surface equipment for well kill. • Pulled BPV. • Kill well with 8.5 ppg seawater. Well killed,slight vacuum, passing no-flow test. o Prognosed Reservoir Pressure: The well is open to the A-sand,but shut-off from the C-sand. • Kuparuk A-Sand Perforations at 6645'MD/6623'TVD:2768 psig/8.1 ppg EMW • Kuparuk C-Sand Perforations: Unknown,modeling shows<seawater gradient,C-sand selective shut-in since 2011. • Install BPV. ND Tree/NU BOPE. • Conduct BOPE test(AOGCC Field Inspector waived witness)to 250/3000 psig(pipe rams&annular). o Prognosed MPSP w/2768 psig reservoir pressure=2768 psig—(0.1*6623'ND)=2106 psig o NOTE:AOGCC Field Inspector informed that because of tight tolerances between the Lower Pipe Ram & the tubing hanger neck,the rams would be tested on the 4"test joint(for the drill pipe)after pulling the VA"tubing. • Unseated tubing hanger and pulled&L/D 3-1/4"tubing to pre-rig tubing cut at 5,680'MD. o NOTE: Issues encountered while TOH where slack-off weight lost&tubing cut showed indications of having been performed in high compression. • Finished BOPE test w/4"test joint to 250/3000 psig. • TIH w/3-34"tubing stub fishing assembly(to go after the remaining Upper Completion tubing to the Seal Assembly)& lost slack-off weight at 36' MD. Attempt to push down,stop at 50' MD w/5klbs top drive weight. 2 • Decision made to Grow/Stretch 7" Production Casing(wellhead work intended to be performed after Upper Completion was out of the hole). • TIH w/4"drill pipe to 1420' MD to hang-off below storm packer to use as barrier—having to push drill pipe down at 1420' MD w/10 klbs top drive weight,never able to freely slack-off. Decision made to TOH, R/B drill pipe,&call-out E-Line. • R/U Dutch Riser&E-Line,Set IBP at 2,990'WLM. Log Multi-Finger Caliper&Cement Bond Log from above IBP to surface(surface casing shoe 2,194' MD). o Caliper showed severely buckled tubing from surface to TOC(OA squeeze performed in 1982)at^'1,690' MD. Processed caliper results returned in the morning(18-Jul-2016) o RWO Officially Turned into Subsidence RWO at this time. o Set Aside E-Line&R/D Dutch Riser(Crew Timed Out) • 55'of sand dumped on top of IBP. Combo IA x OA pressure test to 2,500 psig performed to test IBP from above (IA x OA communication through wellhead pack-offs). Good test. • N/D BOPE stack. • Used Hydratight to grow the 7" production casing(27"of growth,61"of documented wellhead subsidence prior to RWO). • N/U BOPE stack,changed Lower Pipe Rams to 7"solid body rams,test the break, Lower Pipe Rams,&annular w/7"test joint to 250/2,500 psig(reduced test pressure because of 10-%" burst rating). • Currently R/U E-Line. Plan Forward: • N/U Dutch Riser, R/U E-Line,Chemical Cut 7" Production Casing at"1,632' MD(OA Squeeze TOC logged at 1,690' MD). R/D Dutch Riser&E-Line o 5" Extended Reach for 7" Casing • Spear 7" Production Casing Hanger, P/U,Close Rams Around the 7" Production Casing to divert fluids,and circulate out Arctic Pack in OA to Kill Tanks with hot diesel &water. • TOH& L/D 7"Casing to Chemical Cut at 1,632' MD. • Drift 10-%"Casing& Dress-Off 7"Casing Stub at 1,632' MD. o If drift issues are encountered,mill 10-%"surface casing as needed to obtain drift access for the new 7" production casing string. • Run new 7" 26#L-80 Hydril 563 production casing w/casing overshot patch& Halliburton Type H ES stage cementer,engage,&latch-on to 7"casing stub. Install cementing head. • Pressure-test 7"casing to 2,000 psig to verify casing overshot integrity(pressuring-up against IBP set at 2,990' WLM). • Pressure-up on 7"casing to open stage cementer(target 2,500 psig opening pressure),circulate to clean OA, close rams. • Pressure-test to IA x OA 2,500 psig to verify casing overshot integrity to full IA test pressure. • Pump cement OA to surface, bump plug in stage cementer. o Stage Cementer to be within 100' MD of the existing TOC, plan to cement entire annulus from existing OA TOC at 1,690'MD to surface. • ND cement head&WOC to achieve 500 psig compressive strength. • Once 500 psig compressive strength achieved, monitor production casing&OA for flow. • N/D BOPE stack, land casing in slips. Cut excess casing. Install pack-offs&new tubing head. Pressure-test pack-off to 4,300 psig. Shell-test BOP stack&all breaks to 250/3,000 psig. • TIH w/Clean-Out Assembly to Drill-Out stage cementer. • TIH w/Clean-Out Assembly to clean-out debris on top of sand above IBP. Clean-out sand. • Retrieve IBP. • Resume original work-over scope: 3 o MU&TIH while picking-up drill pipe with the tubing stub fishing assembly,engage the tubing stub,&pull tubing free to the seal assembly in the BOT PBR at 6,212'MD. TOH racking pipe,LID assembly,&LID fish. o MU &TIH w/racked back pipe&casing scraper/PBR clean-out assembly. Clean-out to the PBR&obtain IA pressure-test w/clean-out stinger in PBR. o MU &TIH with the new 3%"Stacked Packer Upper Completion. Using the old seal assembly stripped of packing as WLEG into the existing PBR,tag,fully-locate, &space-out 1'from fully-located. o Spot C.I. brine pill,drop ball&rod,&set FHL packer. Pressure-test IA to 2,500 psig to confirm packer has set. Shear seal assembly from PBR. o Slack-off to tag seal assembly on PBR,space-out seal assembly into PBR,mark-pipe at surface,&lay-down two joints. Space-out with tubing pups, M/U tubing hanger, M/U landing joint. o Displace IA to C.I. brine,stab seals,land hanger,&RILDS. o Pressure-test tubing to 3,000 psig&IA to 2,500 psig. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV. o Back-out landing joint&install BPV. o ND BOPE, make-up Plug-Off tool to the BPV, NU tree, &pressure test tree. Remove Plug-Off tool& BPV. o Freeze protect well through SOV. Set BPV. o RDMO Doyon 141. Please advise if you are OK with our plan forward and if we need to submit any additional paperwork to the state. Please call me at 907-227-6037 if you have any questions. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 4 112- OCo`6 2.G`6'05 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. February 5, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECOVED FEB 10 2016 DATA LOGGED 2-/2.1/20,4 AOGCCM.K.BENDER RE: Jewelry Log: 1H-06 Run Date: 1/9/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1H-06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20741-00 Jewelry Log (Field Print) ,ANSE , v `` 1 color log 50-029-20741-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Ma'g -' 6--e4teeft Ima ~roject Well History File Cover XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original.file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing ~o,~ RESCAN Well History File Identifier DIGITAL DATA OVERSIZED (Scannable) n Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type Other items scannable by large scanner OVERSIZED (Non-Scannable) ~ Logs of various kinds [] Other BY: BEVERLY ROBIN VINCENT SHE~INDY Project Proofing ., BY: BEVERLY ROBIN VINCENT~ MARIA WINDY. Scanning Preparation BY: BEVERLY ROBIN ~ SHERYL MARIA WINDY Production Scanning Stage BY: Stage 2 BY: PAGE COUNT FROM SCANNED FILE: .~ Z.] "AGE COU.T MATC.ES.UMBE.,. SCA..,.G PREPARAT,O.: YES ,'~ BEVER.~:>VINCE.T S.ERYL ~ARIA WINDY DATEM~Z:~ ~B''p.~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION I$ REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALI'F'f , GRAY:SCALE OR DOLOR IMAGES) NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES .NO ReScanned (individual page [special at~e,tion] scat~ning completed) RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IS~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned,wpd UNSCANNED, OVERSI7EU MATERIALS AVAILABLE: ~,~~ ~ TILE # /~~ GCS L. 0 ~=- To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 1.00 Anchorage, Alasl~a 99501 Voice (907) 279-1433 ~ rax (907) 276-7542 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 16, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: g o d. 1 H -06 Run Date: 4/27/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 111 -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20741 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. , S r _ 2 0 Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 1) ;�'•— �f� 1 ( Signed: %,„.,y d1/44 • • lovx . . Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RE C 1 E June 5, 2011 1 : o ail S., on o. rt ;o ission Mr. Dan Seamount 1 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 (1i 9 [Oi Dear Mr. Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 111 -06 (PTD 182 -068) for a tubing patch that was pulled and reset. Please call Martin Walters or me at 659 -7224 if you have any questions. Sincerely, Brent Rogers ConocoPhillips Problem Well Supervisor Enclosures STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSI• 1 N1 r `- 1'0 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Rug Perforations r Stimulate r �f 9 , ' ems. rttltTltsilQn Alter Casing r Pull Tubing r Perforate New Pool r Chan Waiver Time Extension Change Approved Program Operat. Shutdown i� p 0 g pp g r op r Perforate r Re -enter Suspended Well �' ' 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 182 - 068 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 ` 50 - 029 - 20741 - 00" 00 7. Property DesignAtion (Lease Number): 8. Well Name and Number: ADL 25639 ALK 464 F 1H-06 9. Field /Pool(s): s , Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 6964 feet Plugs (measured) None true vertical 6942 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 5835, 5837, 5864, 6228, 6462 true vertical 0 feet (true vertucal) 5813, 5815, 5843, 6206, 6440 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 80 80 0 0 SURFACE (QC) 2194 10.75 2194 2194' 0 0 PRODUCTION 6900 7 6900 6878 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 6372' - 6400', 6404' - 6410', 6417'- 6428', 6472' - 6496', 6634'- 6641', 6647' - 6656' True Vertical Depth: 6350'- 6378', 6382'- 6388', 6395-6406', 6450'- 6474', 6612'- 6619', 6625' -6634' Tubing (size, grade, MD, and ND) 3.5 ", J -55, 6549' MD, 6527' ND 2.875 ", J -55, 6566' MD, 6544' ND Packers & SSSV (type, MD, and ND) PATCH PACKER - UPPER ER PACKER @ 5835 MD and 5813 TVD PATCH - SET SPACER PIPE & SNAP LATCH SEAL ASSEMBLY, OAL =31.2 @ 5837 MD PATCH PACKER - LOWER WEATHERFORD ER PACKER @ 5864 MD and 5843 ND PKR - BROWN HB -1 @ 6228 MD and 6206 ND PKR - BROWN HB -1 @ 6462 MD and 6440 TVD TRDP - CAMCO TRDP1A -SSA @ 1778 MD and 1778 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas Water - Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r '' Service r Stratigraphic r 15. Well Status after work: .< Oil J Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. 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: N/A Contact Brent Rogers /Martin Walters Printed Name Brent Rogers Title Problem Well Supervisor Signature Phone: 659 -7224 Date 6/5/2011 ,1 4.-- RBDMS JUN 07 MA Form 10-404 Revised 10/2010 7/‘ 6 1( Submit Original Only 044 • • 1H-06 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/18/11 DRIFT TBG 2.74" & TAGGED ER PKR @ 5842' RKB. SET ER TESTTOOL @ 5842' RKB, MITT PASSED. SI TIFL FAILED, IA INFLOWED 264'. ATTEMPT TO PULL PATCH ASS'Y @ 5842' RKB. LRS TO FREEZE PROTECT IA. IN PROGRESS 03/26/11 FIRST RUN WENT IN AND HAMMERED ON THE PATCH AT 5845 CTMD, PULLED PATCH TO SURFACE, RETOOLED AND WENT IN TO PULL BOTTOM PACKER ASSEMBLY AT 5867 CTMD, PULLED PACKER ASSEMBLY, JOB COMPLETE 04/21/11 GAUGED TBG TO 2.79" TO 5900' MD. BRUSHED & FLUSHED TBG f/ 5900' TO 5800' MD. READY FOR E/L SET ER PKR. 04/27/11 SET 3.5" WEATHERFORD ER PACKER AT 5867' CCL- ME =10' CCL STOP DEPTH 5857'. READY FOR SLICKLINE PATCH SET. 05/12/11 ITBG X IA TESTED @ LOWER ER PKR @ 5867' RKB TO 2500# FOR 15 MIN.GOOD. 1 dT 05/14/11 SET 3 1/2" ER PKR SPACEPIPE SNAP LATCH ASSY FROM 5865' RKB TO 5834' RKB (OAL =31' 2 ",MIN ID 1.75 ") ATTEMPT MITT.DHD TO TIFL AFTER BOL 06/04/11 TIFL (Passed), Initial T /I /O= 225/1170/944. Shot initial IA FL @ 5566' (Sta #7 OV). Shut the well and LG in. Stacked out tubing with LG, T /I /O= 990/970/780. Bleed IA down, T /I /O= 1000/400/745, and shoot 2nd IA FL @ same location. Final T /I /O= 1000/400/745. Summary Pulled previous patch. Set 30' Weatherford retrievable patch from element to element. TIFL passed following patch set. � I I I I � i KUP 1H-06 ConocoPhillips Well Attributes x Angle & MD TD Wel!bore APIIUWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) vilrlkps 500292074100 KUPARUK RIVER UNIT PROD 8.85 3500.00 6,964.0 Comment H23 (ppm) Data Annotation End Date KB (n) Rig Release Data "' _ SSSV: TROP 90 9/17/2010 Last WO: 7/22/1986 29.51 6/3/1982 Well Config: - 1H -06, 5892011 3'.36.28 PM - Schematic - Actual Annotation Depth (ftKB) End Data Annotation Last Mod ... End Date Last Tag: SLM 6,650.0 3/31/2011 Rev Reason: SET PATCH ASSY ninam 5/18/2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, 1 t CONDUCTOR 16 15.062 0.0 80.0 80.0 65.00 H - 40 WELDED 0-60 Casing Description String 0... 'String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SAFETY VLV, f - .o SURFACE(0C) 103/4 9.794 0.0 2,194.0 2,193.7 45.50 K - 55 1,778 Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd SURFACE PRODUCTION (OC) 7 6.151 0.0 6,900.0 6,878.0 26.00 K - 55 (GC), 0.2,194 GAS LIFT, Tubing Strings 2,218 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 0.0 6,549.0 6,527.1 9.20 J - 55 BTC AB - MOD Tubing Description String 0... String ID ... Top (11KB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd GAS LIFT _.. 3.582 TUBING 2 7/8 2.441 6,549.0 6,566.0 6,544.1 6.50 J-55 EUE 8RD Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, Top Depth 4.327 - (TVD) Top Inc/ Top (MB) (BBB) ( °) Description Comment Run Data ID (In) 1,778 1,777.9 0.86 SAFETY VLV Camco TRDP1A 7/22/1986 2.813 GAS LIFT, 4,873 ° - 2,218 2,217.7 1.97 GAS LIFT CAMCO /KBUG/1 /GLV /BK/.125/1295/ Comment: STA 1 12/24/2005 2.875 3,582 3,572.7 8.65 GAS LIFT CAMCO /KBUG/1 /GLV /BK/.156/1325/ Comment: STA 2 12/24/2005 2.875 GAS LIFT, 4,327 4,311.8 5.96 GAS LIFT CAMCO /KBUG/1 /DMY /BK/ // Comment: STA 3 2/22/2004 2.875 4 ' 4,673 4,655.8 5.82 GAS LIFT CAMCO /KBUG/1 /GLV /BK/.25/1465/ Comment: STA 4 12/24/2005 2.875 , 4,959 4,940.5 5.14 GAS LIFT CAMCO /KBUG/1/DMY /BK/ // Comment: STA 5 2/22/2004 2.875 GAS LIFT, °. -. 5,279 5,259.3 4.59 GAS LIFT CAMCO/KBUG/1/GLV/BK/.25/1455/ Comment: STA 6 12/24/2005 2.875 5.279 5,566 5,545.4 4.60 GAS LIFT CAMCO /KBUG/1 /OV /BK/.25// Comment: STA 7 12/31/2010 2.875 GAS LIFT, 5,835 5,813.2 3.69 PACKER UPPER ER PACKER 5/14/2011 1.800 5,568 r 5,837 5,815.5 3.67 PATCH SET SPACER PIPE 8 SNAP LATCH SEAL ASSEMBLY, 5/14/2011 1.750 OAL =31.2 PACKER, 5,835 PATCH, 5,837 .! 5,851 5,829.6 3.56 GAS LIFT CAMCO /KBUG/1 /DMY /BK/ // Comment: STA 8 2/25/2004 2.875 GAS LIFT, ,) 5,864 5,842.7 3.45 PACKER LOWER WEATHERFORD ER PACKER 4/27/2011 1.800 5,851 6,171 6,149.3 1.99 GAS LIFT OTIS/LBX/1.5/DMY/RM// / Comment STA 9 9/7/2004 2.906 PACKER, 5,864 6,212 6,190.3 1.63 PBR Brown 7/22/1986 2.813 6,228 6,206.3 1.66 PKR Brown HB-1 7/24/1986 3.000 GAS LIFT, 6,265 6,243.3 1.71 PRODUCTION OTIS/LBX/1.5/DMY /RM/ // Comment: CLOSED STA 10 4/27/1996 2.906 6,171 Iirr, 6,337 6,315.2 2.01 PRODUCTION OTIS /LBX/1.5/ DMY /RM/ // Comment: CLOSED STA 11 2/3/1999 2.906 6,453 6,431.2 1.95 PRODUCTION OTIS/LBX/1.5/DMY /RM/// Comment: CLOSED STA 12 2/3/1999 2.906 PBR, 6212 6,462 6,440.2 1.91 PKR Brown HB-1 7/22/1986 3.000 III 6,511 6,489.1 1.72 PRODUCTION CAMCO/KBUG/1/DMY/BK/// Comment CLOSED STA 13 11/20/1993 2.875 PKR, 6,228 W 6,543 6,521.1 1.60 PKR Brown 1B 722/1986 3.250 6,547 6,525.1 1.59 NIP BPL ported nipple. AVA. 7/22/1986 2.750 PRODUCTION, 6,547 6,525.1 1.59 SLEEVE -C AVA 2.75" BPI set 3 /31/2003 3/31/2003 2.320 6,265 Ilia! 6,549 6,527.1 1.58 TTL END OF TUBING CUT 822004 8/14/2004 2.441 6,556 6,534.1 1.55 Fish JDC SKIRT 3/11/2004 PRODUCTION, 6,650 6,628.1 1.40 TUBING TAGGED @ 6650' 8/12/2004 721/1986 2.441 6,337 II 6,650 6,628.1 1.40 Fish E -Line Cutter Toolstring TOOLSTRING LEFT IN HOLE 8/2/2004 8/2/2004, TAGGED 8/12/2004 IPERF, 6,3724400 6,652 6,630.1 1.40 VALVE TAGGED @ 6650' 8/12/2004 CAT STANDING VALVE 7/22/1986 IPERF, • • (FISHING NECK PULLED APART 3/29/04) 8,104-5,410 • ;. . • 6,652 6,630.1 1.40 NIP TAGGED @ 6650' 8/122004 Cameo 'D' Nipple NO GO 7/22/1986 2.250 IPERF, 5,417 -6,428 ' 6,660 6,638.1 1.39 SOS TAGGED @ 6650' 8/12/2014 Brown 7/22/1986 2441 6,661 6,639.1 1.39 TTL TAGGED @ 6650' 8/122004 7/22/1986 2.441 PRODUCTION, i 6,728 6,706.1 1.35 Fish 1 X 1 1/2 PIECE OF SKIRT Downhde 5/9/1996 6,453 . • i 6,728 6,706.1 1.35 Fish 1 JDC DOG Downhole 5/9/1996 1 PKR, 6,482 Perforations & Slots APERF, -- - Shot 5,470 -6,456 Top (TVD) Btm (TVD) Dens Top (11KB) Btm (ftKB) (RKB) (ftKB) Zone Data (.h... Type Comment 6,372 6,400 6,350.2 6,378.2 C 1H 6/1/1982 8.0 IPERF 90 deg Ph, 4" HyperJet II PRODUCTION, 6511 6,404 6,410 6,382.2 6,388.2 C-4, 11406 6/1/1982 8.0 IPERF 90 deg Ph, 4" HyperJet II 6,417 6,428 6,395.2 6,406.2 C-3, 1H-06 6/1/1982 8.0 IPERF 90 deg Ph, 4" HyperJet II PKR, 5,543 _ .. 6,472 6,496 6,450.2 6,474.1 C-1, UNIT B, 7/27/1986 12.0 APERF 120 deg Ph, 5" Csg Gun NIP, 6,54 Hill 1 H-06 I SLEE o, 7 6,634 6,641 6,612.1 6,619.1 A-5, 111-06 6/1/1982 8.0 IPERF 90 deg Ph, 4" HyperJet II 6,647 6,656 6,625.1 6,634.1 A-4, 1 H-O6 6/1/1982 8.0 IPERF 90 deg Ph, 4" HyperJet II Notes: General & Safety End Date Annotation OD 1/62005 NO TE: WAIVERED WELL: IA x OA COMMUNICATION Mandrel Details Fish, 5,556 Top Depth Top Port TTL, 8,599 (TVD) Inc! Valve Latch Sian TRO Run Stn Top (ftKB) (RKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Data Com... 1 2,218.4 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,295.0 12/24/2005 2 3,582.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,325.0 12/24/2005 IPERF, 8,634-6,641 3 4,327.1 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/22/2004 Fish, 6,650 4 4,672.5 CAMCO KBUG 1 GAS LIFT GLV BK 0.250 1,465.0 12/24/2005 IPERF, -.,t =_ = 5 4,958.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/22/2004 8,647-9856 ENIP, 6,852 VALVE, 6,652 = 6 5,277.8 CAMCO KBUG 1 GAS LIFT GLV BK 0250 1,455.0 12/24/2005 TUBING, 6,650 ° 1 7 5,565.6 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 12/31/2010 SOS, 5,650 8 5,851.1 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/25/2004 TTL, 6,651 MIL - Fisn, 6,725 9 6,171.4 OTIS LBX 1 12 GAS LIFT DMY RM 0.000 0.0 9/7/2004 Fish, 6,728 PRODUCTION EJ! 10 6265.5 OTIS LBX 1 1/2 PROD DMY RM 0.000 0.0 4/27/1996 Closed (DC 6, T ' TD, , 6,964 664 KUP • 1H -06 ConocoPhillips 0114 conocort KB-Grtl (R) Rig Release Date 29.51 6/3/1982 Well Confiq, - IH -06 5/192011 3'.36'.28 PM Schematic - Actual MIL Notes: General & Safety End Date Annotation CONDUCTOR, 9/23/2010 NOTE: Mandrel @ 5851- Suspect hole in mandrel -dmy pulled 2/25/04, flowcut but pkg in good conditiont o � 0 SAFETY VIN, m 9/23/2010 NOTE: View Schematic w/ Alaska Scheatic9.0 1,778 SURFACE (QC), 0 -2,194 GAS LIFT, f 2,218 t GAS LIFT, p 3,582 GA LIFT, f 4,327 GAS LIFT, _ 4,873 GAS LIFT, 4,959 f' GAS LIFT. 5,279 GAS LIFT, 5,566 PACKER, 5,835 PATCH, 5,837 GAS LIFT, 5,851 PACKER, 5,884 GAS LIFT, . 171 6,171 7 PBR, 6,212 PKR, 6,228 PRODUCTION, lag 6,265 PRODUCTION, 6,337 IPERF, 8,372-6,400 • IPERF, • 8,4045,410 -' IPERF, • •_ 6,4178,428 -- p PRODUCTION, I 8'453 ■ -i PKR, 8,462 APERF, 6,4728,496 - - PRODUCTION, 6,511 Elf PER. 8,543 , NIP, 6,547 SLEEVE-C,� 6,547 Mandrel Details Fish, 6,556 Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run TTL, 8,549 Ste Top (ftKB) (RKB) (') Make Model (in) Sery Type Type (in) (psi) Run Date Com... 11 6,336.7 OTIS LBX 1 1/2 PROD DMY RM 0.000 0.0 2/3/1999 Closed 12 6,452.7 OTIS LBX 1 1/2 PROD DMY RM 0.000 0.0 2/3/1999 Closed IPERF, 6,634.8,641 13 6,510.5 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 11/20/1993 Closed Fish, 6,650 IPERF, 6,6478,656 - stole_ NIP, 8,652 VALVE, 6,652 1 _ TUBING, 6,650 505, 6,660 TTL, 8,881 - Flsh, 6,728 Fish, 6,728 PRODUCTION (QC), 08,900 TD, 8,984 • ~~ ConocoPh i 1 I ~ ps Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ga.- p(o` Enclosed please. find a spreadsheet with a list of wells from the Kuparuk field (KRL)). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 17, 2008 and the corrosion inhibitor/sealant was pumped on February 2, and March- 8, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me or Perry Klein at 907-659-7043, if you have any questions.: Sincerely, ,,,.1 r f ~ /' ~/~~% ~ ~~' v V M.J. veland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Finaf top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 H-04 182-103 23" NA 23" NA 4.5 2/2/2008 1 H-06 182-068 28' 3.2 5" 1/17/2008 5.5 2/2/2008 1H-07 182-084 9' 3" 1 11" 1/17/2008 7 2/2/2008 1 H-08 182-093 SF NA SF NA 4 2/2/2008 1 E-31 .197-138 4'10" NA 4'10" NA 21 3/8/2008 1 E-32 197-132 8" NA 8" NA 3.5 3/8/2008 1 E-35 198-195 12" NA 12" NA 2 3/8/2008 1 E-36 198-213 20" NA 20" NA 4.5 3/8/2008 Re: IH-06 gas lift producer (PTD# 182-068) - permission to pull pat... . . Marie, I don't see a problem with this. Just file a 404 to document the results. Call or message with any questions. Tom Maunder, PE AOGCC SCANNED SEP 132005 NSK Problem Well Supv wrote, On 8/2/2006 4:50 PM: Tom, The TIFL was with the patch in place. The current well test data indicates that the well will not flow without gas lift. We intended to use gas lift during the flow test. Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, August 02, 20063:51 PM To: NSK Problem Well Supv Subject: Re: 1H-06 gas lift producer (PTD# 182-068) - permission to pull patch for evaluation - Perry, Is the TIFL with or without the patch? Will the well be produced via gas lift during the "month or so" of evaluation? Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 8/2/2006 3 :20 PM: Tom, CPAI would like verbal permission to pull the tubing patch set at 5844 - 5864' in order to evaluate 1 H-06 gas lift producer (PTD# 182-068) for possible conversion to a C-sands powered jet pump producer. The patch removal is necessary to facilitate running a production profile (PPROF), obtaining bottom hole static pressures, and drifting pre jet pump installation. The well passed a TIFL, T/I/O = 1100/500/500, for 1 hr with no fluid level change. CPAI would schedule well work to minimize flowing time to not exceed 30 days by pulling the patch, obtaining the static dunks, and performing the drift runs before flowing the well for an PPROF. 10f2 9/12/20069:50 AM Re: IH-06 gas lift producer (PTD# 182-068) - permission to pull pat... . Let me know if you have any questions. . Sincerely, Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 «1 H-06.pdf» 2 of2 9/12/20069:50 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO~$kê' 1 5 2004 Repair Well [2] Pull Tubing D Operat. ShutdownD Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 84' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: Stimulate D Waiver D Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development - [2] Stratigraphic D Exploratory D Service D 5. Permit to Drill Number: 182-068 6. API Number: 50-029-20741-00 Other Time Extension D Re-enter Suspended Well D 9. Well Name and Number: 1 H-06 10. Field/Pool(s): Kuparuk Oil Pool measured 6964' feet true vertical 6942' feet measured feet true vertical 6276' feet Length Size MD 80' 16" 80' 2110' 10-3/4" 2194' 6816' 7" 6900' Plugs (measured) Junk (measured) Burst Collapse TVD Measured depth: 6372-6400; 6404-6410; 6417-6428; 6472-6496; 6634-6641; 6647-6656 true vertical depth: 6350-6378; 6382-6388; 6395-6406; 6450-6474; 6612-665~~5-~,P) NOV "'U\H::J., 1 5 20041 Tubing (size, grade, and measured depth) 2-7/8", J-55, 6566' MD. Packers & SSSV (type & measured depth) pkr= BROWN HB-1 ; BROWN HB-1 ; BROWN HB-1 pkr= 6228'; 6462'; 6543' SSSV= SSSV SSSV= 1778' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A RBDMS BFL Nty, '1/ ,-, 1004 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 296 387 520 30 15. Well Class after proposed work: Exploratory D Development [2] Service D 16. Well Status after proposed work: Oil [2] GasD WAGD GINJD WINJ D 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: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations - Contact Printed Name Signature Oil-Bbl 243 377 Casinq Pressure Tubinq Pressure 1300 169 WDSPLD Brad Gathman/MJ Loveland @ 659-7224 Brad Gathman Title 3;v- h Phone Problem Wells Supervisor . /. 907 -659-7224 Date II/$--/ 0 '1 PreDared bv Sharon AllsuD-Drake 263-4612 Form 10-404 Revised 04/2004 ORtG'NAL RBDMS BFL N°~ul~t t9R3ina' Only ConocoPhillips Alaska, Inc. Kuparuk WelllH-06 (PTD 1820680) SUNDRY NOTICE 10-404 REPORT OF SUNDRY OPERATIONS 2004 November 8, 2004 This Report Of Sundry Operations is a summary of completed well operations that repaired ConocoPhillips (CPA) Kuparuk We1l1H-06 with a tubing patch. On October 31, 2004, a retrievable 3-1/2", 20-foot patch was set in the tubing from 5864' -5844' MD (20-feet including packers). The patch was set to cover a damaged gaslift mandrel at 5851' MD. The minimum ill on the patch is 1.75". A TIFL passed post patch. SCANNED NO\! 1. 5 2004 NSK Problem Well Supervisor ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 4, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION $2--t.0~ 1H-06 Stimulate ~-t'~D 1H-17 Stimulate ~q-i:?¢ 2X-1 5 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR030496 (w/o atch) RECEIVED Ar~c~race AR3B-6003-93 242-2603 STATE OF~ ( , ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 2. Name of Operator ARCO Alaska, In(;:. 3. Address P. O. Box 100360, Anchorage, Operation Shutdown Stimulate X Plugging Pull tubing ~ Alter casing ~ Repair well 5. Type of Well: Development X Exploratory _ Stratigraphic _ AK 99510 Service 4. Location of well at surface 648' FNL, 796' FEL, Sec 33, At top of productive interval 978' FNL, 721' FEL, Sec 33, At effective depth 976' FNL, 733' FEL, Sec 33, At total depth 975' FNL, 736' FEL, Sec 33~ 12. Present well condition summary Total Depth: RECEIVED Perforate Other 6. Datum elevation (DF or KB) RKB 85 7. Unit or Property name Kuparuk River Unit T12N, R10E, UM T12N, R10E, UM T12N, R10E, UM [\~P~ -9 'lga~ T12N~ R10E~ Ul~.~k~' 0it & (~as Cons. C~mmi: Anchorage measured 6 9 6 4 feet Plugs (measured) None true vertical 6942 feet feet 8. Well number 1H-06 9. Permit number/approval number 82-68 10. APl number ~Q-929-20741 11. Field/Pool ~i~Kuparuk River Field/ Oil Pool Effective depth: measured 6 8 1 3 feet true vertical 6791 feet Junk (measured) None Casing Length Size Cemented Measured depth Structural Conductor 7 8' 1 6" 321 Sx AS II 1 0 8' Surface 2165' 10 3/4" 1000 Sx AS III & 2194' Intermediate 250 SX AS II Production 6 8 7 4' 7" 665 Sx Class G & 6 9 0 0' Liner 250 Sx AS II Perforation depth: measured 6372'-6400', 6404'-6410', 6417'-6428', 6472°-6496', 6634'-6641', true vertical 6350'-6378', 6382'-6388', Tubing (size, grade, and measured depth) 6395'-6406', 6450'-6474', 6612'-6619', True vertical depth 108' 2194' 6878' 6647'-6656' 6625'-6634' 3.5", 9.2#, J-55 @ 6555', 2 7/8", 6.5#, J-55 @ 6555'-6576' !Packers and SSSV (type and measured depth) PKR: Brown 'HB-I' @ 6627', Brown 'HB-I' @ 6462', Brown 'lB' @ 6543'; 13. Stimulation or cement squeeze summary Refractured "A" Sands on 1/23/94. Intervals treated (measured) 6634'-6641', 6647'-6656' Treatment description including volumes used and final pressure Pumped 88 Mlbs of 16/20 & 12/18 ceramic proppant into form.~ fl:) was 4975 psi. 14. Re_Dresentative Daily Averaae Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure SSSV: Camco TRDP-4A @ 1825' Tubing Pressure Prior to well operation 268 73 8 900 340 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 1432 634 233 650 16. Status of well classification as: Oil X ...... Gas ~ Suspended Service 313 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Fnrm 10-4C)4 I::lnv i3R/1R/RR Date ~''' 4~r....~ ~ Ri JRMIT IN nL J'P~ ( ARCO Alaska, Inc. ~r Subsidiary of Atlantic Richfield Company WELL 1H-06 DATE 1/23/94 DA Y 1 TIME 060O 0930 ( KUPARUK RIVER UNIT WELL SERVICE REPORT DEScRIPTiON OF WORK ' IAF~/CC# 2 SCA# ' A Sand Refracture Treatment (Procedure dated 12/8/93) ! 998237 - 80529 ~0NTRACTOR / KEy pERSON' '. [FIELD COST EST. '[ACCUMULATED COST .DOWELL / Yoakum [ L $I27,402 [ $127,402 iI:;BTD (RKB) "ILAST tAq (RKB)-' DATE [sssv TYPE / STATUS , 6,813' ! 6,809 - 1/17/94 CAMCO TRDP-1A-SSA W/Frac Sleeve LOG ENTRY MIRU Dowell frac equipment and Veco pump. Hold safety meeting with all personnel. Install tree saver. Verify pop-off at 4,300 psi. Check all lines to be sure no ice plugs. QC fluids and sand. Set and test tree saver. PT lines to 8800#. Set trips at 7500#. Start pumping operations. RATE [ PRESSURE I VOL. I 7',CSG. st PUMP IN (slick water)-pumped at two different rates 35bpmI 6701 i 90 13487° O95O , ~.5 bpm [ 3850 - 3734 DATA FRAC (D,e, lay,.-XL,GW) 2Jl~Pm' ] ' 3803 Frac grad - 0.73 ,, ~ BREAKDOWN FLUSH (non- XL gel water w/5% diesel) .... Frac grad - 0.76 .._ ' 25'bPrn'} . 4,302 :- ,4 (73 .... 1 , 55 ' '], ' ' I ," 2105"",1, Closure-4863# Shut down 30 minutes for closure and calculations. Fluid efficiency = 52%, Reduce pad from . 170 bbl. to 130 bbl. Begin pumping frac (w/5% diesel }. Annulus ~ressure maintained at 3450 to ~500#. tTi't vOL. PROP. PRESSURE ~5 [ 130 25I 60 2s18° ,,2,s t 9o 25/ 100 25 I 45* O959 ~100 STAGE .... pad 1107 l ppa t108 2.ppG 1111. .4 ppG .1114 6 ppG _ , , 1117 8 ppG 1122 10 ppG FLUID Delay-XL GW Delay-XL GW Delay-XL GW Delay-XL GW Delay-XL GW Delay-XL GW tt Delay-XL GW 16/20 16/2O 16/20 12/18 12/18 ,, ~ 12/18 , 3908 4389 4375 4165 ,,, 3775 3721 , 4014 1126 12 ppg . Delay-XL GW 12/18 4091 Anchorage x , , .... *NOTE: Cut proppant 45 bbl: iht? 12 ppG ,stage due !o ,h.,i.gh p, mssure. IPressure began fluctuating 300 to 400 psi while pumping 8 to 12 ppg stages.,. IXICHECK I:HIs BLocK'IF SUMMARy iS cONTINU,-ED oN BAe,~' ' , IKi,"COM~,,LE~El l-,~ !N,~P,MPLETE Weathe;" [Temp. ChiilFactor [Visibil'ity'' [Wind-Vel. ]si'gn4d Report ,,, t ,,.72,5 °F -42 ,°F, [ Good , ,mi?si, REMARKS CONTINUED: · STAGE Flush 1131 1330 Diesel Flush Diesel FLUID .4 I,, 5 ..I 5533 Shut down frac. Clear surface lines and freeze protect. RD Dowell. Bled 7" casing to 500 psi. Dowell leaving location. Summary: Frac screened out at 12 ppa stage. Only 7 bbl. of diesel pumped for flush. · Total proppant pumped - 104,976# · 18,380# of 16/20 · 86,596# of 12/18 .. 88,000# in formation at 11. i ppa · 16,976# left in casing and tubing. Salt water pumped - 806 bbl. ...Diesel pumped - 15 bbl. Additives used - 55 bbl. ·Frac sleeve set in SsSV. SERVICE COMPANY DOWELL VECO PUMP & VAC TRUCK PEAK TRUCKING . H.E.S. LITTLE RED SERVICES PETREDAT Diesel t00 bbl. TOTAL FIELD ESTIMATE iii ...... iil ii i ii i ii i i i [ ii i ii i! i i i. i iiii llllll~ I I III IIII ..I III II I I I iii i i iiiiiiii Signed: DAILY $121,531 $2,000 $1,500 $t,825 $546 $127,402 11 iii i i ii i ii iiiii i i i i ~, ~..Cenz iiiii . [111 i i · mill ! ii / ACcuM, TOTAL $121,531 $2,000 $1,500 $1.,825 . $546 $127,402 ARCO Alaska, Inc~~ Post Offic~ ^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 9, 1987 Transmittal # 5914 RETURN TO: -- ARCO Alaska, Inc. Attn: 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. 1H-6 ' 3N-16 3N-15 CET 7-26-86 4700-6818 CET 6-7-86 7498-9090 CET 6-6-86 6942-8395 Receipt Acknowledged:. DISTRIBUTION: NSK Drilling Mobil Chevron AIast,,,a Oil & Gas Corl.s. ¢o~;nissic~-~ Anch..orag~ BPAE SAPC Unocal Vault ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 82-68 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360' 50- 029-20741 4. Location of well at surface 9. Unit or Lease Name 648' FNL, 796' FEL, Sec. 33, T12N, R10E, UM Kuparuk River Unit 10. Well Number At Top Producing Interval 978' FNL, 721' FEL, Sec. 33, T12N, R10E, UN 1H-6 At Total Depth 11. Field and Pool 975' FNL, 736' FEL, Sec. 33, T12N, R10E, UM Kuparuk River Field , 5. Elevation in feet (indicate KB, DF, etc.) 6, Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB ADL 25639 ALK 464 12. Date Spudded ' 13. Date T'.D, R'eached ' i4. Date Comp., Susp. or Aband. r''1i5, water Depth, if offshore 116. No. of Completions 5/19/82 5/28/82 6/02/82* . .. I ,N/.A .. feet MSL I 1 17. Total Depth (MD+TVD) ' 18.pl~g'Bacl~ bepth (MD~¥D) 1~9'. 'Di;ec'ti°nal S~'rvey I 20. Depth where Sssv se~ '1 21. Thickness of Permafrost" 6964'MD, 6942'TVD 6813'MD,6791 'TVD YES [~X NO [] I 1778 feet MD 1 1900' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/FDC/CNL/Cal/GR, D IL/BHCS/GR, FDC/CNL/GR/Cal, FDC/CNL/GR, RFT, CBL/VDL/CCL/GR, CET ,, '23.' '. ................................ iC.~.S!.N,'G..,r.L_ !.N..ER. A.N.D ~.'.E...M. ENTING....RECOBD_ SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 16,, bZ','b# H-~,U Surf ..... 1.08, ...... ~'/~h ....... ~:~1 sx AS II "'10'3/4" 45.5# ' K-55 Surf ...... ~i9~'i ....... "'13':~/2'''' ""1"06'~"''~x''AS'''I i i""'[ '2~0 Sx" liS' i'1 ~'" ' 26.0# K-55 Surf 6900, ...... 8'-3/4"' 665 eX'Class G & 250 sx AS II . '24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD') ' 6398' - 6404' ,/4 spf .... ~-1'/2" 6564' WLH' 6228',6462"&6543 6411' - 6422' " 6472' - 6496' w/12 spf, 120° phasing ~6.' .......... ACID. FR'A'CTuRE', cEMENT'sQuEEzE, ~'T~~. ...... 6628' - 6635' w/4 spf DEPTH INTERVAL (MD) AMOUNT & Ki:ND OF MATERIAL USED 6641 ' - 6650' " "'See Attached. ' ............................ 6636' - 6394'(twice) w/8 spf . 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I : . . Dat'e of Test Hours Tested PRODUCTION FOR OiiL.B. BL .... GAisi. McF .... WATER.B. BL ~HO.KiE .SlizE. ,ii GAs.oi~. RATIo TEST PERIOD 1.1~ .............I F'I°W' ~ubi~i'~ .... c'asi'n'g"Pressure CALCULATED OIL-BBL .... GAS-MCF wATER-BBL OIL GRAVITY-APl ('corr) ........ Press. 24-HOUR RATE ~ 'r28. ................ CORE DATA ' ' 'Brief description "of lith~logy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See attachment to Well Completion Report dated 6/17/82. EECEIVED OCT 2 o ]986 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 *Note: Well wasc(~l~_lkl~duEODV~)~l ~/E~L:/i~i~ siDWEC1/133 Submit in duplicate Rev. 7-1-80 NAME Include interval tested, pressure data, all fluids r~overed and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6373' 6351' Shut-in Base Upper Sand 6492' 6470' Depth Pressure Top Lower Sand 6625' 6603' Base Lower Sand 6722' $700' 6654' -- 6654' -- 6654' 3290' 6654' -- 6425' -- 6426' -- 6405' 3238' 6390' 3238' 6375' 3230' 6485' 3259' 6654' 3289' ~ 6636 3310' 6425' -- 6426' -- 6425.5' -- 6405' ~2~' 31. LISTOFATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ --~J_.~J Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report 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 pertinent 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 10407 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1H-6 Cont'd Item 26: HYDRAULIC FRACTURE Mix 8 ppg 20/40 frac sand. Tubing 7" Sta~ Pressure Pressure 1. Pre Pad 5190 1700 2. 100 Mesh 4070 1600 3. Pad 4200 1740 4. 3 ppg 4270 1830 5. 8 ppg 3900 1990 6. Flush 3600 1990 Design Volume 55 19 65 17 34 58 Actual Vol ume 60.5 21 72 19 20.5 60.5 Rate 19.3 20.4 20.4 19.4 16.0 Loosing suction 11.0 Average rate End frac, SITP = 2610 = 2600 = 2550 = 2500 Fracture completed 1815 hfs, 9/08/86. WC1/133b:dmr 10-13-86 STATE Of ALASKA LT OIL AND GAS CONSERVATION SION REPO OF SUNDRY WELL ERATIONS 1. Operations performed: Operation shutdown [] Stimulate .~ Plugging ~ Perforate ,~ Pull tubing Alter Casing [] Other~ Workover 2. Name of Operator ARCO Alaska, Inc, 3. Address P.0. Box 100360 Anchorage, AK 99510 4. Location of well at surface 648'FNL, 796'FEL, $ec.33, T12N, R10E, UN At top of productive interval 978' FNL, 721'FEL, Sec.33, T12N, R10E, UN At effective depth 976'FNL, 733'FEL, Sec.33, T12N, R10E, UM At total depth 975'FNL, 736'FEL, $ec.33, T12N, R10E, UN 5. Datum elevation (DF or KB) RKB 85' 6. Unit or Property name Kuparuk River Unit 7. Well number 1H-6 8. Approval number Permit #82-68 9. APl number 50-- 029-20741 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor. Surface 6964'MD 6942'TVD 6813'MD 6791'TVD Production Length Size 78 ' 16" 2165 ' 10-3/4" 6900 ' 7" feet feet feet feet Plugs (measured) Junk (measured) Cemented 321 sx AS II 1000 sx. AS III & 250 sx AS II 665 sx Class G & 250 sx AS II No n e No ne Measured depth 108'MD 2194'MD 6900'MD True Vertical depth 108 ' TVD 21.94 ' TVD 6878 ' TVD Perforation depth: measured 6398'-6404'MD 6411'-6422'MD true vertical 6376'-6382'TVD 6389' -6400' TVD Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail ~ 6564'WLM Packers and SSSV (type and measured depth) HB-1 pkr (~ 6228', 6462' 6472'-6496'MD 6628'-6635'MD 6450"6474'TVD 6606'-6613'TVD 6641'-6650'MD 6636'-6394'MD 6619'-6628'TVD 6614'-6372'TVD , lB pkr ~ 6543'WLM, & TRDP-1A-SSA SSSV ~ 1778' 12. Stimulation or cement squeeze summary NA In{tetrvals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Well History) Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-8y TitleAssociate Enqi neer (DAM) SW0/087 Date ~-It-~& Submit in DupliCate Feet~ ARCO Oil and Gas Company Well History - Initial Report - Daily Inatructiona: 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 Alaska Field Kuparuk R/vet Auth. or W.O. no. ICounty. parish or borough ' North Slope Borough Lease or Unit ADL 25639 Title Re comp let ion IState Alaska IWell no. 1H-6 W/O Pool 102 AP1 50-029-20741 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover I ARCO W.I. ]Hour 1300 hrs. IPri°r status if a w'O' 56.24% Date 7/21/86 Date and depth as of 8:00 a.m. 7/22/86 7/23/86 7/24/86 7/25/86 7/26/86 thru 7/28/86 Complete record for each day reported 7" @ 6900' 6795' PBTD, Spot BridgeSal pill 10.5 ppg Brine Accept rig @ 1300 hfs, 7/21/86. Pull BPV. RU to kill well. w/diesel, followed by 10.5 ppg brine. Spot BridgeSal pill. Fill well 7" @ 6900' 6795' PBTD, WO WL 10.5 ppg Brine Spot & sqz kill pill, circ out gas; well dead. ND tree, NU &tst BOPE. Att to pull tbg free w/o success. Wrk tbg while WO WL. 7" @ 6900' 6795' PBTD, POOR w/compl string 10.5 ppg Brine RU WL, RIH w/string shot to 6220', shoot SS, wrk tbg string in att to shear SBR w/o success. RIH w/tbg cutter to 6206', cut tbg @ 6183', pull hgr to flr, RD WL. RU, CBU, POOH w/3½" compl string. 7" @ 6900' 6795' PBTD, RIH w/FTA #2 10.5 ppg NaC1/NaBr POOH w/3½" compl string, chg out couplings to AB Mod. RIH w/OS,' chase fs to btm; TOF @ 6719' could not dress fsh off, POOH. RIH w/spear assy on 3½" DP. 7" @ 6900' 6830' WLM PBTD, RIH w/CA 10.5 ppg NaC1/NaBr Fin RIH, spear into fsh @ 6719', engage & POOH; full rec'y. RIH, CBU @ 6830', POOH. RU Schl, log CET f/6818'-4700', RD Schl. RIH w/retry BP, set @ 6200' &tst. ND BOPE, chg out tbg adapter, NU &tst BOPE. Tst 7" csg to 3500 psi; OK, rel BP, POOR & LD same. RIH w/bit/csg scrpr/JB to 6830', displ well w/filtered brine, POOH. RU DA, perf w/5" gun, 12 SPF, 120° phasing f/6472'-6496'. Rn gage ring to 6620'. RIH, set WL pkr @ 6543'. RD DA. RIH w/compl. The above is correct IDate Title Drilling Supervisor 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. Accounting District ICounty or Parish State Alaska North Slope Borough I Field ILease or Unit Kuparuk River ADL 25639 Auth. or W.O. no. ~Title AFE AK1061 "I Recompletion Pool 102 API 50-029-20741 Operator IA'R'C°' w'I' Icost rr°tal number °f wells (active °r inactive) °n this AECO Alaska, Inc. 56 o 24~ labandonment of this well Spudded or W.O. begun [Date IHour [Prior status if a W.O, Workover 7/21/86 ~ 1300 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. cost center code Alaska IWell no. 1H-6 W/O 7/29/86 Old TD 7" @ 6900' 6830' PBTD, RR 6.8 ppg diesel in tbg & ann RIH w/201 its, 3½", 9.2#, J-55 BTC & 6 its, 3½", 9.3#, J-55 8RD EUE selective single compl w/SSSV @ 1778', HB-1 Hydraulic pkr @ 6228', & 6462', 1-B Perm pkr @ 6543' (WLM), TT @ 6564' (WLM). Tst tbg, ann & pkrs to 2500 psi. Tst SSSV. ND BOPE, NU & tst tree to 5000 psi. Displ well to diesel. RR @ 0600 hfs, 7/29/86. New TD Released rig Date 0800 hrs. Classifications (oil, gas, etc.) Oil PB Depth 7/29/86 IKind of rig lype completion (single, dual, etc.) Single Producin~g method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 6830 ' (WLM) PBTD Rotary 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 Th e/~0-~j J s correct .--, IDate ~/~o ITM Drilling, Pages 86 and 87. Drilling Supervisor ATTACHMENT I I Drill Site lA Well No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-12 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Log Date Drill Site Well No. Log Date 7/6/83 10/29/83 2~8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 18 18-1 12/26/81 18-2 6/25/81 18-3 11/16-18/81 3/12/82 18-6 11/18/81 9/10/82 18-7 11/23/81 18-8 12/28/81 8/4/82 18-9 6/24/82 8/3/84 Drill Site 1C Well No. 1C-1 1C-2 1C-3 1C-4 1C-5 lC-6 1C-7 1C-8' Log Date 5/9/81. 518181 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date 10 10-1 · 1/80 5/23/83 10-3 8/5/80 10-4 7/30/80 8/13/80 10-5 6/11/81 10-6 6/9/81 10-7 6/8/81 D-8 (WS-8) 5/i0/78 Attachment ~T K Page 2 ,~ Drill Site 1H Well No. Log Da~e 1H-3 8/16/82 1H-4 8/13/82 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Log Date lq ilq:~lZ/1785 Drill Site 1E Wel 1 No. 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 iE-20 1E-24 1E-25 1E-26 1E-27 1E-28 iE-29 1E-30 Log Date 8/19/81 8/17/81 1117/84 10118/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/8'2 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. Log Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. 9/7/82 1F 1F-1 9/25/82 1F-2 9/28/82 1F-3 !2/8/84 1F-4 10/13/82 1F-5 11/12/82 1F-6 3/12/83 1F-7 Alask~ Oil & Gas Log Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 !1/19/82 5/7/83 Attachment Page 3' Drill Site 1Y Wel 1 No. Log Date 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~'~i~~6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~tY.~ 5/10/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 Drill Site 2Z' Well No. Log Date /10/83 2Z-2 ': 6/24/83 7/19/83 2Z-3 ' '8/5/83 '2Z-4 7/12/83 2Z'6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VL F' pg' 0052 Well No. 1H-3 ~1H-4 ~1H-6 ~lH-7 ~1H-8 Lo9 Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Log Date 1E 1E-lA x"8/19/81 1E-2 ~8/17/81"-~ _"1/17/84/ 1E-3 "10/18/81~. ``11/7/81J 4_ "-,8/4/80",,, ..~ 1E-5 "10/27/81, 1E-6 "10/21/81",> '~11/12/8 2 // "~1E-7 '~6/28/81~ x-10/28/81/// ~E-8 '-8/28/8~> ~ "~11/1/81/ 1E-12 "-11/28/84 1E-15 '--8/26/82 1E-16 '"i)/29/82 1E-17 '--9/1/82 1E-20 "~5/7/83 1E-24 "-2/17/83 1E-25 "-1/17/83 1E-26 ~1/13/83 1E-27 ",,f10/31/82 1E-28 ~10/27/82) ",,6/13/83 1E-29 '~10/18/82'-1 '~7/18/83 / 1E-30 '--t0/16/82 Drill Site 1G Well No. Log Date 9/7/82 · 9/25/82x~, 9/28/82 12/8/84 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. Log Date 1F '~1F-1 2/19/83 ~1F-2 2/3/83 'XIF-3 1/31/83 '~1F-4 5/29/83 %1F-5 10/25/82 '~1F-6 10/28/82 '~ 1F-7 11/19/82x,~ ~ 5/7/83~ RECEiV "/ FEB 2 1 19B6 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office B 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 18, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1H-6 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to convert 1H-6 to a selective single completion. Since we expect to start this work on January 1, 1986, your earliest approval will be appreciated. If you have any questions, please call Jeff Qu~.ntana at 265-4620 or myself at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw SN/L085 Enclosure Chorago C°~ri'ilssi~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA '~ ALASKA L AND GAS CONSERVATION C v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLxt~ OTHER [] 2. Name of Operator ARCO A1 aska, I nc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 648' FNL, 796' FEL, Sec.33, T12N, RIOE, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 85' 6. Lease Designation and Serial No. ADI 756_~9 ^LK ~.6~. 7. Permit No. 0~'68 8. APl Number 50-- 029-21~7/~1 9. Unit or Lease Name K,,par,,~ I~ver IJn~t 10. Well Number 1H-6 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~:] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing I--1 Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1H-6 to a selective single completion. The procedure will be as follows: 1. Well will be killed with brine. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test casing. 4. the C1 Sand will be perforated. 5. The well will be completed as a selective single using three packers. 6. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000"psi, SRRA BOP stack will be used on well work. operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. subsurface safety valve will be installed and tested upon conclusion of the job. RECEIVED Estimated Start: January 1, 1986 BOP equipment will be tested weekly and The Alaska 0ii & G,~s Cor~$. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~ ~ ~ Title Associate Enqineer The space bel for Commission use Date Conditions of Approval, if any: Returne~:{ ... ---- Approved by ................. ~J COMMISSIONER the Commission Form 10-403 (JLQ) SN/123 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L£~END & NOTES P~OTRACTED SECTION CORNER, FUTURE WELL LOCATIO~IS. PERMANENT SURVEY LOCATION MONUMENTS. EXISTING W~H~ F~ND THI~ AS*BUILT S~T ELEVATI~. PAO DIMENSION~ S~WN ANE MEAflS TAKEN FR~ AS-~ILT SURVEY ELEVATIONS S~WN ~E REPRESENTATIVE ELEV- ATIONS TAKEN Fq~ A~*BUILT SURVEY ~L[VATIONS ARE ~S(O ~ S~-~ VERTICAL DATUM. C~DINATE SYSTEM, ZONE 4. SECTI~ C~NE~S I~WN &NE ~SED ~ ~ASKA PROTRACTION ~YSTEM, THE ENTIR~ ANEA LIES WITHIN TI~Nt NIOE. UMIAT ~NIDIAN, ~ASKA. ALL AZIMUTH WN ARE ALASKA STAT[ ~ANE GRID AZI~TH ALL DtSTANC[ WN ARE TR~ ~'-IN' %gel.]es.3eu I \ .': :.--_' 7_ ........ , 1 8~t ' . · . - +_. ,~o ._+ ,~o + ,,o + leo + +--. - ' -I '~ IH-B IH-T IH-B ~.....- ...... J , _ _~ ....~ __] ___ ~__-~--. _..~ :.~ .... r .,~ Ifl-I IH-I IH-3 9,16 .............. 'o. I AZ ITS'4T'S$#- II'SO.O* TltUE I ~'~ ~ C[NTIF~AT[ CONDUCTOR HOLE LOCATIONS WITHIN SECTION ' FHL '~' ~' 1 *°'"""'"1 · ~ R-- ~'--I~; ~1' ~2~5~l'H90 35"$1.~7' 5,980,~4.85 549,551 .~ 648 I 796 .. ~-~ ~"~]' ,,-,,. ,,.0,' ,.,,,.,,,.,, i .._~ ,o. ,,' ,o .q ,.,- ,,' ...,' ,.,,,.,,,.- ,,.-,., "' I '"' K~AR~P~JECT :~ '0'"' '0.~1 ""~' ~'-'" '.'''.,,.=~ "''Z'O =0 '" I ,,,0 " AS--BUILT ~' ,0' ,,' ".,:1 ,~,' ~' 0'.',,' ,,,',.,0,.,0 , ~ ,o-~,'..,,:I ,;;-~' 0,.~,' DRILL SITE 14} ARCO AIQskQ, Inc. I I I ARCTIC I~V[YINO~ I I I .. , ...... ,., ..... I I I" ....... , .... I ......"~' ........... I '/"~" I' ! ..... '" =" I ..... ,~ .,, . ,o/~ · '"- I "" I:'1~' aSK-3.2.~-~q-,,,,-'. RETURN TO: ARCO Alaska, In~r Post Off~ :x 100360 Anchorage, Alaska 99510-0363 Telephone 907 276 1215 DATE: 08-16-85 TRANSMITTAL NO: 5254 ARCO ALASKA, INC. KUPAi<UK OPERATIONS ENGINEERING RECOPJ3S CLERK " ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED hEREWITH ARE THE FOLLOWING ITEHS. PLEASE ACKNO¥{LEDGE RECEIPT AND t{ETURN ONE SIGNED COPY OF THIS TRANSMITTAL. PRESSURE FINALS CAMCO lB-3 1D-8 1E-5 1H-6 1L-2 1L-5 lQ-6 lQ-9 2A-5 2A-5 2C-4 2F-7 2F-8 2F-9 2G-1 2G-1 20-5 20-6 20-7 20-8 2X-'l 0 OTIS 2A-2 PBU ' 04-21/22-85 STATIC 04-29-85 PBU 04-26-28-85 STATIC 04-29-85 PBU 04-24/25-85 PBU 04-28/29/85 PRESSURE FALL OFF 05-07-85 PBU 05-12/13-85 PRESSURE FALL OFF 04-21/22-85 .' STATIC 05-05-85 PBU 04-24/25-85 PBU 04-14-85 PBU 04-19/20-85 PBU 04-13/14-85 STATIC 04-17-85 PBU 04-29-85 STATIC 05-02-85 STAT IC '~'05- 03- 85 STATIC 05-04-8 5 STATIC 05-04-85 PBU 04-25/26-85 STATIC '~? 20-14 'PBU i 2V- 2 PBU .. !. 2V- 5 PBU ji 2V-13 STATIC :: 2V-14 STATIC ~ 2W- 7 PBU 3B-3 STATIC. ';' 3B-8 STATIC :. RECEIPT ACKNOWLEDGED: 07-04-85 06-30-85 07-27-85 06-25-85 06-22-85 06-22-85 07-26-85 06-28-85 06-28-85 ~pAE*~ B. CURRIER C~iEVRON* D & M* DRILLING L. JOHNSTON MOBIL* NSK CLERK DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL* J. RATHMELL* A~choraB~ ' STATE OF ~A~KA* SOHIO* UNION* K. TULIN/VAULT RETURN TO: ARC(~: '~ska, Inc. st Office Box 100360 ,~nchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-19-85 --- TRANSMITTAL NO: 5230 PAGE 1 OF 2 ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. 'BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HERE14ITH .ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETUF~N ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE lB-1 lB-2 lB-4 lB-4 ID-8 1E-!A 1E-5 1E-11 1E-23 1E-23 1E-27 1E-27 1G-6 1L-5 1L-5 lQ-1 . .!Q-1 lQ-3 lQ-4 iQ-4 lQ-4 iQ-5 lQ-7 !Q-9 lQ-9 1Y-I2 2A-2 2A-4 2A-4 2A-4 2A-5 , FLUID,. AND ACID DATA SBHP 05-3 0-85 SBHP' 05-30-85 SBHP 05-16-85 PRE-WORKOVER 05-24-85 SBHP 04-29-85 TUBI~]G LEAK 05-03-85 COMP PBU ETC. 04-28-85 LEUTERT BI{ SMPL 06-02-85 SBHP 05-22-85 SBHP 05-23-85 TEM P/SPIN-LEAK 05-0 3-85 TUBING LEAK 05-04-85 PRESSURE FALL- 05-07-85 OFF SBHP 04-29-85 PBU W/E-LINE 04-27-85 PBU 04-29-85 ISIP ~ 05-30-85 SBHP ,A,SDS 05-26-85 TAG FILL BHP 05-18-8.5 SBHP 'C' SD ETC 05-10-85 SBHP ETC 05-14-85 ACID JOB 05-17-85 ISIP TEST 04 -29-85 · ACID JOB 05-26-85 'C' .SD PBU 05-12-85 PBU 'C'SD ETC 05-13-85 FALL-OFF TEST 05 -05-85 BHP 05-27-85 'A'SD B~IP 05-10-85 'A'SD BHP '05-09-85 'A'SD BHP 05-i1-,85 SBHP 05-05-85 (ONE COPY OF EACH) CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO B. J. HUGHES CAMCO CAMCO CAMCO CAMCO NOWSCO/B , J. HUGHES B. J. HUGHES NOWSCO/DOWELL CAMCO CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO ***CONTINUED ON THE'FOLLOWING PAGE* RECEIPT ACKNOWLEDGED: BPAE* DRILLING B. CURRIER L. JOHNSTON CHEVRON* MOBIL* D & M~ NSK CLERK DISTR"iBUTiON: %~. PASHER EXXON PHILLIPS OIL* J. P~ATHMELL~ DATE: · UNION* K. TULIN/VAULT ARCO Alaska, In(:. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc.(F`' Post Office -~ux 100360 Anchora§e, A!aska 99510-0360 .,0, 276 1215 Telephone r. -~ DATE: 05-2 9-8 5 TFJ~N~.-.'~ITTAL NO: 5201 ~E~U:~N TO: ~.,,'I ITTED ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-11i5B P.O. BOX 100360 AI~C~]ORAGE, AK 99510 HERf,~'~ITH ARE Tile FOLLO>~iNG ITE~]S. PLEASE ACKNOWLEDGE RETU~ ONE SIGNED COPY OF THIS TDJ~NSMiTTAL. EQUENCE OF EVENTS ACID AND FLUID ONE COPY OF E.ACH) Q-4/ACID STiMUL%TION-'C' B-12 LEAK DETECTION DATA EQUENCE OF EVENTS/WSR'S O~%RECTED PSI ONE COPY OF EACH) ~-8 SBHP 04-29-85 ~i, SBHP 04-29-85 , CAMCO CAMCO · SAND 05-17-85 04 -16-85 %EIPT ACKNO~,[LEDGE D: CURRIER* ~VRON* DRILLING L. JOH[~STON %OBiL* NSK CLERK DiS'I'RIB' ''~'~u, -. ION: i~. PASiIER EX>iON =-,, ,- ,,~,IPS OiL* Anchorage STATE OF AL:\SK~,* SOHIO* UNION* K. T ULi~/VAULT ARCO Alaska, Inc~~' Post Office boX 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Harch 7, 1984 Mrs. Elaine johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 1H-Pad Wells 1-8 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG6/L20' tw .Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ALASKA OIL AND GAS CONSERVATION COMMISSION Permit No. Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501.;-3192 TELEPHONE (907) 279.--1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subjec~t well v~hich our records indicated was completed ~-~--~>~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, Chairman AClantic Ritchfield Company Arco Alaska, Inc. TRANSMITTAL To: Wm.-Van Al'eh/Sate of AK Date: 31 AUgust, 1983 From: EXTENSION/EXPLORATION' . . o. .. Transm/tted herewith ara the following: Mud logs {rom the following wells' lA-5°~, " g-ll-81 1A-8-{~West Sak 12) 7-22-78 1B-5~West Sak 7) '11-27-77 ./ - lC-4j 1-1-81 1C-5 z ' 2-9-81 1C-6z .3-1r81 1D-4J 12-31-79 1D-8~West Sak. 8) 4-7-78 1F-Si' 8-20-82 1G-4~ 10-12-82 1H-3.~ 7-24-82 1H'6~ 5-19-82 17-14 J 2-4'83 2C-6 j 7-8-83 2C-7~ .. .. 6-29-83 2X-2 / .~. ,7-2-83 2Z-4-?i 6-10-83. Also" included is an expanded' core~ log from well 2X=2,-'7-2-83. A blueli~e copy and a Sepia is provided for each well.. McAlister ipt .Acknowledge? Return rece:~.pt to: ~rco Alaska, Inc. ~ ' At tn: Xg~XNN~ E. . P.0. Box 100360 ~orage, ~ 99510 . Da te: Prepared by: B.BY~ne o · C '{ ARCO Exploration ny Exploration O ,tions - Alaska Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 SAMPLE TRANSMITTAL SHIPPED TO: STATE OF ALASKA Alaska Oil & Gas Conservation Comm. 3001 Porcupine Dr. Anch.,AK. 99501 · HAND CARRIED .b7 R.Pittman DATE: Feb. 3,1983 OPERATOR: ARCO S/MUlPLE TY~E- · 'SAMPLES SENT': _Kuparuk 1E-30 0750- 7084 . Kuparuk 1H-6 6364 - 6421 6424 - 6539 6630 - 6689 Kuparuk iG-4 6444 - 6467 6469 - 6503 6520 - 6616 6624 - 6637 6761 - 6885 Core chips NAME:_K_uparuk 1E-30,1H-6,1G-4, 1E-12,1E-13,and 1E- 14. NUMBE]:: ii [.;" ~' .... : BO_,dx~: _ 64 ~L SAI~{PT.]~.S ARE AT ONE FOOT INTERVALS. -- K_.uparuk 1E- 12 7016 - 7018 7026 - 7038 7040 - 7097 7238 - 7266 7270 - 7310 Kuparuk 1E-13 7086 - 7173 7176 - 7228 7294 - 7322 7324 - 7352 7354 - 7439 Box Count Kup. 1E-30 = 13 Kup. 1H-6 = 9 Kup. 1G-4 = 10 'Kup. 1E-12 = 6 Kup. 1E-13 = 12 Kup. 1E-14 = 14 ~otal boxes =64 .Kuparuk 1E- 14 6603 - 6628 6635 - 6645 U/pO~~~ 6649 - 6766 6769 - .6934 , NT BY: . - _- Paleo _Lab Tech, RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: RECEIVED BY: ARCO EXPLORATION CO. P. O. BOX 360 ANCHORAGE, AK. 99510 ATTN: R. L. BROOKS DATE- ARCO Alaska, Inc./ Post Office I( ~60 Anchorage, Alaska 99510 Telephone 907 277 5637 November 22., 1982 C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001'Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Please find attached the well completion reports for the following producing/injecting wells: 1B-9GI 1H-3 1B-10GI 1H-4 1B-11GI 1H-6 1E-11 1H-7 1E-14 1H-8 1E-15 Very truly yours, Area Operations Engineer slz Attachment cc: L. M. Sellers E. A. Simonsen R. L. Stramp H. C. Vickers ANO-332 w/attachments AFA-311 w/attachments AST-308 w/attachments AFA-326 w/o attachments ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ALASKA AND GAS CONSERVATION CO ,ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, ]:nc. 82-68 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20741 4. Location of well at surface 648i F'NL, 7967 FEL, 58¢ ~ I1ZN~ I~qUl:.~ UM 9. Unit or Lease Name ' Kuparuk River Unit At Top Producing lnterval 978' FNL, 719' FEL, Sec 33,. T12N, R10E, UH 10. WellNumber 1H-6 At Total Depth 975' FNL, 736' FEL, Sec 33, T12N, R10E, UH 1~. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 85' RKB ADL 25639 ALK 464 Kuparuk River 0il PoD 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 5/19/82 5/28/82 6/2/82I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 'l?~ereSSSVseti'' 21.Thic,~Permafrost 6964' 6942' 6813' 6791' YES [] X NO []i%.,o~,~ feetUD .,¢--"'lY00'..~approx) 22. Type Electric or Other Logs Run ~"~ DIL/SFL/SP/FDC/CNL/Cal/GR, DIL/BHCS/GR~ FDC/CNL/GR/Cal~ FDC/CNL/GR~ RFT~ CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 78' 24" 27'0 sx AS II 10 3/4" 45.5# K-55 Surf 2194' 13 1/2" 1000 sx AS III & 250 sx AS II 7" 26# K-55 Surf 6900'. 8 3/4" ..865 sx Class G ,Cnt ' 24. Perforations 'open to Production (MD+TVD of Top and Bottom and , 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6372-6400' w/4 SPF, 90° Phasing 3 1/2" 6305' 6236' 6404-6410' 6417-6428 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,663~-66/41 ' : . DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED . . 6647-6656' N/A : · · , 27. PRODUCTION TEST Date First Production ' I Method of Operation (Flowing, gas lift, etc.) · 6/16/82I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OILRATIO '~ 6/23/82 2.6 TEST PERIOD I1~ ' ~.1020 365 -- : 96/64I ~58 .. Flow 'Tubing. Casing Pressure CALCULA'[ED .OIL-BBL . GAS-MCF WATER-BBL. OIL'GRAVITY-API (corr) Press..1 0- .., .__ 24.HouRRATE I~ ... 107~ · . 384.: .-, 22.2 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · DEC 0 z, ~t~,,, · Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk N/A River Form 6343' 6321' Base Kuparuk River Form. 6722' 6700' 31. LIST OF ATTACHMENTS N/A. ..... 321 I hereby certify that the foregoing is true and correct to the best of my knowledge Signed · · Title Date ...... fl,,, "' - /7 - / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report 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 (m0..Itiple 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 pertinent 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- lng 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 KUPARUK ENGINEERING TO' DATE: Transmitted herewith are the following: PLEASE NOTE: ~BL - BLUE~ F - FILM, T - TAPE ATTN: LORIE L. JOHNS~$~0~E~s~.__v~..o Commissior~ " P.O. BOX 360 ~nchora~e .. 'ANCHORAGE, AK 9951'0 KUPARUK ENGINEERING TO: TRANSMITTAL D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIVED Rscs:~ AC~O~LSD~SD: ~ ~ ~ATS:. JUL ~01982 PLEASE ~TURN RECEIPT TO: A~© ALAS~/INC~ ' ~0il&Gas u0ns. C0mmiss~. ~chorage ATTN: LORIE L. J.OHNSON - AFA/311 P. O. BOX 360 ANCHO~GE~ ~ 9951'.0 KUPARUK ENGINEERING TO: Transmitted herewith are the following: D. W. Bose/Lorie L. Johnson PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: RECEIVED //--~_ JUL 2 3 t982 DATE: ARCO ALASKA, INC. NaS~ 0i1 &~chorageGaS Cons. uommission. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 KUPARUK ENGINEERING TO: FROM: D.W. Bose/Lorie L. Johnson DATE: Transmitted herewith are the following: PLEASE NOTE: F - FILM, T - TAPE C Fa/s.> EASE RETURN RECEIPT TO: '' ARCO ALASKA, INC. ~'"oraOe ~O;~b~ ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 KUPARUK ENGINEERING TO: TRANSMITTAL # ~ ~G~; ~'~%~ FROM: D.W. Bose/Lorie L. Johnson '~~Transmitted herewith are the following: F - FILM, T - TAPE RECEIPT ACKNOWLEDGED: · PLEASE RETURN RECEIPT TO: ATTN: LOR~E L. JOHNSON P. O. BOX 360 ANCHO~GE, AK 99510 ARCO Alaska, Inc. / Post Office B(~x J60 Anchorage, Alaska 99510 Telephone 907 277 5637 June 21, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1H-6 Completion Report Dear Mr. Chatterton' Enclosed are a well completion report and two copies approved gyroscopic survey for Kuparuk well 1H-6. Sincerely, of the ~.Gruber Associate Engineer JG-11m Enclosures GRU1/L28 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ALASK ~cAND GAS CONSERVATION .MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, :[nc. 82-68 3. Address B. APl Number P. 0. Box 360, Anchorage, AK 99510 50-029-20741 4. Location of well at surface --- _ ~_ 9. Unit or Lease Name 648' FNL, 796' FEL, Sec. 33, T12N, RIOE, UM ILOCATION~. Kuparuk River Unit -- VEI~JI:J~D i 10. Well Number At Top Producing Interval 978' FNL, 721' FEL, Sec. 33, T12N, R10E, UH Surf,~ 1H-6 , I'~..~ 11. Field and Pool At Total Depth . .- 975' FNL, 736' FEL, Sec. 33, T12N, RIOE, UH . Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 85' RKBI ADL 25639 ALK 464 ., 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 16. Water Depth, if offshore 16. No. of Completions 05/19/82 05/28/82 06/02/82} N/A feet MSL 1 I " 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+IA/D) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 6964'MD, 6942' TVD 6813'MD,6791'TVD YES~] NO []I 1899' feetMD 1900' (Approximate) 22. Type Electric or Other Logs Run DIL/SFL/SP/FDC/CNL/Cal/GR, DIL/BHCS/GR, FDC/CNL/GR/Cal, FDC/CNL/GR, RFT, CBL/VDL/£CL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 78' 2A" 7711.~× AR TT 10-3/4" 45.5~I K-55 Surf 2194' 13-1/2" lflOfl~× AS ITT & 25R .~× AR IT 7" 26.0# K-55 Surf 6900' 8-3/~" RF;5.~× CI~.~ R 24. Perforations open to Production (MD+TVD of Top and Bottom and 26. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6636'-6394' ~,~--- offset: to give 'f-!/2" 6~05' 6236' · 6636'-6394'J equivalent of 8 spf 6641 ' -6650'"X across t:his inte]:val 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6628'-6635!.t DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6398' _6404 N/A 6411'-6422 4 spf, 90° phasing 27. N/A . PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD ~I __ Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co/r} Press. 24-HOUR RATE "~ 28. CORE DATA Brief description of' lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Att:ached Sheet R ~ C ~ 1 V JUN 2 1 i982 A~ska Oil & Gas Cons. Form 10-407 GRU7/B1/2/3 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME , Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6373' 6351' N/A Base Upper Sand 6492' 6470' Top Lower Sand 6625' 6603' Base Lower Sand 6722' 6700' 31. LIST OF ATTACHMENTS · Drilling History, Gyroscopic Survey (2 copies)~ ~or~ 3t~fllQ~ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~-Z~J~)~ Title Sr. Drlq. Enqr. Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report 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-~i'n item 16, and in item 24..show the producing intervals for dnly the interval reported .~ in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent 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- lng 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 CORE S~Y KUPARUK 1H-6 APT # 50-029-20741 CORE INTERVAL 6364.0'-6424.0' 6424.0 '-6484.0 ' 6484.0 '-6544.0' 66 30.0'-6690.0' CUT/mECOVERY % _ 60.0'/59.75' 99.6% 60.0'/59.9' 99.8% 60.0'/56.0' 93.3% 60.0'/60.0' 100% LITHOLOGY Sands tone/Shale/Silts t one Sa{ds tone/Shalef. Silts t6ne San ds tone/Muds tone Sands tone/Muds tone Kuparuk 1H-6 Drilling Hi story NU Hydril & diverter. Spudded well @ 0730 hrs, 05/19/82. Drld 13-1/2" hole to 2215'. Ran DIL/SFL/SP/FDC/CNL/Cal/GR. Ran 53 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2194'. Cmtd w/lO00 sx Arctic Set III & 250 sx Arctic Set II. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new formation - tstd form. to 12.5 EMW --ok. Chg'd mud over to XC polymer. Drld 8-3/4" hole to 6364'. Cut core #1 f/6364'-6424'; recovered 60'. (sh & sd.s). Cut core #2 f/6424'-6484'; recovered 60' (sd.s & siltstone). Cut core #3 f/6484'-6544'; recovered 60'. Cont drlg 8-3/4" hole to 6630'. Cut core #4 f/6630'-6690' (ss, sandstone, sh). Drld 8-3/4" hole to 6964' TD (05/28/82). Ran DIL/BHCS/GR f/6961'-2190'; FDC/CNL/GR/Cal f/6961'-2130' & FDC/CNL/GR f/6958'-6200' & f/4400'-2400'. RIH w/RFT #1; attempted to take sample @ 6654' - stuck tool & worked loose (no sample recovered). Ran RFT #2 to 6485' (recovered only 1 gal sample). Ran RFT #3 set @ 6485'. Ran RFT #4 set @ 6654'. Ran 172 jts 7'~, 26#/ft, K-55, BTC csg w/shoe @ 6900'. Cmtd w/865 sx Class G cmt. Instld 10-3/4" x 7" packoff & tstd to 3000 psi - ok. Arctic packed 7" x 10-3/4" annulus w/250 sx Arctic Set II &"98 bbl Arctic Pack. Installed 10-3/4" x 7" packoff. Ran Gyro/CCL. Ran CBL/VDL/CCL/GR from 6797' to surface. Perf'd 6636'-6344' (4 spf, 90° phasing); 6636' -6394' (4 spf); 6641' -6650'; 6628' -6635'; 6398' -6404'; 6411'-6422'. Tstd BOPE to 3000 psi - ok. Ran 3-1/2" completion assembly with tail @ 6305' & pkr @ 6212'. SSSV set @ 1899'. Tstd packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Dropped ball & set packer. Flow tstd well. Closed SSSV. Instld BPV. Secured well & released rig @ 1530 hrs, 06/02/82. JG-11m 06/07/82 GRU1/DH15 JUN 2 ! i982 At2$ka Oil & Gas Cons. Commission Anchorage Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · Operator~ ~ell Name knd' N~mber Reports and Materials to be received by: Required Date Received Remarks , Cc~pletion Report Yes Well.History Yes ~-- . , ?/V - p - , , Core Registered ~¢7 Plat'~.,,,.,~ , ~ .... Inclination Su~ey/&¢,3 ~f ,,,,' , ~- ,,, ~ ~" Drill St~ Test Re~s . ,,, ,, '*".., ~s R~, Yes ,, ., KUPARUK ENGINEERING TO: DATE: ~//~/~/~/~ WELL NAME: Transmitted herewith are the following: TRANSMITTAL # j~-~ ~ FROM: D.W. Bose/Lorie m Johnson PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T~- TAPE~~ · RECEIVED R~~EIPT AC KNOWLE D G~D~~~~,,~~~~DATE.~U~ ~PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ~nchomge ~. O. ~0~ 260 ~NC~O~, ~ 995 ~ 0 Atlantic Ritchfield Company Arco Alaska, Inc. TR~NSMI T TAL Date: ~/~/~- From: Transmitted herewith are the following: Receipt Acknowle ~ . _ . _ Date:_ ~eturn receipt to: Arco Alaska, Inc. At tn: C. Mulliken P.O. Box 360 ~h~chorage, AK 99510 JUN 1 o 1982 'Oil & Gas Cons. Com~issio~ ~nChorago ARCO Alaska, Inc. po~t Office Bo] AnchorageAil s9510 Telephone 907 277 5637 June 8, 1982 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK ~99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are monthly reports for May on these drill sites' 1-9 13-26 2-21 14-17 2-22 14-22 2-24 15-5 13-21 15-6 13 - 22 · ~~?'" 13-24. 1E-12 AlSo enclosed is a well cOmpletion report for Kuparuk 1E-11. Sincerely, P. A. Van Dusen Regional Drilling Engineer PAV/JG'llm Enclosures GRU1/LI$ RECEIVED JUN - 91982 '~aska Oil & Gas Cons Com=is$1o Anc,borag'~ n ARCO Alaska, lnc is a s~)bsidiary of AtlanlicRiChli*eldCompany ~ , ,~ STATE OF ALASKA ~' ALASK~'~ ,. AND GAS CONSERVATION ~'] .MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well)~ Workover operation [] 2. N~ec(~ o ator. 7. Permit No. ~"[aska, Inc. 82-68 3. A~a.r~s BOX 360 Anchorage AK 99510 8'AP'~)~I~-~r20741 · ' ' ' 50-- 9. Unit or Lease Name FNL, 795' FEL, Sec. 33, T12N,RlOE,UM (approx) Kuparuk River Field 4. Location of Wel~/19 , at surface 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 85' RKB I ADL 25639 ALK 464 10. Well No. 1H-6 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. May ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0730 hrs, 05/19/82· Drld 13-1/2" hole to 2215'; ran logs; ran~cmtd & tstd. 10-3/4" csg. Drl,d, 8-3/4" hole to 6364'. Cut cores. Drld to 6964'. Ran logs & RFTs. Ran & cmtd 7 csg. Arctic Packed 7" x 10-3/4" annulus as of 05/31/82 See Drilling Hi story 13. Casing or' liner run and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, Weld, conductor set @ 78'. Cmtd w/270 sx AS II. 10-3/4", 45.5#/ft,K-55,BTC csg w/shoe @ 2194'. Cmtd w/lO00 sx AS III & 250 sx AS II 7", 26.0#/ft, K-55,BTC csg w/shoe @ 6900'. Cmtd w/865 sx Class G. See Drilling History 14. Coring resume and brief description Core #1 6364'-6424' sh & sd.s. Core #2 6424'-6484' sd.s. & siHstone Core #3 6484'-6544' Core #4 6630'-6690' s.s., sd.s., sh (A detailed core description will be provided with the compiation report.) 15. Logs run and depth where run DIL/SFL/SP/FDC/CNL/GR/Cal ~jsur~'qo 22.15~. DIL/BHCS/GR f/6961 '-2190' FDC/CNL/GR/Cal f/6961 '-2130' FDC/CNL/GR f/6958'-6200' & f/4400'-2400' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A JUN - 9 1982 Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Rep~ o~this f~m is required for each calendar month, regardless of the status of operations, and must be ~ in duplicate with ~he Alaska Oil and Ga~onservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~O4 Submit in duplicate Rev. 7-1-80 GRU1/MR9 Kuparuk 1H-6 Drilling History NU Hydril & diverter. Spudded well @ 0730 hrs, 05/19/82. Drld 13-1/2" hole to 2215'. Ran DIL/SFL/SP/FDC/CNL/Cal/GR. Ran 53 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2194'. Cmtd w/lO00 sx Arctic Set III & 250 sx Arctic Set II. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new formation - tstd form. to 12.5 EMW - ok. Chg'd mud over to XC polymer. Drld 8-3/4" hole to 6364'. Cut core #1 f/6364'-6424'; recovered 60'. (sh & sd.s). Cut core #2 f/6424'-6484'; recovered 60' (sd.s & siltstone). Cut core #3 f/6484'-6544'; recovered 60'. Cont drlg 8-3/4" hole to 6630'. Cut core #4 f/6630'-6690' (ss, sandstone, sh). Drld 8-3/4" hole to 6964' TD (05/28/82). Ran DIL/BHCS/GR f/6961'-2190'; FDC/CNL/GR/Cal f/6961'-2130' & FDC/CNL/GR f/6958'-6200' & f/4400'-2400'. RIH w/RFT #1; attempted to take sample @ 6654' - stuck tool & worked loose (no sample recovered). Ran RFT #2 to.6485' (recovered only I gal sample), Ran RFT #3 set @ 6485'. Ran RFT #4 set @ 6654'. Ran 172 jts 7#, 26#/ft, K-55, BTC csg w/shoe @ 6900'. Cmtd w/865 sx Class G cmt. Instld 10-3/4" x 7" packoff & tstd to 3000 psi - ok. Arctic packed 7" x 10-3/4" annulus w/250 sx Arctic Set II & 98 bbl Arctic Pack as of 05/31/82. JG:llm 06/07/82 GRU1/DH15 RECEIVED JUN_ 91982 Alaska Oil & Gas Cons. Commission Anchorage TO: T~RU: FROM: MEMOR( NDUM St [e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Cha ~~ rton Lo~ hie C. Smith CCtv, mi~,,:~ Ssi.nor ~ TELEPHONE NO: BeTt~ ~NO~ ~1 SUBJECT: Petroleum Inspector DATE: May 26, 1982 FILE NO: 10 8A/N Witness BOPE Tests on ARCO ' s Kuparuk 1H-6 Sec. 33, T12N, R10E, UM K_upar~ River Undefined _Wgdnesday, May 19, 19~2 - I departed my home at 4:20 p.m. for a 4:50 p.m. showup and 5:50 p.m. departure via Alaska Airlines flight #87 for Deadhorse arriving at 8:10 p.m. ~{eather: +22"F, light snow, light wind. Thursday, May 20, 19.82 - Plugging for abandonment of ARCO's DS 7-7 began with four plugs witnessed through Saturday, May 22, 1982, the subject of a separate report. com~ 1'982 - BOPE tests on ARCO's DS 14-22 w~re ect of a separate report. BOPE tests on ARCO's. Kuparuk 1H-6 began at 11=50 p.m. Satu .ns 1982 - . . . and were completed at 1:35 report is attached. I departed Deadhorse via Alaska Airlines flight #56 at 4:25 p.m. arriving in Anchorage at 6:05 p.m. and at my home at 6:35 p.m. In summary, I witnessed successful BOPE tests on .ARCO'$ Kuparuk 1H-6. 02-O01/%(Rev.10/79) · #4 OF ALASKA STATE ALASKA OIL & -CAS CONSERVATION CQv~2ISSION B.O.P.E Inspection Report Operator ~ ~ Location: Sec ~ T/~R/~M ~ Pril linq Contractor Representative asing Set ~'~~ Rig # /~/ Representative Location, General Wel 1 Sign Cenera 1 Housekeeping ~.eserve pit Rig BOPE Stack Annular Preventer-- Pipe Rams -~ Blind Rams Choke Line Valves__ H.C.R. Valve Kil 1 Line Valves ~ Check Valve Test Pressure ACCUMUIATOR SYSTEM Full Charge Pressure ~_~~o psig Pressure After Closure /~--~Pd) psig .Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: N2 ~:~:~ '.z '~~'~~/~/~ psiq_ Controls: Master min ~ sec. min~__sec. __Remote ~Blinds switch cover ./%'"~__~ Kelly and Floor Safety Valves Upper Kelly Test Pressure Lower Kelly_ Test Pressure Ball Type ~9~. Test Pressure Inside BOP/__~~est Pres sure Choke Manifold No. Valves No. flanges ._ Adjustable Chokes ' Hydrauically operated choke / TestPressure~~ Test Results: Failures ~ Test Tim~,' /~J'?6. hrs Repair or Replacement of failed equipment .to be made within.., · days and Inspector/Ccmmission office notified. Remarks: 27~_~-~5- ~~.~.~ .~ //o'~Tz~ /.-~ ~',5--..%.*_~) ~ . Distribution orig. - AO&CCC cc -Operator cc - Supervisor ARCO Alaska, Inc. Post Office B~.. J60 Anchorage, Alaska 99510 Telephone 907 277 5637 Hay 17, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501. SUB3ECT: Drill Site 1H-6, Revised Permit Dear Mr. Chatterton: Enclosed is our application for a revised bottom hole location on DS 1H-6 and the required $100.00 filing fee. Attachments include a drawing of the proposed wellbore, and a drawing and description of both the surface hole diverter system and the BOP equipment, including anticipated reservoir pressures. Since we estimate sPudding this well Hay 16, 1982, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, ~ Senior Drilling Engineer 3BK:CLC/llm Enclosures DS 1H-6 CRA1/BIO ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany t 719B A!~S~ 0iX & Gas Cons. Commission Anchorage STATE OF ALASKA O(i ALASKA ~L AND GAS CONSERVATION C ,MISSION PERMIT TO DRILL 20 AAC 25.O05 la. Type of work. DRILL I~i lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL ~] SINGLE ZONE [] DEEPEN [] R E~E~4VP~m GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. )JAY I 7 !982 3. Address P. 0. Box 360, Anchor age, AK 99.510 A?sv° nil & G,~ Cons. C0mmi.~.qinn 4. Location of well at surface ~ ....... /~ch0rag9 . . -~-" 9. Unit or lease name 6z~8' FNL, 79.5' FEL, See. 33, T12N, R10E, UM kapproxzmate) Kuparuk River Field At top of proposed producing interval 10. Well number (STRAIGHT HOLE) 1H-6 Revised BHL At total depth 11. Field and pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) ! 6. Lease designation and serial no. Kuparuk River 0il Pool 85' RKB 54.5' Pad~DL25639 ALK 12. Bond information (see :~0 AAC 25.025) Fedetai insurance Co. Type Statewide surety and/or number 8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 miles NW Deadhorse miles ~ surface FWL 4485' feet 1H-1 well I~ surface 120' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7205' TVD feet 2560 05/10/82 19. If deviated (see 20 AA~25.050) 120. Anticipated pressures ~_.6~J/4 psig@EU °1' Surface ps,g@63 TD (TVD) KICK OFF POINT 2~..._,. feet. MAXIMUM HOLE ANGLE~° I (see 20 AAC 25.035 (c) (2) 3215 ,, ' 10 ft. Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight ~ Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24 16 65# H-40 Welded 80' 30' 130' 110' I 110' +200 CF 13-1/2 10-3/~ 45.5# K-55 BTC 2172' 28' 1128' 2200' 112200' 950ax Fondu & 250ax 8-3/4 7 26# K-55 BTC 7179' 26' 1~26' 7205' 17205' lO00sx Class G cement I i I 22. Describe proposed program: :ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximate- ly 7205' TVD A 20", 2000 psi annulur diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RS-RRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). The Kuparuk interval will be p~qz~-_~l~. Expected maximum surface pressure will be 269z~ psi~j'-'~iJ'~'~'~i'on"~'~'~'~i'~i~"b'f bubble rising at constant volume. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, 3-55 buttress tbg. Non-freezing fluids will be left in un- cemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and ~eported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job . .23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED d/~ ,~,,_,,~,,~,,~ ~ J. ~. ~/'~.~z'/t TITLE Sr. Drillinq Engineer DATE The space bel~/fo~ C-~ommis~se ~/ / CONDITIONS OF APPROVAL ' Samples required Mud log required Directional Survey required APl number r--lyES ~NO [-]YES I~NO []YES [~O 50- 0'7-, ?- ~/., O'? ~ / Permit number Approval date .~-",..q~/~,:0!~. /~.. I SEE COVER LETTER FOR OTHER REQUIREMENTS 15, 1982 bv orde~ of the Commission ? Form 10q01 ' Submit in triplicate Rev. 7-~-80 CRA1/Bll Surface Divert(~' System 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlasts. 4. 10" ball valves', hyraulically actuated~ ,w~lO" lines to reserve p~t. Valves to open.automa,ti- cally upon closure of annular preven~t_e~,~' 5. 20" 2000 psi annular preventer. 6. 20" bell ,nipple. valves ow air 2 hours. 3, Close annular preventer in the event that gas or fluid flow to surface is 'detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well under any circumst'ances. O. . 16" Conductor ..~"S/8" 5000 PSI RSRRA BOP sTACK (r' ~NNUL.qR PREVENTOR ) (' J _I- BLtND RRMS -L-1 '" 8' C) '(. ) P~PE RRM$ ) 7 {. C ) ~' ,' ~R'~LL~NS~,~ ' ) ~,,, PIPE. ) s ( . 2. 3. 4. e e o . 9~ 10. 11. 12. 13. 14. 2~ 3~ 4. 5. 6. 7. 8. 15. 16" Bradenhead 16" 2000 PSI x lO" 3000 PSI casing head lO" 3000 PS! tubing head 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 13-5/8" 5000 PSI pipe rams 13-5/8" 5000 PSI drilling spool w/choke and kill lines . 13-5/8" 5000 PSI pipe rams- 13-5/8" 5000 PSI. blind rams -- 13-5/8" 5000 PSI annular -. ACCL~-IULATOR CAPACITY TEST -. . . · CHECK ~';D FILL ACCLD~LATOR RESERVOIR '~0 PROPER L~'E[ WI?ri HYDRAULIC FLUID~ ASSURE TYAT ACCLI.iULA, TOR PRESSURE IS 3000 PSI WITH.1500 PSI D[7~I~TREAJ4 OF THE REGBLATOR. OBSERVE'TIHE THEN CLOSE AJ_L Ut;ITS SII~JLTA~IE- OUSLY ~uqD RECORD T~E TIP~ A~D PRESSU.~,E REMAIII- ' i,qG AFTER ALL UiilTS ARE CLOSED lJITrl ~_-rlARG!NG PL~:~ OFF. RECORD 0~( IADC REPO2T. THE ACCEPT~Z.Bllr LCr.~ER LIHIT IS 45 SECO,~;DS CLOSI)~ '[IV~E AND 1200 PSI RBv~thI,,: PRESSURE. - - · 13-5/8' BOP STACK TEST FILL BOP STACK AND H~,NIFOLD WITH ARCI'iC DIESEL. C~,ECX I"?AT ALL HOLD D~',¢N S£REWS ARE FULLY RE- aP, ACTED. PREDEZE~,II(E DEPTH iHAT TEST PLUG I,'ILL SEAT AIiD SEAT I,q WELLHEAD. RU'iI Il( LOCK DDRN SCR~IS IN HEAD. CLOSE AJ;:,'ULAR PREVENTER AI~D CHOKES AIID BYPASS YALVES 0;~ I.tA~qIFOLD. CO~,POi,~,,TS TO 250 PSI AND F. OLD FOR TEST ALL '~ lO HIIiUTES. ' II{CREASE PRESSU2E TO 1800 PSI AND ROLO FOR lO MIIiUTES. BLEED TO ZERO PSI. OPg{ 'AJ~HULAR PREVE~EP, '~D CLOSE TOP SET OF " PIPE P~¢~q. INCREASE 'PRESSURE TO 3000 PSI' AND HOlD FOR lO HII~TES. CLOSE VALVES DIRE?~? UPSTR~-I OF CHOKES. BLEED Dg41(STREAJ4 PrTESSU_RE TO)ZERO PSI TO TEST VALVES. ZEST RD'IA!t(!t~x'UNT~STED HA~¢IFOLD VALVES, IF A~{Y, '4i,'-H ~000 P/SI UPST ~FLE~"4 OF ' VALYE A~D ZERO PSI DO~'¢S~_AH. BLEED SYSTEM TO ZERO PSI. - '-~ ' OPE)( TOP SET OF PiPE PO;~S At-iD CLOSE SET OF PIPE II;CREASE PRESSURE TO 30DO PSI AqD HOLD FOR lO HII~UTES. BLEED TO ZERO PSI. OPEN 80TTOH SPT OF PIPE RA'.IS. 8AC)C OFF RUN- NI,~;G JOI;fT AND PULL OUT OF , c HOur. CLOSE BLIND -.. R~..'.iS AND TEST TO 3000 PSI FOR tO HINUTES. BLEED TO ZERO PSI. OPE:¢ BLI:iD P~qS A,~;D RECO~'ER lEST PLbl~. F'~KE -' SURE Fb~'IIFOLD Fu','D LI:~ES ARE FULL OF ARCTIC CO S I.SZDE TO 000 !-7 WI TH )~O~EY PC~{P.. "' ": -": -... . RECORD TEST tNFOP3~ATION O~ BLCYJOUT PREYE;(~.E~C,,,~ S~,D TO DRILLI~¢G SUPERJ TEST FOP~'q SIG;( A:~D VISOR. PERFOPJ.I CC~IPLETE BOPE TEST O;:CE A I4EEK A~ID ' FU;'~CTIOt~,LLY OPERATE BOPE DAILY.._-" . ...-" ~. ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3230 psia from RFT and pressure build-up data. This pressure ~ 6225' SS = 6310' TVD will be balanced by 9.84 ppg mud weight. Normal drilling practice calls for 10.4 ppg weight prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 175 psi overbalance. It is anticipated the surface BORE equipment could be subjected to a maximum of 2694 psi during drilling operations. Derivation assumes a gas kick at reser- voir temperature and pressure (160°F, 3230 psia), gas migration to the surface without expansion, and cooling to 6O°F cellar temperature. This is well below the 5000 psig BOPE working pressure and less [han the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi = volume initial (reservoir) Pf = pressure final (surface) Tf = temperature final (surface) Vf = volume final (surface) PiVi = PfVf Ti Tf Since Vi = Vf, i.e., no expansion. Pi = Pf PiTf ~i -~f Then Pf _ Ti _ (3230 psia)(60°F + 460) (160°F + 460) Pf = 2709 psia = 2694 psig 05/17/82 CRA1/B12 ~., J. B. Kewin Senior Drilling l/ngineer ARa) Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: I/upa~,uk River Fi el d 11i-6 ARCO Alaska, Inc. Per~it No. 82-68 Sur. Loc. 648tFI~L, ?95tFEL, See. 33, T12N, F,10E, U~. Btmho I e Loc. Dear ~. I/ewin: Enclosed is the approved applioation for permit to drill the above referenced well. Well samples and a ~ud Io~ are required. An inclination survey is required as per 20 AAC 25.050(b)(§). If available, a tape containing the digitized log infor~ation shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~any rivers in Alaska and their drainage systems have been classified as important for the spawning or ~nigration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the re~lations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to c~ncin~ operations you may be contacted by the 14abitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ? .and the regulations promulgated thereunder (Title 18, Alaska AdMinistrative Code, Chapter 79) and by the Federal Water Pollution Control Act, as amended. P~ior to coamenein~ operations you may be contacted by a representative of the Department of ~nvironmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is 'spudded. We would also like to be notified so that a representative of the ~ission ~my be present to witness ~r. J. B. Kewin Kuparuk River Field 11/-6 -2- ~tay 15, 1082 testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C, Vo Chatterton Chairman of BY OR~ o~ T~ C~~t~N Alaska 0ii and Gas Conse~,vatton Commission sure Department of Fish & Garde, Habitat Section w/o encl. Department of Enviro~ntal Conservation w/o encl. CVC-= be SIGNED '~C~ra~ C°~rni,~ion DATE ~-~e 4S 469 .-,-,. v o,,k, ~_~n ~o~ ,~p 469 .J SIGNED SEND PARTS 1 AND 3 WITH CARBON INTACT. - PART 3 WILL BE RETURNED WITH REPLY. ill ~ · - f.. ..... April S0, 1982 ~tr, Mark A, ~laJor Area Drilling Engineer ARCO Alaska, Ins, P. O. Box 360 Anchorage, Alaska t~95X0 Re ~ Kuperuk River Fi eld 1It-6 ARCO Alaska, Inc. Permit No. 82-68 Sur. Loc. 648*FIq~, ?9$'FBL, See 33, T12~, ~iOB, U~. Bt~ole Loc. 1656*FSL, 1680'~, See 27, T1ZN, ~10B, ~. Dear Mr. ~aJor~ Enclosed is the approved application .for permit to drill the above re fe~eneed wel I. Well samples and a mud log ave not required. A eon'tinuous directional survey is required, as per 20 AAC 25,050(b)(5), If available, a tape containing the digitized log info~atio.n shall be submitted on ali logs for copying except experimental. logs, velocity surveys and dipmeter surveys, Many rivers in Alaska and their drainage system-s have been classified as important for the spawning or migration of anadro~ous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollutton:'of any waters of the State is prohibited by AS 46, Chapter 3, Article ? and the re~tlations pronmlgated thereunder (Title 18, .Alaska Ad~inistrative Code, Chapter ?0) and by the Federal Water Pollution Control Act, as ~ended. Prior to c~ncing operations you may ~ contacted by a representative of the Department of Environmental ~nservatton. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded, l~e would al so like to be notified so that a representative of the Come, lesion may be. present to ~itness 'Il ~. ~ark A. Major Kuparuk River Field 1H-6 -2- April 30, 1982" testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chat terto~y Cha i rman o f O~D~ OF TH1/ CO~,~M:S$~ON Alaska Oil and Gas Conse~ation Commission sure Department of l~ish & Game, Habitat ~ection w/o anal. Department of Envtron~ntal Conservation w/o anal. ~C: be ARCO Alaska, Inc. ~' Post Office Bt .~60 Anchorage, Alaska 99510 Telephone 907 277 5637 April 27, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001Rorcupine Drive Anchorage, AK 99501 SUBOECT: Drill site 1H-6, Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill on DS 1H-6 and the required $100.00 filing fee. Attachments include a drawing of the proposed wellbore, and a drawing and description of both the surface hole diverter system End the BOR equipment, including anticipated reservoir pressures. Since we estimate spudding this well May 10, 1982, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Senior Drilling Engineer JBK: OG/hrl Enclosures GRU4/A16 ECEiVED APR 81982 Oil & G~s Cons. Commission Ar~chorag9 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany O~.. STATE OF ALASKA ALASKA AND GAS CONSERVATION COI~i.,ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DR ILL [~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPH lC [] REDRILL [] DEVELOPMENT OIL IX] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, AK 99510 4. Location of well at surface 9. Unit or lease name 648' FNL, 795' FEL, Sec. 33, T12N, R10E, UM (approximate) Kuparuk River Field At top of proposed producing interval 10. Well number 1203' FSL, 1195' FWL, Sec. 27, T12N, R10E, UH 1H-6 At total depth 1 1. Field and pool 1656' FSL, 1680' FWL, Sec. 27, T12N, R10E, UH Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Kuparuk River 0il Pool 85' RKB 54.5' PadIADL 25639 ALK 464 12. Bond information (see ~0 AAC 25.025) Federal Insurance Co. Type St atewide surety and/or number 8088-26-27 Amount $500,000 .13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 miles NW Deadhorse miles ~ surface FWL 4485' feet 1H-..~well ~ surface 120' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8350' MD, 7161' TVD feet 2560 05/10/82 i psig@60 F Surface 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures 272:~ KICK OFF POINT 2500 feet. MAXIMUM HOLE ANGLE40 o 5° (see 20 AAC 25.035 (c) (2) 3265 psig@6385 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24 16 65# H-40 Welded 80' 30' 130' 110' 110' +200 CF 13-1/2 10-3/4 45 5# K-55 BTC 2172' 28' 128' 2200' 2200' 950sx Fondu & 250sx ' I ~ I AS II 8-3/4 7 26# K-55 BTC 8324' 26' 1~26' 8350' 17161' lO00sx Class G cement I I ~ I 22. Describe proposed program: ARCO Aiaska, Inc., proposes to directionaIiy driii a Kuparuk River Fieid deveiopment weii to approximateiy 835'0' MD, 7161' TVD. A 20", 2000 psi annuIur diverter wiii be instaIIed on the 16" conductor whiie driiiing the surface hoie. A 13-5/8", 5000 psi, RSRRA BOPE stack wiIi be instaiied on the 10-3/4" surface pipe. It wiiI be tested upon installation and weekiy thereafter. Test pressure wiIi be 3000 psig (1800 psi for annuIar). Expected maximum surface pressure wili be 2735 psig based on cooIing of a gas bubbie rising at con- stant voiume. Seiected intervais wiIi be iogged. The weii wiii be compieted with 3-1/2", 9.2#, 3-55 buttress tbg. Non-freezing fiuids wiiI be ieft in unCemented annuii through the 3ermaftost interval. Seiected intervaIs wiii be perforated within the Kuparuk formation and reported on subsequent reports. A downhoie safety vaive wiii~ be instaIied and tested upon completion of the job. ~t~ ~ VfFmDk 23. I hereby certify that the foregoing is true and corre t t nowledge SIGNED ~j~~j ~, ~ ,APR ,2 $ i98~TM Sr. Drilling Engineer DATE The space be~w~i~'Com~is~ion us~ ~o~.'~ Oil & Ga-~ Cons, Comm)ssio~ C~$01r~,I~NS OF APPROVAL Samples required Mud log required Directional Survey required I APl number []YES ~10 []YES [~NO ~,Y ES []NO Permit number Approval date °~'7'"~'~ ~ ;~J,~h/~_ ~ I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY_ OMMISSIONER DATE _.. by order of the Commission "-~"' *' "~" ~ '"~" " - Form 10~,01 GRU4/A17 Submit in triplicate Rev. 7-1-80 PRO H, WELL NO:t ~ ~ECIPOSED i : ' _.K_.LI_P_ F~ .Ll._~_. E_[E ,L.D_- _LNO_R_ T_H_ '~L O_~_E,_ -aLns~n ERSTI~N ~HIP, STD~I~; INC. _ . [. ' 3/4; CR~ING Pl' BU[ .o-3. s~Nos" . TVD=~)74 t )-1i: i'DEG '(9. Surface Divert~~''- System 1. 16" Bradenhead. 2. 16"x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves', hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. ~ 20" bell ,nipple. O. . Maintenance & Operation ~ l. Upon initial installation close annular I preventer and verify that ball valves ! - _ h_ave opened properly. · . I 2. Close annular preventer and blow air ~__. . through diverter lines every 12 hours. 3~ Close annular preventer in the event that gas or fluid flow to surface is · detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well u.nder ~ circumstances. 16" Conductor 13-5/8" 5000 PSI RSRRA BOP STACK IRNNULgR PREVENTOR 9 . ) ( BLIND RR~S · ( ,. 2. 3. 4. e e l_J .-- LL~ RRHS' PIPE . " :5 -4 TBG HD 3 CSG HD 2 . 16" Bradenhead 16" 2000 PSI × lO" 3000 PSI casing head lO" 3000 PSI tubing head lO" 3000 PSI x 13-5/8" 5000 PSI adapter spool 13-5/8" 5000 PSI pipe rams 13-5/8" 5000 PSI drilling spool w/choke and kill lines . . 13-5/8" 5000 PSI pipe rams- 13-5/8" 5000 PSI. blind rams 7 13-5/8" 5000 PSI annular ' . -' . . - = - ACCL~-IULATOR CAPACITY TEST . .- ..' - · .,...~ . - .. - - -: '. . . .:-.: i~:'~ -'- - '~'" CHECK ~/~ FILL ACCL~,~ILATOR £ESERVOIR '[0 PROPER L~'E[ ~ITH HYDRAULIC FLUID-' -. ASSURE THaT ACCL~.iULATOR PP. ESSURE IS 3000 PSI --: I~ITH. 1500 PSI D~g~TREA/~ OF THE REGt)LATOR. OBSERVE TIHE THEN CLOSE ALL UNITS SII~JLTANE- OUSLY A~XD RECORD THE TIP£ AND PRESSUi~ REHAIN- ING AFTER ALL UHITS ARE CLOSED ~/ITH CI~GING p U~.to OFF. RECORD ON IADC REPORT. THE ACCEPTABLE LiT.{ER LIHIT IS 45 SECONDS CLOSINq~ TIME At{D 1200 PSI R~V~AINI~ PRESSURE. - 13-5/8" BOP STACK TEST I. FILL BOP STACK AND H~NIFOLD WITH ARCTIC DIESEL. 2. CHECX I'~AT ALL HOLD D~N SCREN'S ARE FULLY RE- TP~CTED. PREDETE~':INE DEPTH lHAT TEST PLUG I~ILL SEAT AND SEAT IN WELLHEAD. RUII III LOCK l)rJ~N SCP~dS IN HEAD. 3. CLOSE ~'~'~ULAR PREVERTER AND CHOKES ALII3 BYPASS ] YALVES 0;( ~'~gIFOLD. l-jr- 4. ~EST ALL CCXqPONENTS TO 250 PSI AND HOLD FOR l0 MINUTES. - 5. INCREASE PRESSURE TO ]800 PSI AND HOLD FO~ l0 MINUTES. BLEED lO ZERO PSI. 6. OP~ 'ANHULAR PREVE~XTER A~;D CLOSE TOP SET OF PIPE 7. INCREASE 'PRESSURE TO 3000 PSI' AND NOLO FOR l0 HIIDTES. 8. CLOSE VALVES DIRECTLY UPSTREN-I OF CI40KES. ' BLEED DD^~NSTRE~'4 PRESSURE TO ZERO PSI TO TEST VALVES. TEST RD-IA!~(!NG UNTESTED HA~IIFOLD VALVES, IF ~(Y, WITH 3000 PSI UPSTRE~"4 OF VALVE AJiD ZERO PSI D~NSTRF_~9. BLEED SYSTE~I TO ZERO PSI. - 9. OPEN TOP SET OF PIPE I~S ,eu'iD CLOSE BOTTO}I SET OF PIPE P,:~¥~S. lO.I~;CREASE PRESSURE TO 3000 PSI A~qD HC)LD FOR 10 ItIh'UTES. BLEED TO ZERO PSI. 11. OPEN 80TTOH SET OF PIPE RA'IS. BACK OFF RUN- tiING JOIhrT AND PULL OUT OF HOLE. CLOSE BLIND -'..' R~,IS AND TEST T0 3000 PSI FOR lO HINIJTES. BLEED TO ZERO PSt. 12. OPE:{ BLIIID P~S AND RECO~ER TEST PLbt~. P~KE '.. - ": .-- SURE I-MdlIFOLD ~'~D LINES ARE FULL OF ARCTIC .- - DIESEL A,qD ALL VALVES ",~RE SE'[ 'IN DRILtII;G · POSI TI 0~1. _ . '..'!-v 13. TEST STA/;DPIPE V~J-YES TO 3000 PSI.. -...:..-_ . '. 14. TEST KELLY COCKS ~;D INSIDE SOP TO 3000 PSI G- a~. Cons,"': RECORD TEST INFO.~JATIO:( O~ BLO',~OUT PREvE;ITER - ~-~!~.skaF0ii &'~ ;n'~mm~~s' w KOmEY PL~,,P.. ~?~-~,~0F2~.~9. "i' '~?'" TEST FORd SIG~( AND SD:D TO DRILLI;~G SUPER- . ~-. i ' j-',~.-~": VISOR. - - --- - -: .... -. . . -.~,.._- ... - ..?~ _ '- '-?' FU~;CTIO~ALLY DPEPJqTE BOPE DAILY.. :ut'-:'-:..'. ] - :" .- .:'t-.~:.'" '- . ANTICIRATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3265 ps. from RFT and pressure build-up data. This pressure ~ 6300' SS = 6385' TVD will be balanced by 9.83 ppg mud weight. Normal drilling practice calls for 10.4 ppg weight prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 175 psi overbalance. It is anticipated the surface BORE equipment could be subjected to a maximum of 2723 psi during drilling operations. Derivation assumes a gas kick at reser- voir temperature and pressure (160°F, 3265 psi), gas migration to the surface without expansion, and cooling to 60°F cellar temperature. This is well below the 5000 psig BORE working pressure and less than the 3000 psi weekly test pressure. Ri = pressure-initial (reservoir) Ti = temperature initial (reservoir) V. = volume initial (reservoir) 1 Pf = pressure final (surface) Tf = temperature final (surface) Vf = volume final (surface) RiVi = RfVf Ti Tf Since Vi : Vf, i.e., no expansion. Pi = Pf PiTf ( 3265 psi(a~( 60°F + 460) Then P - Ti Tf f - Ti (160°F 8 460) Pf = 2738 psia = 2723 psig ~/~ 04/27/82 GRIJ4/A18 CHECK LIST EOR NEW WELL PERMITS ITeM APPROVE DATE Loc (2) thru 8) Company Lease & Well No. YES NO 1. 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 ................... 5. Is sufficient undedicated acreage available in this pool ........... .~__~ 6. Is well to be deviated and is well bore plat included .............. 7. Is operator the only affected party ................................ 8. Can permit be approved before ten-day wait ......................... (3) Admin ~k..-- ~L~'~ 9. (~ thru 11) 10. 11. (4) Casg ~~u~'~'g'~20) (5) -- ~ thru 24) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24, 25. REMARKS Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ............................. ' ......... Is enough cement used to circulate on conductor and surface ...... Will cement 'tie in surface and intermediate or production strings Will cement cover all known productive horizons ................... Will surface casing protect fresh water zones .................... 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 a equate well bore separation proposed .......................... Is a diverter system required ............... ;iii Are necessary diagrams of diver~er ~'~OP'gqui~g~t a;~c~ed Does BOPE have sufficient pressure rating -Test to ~O~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements .............................................. Additional Remarks:~ ~z[. ~-~-~f~_ ~~~*'~ ~ 7~/-.5' ~ Geology: Engi~e~er ing: M cs%cy WVA JKT~ RAD gAL ~---~. MTM~/~Z~ rev: 01/13/82 INITIAL' GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE CHECK LIST FOR NEW WELL PER.MITS ITeM APPROVE DATE (1) Fee (2) Loc thru 8) (3) Admin (9/ thru ® 10. 11. Company 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 ....... 5. Is sufficient undedicated acreage available in this pool[ 6. Is well to be deviated and is well bore plat included .... 7. Is operator the only affected party .................... 8. Can permit be approved before ten-day wait ............. Does operator have a bond in force .................................. Is a conservation order needed .................... · .................. Is administrative approval needed ................................... (4) Casg {~[2 thru 20) 13'. 14. 15. 16. 17. 18. 19. 20. (21 thru '24)' 22. 23. 24. 25. ~'~ Lease & Well No. 1~~'"/~- /P' C YES NO REMARKS Is conductor string provided .................... , ............... Is enough cement used to circulate on conductor and surface ..... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ..... ' ............ Will surface casing protect fresh water zones ........ · ..... Will all casing give adequate safety in collapse, t~nsio~ an~ Is this well to be kicked off from an existing wellbore .......... Is old wellbore abandonment procedure included on 10-403 ......... eeo Is adequate well bore separatiOn proposed ......... - ................ ~~ Is a diverter system required ............... '.~~ Are necessary diagrams of diverter ~n~'B~ g~ip~; ~[;~c~g~ 11 ...~~--- Does BOPE have sufficient pressure rating- Test to ~P~O psig [. Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: Geology: Engin. eer ing: WVA J K~RAD .- . 01/13/82 -- INITIAL' GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ') , Well Histo.ry 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 APPENDIXi No 'special'effort has been made to chronologically organize this category of information. .o LYP OIO.HO1 YE~IFICATION $* REEL HEADE~ SEPVICK NA~E :SE~VIC DATE :82/06/10 OPIGIN : REEL, NAME :~EEL ID CONTI~)UITICN ~ :0! PREVIOUS REEL CO~ENTS :REEL CO~ENI'S ** TAPE HEADER SERVICE DATE :B2/Ob/lO ORIGIN :6515 TAP~ ~AME CONTINUATION PREVIOUS TAPE CO~EN2S :TAPE :SERVIC :01 CO~ENTS ** FILE HEADEk FILM ~A~F :SWRVIC.O01 SERVICE NAME V~RSION # DATE : M~XI~U~ L~NGTM : 10~4 FILE TYPE : ** INFORMAT!OM RECORDS CN : ATLANTIC WN : 18-6 FN : KUPARUK R~NG: IOE TOWN: 12N SECT: 33 COUP: NORTN SLOPE STAT: ALASKA CTRY: MNE~ CONTENTS P~ES: DILOOiE ** RECORD LVP OIO.HO1 YERII"I. CATIOiU LISTING ~ ..~ ~: ¢.EC~RD ~,~ · ~ , COr~PA~Y : ATLANTIC RICHFIELD CO FIELD = KUPAaU~ COUNTY -- NORTH SLOPE BOROUG8- :...:::.: - STATE : ALASKA ======================== ............ . -- --. ---- .----.-.. --..------ ~ -..- .... .. ,~ ,..... -- ,. .... .. ----. .... .------~..~1:-- -- .... .. .. . ~ .. ~ . ~.. ~'"~ .~.:..~ :: i ~: :. -.~ : . .'-:. :..,::.:' .. ~ · -:j ~- - '.' ' !' -:.: -.. : . - - _ JOb NU~BEa AT ACC: 10707,65155 aUN #2, DAI'E LOGG£D: 28 MAY B2 80TTO~ DEPTD : 6954 FT. TOP DEPT~ : 2194 FT. CASING = 10 ~/8 IN. BIT SIZE = 8 !5 IN, TYPE FLUID : X~-POLY~ER DENSITY : ~0.4 LB/G ¥I$COSITY : 40.0 $ LVP 010.hO1 VERIFICATIO~ LISTING PH FLUID LOSS R~ R~C R~ AT EHT ~TPI× SANDSTCNE 9,5 6.0 C3 3,5 9 67 DF 1.58 ~ 67 DF 2,76 ~ 67 DF 1.7~ S 144 DF ** DATA FORMAT RECORD ** ENTRY RLOCK6 TYPE 4 9 DEPT SFLU IL~ DIL ILD SP G~ DIL NPHI FDN DPHI FDN RHOB FDN GP FDN CALI FDN DRHO FDN NRAT RNRA FDN NCNL FDN FCNL FDN DT BHC GR ~HC MNEM SERVICE SERVICE UNIT API API ID .n. RDE'R # LOG TYPB' _::..,.:,:.~.. : "-SEV~L":-<-':: :':::': ........ :"-"'(ODE FT 0 0 O: _0 :-:.:-0::.::~.~.::-:..:': ::;~:...:::": .:. .... ::':':'~:O:::.-,.'.: ,: :'.:. &::~,.~:::: OHM~ 7 0 0 0 ..... -0 -': -:' ~':"- 0' .... ....-"" ~1": :''-68 ........ OHM~ 7 U- :- .:-0 PU 42 68 2..-: -0.:-: :,~.~4:-':'::.:...L?: P U 4 2 0 -0~ :'0:" :" '::: O: "~;~;~": :~?0:': GAPI 42 31 :~ 32-" 0 :'' -O ~:'~":':':"'"'~::':: ,'~ ':: :"i ....... :'~'- .... G / C 3 42 44 0 *:'0 ....... -:-0 ':'~ :" "" ": ~ ::: :"::' 42 0 6- ~O:';":* ':' 'O''~ :"4~' ~::' ":"":"'--::~?"';;: '~'::::: ~ .... ::~ ;*;':6:'8 42 ]4 92:.- O..0 ;..~,:,.:' ..: &::;:~:'.. ,_::';:~:~:.::;.:0.::;:.: ..: :~:: ;: 4 ~ 34 93 0:': 0 .... ~"" ....... *:~* :':':':::::':" ':':~'"':':"::~ 0:': ~':': '::: '?':' '?:::I' '::* ::":6::8 D~PT SP RHOB NPAT DT DEPT SP RHOB DT DEPT SP RHOB N~AT DT DEP3~ SP RHOB NPAT DT DEPT SP RHOB NRAT DT DEPT SP RHOB NRAT DT DEPT SP RHOB NRAT DT DEPT SP RHOB NRAT DT DEPT SP RHOB VERIFICATION ~9~7.5000 SFhU 999.2500 GR -999.2500 GR -qgg ~500 R R~ -999.2500 GR t~90 -2 q 680 -1 10 670 -1 9 e. o g 65O -1 9 640 -? 9 11 0.0000 SFLU 2.7969 GR 2.4609 GR 3.0469 RNRA 7.7500 G~ 0.0000 SFLU 9.6406 GR 2.5215 GR 3.5625 R~RA 0.0000 SFLU o.6563 GR 2.3945 GR 2.8437 RNRA 2.5625 GR oooo sFbu 2,4277 GR 2.9648 RNRA 5.7500 GR O.O000 SFLU 9.2500 GR 2.~652 GR 570 RNRA 0.0000 GR 0,0000 SFLU 9.7031 GR 2.2402 GR 2.6250 RNRA 0.7500 GR 0.~000 SFDU 6. 219 GR . ~7~ A D.O000 GR 0 ~000 5FLU 3:500 GR 2.3438 GR LI$'i'ID~G '999.~50:0' ~: 4 ~ 9S -999,2500 ': 92.9121~ ~ ~ ' . ~ 73 ~ ] 0 ~ 7 96, ~250 .- - :-:~-; ~::..~:.; ~?~ ~. }~:: ::~:::.: r'<';:~::{.~:/'~;L :t~'>; :~ :):. ~<<;....~: f~.;:~.~ ::?. 2,~72 IbM :...:. · g2. ~&~':~ ~ O~ [ 2500: ' 5 g 3 8 92.5625 ,9902 N'CN~~'~' - 85 -6 250 8. 66 ,~C~'L 2~84 .'O0'OO ~ C-5 769;5000 ~ 0469 ~:.~b.M~-. ~ $1:t.::,:.::~:GD- ~: 7~:3 51.7813 1.537t: .1bM-'.~ i 10.6 5 0 6 10 ~. 625:0 110.0000 2, ~ 484 , -' :; .~-' f .]: ====================== "3 'd_ Y- ':- . j33 .:: .:; .:::~:: :.:::- ::.:- .;~ -:::: :'.:: ~:;~: -- ~:: :;t .:.;~. :;: .;:: : ::~: :~Y::: ~ _:. ?:2 ~~ bVP OI(,,H01 VERIF!CATION bI~TING NRAT DT SP RHOB NPAT DT DEPT SP N~AT DT DEPT RHOB NRAT DT DEPT SP RHOE NRAT DT DEPT SP RHOB NPAT DT DEPT RHOB NRAT DT DEPT SP RHOB NRAT DT DEPT SP RHOB NRAT DT DEPT 8P RHOB 3.593~ RNRA 113.1875 GR 6100,0000 SFLU -35.4375 GR -999,2500 GR -999.2500 PNRA 117,0000 GR 6000,0000 SFDU -4[;.9687 GR .-999 2500 GR 999:2500 RNRA 110.1875 GR 59.oo oooo srbu -999.2500 GR -999,2500 ~NRA 116,7500 GR 5800,0000 SFLU -15.5391 GR 2500 999;2500 Rt, l~a 103.7500 GR 7.ooo:oooo s nu 7900 G~ .-999 2500 GR 999;2500 RNR~ 118.1875 GR 5.600.0000 SFbU 28.5313 GR -999 2500 -999,"2500 RNRA 112,7500 5500,0000 SFLb -44,2813 GR -999,2500 GR -999,25o0 RNRA 120,1875 GR 5400:~000 SFbO -18 156 GR -999 ~500 GR -999:500 RNR.~ 103. 1875 GR 0000 SFLU -999.2500 GR 199:;500 NPHI ' '999:;2'500 ' 213 6250 'CA~t::", :.,: : :.'- =: :' 199.7500 _ . ~ - ~ · _ .' : : .'~:.<:~ '::... ::,% .: ?. "': ~: ~.~ ::.:.... -;: , 157 157.5000 123 68 75 :.Cab:I:: <, :: ',. :::~::.::~:-: ::~:~...:. ,,,::,~ ..'-.::~,9 :2 :<::: 9 g 9: 250'0 ~C~L- : =-: ~:9'9:':~'5:0:0':~=<=::<F:C N'[i~ ..... "~999:':':"~ 500 ' 11 ~. 1 250 4 023:4 .- ,~b-M:- ,:::-:.: ::: .:.::,: ::::.::: 3::.0~::,1.~:: ..~' '?.:: :::: :~,::::: :, ~.,,' :,:.:: ::: _ - : , : I 09: 6 250 ~PHi ....... ' :': 'a99 '9 :':' 2:5:'0:~'~ ..... ::': ~99 9:';" :~5:0:0 :'""< ' 109 ~625 CAL::I:: ': ':::. :-~:.:1.0~.:~9:fi9::::~; : ': ':-.:' :2 :: _: : : .... ' ' : -999: 50'0 MCNL:"-'" ::~999"::2':5~0 .... -' ' 109.6250 0 9365: :~bM-::: _::: :':~:?: :,::~:~D:: ':', .' :::":': '. ', '::- :::-.::: -' ' 116: 6875 NPHi: ........ "999=~:~25'"00 :':::: ":' :" :' 120., 4375 .:CA~t:' .:' :': :'-9 99::,..2'50:O 11 6,6875 :. : 3 · 2461 ~LM' :. ..:: .:..~,:~: ':::,.::2: ~: .... - - 127, i 87:5 - :~ ~::HI<: .... ":' ::::: :: :::::: ::::::0 : ::::: 129. 7 50' :--======================== .: -999. jSO0 :~C:~':: :<: :::~99:9: :=:::::::::::: :::::: 9'9:~' : .... : -- :': ': 12 7.1 6563 13 ~: ~75-0 ~PH:':'-: ::::"~:999:;:: '~":"':<'DPff:l ":":": ': ::::: '999:'~5:::O0`:::::~ =:: "': :: : ::: 156 0000 :.:C Ab 1 :.: :::-:: 8: .... :.: ,:.::,: ..::::' ::?::9 99 :::::: 1 8789 ::--: :::::: : ::<::I :b D:.: - : .... , :, : ' -- : 2754 - ?1bt4 ::- :,< :::!::~'~6:39' ....... ..:, _:> : ::...::,+ :: =================================== .:.:, :.:: : :: :. :. :.:::::::: .... _: :. :: ::.: ::::.::~ ~: :, :: :::: ::::':: :::::: :::::::::::::::-:::'.:::::~:.~':.: :.:.: ::: :: ::: - :_ _ _ . _ LVP OIO.HOi VERIFICATION LISTING NRAT -999.2500 RNRA DT 115.1875 GR 00oo SFbU RHOB -999.2500 GR NPAT -999.2500 RNRA DT 103.5625 GR DEPT 5/_00 0000 SFLU SP -11:0000 GR RHOB -999. 2500 GR NRAT '999,2500 RNRA DT lO8.OOOO G~ RHOB 999.2500 GR NRAT -999.2500 RNRA DT 104.3750 GR . :oooo ~469 GR SP NmAT 99.2500 RNRA xo . 87 OEPT 4700 0000 SFLU SP -3:2676 GR RHOB -999,2500 GR NRAT -999.2500 RNRA DT 90.5625 GR . oo ooo D ~sP r . SP 32. 938 GR RHOB -999.2500 GR N~AT -999.2500 RMRA DT 106.1875 GR DEPT 4400 0000 SFLU sP -~6:5938 GR RHOB 2.2676 GR 78.. 5000, CAb:I::: ,: :. :: ~::~::10-1~6' · '::...'--: · ' : - ' -ggg. 2500 NCNb'"'- ' .... ~g99":.:2S00'-:~ :- :: · 8 ~ ' 125'0'·'- <N PHI .... gg:; 2'500 .... :::::D-P::~'t .... :': :-< :: .g~ 6~75-CA.:ii:<:::-::::<:-.1:.O :8 ::::::::::M:: ::: ::: ::: :::9 500:::::::::::::::: 2,3125: :IBM:: .:::.:<: :: ::4::.- 7 . 6 250 NPHI"::: '~~gg':2:S:O0: ...... :D'P~I'<:: ......... "9 99,5000 ::- :CA:bi:-::: ::~.:::.9: .3~:7::: :iD:H:::::::::: : :::: :: : ::" ~ 7.6250 L 5 - 999 i 2500' N'C'NL ': '":' ': :-,':,:999:2500 2,664i :I.~M' :: :_ <::::::::::::::::::2: ::Z~,'D::: ::.:: ?..:::::: 9 g 8 62 50 :CA:~I:- .... :::::::t' 5::::':' 89, ~75.O :id:<: ::::: :'::: ::: :::': 87.93'7:S" -:::9~'<:~:0'O<::'.::::DPH::i::::- ::-: '9 g 2,8750--CAb:I:.:: :: ::::::: .';:::.::~ ,559 :: I b:i~:-:: -::~:~:.::: :.:,::2:6:: '9:':=:=: :~D: ......... ,< .::: ::::::-'.,::--::~,:: 55:9 8 7 O 0 0'0 C.Ah!. :-: ::::::::::: 8.~:'..:~8::~O::::<_::::.::~ 0:0<::::::::': ::: 95,93 75: CA,ii :: ::.:< <: ::.t:..::::::: ~:;:, .:::.:D~.::. :::.. :::::.:: 500 85,4375 N:P:'fi:'I: :=:: :::<~':')'4: '::" ::::':;::: :::" :::: 83.5000' ,CA~t ::::: :::-:: ::: .~8~:.A.::.:::.~.D Rtl, O: :.,. ....... ::_:::, ........ 0':~220:: ':":.~ .::: ~ '::- ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::'-::: :::: =============================================================================== ::: ::: :':::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: DT NRAT DT DEPT SP RHOB NRAT DT DEPT SP RHOP N~AT DT DEPT SP RHOB NRAT DT DEPT SP RHOB NRAT DT DEPT SP RHOB NRAT DT DEPT $P RHOB NRAT DT DEPT RHOB N~AT DT DEPT SP OIO.H01 VERIFICATION 3.1543 RN~A 109.O000 GR 4300.0000 SFLU -35.0625 GR 2.2852 GR 3.2891 R~RA I08.1875 G~ 4200.0000 SFLU -30 9844 G~ 2i1738 G~ 3 4805 R~A 113.7500 GR 4000.0000 SFLU -28,2344 G~ 2,1148 GR 3.6074 Rr,!RA 113,1875 gH 3~00.0000 SFLU 34.4688 GR .2187 GR .3906 ~qRA 118.1875 G~ 3~o0.0000 SFLU ~6.2500 G~ . 0879 G~ ,]242 RNRA 127.3750 GR 3700.0000 SFLU -54.7813 GR 2,1230 GR 3,1094 RNRA 121.7500 GR 3..0 0000 SFLU . 125 RNRA 115.5625 GR 3~00 0000 SFLU 59:5000 GR 2.2363 GR LISTING 3.49 22 85.4375 R5.8~5 ~PH'I ~ ~37::9395 ..... DPH1 :: 22,0703 6 .5625: CALI.~:.::: :':. ::~:.::~ :I. O:'..~::D .~ ::::~: ::'.. :.::0:~:0. 83. 8223 2298:0000 ..... FC'N-5:' 0~:4863 .I5~- ::: -: .~.:'3.'6: .:.::: 9375 NPMI ...." ........ "~-' :: 28";857~ 06 0625 .CAb1: ,- :~' :::::::::::::::::::::::::: .:.: ~.: :...: ~.,:.~.:~:~:::~::.~. :,.::' ~ 3: 7~56 -t-bONE' ~1'9~4';':0000- 'FCN'L- ~:: 521.5000' ], 2129 : I-5~ :~-:.. :: ':. ::~:.: .::~.-2~,: :::.:: 95,~750 NP~'I"': 3 : ' 6680 N CNL ...... 1908:;':'0000 ':FCN::h ....... -:'~:' :: ' B20-,-O 0"00 ' . . . : -3: : _:::~ _:.; -. _..: :.::: : :::' '.._ : ::_ _ -/: :.: .:..: :::;. 2 4473 ..iht4' : ::. :: :::::, 2:',: ~:..:.I::~:~.::'::: ~ :=~:.- 4: 2 266, ' =N C N:'L':: :" 2012= 000':0<:': -"FC~[, :: :- 475;-75'::0~0:: 86.06 96.8750 N PH?I' ...... "~"-'38=;:8:67:2 ...... ~P'Ht "::-': 26; i230': 97,6250 -CAb ..~. 3 ,7070 '"NCNT- ~'"' :209ff'~"00::0~0 .... "FCN::L -': 56'3':':;'500:0 .... 96.8750 :~ 15.5938 · I hg ,:,': _: - ':~:[:8::,8~9~.:::::: :~ :::':: ::.:::-~:~ :'-.1:'9::~::g00:0.~::._ 58.750 ~ N P'H"I :::::--"' ::~'- :':- ':~ :':~ 3::"i:":93~:':36: .7598 ' :NCNL ...... :-': 2078':':':O000 ::~' :":FCN:5 .... bVP 010,HO1 VERIFICATION NPAT 3.5059 RHRA DT I19.1500 GR DEPT 3400,0000 SFbO SP -39.0625 GR RHOB 2 2090 GR N~AT ~4395 PNRA DT 123.1875 GR DEPT 3300 0000 SFLU RHOB ~.0313 GU NRAT .4531 RNRA DT 131.1250 G~ DEPT 3200,0000 SCLU SP -55.718~ GR RHOB 2,1660 GR NRAT 3.5977 RNRA DT 127.1875 GR DEPT 3100,0000 SFDU SP -53,531] GR RHOB ].1543 GR NRAT .5254 RNRA DT 124,0000 GR DEPT 3~00,0000 SFSU SP 48.0000 GR RMOB 2 1953 GR NRAT 3i6602 RNRA DT 133 1250 GR DEPT 2.9.~0,0000 SFLU SP 1.9687 GR RHO~ 2.4191 GR NRAT 3. 156 R?~RA DT 136.3750 GR DEPT 2~00.0000 SFLU SP 37.7500 GR RHOB 2.1484 GR NRAT 3.3867 R~RA DT 128.7500 GR DEPT 2:000 0000 SFLU Sm 5 ; 7500 OR RHOB ]~133 GR NRAT : 8]6 RNRA DT 128. 1250 GR DEPT 2~00.0000 SFLU SP 48.7813 GR RMO0 2.1426 GR 18 7 5 5 O00 NPHi' ": ~ 2-6;7 090 500O -. - 9 785 N C 2 813 9687: ,,C Ab.,I ~. ::. ," _.._-::: ,":~9::~, ::; 0:';,:' ::.: :'-, . : _ . 2500 NC '~' 2'::2'~:6" 'O'OOO<'~'~ FC~'5 :': ' 5I T;5 0:00-:' * :- ' 125o : ..~,..; :.;..j :_ :~.:.._ : ~ · - 7969 ~ :': ,. , '.: : :,:::t 'k D: 8:8. :. : -, :. :', : · , : : - 1250 N:PN'I:"' "" :" ::"DP~I"'-':":" : ..... :]0:;'0'293'':~:'- ' 1250 0273- ~ 5 0 0 8770 250-0 _- 046'9 6875 ' -NP~I:'.:' :' ':' ":: ....... 32::;1' 2'89 :::::':- 5820 ' ~4-3~ ~c~::: :r~-O"O:O:O":-:Y:C~::- .......... soo-. so:oo 6 250 :< .:.: _: :.._:.::' :: :::: ~::.::: ============================ :: .::::::::::::::::::::::::::::::::::====================== ::: ,:,. _.:::: :_ .._ 4688 8125 "'NPfft-" '::: "*:] 2:1 ...... 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LVP 010,MOl VERIFICATION LISTING NRAT 3.5527 RNRA DT 128,3750 GR oooo SP - ,~2:546,9 GR RHOB 2,0898 GR N.~AT 3.5117 RNRA DT 12~.0000 G~ DEPT 2!00.0000 SFLU SP 33.7813 GR RHO~ ~.1172 GR N~AT .2402 RNRA DT 132.0000 GR DEPT 2300,0000 SFLU SP -39.5313 GR RHOB 2 1191 GR NRAT 3:g926 RNRA DT 142.1250 GR oooo RHOB Z'6406 ~NRA DT -99 2500 GR DBPT 200~0 0000 SFDU sp - ~,~ :o~3 ~ RHOB 1. 9277 GR N ;~AT 3.8516 RNRA DT -999,2500 GR DEPT 1900 0000 SFbU SP '69" .2500 GR DEPT 1.800,0000 SFLU SP 7! .7500 GR RHOB ~ 0703 GR NRAT .., :9531 RNRA DT -999,2500 GR .DEPT !700 0000 SFLU -7t:5625 c,R RHOB 2.1914 GR 57.! 0625 51,5938 4 ,06-6~- 52.5938 :, 6 . 3750 52.718'8 :. 61.3 '9'?~i~ 60.7 17,484-4 ~ 254~. 0000-: 4~,656'3:- 7~' 750 -999, -: -999.. 26,234::4 -~ 4 5, 7813 :.:< .::CAb:~'::::::. 0 ': 0,7188 - 9 -999.2500 . $7 5938 57,5 bVP OlO,MO! 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