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195-132
STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COM i ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon I Plug Perforations IT Fracture Stimulate n Pull Tubing F Operations Shutdown Performed: Suspend Y Perforate IT Other Stimulate IT Alter Casing F Change Approved Program IT Plug for Redrill IT Perforate New Pool IT Repair Well F Re-enter Susp Well IT Other.Stack Packer Imo' 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory 195-132 3.Address: 6.API Number: Stratigraphic I Service P.O. Box 100360,Anchorage,Alaska 99510 50-029-22590-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 26641 KRU 1Q-26 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7010 feet Plugs(measured) 6602 true vertical 6549 feet Junk(measured) 6900 Effective Depth measured 6904 feet Packer(measured) 6203,6342 true vertical 6452 feet (true vertical) 5815,5941 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 3768 7 5/8 3809 3716 PRODUCTION 6960 5.5SKANO6993 OCTyn33 [JLV RECEIVED 4AY 12 2016 Perforation depth: Measured depth: 6417-6432,6445-6467,6507-6522,6696-6726 True Vertical Depth: 6009-6023,6034-6054,6091-6105,6262-6290 O(°".`,("6C Tubing(size,grade,MD,and TVD) 2.875, L-80,6363 MD,5960 TVD Packers&SSSV(type,MD,and ND) PACKER-HS RETRIEVABLE PACKER,450-237, BAKER @ 6203 MD and 5815 TVD PACKER-BAKER SAB-3 PERMANENT PACKER @ 6342 MD and 5941 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation Shut-In 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E. Development F Service r Stratigraphic Copies of Logs and Surveys Run 16.Well Status after work: Oil F Gas ' WDSPL [— Printed Printed and Electronic Fracture Stimulation Data GSTOR r WINJ r WAG r GINJ IT SUSP I' 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: 316-240 Contact Diana Guzman(a.265-6318 Email Diana.Guzmanaconocophillips.com Printed Name Dia Guzman Title Sr.Wells Engineer Signature Phone:266-6318 Date 5//0// Form 10-404 Revised 5/2015 RBDMS 0--MAY 1 2 2016 Submit Original Only • • Operations Summary (with Timelog Depths) a a 1Q-26 Comic°Phitli ps Rig: NABORS 7ES 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) 4/12/2016 4/12/2016 10.00 MIRU MOVE WAIT T Wait for the well house to be removed 0.0 0.0 06:00 16:00 from 1Q-26 due to high winds. SimOps: Finish the PM on the draw works and reinstall guards. Change the oil in the bridge cranes. Clean suction screens on both mud pumps. Inspect the tires and moving system. Change oil in the agitators. 4/12/2016 4/12/2016 2.00 MIRU MOVE RURD P RD all the lines in the interconnect. 0.0 0.0 16:00 18:00 Bridle up the blocks. RD the berming. Blow down the steam and water in the pits. 4/12/2016 4/12/2016 4.00 MIRU MOVE MOB P PJSM. Jack up the pits,pull the 0.0 0.0 18:00 22:00 cutting box and mats. Pull the pits away from the sub and install the jeep. Load up the shop and satellite office. Move the pits,shop,and satellite office from 1C pad to 1Q pad. 4/12/2016 4/12/2016 1.00 MIRU MOVE MOB P Pull the sub off well 1C-102,move to 0.0 0.0 22:00 23:00 the end of the pad,and stage with the wind at the back of the sub. 4/12/2016 4/13/2016 1.00 MIRU MOVE RURD P Clean up the cellar,roll up the 0.0 0.0 23:00 00:00 herculite,load rig mats,and clean up around well 1C-102. 4/13/2016 4/13/2016 1.50 MIRU MOVE RURD P Pull the derrick pins and lay over the 0.0 0.0 00:00 01:30 derrick. 4/13/2016 4/13/2016 0.50 MIRU MOVE MOB P Move the sub to the entrance of 1C 0.0 0.0 01:30 02:00 pad. 4/13/2016 4/13/2016 3.00 MIRU MOVE MOB P Move the sub 5.5 miles from 1C pad 0.0 0.0 02:00 05:00 to the Oliktok Y. 4/13/2016 4/13/2016 1.50 MIRU MOVE WAIT P Wait for field wide change out. 0.0 0.0 05:00 06:30 4/13/2016 4/13/2016 2.00 MIRU MOVE MOB P Move the sub 2.6 miles from Oliktok Y 0.0 0.0 06:30 08:30 to 1Q pad. 4/13/2016 4/13/2016 0.50 MIRU MOVE MOB P Move the sub to the middle of the pad 0.0 0.0 08:30 09:00 and stage with the wind at the back of the sub. 4/13/2016 4/13/2016 2.00 MIRU MOVE RURD P PJSM. Raise and pin the derrick. 0.0 0.0 09:00 11:00 Hang the tree in the cellar. 4/13/2016 4/13/2016 1.00 MIRU MOVE WAIT T Wait for the flow lines to be removed 0.0 0.0 11:00 12:00 from well 1Q-26 and the well prep to be finished around the well. SimOps. Raise the cattle chute. Bridle down the blocks,hang bridle lines in the derrick,and pin the blocks to the TD. 4/13/2016 4/13/2016 2.00 MIRU MOVE WAIT T Wait for the flow lines to be removed 0.0 0.0 12:00 14:00 from well 1Q-26 and the well prep to be finished around the well. SimOps. Hang the rig tongs and set up the rig floor. Page 1/12 Report Printed: 5/9/2016 • • Operations Summary (with Timelog Depths) 5 5 " 1Q-26 wit Ptatl6 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-x Operation (EKE) End Depth(ftKB), 4/13/2016 4/13/2016 4.00 MIRU MOVE WAIT T Wait for the flow lines to be removed 0.0 0.0 14:00 18:00 from well 1Q-26 and the well prep to be finished around the well. SimOps. Grind edges of hammer unions. Clean and organize the sub. Perform general maintenance on the sub. 4/13/2016 4/13/2016 0.50 MIRU MOVE MOB P Move the pits near well 1Q-26. 0.0 0.0 18:00 18:30 4/13/2016 4/13/2016 1.00 MIRU MOVE RURD P Set mats around well 1Q-26 and lay 0.0 0.0 18:30 19:30 out herculite around the well. 4/13/2016 4/13/2016 2.00 MIRU MOVE MOB P PJSM. Spot the sub over well 1Q-26. 0.0 0.0 19:30 21:30 Set mats,lay out herculite in front of the sub,and set the sub down. 4/13/2016 4/14/2016 2.50 MIRU MOVE MOB P PJSM. Spot the pits to the sub,set rig 0.0 0.0 21:30 00:00 mats,lay down herculite for the pits/cuttings box,and spot the cutting tank. 4/14/2016 4/14/2016 4.00 MIRU MOVE RURD P RU berming around the sub,pits,and 0.0 0.0 00:00 04:00 cuttings box. Hook up the interconnect. RU steam,water,and air in the pits. Swap the pits to rig generators. Connect parts house and mud shack to rig power. Rig accepted at 04:00 hours on 4/14/16. 4/14/2016 4/14/2016 3.00 MIRU WELCTL RURD P Load the pits with 8.8 ppg NaCI brine. 0.0 0.0 04:00 07:00 RU circulating lines for the well kill operation. 4/14/2016 4/14/2016 1.50 MIRU WELCTL MPSP P PU the lubricator and make up 0.0 0.0 07:00 08:30 crossover. RU lubricator to the tree and PT to 1500 psi(good test). Pull 3" ISA BPV and RD the lubricator. 4/14/2016 4/14/2016 0.50 MIRU WELCTL RURD P RU circulating lines to the tree through 0.0 0.0 08:30 09:00 the choke manifold to the kill tank. Blow steam and air through line to the kill tank and check connections. PT lines to 3000 psi(good test). Blow down lines. 4/14/2016 4/14/2016 3.00 MIRU WELCTL KLWL P PJSM. Circulate 150 bbls of 8.8 ppg 0.0 0.0 09:00 12:00 NaCI brinedown the tubing taking return out the IA to the kill tank at 1 BPM(ICP=650 psi and FCP=800 psi)getting clean 8.8 ppg seawater at surface. 4/14/2016 4/14/2016 1.00 MIRU WELCTL OWFF P Bleed off the pump pressure. Install 0.0 0.0 12:00 13:00 low pressure gauges on the tubing and IA. Monitor the well pressures for 30 minutes;25 psi on the tubing and IA. Bleed both tubing and IA to 0 psi. Monitor the well pressures;tubing=0 psi and IA=0 psi. Bleed IA to 0 psi. Both tubing and IA slightly dripping. 4/14/2016 4/14/2016 3.00 MIRU WELCTL WAIT T Wait on weather due to field wide 0.0 0.0 13:00 16:00 phase 3 conditions. SimOps: Continue to observe the well for flow for 30 minutes and the well is static. Page 2/12 Report Printed: 5/9/2016 a • r . , Operations Summary (with Timelog Depths) . , _ 1Q-26 t ,i Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time-. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftKB). 4/14/2016 4/14/2016 0.50 MIRU WELCTL CIRC T RU to reverse circulate down the IA 0.0 0.0 16:00 16:30 taking returns out the tubing through the gas buster to the pits. Reveres circulate 31.5 bbls at 1 BPM=880 psi. 4/14/2016 4/14/2016 0.50 MIRU WELCTL OWFF T Bleed off the pump. Observe the well 0.0 0.0 16:30 17:00 for flow for 30 minutes and the well is static. 4/14/2016 4/14/2016 0.50 MIRU WELCTL RURD P Close in the well,blow down all 0.0 0.0 17:00 17:30 circulating lines,and secure the cellar. 4/14/2016 4/14/2016 1.00 MIRU WELCTL SFTY P Hold an appreciation dinner for both 0.0 0.0 17:30 18:30 rig crews for excellent work and safety record. 4/14/2016 4/14/2016 1.00 MIRU WELCTL RURD P RD all circulating lines and install 0.0 0.0 18:30 19:30 secondary annulus valve. 4/14/2016 4/14/2016 0.50 MIRU WHDBOP MPSP P Install 3"ISA BPV with dry rod. 0.0 0.0 19:30 20:00 Pressure up on the IA to 1000 psi to PT the BPV from below in the direction of flow for 10 minutes(good test). 4/14/2016 4/14/2016 2.00 MIRU WHDBOP NUND P RU wire slings to the TD and RU 0.0 0.0 20:00 22:00 slings to the tree. ND the tree and tubing head adapter. Pull the tree free with the TD. RU the bridge crane to the tree. Lay down the tree and tubing head adapter. Clean and inspect the tubing hanger lift threads. Install the blanking plug(8 right hand turns). 4/14/2016 4/15/2016 2.00 MIRU WHDBOP NUND P NU the DSA and NU the BOP stack. 0.0 0.0 22:00 00:00 4/15/2016 4/15/2016 1.50 MIRU WHDBOP NUND P Torque bolts on the DSA and BOP 0.0 0.0 00:00 01:30 stack. Install the turn buckles and riser. Air up the air boots on the riser. 4/15/2016 4/15/2016 1.50 MIRU WHDBOP RURD P RU BOPE testing equipment. Fill 0.0 0.0 01:30 03:00 BOP stack and choke manifold with fresh water. MU 2-7/8"doughnut test joint with HT-38 TIW and MU the TD. Page 3/12 Report Printed: 5/9/2016 • r Operations Summary (with Timelog Depths) • 1Q-26 ConocoPhiflips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr),', Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth(ftK8). 4/15/2016 4/15/2016 1.50 MIRU WHDBOP BOPE P Conduct initial BOPE: test 2-7/8"x 5" 0.0 0.0 03:00 04:30 VBR's(upper and lower pipe rams)to 250/3000 psi with 2-7/8"and 3-1/2" test joints;test annular to 250/3000 with 2-7/8"and 3-1/2"test joints; conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Bob Noble via email on 4/13/16 at 09:36 hours. Tests: 1) Lower Pipe Rams with 2-7/8"test joint, Upper IBOP(Passed) 2) Upper Pipe Rams with 2-7/8"test joint,Lower IBOP,2"Demco,Chokes 1,2,3,&16(Passed) 3) Upper Pipe Rams with 2-7/8"test joint,HCR Kill, HT-38 TIW,Chokes 4, 5,&6(Passed) 4) Upper Pipe Rams with 2-7/8"test joint,Manual Kill,Chokes 7,8,&9 (Passed) 5) Super Choke and Manual Adjustable Choke(Passed) 6) Upper Pipe Rams with 2-7/8"test joint,Manual Kill,Chokes 8, 10,&11 (Passed) 4/15/2016 4/15/2016 1.50 MIRU WHDBOP BOPE T Test: 0.0 0.0 04:30 06:00 7) Annular with 2-7/8"test joint, Manual Kill,Chokes 8, 12,&13 (Passed) Note: Annular failed the high pressure test and retest passed. 4/15/2016 4/15/2016 5.00 MIRU WHDBOP BOPE P Tests: 0.0 0.0 06:00 11:00 8) Blind Rams, Manual Kill,HT-38 Dart Valve,Outer Test Spool,Chokes 8, 12,&13(Passed) 9) Blind Rams, Manual Kill, Inner Test Spool,Chokes 8, 12,&13(Passed) 10)Annular with 3-1/2"test joint, Manual Kill,3-1/2"EUE 8rd TIW, Choke 15(Passed) 11)Upper Pipe Rams with 3-1/2"test joint,3-1/2"EUE 8rd TIW,Choke 14 (Passed) 12)Upper Pipe Rams with 3-1/2"test joint,3-1/2"EUE 8rd TIW, Manual Choke(Passed) 13)Upper Pipe Rams with 3-1/2"test joint,3-1/2"EUE 8rd TIW,HCR Choke (Passed) 14)Lower Pipe Rams with 3-1/2"test joint,3-1/2"EUE 8rd TIW(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3000 psi Accumulator Pressure After Closer= 1650 psi Pressure Gain of 200 psi=10 seconds Full System=88 Seconds Average N2(5 Bottles)=1961 psi Page 4/12 Report Printed: 5/9/2016 • • M -4 '' Operations Summary (with Timelog Depths) L171 1Q-26 ConocdPt 35 ,' Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time, End Time Our(hr);, Phase Op Code Activity Code Time P-T-X Operation (ft(i3) End Depth(ftKE), 4/15/2016 4/15/2016 1.00 MIRU WHDBOP RURD P Pull blanking plug with 3-1/2"test joint 0.0 0.0 11:00 12:00 and lay down the test joint. Drain the BOP stack and gas buster. Blow down lines,choke manifold,and BOPE testing equipment. RD BOPE testing equipment. 4/15/2016 4/15/2016 0.50 COMPZN RPCOMP MPSP P Check for pressure under BPV(no 0.0 0.0 12:00 12:30 pressure)and pull 3"ISA BPV with dry rod. 4/15/2016 4/15/2016 0.50 COMPZN RPCOMP RURD P RU 3-1/2"tubing elevators,MU 0.0 0.0 12:30 13:00 landing joint, MU 3-1/2"EUE 8rd TIW, and MU TD. 4/15/2016 4/15/2016 0.75 COMPZN RPCOMP RURD P PJSM. Attempt to BOLDS but LDS 0.0 0.0 13:00 13:45 were tight. RD landing joint with 3- 1/2"EUE 8rd TIW. RU 3 pup joints for landing joint,MU 3-1/2"EUE 8rd TIW, and MU the TD. 4/15/2016 4/15/2016 0.25 COMPZN RPCOMP PULL T BOLDS and unseat the tubing hanger 0.0 6,342.0 13:45 14:00 at 50K. Establish PU parameters 50K to 100K. Set torque limit to 2200 ft- lbs. Rotate 1 turn to the right and work torque down. Rotate an additional 2-1/4 turns to right and work torque down. Unable to get the tubing to rotate with max allowed torque. Call out for SLB DSL(digital slickline). 4/15/2016 4/15/2016 1.00 COMPZN RPCOMP WAIT T Wait for SLB DSL to arrive. 6,342.0 6,342.0 14:00 15:00 SimOps: Continue to work the tubing attempting to rotate to the right to release the K-22 anchor from the SAB -3 packer. 4/15/2016 4/15/2016 0.50 COMPZN RPCOMP RURD T Set the landing joint in the slips with 6,342.0 0.0 15:00 15:30 75K. Break out the TD,crossover, and 10'pup joint from landing joint. MU 3-1/2"EUE 8rd TIW. 4/15/2016 4/15/2016 4.50 COMPZN RPCOMP DSL T Spot up SLB DSL unit. PJSM with 0.0 0.0 15:30 20:00 both crews. Bring tools and equipment to the rig floor. RU SLB DSL. 4/15/2016 4/15/2016 1.00 COMPZN RPCOMP DSL T DSL damaged. Cut DSL and re head. 0.0 0.0 20:00 21:00 MU 2"bailer. 4/15/2016 4/15/2016 2.00 COMPZN RPCOMP DSL T RIH with 2"bailer and tag top of sand 0:0 0.0 21:00 23:00 at 6262'ORKB. Activate bailer and POOH. 4/15/2016 4/15/2016 0.50 COMPZN RPCOMP DSL T Bailer at surface and did not recover 0.0 0.0 23:00 23:30 any sand. Break out 2"bailer and MU new 2"bailer. 4/15/2016 4/16/2016 0.50 COMPZN RPCOMP DSL T RIH with new 2"bailer. 0.0 0.0 23:30 00:00 4/16/2016 4/16/2016 0.50 COMPZN RPCOMP DSL T Continue to RIH with new 2"bailer. 0.0 0.0 00:00 00:30 Tag sand at 6262'ORKB,activate bailer,and POOH. 4/16/2016 4/16/2016 0.25 COMPZN RPCOMP DSL T Bailer at surface and recover 0.0 0.0 00:30 00:45 approximately.5 gallon of river sand. Break out 2"bailer and MU 1-3/4" bailer. 4/16/2016 4/16/2016 0.50 COMPZN RPCOMP DSL T RIH with 1-3/4"bailer. Tag sand at 0.0 0.0 00:45 01:15 6264'ORKB,activate bailer,and POOH. Page 5/12 Report Printed: 5/9/2016 S Et Operations Summary (with Timelog Depths) 1Q-26 ithp5 Rig: NABORS 7ES 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)'. 4/16/2016 4/16/2016 0.25 COMPZN RPCOMP DSL T Bailer at surface and 1 gallon of river 0.0 0.0 01:15 01:30 sand. Break out 1-3/4"bailer and MU 2"bailer. 4/16/2016 4/16/2016 19.75 COMPZN RPCOMP DSL T RIH with 2"bailer,activate bailer,and 0.0 0.0 01:30 21:15 POOH. Recovered 1 gallon of river sand. RIH with 1-3/4"bailer 21 times recovering.75 to 1.5 gallons of sand each run. Recovering river sand down to 6270'SLM(6300'ORKB),clean frac sand from 6270'-6278'SLM (6300'-6308'ORKB),and dirty frac sand from 6278'-6290'SLM(6308'- 6320'ORKB). On run#25 tagged sand at 6281'SLM(6311'ORKB). Sand is coming in from the IA through the open GLM at 6297'ORKB into the tubing. RD SLB DSL off to the side. 4/16/2016 4/16/2016 1.25 COMPZN RPCOMP CIRC T RU circulating equipment. Circulate 0.0 0.0 21:15 22:30 1.5 hole volumes;ICP at 2 BPM=600 psi and FCP at 4 BPM= 1030 psi. Sand recovered across the shakers at bottoms up. Blow down and RD circulating equipment. 4/16/2016 4/17/2016 1.50 COMPZN RPCOMP DSL T RU SLB DSL. RIH with 1-3/4"bailer 2 0.0 0.0 22:30 00:00 times recovering 1.5 gallons of dirty frac sand each time down to 6295' SLM(6325'ORKB). 4/17/2016 4/17/2016 6.50 COMPZN RPCOMP DSL T RIH with 1-3/4"bailer 4 times 0.0 0.0 00:00 06:30 recovering 1 to 1.5 gallons of dirty frac sand each time down to 6303'SLM (6333'ORKB). RIH with 1-3/4"bailer 4 times recovering.5 to 1 gallons of silty/frac sand each time down to 6308'SLM(6338'ORKB). RIH with 2- 1/4"bailer(drift run for the jet cutter)to 6307'SLM(6337'ORKB). Correlate with CCL and true tag depth is 6334' ORKB. 4/17/2016 4/17/2016 4.50 COMPZN RPCOMP DSL T MU and RIH with 2-1/8"Power Jet 0.0 0.0 06:30 11:00 Cutter. Correlate and tie into GLM at 6297'ORKB. Cut the tubing at 6314' ORKB and POOH. Confirmed cutter fires at surface. RD SLB DSL off to the side. PU on the tubing(85K)and confirmed that the tubing was free. RD SLB DSL and offload equipment from the rig floor. 4/17/2016 4/17/2016 1.00 COMPZN RPCOMP CIRC T RU circulating equipment. Circulate 0.0 6,314.0 11:00 12:00 1.5 hole volumes at 5 BPM(ICP= 1250 psi and FCP=1150 psi)while reciprocating the tubing. 5 gallons of sand recovered across the shakers at bottoms up. Blow down and RD circulating equipment. PU=80K. 4/17/2016 4/17/2016 0.50 COMPZN RPCOMP RURD P Bring Weatherford power tubing tongs, 6,314.0 6,314.0 12:00 12:30 3-1/2"handling equipment,and 2-7/8" handling equipment to the rig floor. RU Weatherford to pull 3-1/2"x 2-7/8" completion. Page 6/12 Report Printed: 5/9/2016 • • c. E Operations Summary (with Timelog Depths) t',t co,o t,ilii r 1 Q-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log StartDepth Start Time End Time Dur(hr)', Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/17/2016 4/17/2016 1.25 COMPZN RPCOMP PULL P PJSM. Pull the tubing hanger to the 6,314.0 5,717.0 12:30 13:45 rig floor and lay down. POOH laying down 3-1/2"x 2-7/8"tubing to 5717' RKB 4/17/2016 4/17/2016 0.25 COMPZN RPCOMP SFTY P Kick while tripping drill: well secured 5,717.0 5,717.0 13:45 14:00 in 45 seconds and CRT=73 seconds. AAR with crew. 4/17/2016 4/17/2016 0.50 COMPZN RPCOMP SVRG P Service and DOMS inspection on the 5,717.0 5,717.0 14:00 14:30 TD. 4/17/2016 4/17/2016 7.00 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 5,717.0 0.0 14:30 21:30 x 2-7/8"tubing from 5717'RKB to surface. Recovered 192 joints of 3- 1/2"tubing,7 joints of 2-7/8"tubing, 2.812"DS nipple,4 KBMM GLM's and cut joint=7.40'(tubing cut at 6311.29' ORKB). Hole found in cut joint 2.12' from the top of the joint(6306.01' ORKB). Clean and clear the floor. 4/17/2016 4/17/2016 0.50 COMPZN WELLPR RURD P MU wear ring running tool,install the 0.0 0.0 21:30 22:00 wear ring,and lay down wear ring running tool. 4/17/2016 4/17/2016 0.25 COMPZN WELLPR SFTY P PJSM for PU and MU cleanout 0.0 0.0 22:00 22:15 assembly with dress off shoe. 4/17/2016 4/18/2016 1.75 COMPZN WELLPR BHAH P PU and MU BHA#1 -cleanout 0.0 230.0 22:15 00:00 assembly with dress off shoe. 4/18/2016 4/18/2016 0.25 COMPZN WELLPR SFTY P Kick while tripping drill: well secured 230.0 230.0 00:00 00:15 in 41 seconds and CRT=99 seconds. AAR with crew. 4/18/2016 4/18/2016 5.75 COMPZN WELLPR PULD P RIH with BHA#1 -cleanout assembly 230.0 5,543.0 00:15 06:00 with dress off shoe on 3-1/2"PH-6 work string to 5543'RKB(PU=95K and SO=85K). 4/18/2016 4/18/2016 0.50 COMPZN WELLPR SVRG P Service and DOMS inspection on the 5,543.0 5,543.0 06:00 06:30 TD. Derrick inspection. 4/18/2016 4/18/2016 1.50 COMPZN WELLPR PULD P Continue RIH with BHA#1 from 5543' 6,294.0 6,294.0 06:30 08:00 to 6294'RKB. 4/18/2016 4/18/2016 0.50 COMPZN WELLPR MILL P MU the TD and establish parameters. 6,294.0 6,294.0 08:00 08:30 PU=105K,SO=85K,rotating weight =90K,and free torque=2000 ft-lbs. SPR with mud pump#2: 2 BPM=280 psi and 3 BPM=660 psi. Tag the top of the tubing stub at 6295'RKB. Bring the pumps up to 5 BPM=1800 psi, rotate at 50 RPM,and dress off the top of the cut 2-7/8"tubing stub. 4/18/2016 4/18/2016 0.50 COMPZN WELLPR WASH P Wash over tubing stub cleaning out 6,294.0 6,320.0 08:30 09:00 sand at 5 BPM=1750 psi down to 6320'RKB. 4/18/2016 4/18/2016 1.00 COMPZN WELLPR CIRC P Pump 40 bbl hi vis sweep and 6,320.0 6,320.0 09:00 10:00 circulate the well clean at 8 BPM= 3900 psi(pumped 228 bbls). Page 7/12 Report Printed: 5/9/2016 • 0 Operations Summary (with Timelog Depths) • Y . .ear f CSR .. 1Q-26 Cil6 .�. Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (RKB) End Depth(EKS) 4/18/2016 4/18/2016 1.00 COMPZN WELLPR PRTS T Close the upper pipe rams. Attempt to 6,320.0 6,320.0 10:00 11:00 PT the 5-1/2"casing and SAB-3 packer/PXN plug to 2500 psi but unable to get the pressure above 2450 psi pumping at 0.8 BPM. Shut down the pumps and the pressure bleed off to 1800 psi in 15 minutes. Blow down the TD. Notified town engineer. Attempt to pressure test again to verify IC packoff integrity but still unable to get the pressure above 2400 psi while continuously pumping. Shut down the pumps and the pressure bleed down to 2000 psi in 10 minutes. Bleed off the pressure and open upper pipe rams. 4/18/2016 4/18/2016 0.50 COMPZN WELLPR RURD P Blow down pressure testing lines. 6,320.0 6,320.0 11:00 11:30 PJSM. Install stripping rubbers and air slips. 4/18/2016 4/18/2016 3.00 COMPZN WELLPR TRIP P TOOH with BHA#1 from 6320'to 230' 6,320.0 230.0 11:30 14:30 RKB. 4/18/2016 4/18/2016 2.50 COMPZN WELLPR BHAH P Lay down BHA#1 -cleanout 230.0 0.0 14:30 17:00 assembly with dress off shoe. Clean and clear the rig floor. 4/18/2016 4/18/2016 1.00 COMPZN WELLPR BHAH T PJSM. PU and MU BHA#2- test 0.0 14.0 17:00 18:00 packer assembly. 4/18/2016 4/18/2016 4.75 COMPZN WELLPR TRIP T TIH with BHA#2 to 6285'RKB. 14.0 6,285.0 18:00 22:45 4/18/2016 4/18/2016 0.25 COMPZN WELLPR SFTY P Kick while tripping drill: well secured 6,285.0 6,285.0 22:45 23:00 in 37 seconds and CRT=81 seconds. AAR with crew. 4/18/2016 4/18/2016 0.25 COMPZN WELLPR MPSP T Set the test packer with center of 6,285.0 6,285.0 23:00 23:15 element at 6281'RKB. 4/18/2016 4/18/2016 0.50 COMPZN WELLPR PRTS T Close the upper pipe rams and 6,285.0 6,285.0 23:15 23:45 pressure up on the IA to 2500 psi for 10 minutes to PT the 5-1/2"casing from 6281"RKB to surface(good test). Bleed off the pressure and open the upper pipe rams. Pressure up on the DP to test the 5-1/2"casing and SAB-3 packer/PXN plug combination to 2500 psi but unable to get the pressure above 2400 psi pumping at 1 BPM. Bleed the pressure off. The 5- 1/2"casing leak likely at the same depth as the hole in the 2-7/8"tubing (6306'ORKB). 4/18/2016 4/19/2016 0.25 COMPZN WELLPR MPSP T Release the test packer and 6,285.0 6,285.0 23:45 00:00 manipulate back into the running position. 4/19/2016 4/19/2016 3.00 COMPZN WELLPR PULD T POOH laying down 3-1/2"PH-6 work 6,285.0 2,920.0 00:00 03:00 string from 6285'to 2920'RKB(PU= 65K and SO=60K). 4/19/2016 4/19/2016 1.50 COMPZN WELLPR TRIP T TOOH standing back PH-6 work string 2,920.0 14.0 03:00 04:30 from 2920'to surface. 4/19/2016 4/19/2016 0.50 COMPZN WELLPR BHAH T Lay down BHA#2- test packer 14.0 0.0 04:30 05:00 assembly. 4/19/2016 4/19/2016 0.50 COMPZN WELLPR BHAH T PU and MU BHA#3-'G'lock-set RBP 0.0 20.0 05:00 05:30 assembly. 4/19/2016 4/19/2016 2.00 COMPZN WELLPR TRIP T TIH with BHA#3 to 2911'RKB 20.0 2,911.0 05:30 07:30 Page 8/12 Report Printed: 5/9/2016 • • r Operations Summary (with Timelog Depths) `Phiitii� 1 Q-26 Rig: NABORS 7ES 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) 4/19/2016 4/19/2016 0.75 COMPZN WELLPR MPSP T Set the'G'lock-set RBP at 2905'RKB 2,911.0 2,891.0 07:30 08:15 (center of element). Release running tool from the'G'lock-set RBP and 20'. Close the upper pipe rams. PT to 1500 psi for 10 minutes(good test). Bleed off the pressure and open the upper pipe rams. 4/19/2016 4/19/2016 0.50 COMPZN WELLPR TRIP T TOOH standing back 3 stands. 2,891.0 2,612.0 08:15 08:45 4/19/2016 4/19/2016 0.50 COMPZN WELLPR BHAH P PU and MU BHA#4-storm packer 2,612.0 2,633.0 08:45 09:15 assembly. 4/19/2016 4/19/2016 0.50 COMPZN WELLPR MPSP P Set the storm packer at 106'RKB 2,633.0 2,724.0 09:15 09:45 (center of element). Release from the storm packer and stand back the stand. Close the blind rams. PT to 1500 psi for 10 minutes(good test). Bleed off the pressure and open the blind rams. 4/19/2016 4/19/2016 1.75 COMPZN WELLPR NUND P Drain the BOP stack and blow down 0.0 0.0 09:45 11:30 lines. ND BOPE and ND the DSA. 4/19/2016 4/19/2016 0.50 COMPZN WELLPR NUND P Pull the wear ring. 0.0 0.0 11:30 12:00 4/19/2016 4/19/2016 1.50 COMPZN WELLPR NUND P ND IA valve on blank flange off tubing 0.0 0.0 12:00 13:30 head. Remove every other blot.Check for 5.5"casing growth and the casing did not grow. Remove old tubing head. 4/19/2016 4/19/2016 1.50 COMPZN WELLPR WWSP P Pull the 5-1/2"casing packoff,install 0.0 0.0 13:30 15:00 new 5-1/2"casing packoff,and torque the bolts on the packoff. 4/19/2016 4/19/2016 1.00 COMPZN WELLPR NUND P NU new tubing head and torque bolts. 0.0 0.0 15:00 16:00 Test packoff to 250/3000 psi for 5 minutes each(good test). 4/19/2016 4/19/2016 3.00 COMPZN WELLPR NUND P NU the DSA,NU the BOP stack,and 0.0 0.0 16:00 19:00 NU second IA valve. 4/19/2016 4/19/2016 0.50 COMPZN WELLPR BOPE P RU to test BOPE.Set test plug and fill 0.0 0.0 19:00 19:30 stack. 4/19/2016 4/19/2016 0.50 COMPZN WELLPR BOPE P PT the break on BOP Stack to 0.0 0.0 19:30 20:00 250/3000 psi for 5 minutes each(good test) 4/19/2016 4/19/2016 0.50 COMPZN WELLPR BOPE P Blow down BOPE testing equipment, 0.0 0.0 20:00 20:30 drain the BOP stack,and RD BOPE testing equipment. 4/19/2016 4/19/2016 0.50 COMPZN WELLPR RURD P MU wear ring running tool,install the 0.0 0.0 20:30 21:00 wear ring,and lay down the wear ring running tool. 4/19/2016 4/19/2016 0.75 COMPZN WELLPR MPSP P PU 1 stand,RIH,engage the storm 0.0 2,633.0 21:00 21:45 packer,open the equalizing valve(no pressure),release the storm packer, and stand back 1 stand. 4/19/2016 4/19/2016 0.25 COMPZN WELLPR BHAH P Lay down BHA#4-storm packer 2,633.0 2,612.0 21:45 22:00 assembly. 4/19/2016 4/19/2016 0.25 COMPZN WELLPR TRIP T TIH with 3 stands. 2,612.0 2,911.0 22:00 22:15 4/19/2016 4/19/2016 0.75 COMPZN WELLPR MPSP T Engage'G'lock-set RBP,release,and 2,911.0 2,911.0 22:15 23:00 monitor the well for 5 minutes. 4/19/2016 4/20/2016 1.00 COMPZN WELLPR PULD P POOH with BHA#3 from 2911'to 2,911.0 1,500.0 23:00 00:00 1500'RKB at midnight. Page 9/12 Report Printed: 5/9/2016 • r = Operations Summary (with Timelog Depths) 1Q-26 ConocoPhitlips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr)i Phase Op.Code Activity Code Time P-T-X Operation (SKE) End Depth(ftKS)i 4/20/2016 4/20/2016 1.50 COMPZN WELLPR PULD P Continue POOH with BHA#3-'G'lock 1,500.0 20.0 00:00 01:30 -set RBP assembly laying down 3-1/2" PH-6 work string from 1500'RKB to 'G'lock-set RBP. 4/20/2016 4/20/2016 0.25 COMPZN WELLPR BHAH T Lay down'G'lock-set RBP. 20.0 0.0 01:30 01:45 4/20/2016 4/20/2016 0.50 COMPZN WELLPR RURD P MU wear ring pulling tool,pull the 0.0 0.0 01:45 02:15 wear ring,and lay down wear ring pulling tool. 4/20/2016 4/20/2016 0.25 COMPZN RPCOMP RURD P Change elevators to 2-7/8"tubing 0.0 0.0 02:15 02:30 elevators and organize jewelry in the pipe shed into running order. 4/20/2016 4/20/2016 3.00 COMPZN RPCOMP PUTB P PJSM. PU and MU poorboy overshot, 0.0 2,184.0 02:30 05:30 1 joint,nipple assembly, 1 joint,HS packer/PBR assembly, 1 joint,and GLM#1. Continue to RIH with stacked packer gas lift completion per tally with 2-7/8"6.5#L-80 EUE 8rd Mod tubing to 2184'RKB(PU=42K and SO=45K) 4/20/2016 4/20/2016 0.50 COMPZN RPCOMP SVRG P Inspect and service the TD. 2,184.0 2,184.0 05:30 06:00 4/20/2016 4/20/2016 4.50 COMPZN RPCOMP PUTB P Continue to RIH with stacked packer 2,184.0 6,302.0 06:00 10:30 gas lift completion from 2184'to 6290' RKB(PU=63K and SO=60K). Locate tubing stub with poorboy overshot,set down 10K to shear indicating shear screws,SO an additional 6'to no-go,and PU 1'(bottom of poorboy overshot at 6301.89'RKB). 4/20/2016 4/20/2016 0.75 COMPZN RPCOMP CRIH P MU to top drive and circulate 60 bbls 6,302.0 6,302.0 10:30 11:15 of 8.8 ppg corrosion inhibited NaCI brine at 3 BPM=400 psi. 4/20/2016 4/20/2016 0.75 COMPZN RPCOMP PACK P Drop the ball&rod. Pressure up on 6,302.0 6,302.0 11:15 12:00 the tubing to 2500 psi to set the HS packer and hold for 10 minutes. Bring the tubing pressure up to 3000 psi to shear the PBR. Top of the PBR at 6164.52'RKB and top of the HS packer at 6167.47'RKB, 4/20/2016 4/20/2016 0.25 COMPZN RPCOMP HOSO P Lay down joints#195-193. PU and 6,187.0 6,149.0 12:00 12:15 MU 6.17'pup joint and joint#193. 4/20/2016 4/20/2016 0.50 COMPZN RPCOMP THGR P PU and MU 2-7/8"x 3-1/2"crossover 6,149.0 6,154.0 12:15 12:45 and MU the FMC tubing hanger with 3 -1/2"pup joint below. MU the landing joint. 4/20/2016 4/20/2016 0.25 COMPZN RPCOMP SFTY P Kick while tripping drill: well secured 6,154.0 6,154.0 12:45 13:00 in 38 seconds. AAR with crew. 4/20/2016 4/20/2016 1.00 COMPZN RPCOMP CRIH P Circulate 85 bbls corrosion inhibited 6,154.0 6,154.0 13:00 14:00 NaCI brine down the tubing taking return up the IA and chase with 10 bbls of 8.8 ppg NaCI brine at 2 BPM= 165 psi. 4/20/2016 4/20/2016 0.50 COMPZN RPCOMP THGR P Drain BOP stack. Land the tubing 6,154.0 6,179.0 14:00 14:30 hanger(PU=67K and SO=60K)and RILDS. Page 10/12 Report Printed: 5/9/2016 • • • Operations Summary (with Timelog Depths) 3 � 1Q-26 CcicKacoPhiHips Rig: NABORS 7ES 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(5K13) 4/20/2016 4/20/2016 1.00 COMPZN RPCOMP PRTS P PT the tubing to 3000 psi for 15 6,179.0 6,179.0 14:30 15:30 minutes(good test),bleed the tubing to 1500 psi,and PT the IA to 2500 psi for 30 minutes(good test). Quickly bleed the pressure off the tubing to shear the SOV. Pump 1 bbls each way through the SOV. 4/20/2016 4/20/2016 0.50 COMPZN RPCOMP RURD P Break out and lay down landing joint. 6,179.0 0.0 15:30 16:00 Blow down the TD and RD circulating equipment. 4/20/2016 4/20/2016 1.00 COMPZN WHDBOP MPSP P Drain the BOP stack. Install the 3" 0.0 0.0 16:00 17:00 ISA BPV with dry rod and pressure up on the IA to 1500 psi for 10 minutes to test the BPV from below in the direction of flow(good test). Bleed off the pressure. 4/20/2016 4/20/2016 1.00 COMPZN WHDBOP WWWH P PU single joint of DP and MU stack 0.0 0.0 17:00 18:00 jetting sub. MU the TD and space out to bottom pipe ram. Pump 8 BPM= 800 psi with slow rotation,PU slowly and make two passes to clean out sand from BOP stack.Lay down stack jetting sub and joint of DP. Blow down the TD,kill,choke,fill up line,and choke manifold. 4/20/2016 4/20/2016 2.00 COMPZN WHDBOP SVRG P Clean under the rotary table,steam 0.0 0.0 18:00 20:00 tables,and draw works with a super sucker. 4/20/2016 4/20/2016 1.50 COMPZN WHDBOP SVRG P Perform CPAI Between Wells 0.0 0.0 20:00 21:30 Maintenance(BWM)on the BOP stack: Break bolts on the lower ram doors,open doors,and function ram pistons to the closed position. Inspect rams,ram cavities,sealing surfaces, and door seals. Close the lower ram doors and tighten the bolts(photos taken of all components and of stack cavities). 4/20/2016 4/21/2016 2.50 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Break 0.0 0.0 21:30 00:00 bolts on blind ram doors,open doors, and function ram piston to the closed position.Inspect ram cavities,sealing surfaces,and door seals. Inspect blind upper seal and front packer assembly.Change out the top seal on the blind rams(photos taken of all components and of stack cavities). 4/21/2016 4/21/2016 1.00 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Break 0.0 0.0 00:00 01:00 bolts on the upper ram doors,open doors,and function ram pistons to the closed position. Inspect rams,ram cavities,sealing surfaces,and door seals. Close the upper ram doors and tighten the bolts(photos taken of all components and of stack cavities). 4/21/2016 4/21/2016 0.50 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Pull 0.0 0.0 01:00 01:30 the riser. Install 3-1/2"joint of DP and function annular checking for excessive wear and overall condition (photos taken of annular). Page 11/12 Report Printed: 5/9/2016 • • f` Operations Summary (with Timelog Depths) ,,, 1Q-26 ,. t iups Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase ,Op Code Activity Code Time P-T-X Operation (ftK6) End Depth(ftK(3)'.. 4/21/2016 4/21/2016 2.00 COMPZN WHDBOP NUND P Remove lower Koomey line off the 0.0 0.0 01:30 03:30 annular,remove turn buckles,and attach the lift ring. ND the BOP stack and ND the DSA. Set the BOP stack on the stump and secure. 4/21/2016 4/21/2016 1.00 COMPZN WHDBOP NUND P Remove the DSA,clean around the 0.0 0.0 03:30 04:30 tubing hanger,and NU the tubing head adapter. 4/21/2016 4/21/2016 0.25 COMPZN WHDBOP PRTS P PT the tubing hanger void to 250/5000 0.0 0.0 04:30 04:45 psi(good test). 4/21/2016 4/21/2016 0.75 COMPZN WHDBOP NUND P NU the 3-1/8"tree and torque the 0.0 0.0 04:45 05:30 bolts. 4/21/2016 4/21/2016 0.50 COMPZN WHDBOP MPSP P Pull the 3"ISA BPV with dry rod and 0.0 0.0 05:30 06:00 install the tree test plug with dry rod. 4/21/2016 4/21/2016 1.25 COMPZN WHDBOP PRTS P Fill the tree with diesel and RU testing 0.0 0.0 06:00 07:15 equipment. PT the tree to 250/5000 psi for 5 minutes each(good test). RD tree testing equipment. 4/21/2016 4/21/2016 0.25 COMPZN WHDBOP MPSP P Pull the tree test plug with dry rod. 0.0 0.0 07:15 07:30 4/21/2016 4/21/2016 1.00 COMPZN WHDBOP FRZP P PJSM. RU circulating lines to pump 0.0 0.0 07:30 08:30 down the IA taking returns out the tubing to the cuttings box. RU Little Red Services(LRS). PT LRS and surface lines to 3000 psi(good test). 4/21/2016 4/21/2016 0.50 COMPZN WHDBOP FRZP P Freeze protect the well by pumping 52 0.0 08:30 09:00 bbls of diesel with LRS at 2 BPM(ICP =525 psi and FCP= 1300 psi)and sucked backed 2 bbls. 4/21/2016 4/21/2016 1.25 COMPZN WHDBOP FRZP P Place the tubing and IA in 0.0 0.0 09:00 10:15 communication allowing the well to u- tube and equalize. Blow down and RD circulating lines. SimOps: RD LRS. 4/21/2016 4/21/2016 0.25 COMPZN WHDBOP MPSP P Install 3"ISA BPV with dry rod. 0.0 0.0 10:15 10:30 Final well pressures: Tubing=0 psi, IA=0 psi,and OA=50 psi. 4/21/2016 4/21/2016 1.50 DEMOB MOVE RURD P RD all cellar lines and RD annulus 0.0 0.0 10:30 12:00 valve. Install gauges on the tree, secure the well,and secure the cellar. Release the rig at 12:00 hours on 4-21 -16 Page 12/12 Report Printed: 5/9/2016 KUP �OD 16,-26 ConocoPhiflips Well Attribu Max Angle MD TD Alaska,Inc, % .k,„,,,, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) • c,,,,, (00,.`T 500292259000 KUPARUK RIVER UNIT PROD 31.89 4,231.66 7,010.0 „, ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1Q-26,5/9/20162:5713 PM SSSV:NIPPLE 90 11/5/2014 Last WO: 4/21/2016 9/23/1995 Vertical sctwmagc(aptuap Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,483.0 4/28/2016 Rev Reason:WORKOVER;GLV C/O;TAG lehallf 5/2/2016 HANGER;364 { Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 40.9 121.0 121.0 62.50 H-40 WELDED XO.39.5 Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen)I...Grade Top Thread kr SURFACE 7 5/8 6.875 40.9 3,809.2 3,715.7 29.70 L-80 LTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread PRODUCTION 51/2 4.950 33.3 6,992.8 6,533.4 15.50 L-80 LTC-MOD Tubing Strings CONDUCTOR;40.9-121.0-4 \ Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(16/ft) Grade Top Connection TUBING RWO 2016 1String 27/81 2.441/ 36.31 6,317.91 5,919 .11 6.501 L -80 I EUE 8rd Mod Completion Details GAS LIFT;0504.1 1 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 36.3 36.3' 0.10 HANGER 'FMC Tubing Hanger,TC-1A-EN,6"x 3-1/2"EUE 8rd Box 2.992 x Box,3"ISA BPVG 39.5 39.5 0.11 XO Crossover,3-1/2"EUE 8rd Mod Box x 2-7/8"EUE 8rd Pin 2.375 6,172.1 5,786.9 25.33 LOCATOR 'Locator Sub,GBH-22(bottom of locator spaced out 8.19') 2.400 GAS LIFT;3,790 2 6,173.1 5,787.8 25.33 SEAL ASSY Seal Assembly,80-32(seal assembly=21.58') 2.400 a. 6,180.5 5,794.5 25.29 PBR PBR,80-32,Baker(effective stroke=20.28') 3.250 6,203.4 5,815.3 25.16 PACKER HS Retrievable Packer,450-237,Baker(shear release= 2.373 30K) SURFACE,400-3,0092-. 6,256.6 5,863.5 24.87 NIPPLE Nipple,Camco,2.312"DS,SN:T041416 2.312 6,309.9 5,911.9 24.58 POORBOY Poorboy Overshot with Packoff(swallow=7.56') 2.950 OVERSHOT GAS LIFT;4,8250 ir Tubing DescriptionString Ma...ID(in) Top(RKB) Set Depth(ft..Set Depth(TVD)(... ((b/ft) Grade Top Connection Original Tubing 1 2 7/81 2.4411 6,311. 3 6,362 .81 Wt 5,960.01 6.501 L-80 1EUE8RDMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;5,620.9 6,341.7 5,940.8� 24.41 PACKER BAKER SAB-3 PERMANENT PACKER w/K-22 3.000 ANCHOR SEAL 6,352.9 5,951.0 24.35 NIPPLE CAMCO XN NIPPLE(2.31"x 2.25"NO GO)PLUG SET 2.250 11 16 15 GAS LIFT;6,1170 vs 6.362.0 5,959.3 24.38 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Inc! Top(ftKB) (ftKB) (') Des Com Run Date ID(in) 6,528.4 6,110.6 24.88 CEMENT DUMP BAIL 10 GAL CEMENT 9/7/2015 LOCATOR;6,t72.1 -_ 6,539.0 6,120.2 24.91 SAND DUMP BAIL SAND TO 6539' 9/3/2015 SEAL ASSY;6,173.1 _ PBR,e,teos 6,557.0 6,136.5 24.96 SAND DUMP BAIL 20006 OR FIVER SAND ON TOP OF 8/31/2015 IBP @6609' PACKER;6,203.4 6,602.0 6,177.3 25.10 PLUG 2.13"IBP 7/7/2015 0.000 1 6,900.0 6,448.4 23.73 FISH GLV 1"GLV LOST IN CASING,EXACT DEPTH 8/16/2004 0.000 UNKNOWN NIPPLE;6,258.6 III Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/ Top(15(81 Bern(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn all 6,417.0 6,432.0 6,009.4 6,023.0 C-4,1Q-26 8/13/2005 6.0 APERF 2"PJ,60 deg phase,0 deg orient POORBOY OVERSHOT; MIL 6,417.0. 6,432.0 6,009.4 6,023.0 C-4,1Q-26 1/6/2006 6.0 RPERF 2"HJ,60 deg.phase 6,309.9 II 6,445.0 6,467.0 6,034.8 6,054.8 C-4,C-3,10- 8/13/2005 6.0 APERF 2"PJ,60 deg phase,0 II 26 deg orient PACKER;8,341 6,507.0 6,522.0 6,091.1 6,104.8 C-1,1Q-26 8/13/2005 6.0 APERF 2"PJ,60 deg phase,0 r 1deg orient 6,696.0 6,726.0 6,262.4 6,289.7 A-3,1Q-26 1/21/1996 8.0 IPERF 180 deg.phasing; NIPPLE;6,352.8 Oriented(+/-)F/Btm Side;2 1/8"EnerJet SOS;6,3620 Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) RPERF;8,417.08,432.0 I I (ftKB) (ftKB) (5KB) (ftKB) Type Date Com APERF;6,417.0-6,432.0 C-SAND FRAC;6,4170 II I I 6,417.0 6,432.0 6,009.4 6,023.0 C-SAND FRAC 1/7/2006 PLACED 155M#1620 CARBOLITE IN THE I FORMATION,9 PPA ON PERFS,100%OF DESIGN. SAW TSO-55 MINUTES INTO FRAC,WELL WAS 1 PRESSURING UP AT END OF JOB. FLUSHED TO APERF;6,445.0-6,4670 COMPLETION. Cement Squeezes APERF,6,507.08,522.0 Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 6,651.0 6,992.0 6,221.6 6,532.7 Cement Plug 5/19/2015 5BBL pumped,dropped 5/8"ball,15.8 ppg CEMENT;6,526.4 Mandrel Inserts SAND,6,539.0 St ati SAND,6,557.0 on Top(TVD) Valve Latch Port Size TRO Run N, Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (pm) Run Date Corn PLUG;6,602.0 , 1 1 2,504.1 2,501.3 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,279.0 4/26/2016 2 3,790.2 3,699.4 Camco KBMG 1 GAS LIFT OV BEK 0250 0.0 4/26/2016 eNrks � 3 4,825.0 4,583.5 Camco KBMG 1 GAS LIFT DMY 'BK 0.000 0.0 4/20/2016 IPERF,8,696.0-6,726.0 .e' 4 5,620.9 5,296.4 Camco KBMG 1 GAS LIFT DMY BK 0.000' 0.0 4/20/2016 5 6,117.0 5,737.1 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 4/20/2016 FISH;6,900.0 Notes:General&Safety End Date Annotation ISI 1/15/2010 NOTE:DRIFTED TBG w/2.345"gauge to 6353'RKB 10/13/2010 NOTE:View Schematic w/Alaska Schematic9.0 PRODUCTION;33.3-6,992.8 •oFT8 09' \� //7. 6. THE STATE Alaska Oil and Gas ofALASKA Conservation Commission =-� 333 West Seventh Avenue w , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 per., Main: 907.279.1433 S Fax: 907.276.7542 www.aogcc.alaska.gov Diana Guzman Sr. Wells Engineer SCANNED " ;i 'A ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1Q-26 Permit to Drill Number: 195-132 Sundry Number: 316-240 Dear Ms. Guzman: 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 P oerster Chair DATED this day of April, 2016. RBDMS LC/APR 2 7 2016 , • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 0 2016 APPLICATION FOR SUNDRY APPROVALS SCC 20 AAC 25.280 1.Type of Request: Abandon I— Plug Perforations I....... Fracture Stimulate I Repair Well (� Operations Shutdown Suspend f— Perforate r Other Stimulate F Pull Tubing I' Change Approved Program r Plug for Redrill (- Perforate New Pool I— Re-enter Susp Well I— Alter Casing l Other: Stack Packer 17 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory I Development R7 • 1 95-1 32 ' 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-22590-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a • Will planned perforations require a spacing exception? Yes h- No I ./ KRU Q-26 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL 25641 • 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): 7,010' , 6,549' • 6904 ' 6452 2134 psi Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 121' 121' Surface 3,768' 7 5/8 3,809' 3,716' Production 6,960' 51/2 6,993' 6,533' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6417-6726 1 6009-6288 2.875" L-80 6,362' Packers and SSSV Type: PACKER-BAKER SAB-3 Permanent Packer Packers and SSSV MD(ft)and TVD(ft): Packer @ 6342 MD,5941 TVD SSSV:NONE 34 11 AklitAr SSSV: N/A 12.Attachments: Proposal Summary I] Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory I— Stratigraphic I— Development I 'Service 14. Estimated Date for 4/12/2016 15.Well Status after proposed work: Commencing Operations: OIL • I WINJ F WDSPL P Suspended 1--- 16.Verbal Approval: Yes Date: 4/19/2016 GAS „«« WAG j....... GSTOR ...... SPLUG I.. Commission Representative: Victoria Loepp GINJ I Op Shutdown ...... Abandoned I....... 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Diana Guzman @ 265-6318 Email Diana.Guzmancop.com Printed Name Diana G man Title Sr.Wells Engineer •- 1�pr,i 1 20/, 2:016 Signature Phone 265-6318 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: V4. - 2./-to Plug Integrity ❑ BOP Test f Mechanical Integrity Test ❑ Location Clearance ❑ Other: gep fps f- fa 3 ciao/51 ff�vivlas" pye'✓-e k-7 +' tS.-f ZrJDU f.JSry Post Initial Injection MIT Req'd? Yes ❑ No (vim Spacing Exception Required? Yes ❑ No V Subsequent Form Required: C 0 — 46 4- RBDMS r,YAPR 2 q 2016 (I APPROVED BY Approved by: � jLC�a COMMISSIONER THE COMMISSION Date: 4-2,6 —/� Submit Form and FormVri-�v�1d 1,1��5 0 i6iNtAtand for 12 hs thefrom of approv6l.���� Attachments in Duplicate s • ConocoPhillips Alaska P.O. BOX 100360 RECEIVED ANCHORAGE,ALASKA 99510-0360 APR 2 0 2016 April 20,2016 AOGCC Commissioner Cathy Foerster l� 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 a retroactive Sundry Approval to workover the Kuparuk Well 1Q-26(PTD: 195-132). Well 1Q-26 is a Kuparuk A and C sand producer drilled in 1995. Well 1Q-26 is a known rock producer.Light to medium sand with small rocks have been recovered during different fill cleanouts starting in 2006.Fill and recovered rock samples have been identified as the Kuparuk A.A fill cleanout was performed and A-sand isolation was achieved by setting an IBP at 6602' RKB mid-2015.20001bs of sand and then 10 gal of cement were pumped on top of the IBP for further isolation with a new plug top depth at 6528'.The C-sand was tested for 16 days on a waiver,and sand production was observed but no rocks.The test ended due to a spool erosion leak and a failed MIT-T with the IA tracking.A leak detection log(LDL) was then ran and a tubing leak in the 3 'h"tubing was identified at 6257'. 1Q-26 could not be patched due to the mixed 3 '/z"x 2%8"tubing string. A workover on 1Q-26 started on April 12,2016 in order to repair the tubing leak at 6257'. Since the well is a producer no sundry application was submitted prior the rig workover.Due to the K-22 anchored seal assembly a tubing cut was required. About 61'of sand had to be bailed from the tubing to the to the proposed tubing cut depth at 6314'.The 2%8"tubing was cut and the upper completion was pulled out of the hole.A cleanout BHA was run to clean out the 5 ''A"casing and dress off the tubing stub at 6314'.Even though there was a passing CMIT TxIA prior the workover,due to the unexpected sand, it was decided to confirm the integrity of the 5 '/2"casing and existing packer at 6341'. On April 18,the 5 ''/2"was pressure tested against the packer and PXN plug in the tubing tail at 6353'.The pressure only got to 2450 psi when it was noticed it bled down to 1800 psi in less than 10 minutes.The AOGCC was then contacted to request approval to stack a packer at a TBD depth to either fix a packer or a casing leak. Approval was granted with a new stack packer depth to be determined depending the test packer run results. On April 19 the test packer was set at 6281'(center of element)and the IA tested to 2500 psi.A good test was obtained from 6281' to surface.However,the pressure test against the existing SAB-3 packer/PXN plug combo did fail. Once again the rig was unable to pressure up above 2400 psi. Since there is a tubing stub at 6314' we can't get any closer to determine if the packer or the casing is leaking.The assumption is that the 5 '/2"casing is leaking since it's about the same depth were the 2%8"tubing was leaking. The purpose of this letter is to formalize the verbal approval and request a retroactive sundry to complete the workover on 1Q-26 by pulling the mixed 3 '/2"x 2%8"upper completion, stack a packer to fix the casing or packer leak, change the IC packoff and run a new 2%8"gas lifted completion with a poor-boy overshot and stacked a packer. If you have any questions or require any further information, please contact me at 907-265-6318 or Diana.Guzman@conocophillips.com. Sincerely, ZaGuzm Wells Engineer CPAI Drilling and Wells • • 1Q-26 Rig Workover P&R Tubing and csg/packer leak repair (PTD #: 195-132) • Current Status: Nabors 7ES is currently working over the KRU producer 1Q-26. Scope of Work: • Pull the leaking upper 3 '/2"x 2'/s"completion. • Replace IC packof£ • Run a new 2'/s"gas lift completion with a stacked packer. General Well info: Well Type: Producer MPSP: 2134 psi using 0.1 psilft gradient(Most recent SBHP=2753 psi on 8/7/15 Reservoir Pressure/TVD: 2753 psi/6194' TVD(8.5 ppg)on 8/7/15 Wellhead type/pressure rating: FMC Gen IV/5M psi TH,3M Csg Hd. BOP configuration: Annular/Pipe Rams/Blind Rams/Flow Cross/Pipe Rams TIFL/MIT results(pre-rig): CMIT—T x IA to 2500 psi passed April 4,2016 CMIT—DDT to 0 psi passed on April 4,2016 MIT-OA to 1800 psi passed April 7,2016 OA—DDT to 0 psi April 7,2016 RWO Start Date: April 12,2016 Workover Engineer: Diana Guzman Work:265-6318 E-mail: Diana.Guzman@conocophillips.com Pre-Rig Work(completed) 1. Set a 2.31 PXN Plug at 6353' and catcher on top. 2. Dummy off all GLM's leaving bottom GLM open for circulation.Perform CMIT TxIA to 2500 psi and DDT. 3. Perform MIT OA to 1800 psi and DDT to 0 psi. 4. PT tubing and casing packoffs,FT LDS's. 5. Set BPV. Proposed Procedure(completed): 1. MIRU 2. Pull BPV. Circulate workover fluid. Obtain SITP& SICP, if still seeing pressure at surface, calculate new KWF,weight up,and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug,ND tree,NU BOPE and test to 3000 psig. f 4. Pull blanking plug&BPV. Screw in landing joint,BOLDS's 5. RU DSL and MU 2"bailer,tag top of sand at 6262' ORKB and bail sand to 6325' ORKB. 6. RIH with a 2 '/4"bailer to drift for the jet cutter. 7. MU and RIH with a 2 1/2"Power Jet Cutter. Cut the tubing at 6314' ORKB and POOH. 8. Put SLB off to the side and PU on the tubing to confirm is free.RD DSL and offload equipment from the rig floor. 9. Circulate hole clean. 10. TOOH laying down 3 I/2"x 2%"tubing. 11. RIH on DP and cleanout assembly with dress off shoe,wash over the tubing stub to cleanout sand. 12. Pressure test to 2500 psi from cleanout depth to surface. TOOH. 13. RIH on DP with a test packer assembly. 14. Set test packer with center of element at 6281' and pressure up on the IA to 2500 psi for 10 minutes.Passed. 15. Bleed off pressure and pressure up on the DP to test the 5 '/2" csg and SAB-3/PXN plug combo to 2500 psi. Failed. • • 1Q-26 Rig Workover P&R Tubing and csg/packer leak repair (PTD #: 195-132) 16. Release test packer and POOH laying down DP. 17. MU and RIH with a RBP assembly and set at 2911'. 18. Release from running tool and pressure test to 1500 psi for 10 minutes.TOOH 19. PU and MU storm packer. Set storm packer at 106'.PT to 1500 psi for 10 minutes. 20. Bleed off the pressure.ND BOP and tubing head. 21. Pull the 5 '/2"packoff, spear the 5 '/2" casing, re-land on slips, cut off excess if necessary. Install new 5 '/z" packoff. 22. NU the new tubing head and PT void to 3000 psi.NU the BOP stack and PT break to 3000 psi. 23. RIH with RBP retrieving assembly. Retrieve RBP. POOH laying down DP. 24. RIH and retrieve the storm packer.POOH. 25. Run new 3 '/2"gas lift completion to just above the tubing stub. Proposed Procedure(to be completed): 26. Pump a pill of corrosion inhibited fluid. 27. Record up/down weights and block weight.Engage tubing stub and PU 1'to space out from fully located. 28. Drop ball and rod and pressure up on the tubing to 2500 psi to set the packer. 29. Bleed down to 2000 psi.PT the IA to verify the upper packer is set. 30. PU to shear the PBR, shear out, and MU the tubing hanger. 31. Swap the well over to corrosion inhibited fluid. 32. Land the hanger and RILDS. 33. PT tubing.Pressure test the IA. 34. Bleed T and IA. Shear the SOV.Bleed tubing and IA pressures to zero. Monitor for flow. 35. Pull landing joint. Install BPV and pressure test IA to test the BPV from below. 36. ND BOP stack,NU tree. Install blanking plug and PT tree and tubing hanger packoffs. 37. Pull blanking plug and BPV. 38. Freeze protect w/diesel. Set BPV. 39. RDMO. Proposed Post-Rig Work: 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline.Pull ball and rod and RHC plug.Run new gas lift design. Pull catcher and plug at 6353'. Set up for production 4. Handoff to operations to put back on production. KUP PROD • 1Q-26 ConocoPhillips r Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MO(ftKB) Act Btm(ftKB) cTM.,wvslts 500292259000 KUPARUK RIVER UNIT PROD 31.89 4,231.66 7,010.0 ..- Comment H28(pPm) Date Annotation End Date KBGrd(ft) Rig Release Date 10-26,12/2/2015 2:49:00 PM SSSV:NIPPLE 90 11/5/2014 Last WO: 9/23/1995 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 6,528.4 9/17/2015 Rev Reason:SET PLUG lehallf 12/2/2015 Casing Strings HANGER;36.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 40.9 121.0 121.0 62.50.H-40 WELDED Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread E�, SURFACE 7 5/8 6.875 40.9 3,809.2 3,715.7 29.70 L-80 LTC ," Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 51/2 4.950 33.3 6,992.8 6,533.4 15.50 L-80 LTC-MOD CONDUCTOR;40.9-121.0-4- :`Tubing Strings Tubing Description 'String Ma...I ID(in) 'Top(ftKB) 'Set Depth(ft.."Set Depth(TVD)(...I WI(15111) 'Grade 'Top Connection TUBING 3.5x2.875 3 1/2 2.992 36.3 6,362.8 5,960.0 9.30 L-80 EUESRDMOD NIPPLE;509.7 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Gem (in) 36.3 36.3 0.10 HANGER 'FMC GEN IV TUBING HANGER 3.500 • 509.7 509.7 1.26 NIPPLE CAMCO DS LANDING NIPPLE;2.856"NO GO 2.812" 2.812 GAS LIFT',2,489.7 I 6,341.7 5,940.8 24.41 PACKER BAKER SAB-3 PERMANENT PACKER w/K-22 3.000 ANCHOR SEAL 6,352.9 5,951.0 24.35 NIPPLE I CAMCO XN NIPPLE(2.31"x 2.25"NO GO) 2.250 6,362.1 5,959.4 24.38 SOS 'BAKER SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (RKB) 1") Des Com Run Date ID(in) 6,353.0 5,951.1 24.35 PLUG PXN PLUG 11/16/2015 6,528.4 6,110.6 24.88 CEMENT DUMP BAIL 10 GAL CEMENT 9/7/2015 SURFACE;40.9-3,809.2 6,539.0 6,120.2 24.91 SAND DUMP BAIL SAND TO 6539' 9/3/2015 6,557.0 6,136.5 24.96 SAND DUMP BAIL 2000#OR FIVER SAND ON TOP OF -8/31/2015 IBP @6609' GAS LIFT;4,250.4 6,602.0 6,177.3 25.10 PLUG 2.13"IBP 7/7/2015 0.000 6,900.0 6,448.4' 23.73 FISH 'GLV 1"GLV LOST IN CASING,EXACT DEPTH "8/16/2004 0.000 UNKNOWN Perforations&Slots snot Dens GAS LIFT;5,509. Top(TVD) Btm(TVD) (ahots/f Top(ftKB) Btm(RKB) (ftKB) (ftKB) Zone Data t) Type Com 6,417.0 6,432.0 6,009.4 6,023.0 C-4,1Q-26 8/13/2005 6.0 APERF 2"PJ,60 deg phase,0 deg orient 6,417.0 6,432.0 6,009.4 6,023.0 C-4,10-26 1/6/2006 6.0 RPERF 2"HJ,60 deg.phase 6,445.0 6,467.0 6,034.8 6,054.8 C-4,C-3,10- 8/13/2005 6.0 APERF 2"PJ,60 deg phase,0 26 deg orient GAS LIFT;6,297.3 6,507.0 6,522.0 6,091.1 6,104.8 C-1,1Q-26 8/13/2005 6.0 APERF 2"PJ,60 deg phase,0 deg orient if-- 6,696.0 6,726.0 6,262.4 6,289.7 A-3,10-26 '1/21/1996 8.0 IPERF 180 deg.phasing; Oriented(+/-)F/Btm Side;21/8"EnerJet PACKER;6,341.7 Stimulations&Treatments Min Top Max Btm NIPPLE;6,352.9 Depth Depth Top(TVD) Btm(TVD) (RKB) (ftKB) (ftKB) (RKB) Type _ Date Com PLUG;8,353.0 6,417.0 6,432.0 6,009.4' 6,023.0 C-SAND FRAC 1/7/2006 PLACED 155M#16/20 CARBOLITE IN THE FORMATION,9 PPA ON PERFS,100%OF DESIGN. SAW TSO-55 MINUTES INTO FRAC,WELL WAS PRESSURING UP AT END OF JOB. FLUSHED TO SOS;6,362.1 COMPLETION. Cement Squeezes Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (RKB) Des Start Date Com RPERF;6,417.0-8,432.0 6,651.0 6,992.0 6,221.6 6,532.7 Cement Plug 5/19/2015 5BBL pumped,dropped 5/8"ball,15.8 ppg C-SAND FRAC;6,417.0 APERF;8,417.0-8,432.0 Mandrel Inserts St atl on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,489.7 2,487.0 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,273.0 2/3/2012 APERF;8,445.0-6.467.0 2 4,250.4 4,092.3 CAMCO KBMM 1 GAS LIFT OV BK 0.250 0.0 9/19/2015 3 5,509.4 5,1962 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 9/19/2011 4 6,297.3 5,900.4 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 6/15/2015 EXT APERF;6,507.0-8,522.0 HI- SEAL PKG CEMENT;6,528.4 Notes:General&Safety End Date Annotation SAND;6,539.0 1/15/2010 NOTE:DRIFTED TBG w/2.345"gauge to 6353'RKB SAND;6,557.0 10/13/2010 NOTE:View Schematic w/Alaska Schematic9.0 , PLUG;6,602.0 ....i. IPERF;6,696.0-6,726.0 FISH;6,900.0 PRE-RIG SCHEMATIC PRODUCTION;33.3-6,992.0 • • ConocoPhillips i 1 Q-26 Proposed Completion 2'/e" GL Completion Casing Leak Repair 16"62.5#, H-40 to 121' MD --11.- 2'/8"x 1"KBG 2-9 Mandrel I 4 2'/8"x 1"KBG 2-9 Mandrel I 7 5/8" 29.7#, L-80 to 3809' MD ► -- 2'/e"x 1"KBG 2-9 Mandrel f 2'/e"x 1" KBG 2-9 Mandrel GLM# Depth-ft TVD Depth-ft MD Valve Type , 7 „ 1 2,500 2,503 Dummy 2 /e x 1" KBG 2-9 Mandrel 2 3,700 3,796 SOV(IA to Tbg shear) 3 4,600 4,831 Dummy 4 5,300 5,625 Dummy 2'/8" 6.5#L-80 8rd EUE Tbg 5 5,782 6,166 Dummy f Baker Locator&Seals Good cement bond over the logged ' interval 5900' -6850' I l SLB Cement Bond Log 24-Oct-1995i . Baker PBR Baker 2 7/8"x 5 1/2" Packer @—6214' L__ 1 2.31" DS Nipple Profile with a RHC plug in place Casing Leak @—6306' ► 6314' MD—Tubing Cut . 2'/8" Poor Boy Overshot and '/2" Pi- muleshoe **Tubing Cut Performed on rig** r Baker SAB-3 Permanent Packer w/ - K-22 Anchor Seal @ 6341' i f 2.31"x 2.25" NO GO XN Nipple 11 Profile w/a PXN Plug @ 6353' I I Baker Shear Out Sub @ 6362' Date ::::::: Cement @ 6528' Well Perf Top MD Btm MD Zone 1Q-26 1/6/06 6417 6432 C-4 INTERVAL 2000#of River Sand 1Q-26 8/13/05 6445 6467 C-4 INTERVAL IIIII 2.13" IBP @ 6602' 10-26 8/13/05 6445 6467 C-3 INTERVAL 10-26 8/13/05 6507 6522 C-1 INTERVAL 10-26 1/21/96 6696 6726 A-3 INTERVAL gii.„.. Fish—GLV 1" Exact Depth unknown 5 1/2" 15.5#, L-80 to 6993' MD—Po- ::: : :::K: L Date: April 19,2016 I Drawn By: Diana Guzman • • Guzman, Diana From: Loepp, Victoria T(DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, April 19, 2016 2:30 PM To: Guzman, Diana Subject: [EXTERNAL]RE: CPAI KRU 1Q-26 (PTD 195-132) - RWO Scope Change Notification Diana, Since now we are dealing with PC leaks, a sundry 10-403 should be provided. Please prepare and submit indicating that verbal approval has been granted on the 10-403 form. 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.LoeppCu�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Guzman, Diana [mailto:Diana.Guzman@conocophillips.com] Sent: Tuesday, April 19, 2016 2:20 PM To: Loepp, Victoria T(DOA) Subject: RE: CPAI KRU 1Q-26 (PTD 195-132) - RWO Scope Change Notification Victoria, Just for clarification, CPAI did not submit a sundry for the KRU producer 101-26 since the original scope was only to pull and replace the tubing.The leak was found during the rig workover itself. As I mentioned we're not able to determine if it's a packer or a casing leak due to the tubing stub above the packer. Please let me know if the approval with the emails is sufficient or if you want me to submit a retroactive sundry. Thank you, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 1 • • Cell:305-332-6332 Fax:918-662-1893 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,April 19, 2016 2:07 PM To:Guzman, Diana <Diana.Guzman@conocophillips.com>; Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov> Subject: [EXTERNAL]RE: CPAI KRU 1Q-26(PTD 195-132) - RWO Scope Change Notification Diana, Approval is granted to proceed as you have outlined below. Please include this approval with your copy of the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeooCo,alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Guzman, Diana [mailto:Diana.Guzman@conocoDhillips.com] Sent: Tuesday, April 19, 2016 11:39 AM To: Loepp, Victoria T(DOA); Schwartz, Guy L(DOA) Subject: FW: CPAI KRU 1Q-26 (PTD 195-132) - RWO Scope Change Notification Importance: High All, I apologize if this email is a duplicate. I got a notification that the original email didn't go through. Thank you, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(AT0-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 2 • S From:Guzman, Diana Sent:Tuesday,April 19, 2016 9:17 AM To:'Schwartz, Guy L(DOA)' <guy.schwartz@alaska.gov>; Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Cc: Herbert, Frederick 0<Frederick.O.Herbert@conocophillips.com>; Rauchenstein, Rock D <Rock.D.Rauchenstein@conocophillips.com>; Buck, Brian R<Brian.R.Buck@conocophillips.com>; Nabors 7ES Company Man<n2364@conocophillips.com>; Cookson,John<John.Cookson@conocophillips.com> Subject: RE: CPAI KRU 10-26 (PTD 195-132) - RWO Scope Change Notification Good morning Victoria and Guy, This is an update of the workover operations on 1Q-26.As planned we TIH with a test packer. We set the test packer at 6281' (center of element) and tested the IA to 2500 psi. We got a good test from 6281'to surface. We did however failed our test against the existing SAB-3 packer/PXN plug combo. Once again we were unable to pressure up above 2400 psi. Since we have the tubing stub at 6314' we can't get any closer to determine if the packer is leaking or the casing. My assumption is that the 5 1/2" casing is leaking since it's about the same depth where the 27/8"was leaking. As agreed, we will stack a packer at 6214'. I confirmed we have a good cement bong over this interval based on the SLB Cement Bond Log dated 24-Oct-1995. I attached the log for your review. We're currently done with the testing and getting ready to perform an IC packoff change. We will be running with the stacked packer later this afternoon. I also attached the following for your review: • Workover time log summary(April 12—Present) • Final proposed casing leak repair schematic. • Test packer run PT chart Please let me know if you approve of this scope change or if you have any questions. Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 From:Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday,April 18, 2016 4:47 PM To:Guzman, Diana<Diana.Guzman@conocophillips.com> Cc: Loepp,Victoria T(DOA) <victoria.loepr alaska.gov> Subject: [EXTERNAL]RE: CPAI KRU 10-26(PTD 195-132)-RWO Scope Change Notification Diana, 3 • • You have verbal approval to stack an extra packer in order to isolate a casing leak in well 1Q-26(oil producer). A sundry is not required as follow-up for this change of workscope. I will file this email in our system as documentation... if casing repairs other than a simple stacker packer are required a sundry may be needed... Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Guzman, Diana [mailto:Diana.Guzman@conocodhillips.com] Sent: Monday, April 18, 2016 4:38 PM To: Schwartz, Guy L(DOA) Cc: Loepp, Victoria T(DOA) Subject: FW: CPAI KRU 1Q-26 (PTD 195-132) - RWO Scope Change Notification Importance: High Good afternoon Guy, I am sorry to bother you but I haven't heard back from Victoria yet. I tried to follow up with a phone call but I'm not sure if she's in today. N7ES should be running with the stacked packer this evening and I'm trying to avoid having them on standby if possible. Thank you, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 From: Guzman, Diana Sent: Monday, April 18, 2016 2:17 PM To: Loepp, Victoria T(DOA) <victoria.loepp@alaska.gov> Cc: Nabors 7ES Company Man <n2364@conocophillips.com>; Buck, Brian R<Brian.R.Buck@conocophillips.com>; Rauchenstein, Rock D<Rock.D.Rauchenstein@conocophillips.com>; Herbert, Frederick 0 <Frederick.O.Herbert@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com> Subject: CPAI KRU 1Q-26(PTD 195-132) - RWO Scope Change Notification Importance: High Good afternoon Victoria, 4 • • This is a preemptive email to request approval for a work scope change on the rig workover of the KRU 10-26 Producer with PTD 195-132. The initial purpose of the workover on 10-26 was to repair a tubing leak at 6257'. Due to the K-22 anchored seal assembly a tubing cut was required. We had to bail —61' of sand in the tubing to get to our cutting depth at 6314'. We cut the 2%8" tubing and POOH with the upper completion after circulating the hole clean. We proceeded to run in the hole with a cleanout BHA to clean the 51/2" casing and dress off the tubing stub at 6314'. Even though we had a passing CMIT TxIA prior the workover, due to the unexpected sand,we decided to confirm the integrity of the 5 Y2"casing and existing packer at 6342'. We pressure tested against the PXN plug in the tubing tail at 6353'. We were only able to get to 2450 psi and noticed the pressure bled down to 1800 psi in less than 10 minutes. I'm requesting approval to stack a packer at a TBD depth to either fix a packer or casing leak.The new packer depth will be determined depending the test packer run results. We won't get the results of the test packer until later this afternoon. We anticipate to be running in the hole with our new stacked packer this evening or early morning tomorrow. I attached the following for your review: • 1sT 5 yZ" casing PT chart • 2nd 5 34" casing PT chart(after confirming the surface equipment was working properly). • Workover time log summary(April 12—Present) • Schematics for 10-26 o Proposed casing leak repair. o Current o Pre-rig General Well info: Well Type: Producer MASP: 2134 psi using 0.1 psi/ft gradient(Most recent SBHP=2753 psi on 8/7/15) Reservoir Pressure/TVD: 2753 psi/6194'TVD(8.5 ppg)on 8/7/15 Wellhead type/pressure rating: FMC Gen IV/5M psi TH,3M Csg Hd. TIFL/MIT results: CMIT—Tx IA to 2500 psi passed April 4,2016 CMIT—DDT to 0 psi passed on April 4,2016 MIT-OA to 1800 psi passed April 7,2016 OA—DDT to 0 psi April 7,2016 Current operations:TOOH with cleanout BHA on DP Plan forward: PU and MU a test packer BHA to identify the leak location. Victoria, due to the original workover scope and well type, no sundry was submitted for 1Q-26. Please let me know how you want me to proceed and if you need me to submit anything else besides this notification and an update once we determine the leak type. I await your approval for the new scope on 10-26. If you have any questions or require any other documentation do not hesitate to contact me. Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 5 • • Durati Date From To on Time Activity 4/12/2016 0:00 6:00 16:00 10 T Wait for the well house to be removed from 1Q-26 due to high winds. SimOps: Finish the PM on the draw works and reinstall guards. Change the oil in the bridge cranes. Clean suction screens on both mud pumps. Inspect the tires and movina system. Chanae oil in the agitators. 4/12/2016 0:00 16:00 18:00 2 P RD all the lines in the interconnect. Bridle up the blocks. RD the berming. Blow down the steam and water in the pits. 4/12/2016 0:00 18:00 22:00 4 P PJSM. Jack up the pits, pull the cutting box and mats. Pull the pits away from the sub and install the jeep. Load up the shop and satellite office. Move the pits, shop, and satellite office from 1C Dad to 10 Dad. 4/12/2016 0:00 22:00 23:00 1 P Pull the sub off well 1C-102, move to the end of the pad, and stage with the wind at the back of the sub. 4/12/2016 0:00 23:00 0:00 1 P Clean up the cellar, roll up the herculite, load rig mats, and clean up around well 1C-102. 4/13/2016 0:00 0:00 1:30 1.5 P Pull the derrick pins and lay over the derrick. 4/13/2016 0:00 1:30 2:00 0.5 P Move the sub to the entrance of 1C pad. 4/13/2016 0:00 2:00 5:00 3 P Move the sub 5.5 miles from 1C pad to the Oliktok Y. 4/13/2016 0:00 5:00 6:30 1.5 P Wait for field wide change out. 4/13/2016 0:00 6:30 8:30 2 P Move the sub 2.6 miles from Oliktok Y to 1Q pad. 4/13/2016 0:00 8:30 9:00 0.5 P Move the sub to the middle of the pad and stage with the wind at the back of the sub. 4/13/2016 0:00 9:00 11:00 2 P PJSM. Raise and pin the derrick. Hang the tree in the cellar. 4/13/2016 0:00 11:00 12:00 1 T Wait for the flow lines to be removed from well 1Q-26 and the well prep to be finished around the well. SimOps. Raise the cattle chute. Bridle down the blocks, hang bridle lines in the derrick, and Din the blocks to the TD. 4/13/2016 0:00 12:00 14:00 2 T Wait for the flow lines to be removed from well 1Q-26 and the well prep to be finished around the well. SimOps. Hang the rig tongs and set up the rig floor. 4/13/2016 0:00 14:00 18:00 4 T Wait for the flow lines to be removed from well 1Q-26 and the well prep to be finished around the well. SimOps. Grind edges of hammer unions. Clean and organize the sub. Perform general maintenance on the sub. 4/13/2016 0:00 18:00 18:30 0.5 P Move the pits near well 1Q-26. 4/13/2016 0:00 18:30 19:30 1 P Set mats around well 1Q-26 and lay out herculite around the well. 4/13/2016 0:00 19:30 21:30 2 P PJSM. Spot the sub over well 1Q-26. Set mats, lay out herculite in front of the sub, and set the sub down. 4/13/2016 0:00 21:30 0:00 2.5 P PJSM. Spot the pits to the sub, set rig mats, lay down herculite for the pits/cuttings box,and spot the cutting tank. 4/14/2016 0:00 0:00 4:00 4 P RU berming around the sub, pits, and cuttings box. Hook up the interconnect. RU steam, water, and air in the pits. Swap the pits to rig generators. Connect parts house and mud shack to rig power. Rig accepted at 04:00 hours on 4/14/16. 4/14/2016 0:00 4:00 7:00 3 P Load the pits with 8.8 ppg seawater. RU circulating liner for the well kill operation. 4/14/2016 0:00 7:00 8:30 1.5 P PU the lubricator and make up crossover. RU lubricator to the tree and PT to 1500 psi (good test). Pull 3" ISA BPV and RD the lubricator. 4/14/2016 0:00 8:30 9:00 0.5 P RU circulating lines to the tree through the choke manifold to the kill tank. Blow steam and air through line to the kill tank and check connections. PT lines to 3000 psi (good test). Blow down lines. 4/14/2016 0:00 9:00 12:00 3 P PJSM. Circulate 150 bbls of 8.8 ppg seawater down the tubing taking return out the IA to the kill tank at 1 BPM (ICP = 650 psi and FCP= 800 psi) getting clean 8.8 ppg seawater at surface. • • 4/14/2016 0:00 12:00 13:00 1 P Bleed off the pump pressure. Install low pressure gauges on the tubing and IA. Monitor the well pressures for 30 minutes; 25 psi on the tubing and IA. Bleed both tubing and IA to 0 psi. Monitor the well pressures; tubing = 0 psi and IA = 0 psi. Bleed IA to 0 psi. Both tubing and IA slightly dripping. 4/14/2016 0:00 13:00 16:00 3 T Wait on weather due to field wide phase 3 conditions. SimOps: Continue to observe the well for flow for 30 minutes and the well is static. 4/14/2016 0:00 16:00 16:30 0.5 P RU to reverse circulate down the IA taking returns out the tubing through the gas buster to the pits. Reveres circulate 31.5 bbls at 1 BPM = 880 psi. 4/14/2016 0:00 16:30 17:00 0.5 P Bleed off the pump. Observe the well for flow for 30 minutes and the well is static. 4/14/2016 0:00 17:00 17:30 0.5 P Close in the well, blow down all circulating lines, and secure the cellar. 4/14/2016 0:00 17:30 18:30 1 P Hold an appreciation dinner for both rig crews for excellent work and safety record. 4/14/2016 0:00 18:30 19:30 1 P RD all circulating lines and install secondary annulus valve. 4/14/2016 0:00 19:30 20:00 0.5 P Install 3" ISA BPV with dry rod. Pressure up on the IA to 1000 psi to PT the BPV from below in the direction of flow for 10 minutes (good test). 4/14/2016 0:00 20:00 22:00 2 P RU wire slings to the TD and RU slings to the tree. ND the tree and tubing head adapter. Pull the tree free with the TD. RU the bridge crane to the tree. Lay down the tree and tubing head adapter. Clean and inspect the tubing hanger lift threads. Install the blanking plug (8 right hand turns). 4/14/2016 0:00 22:00 0:00 2 P NU the DSA and NU the BOP stack. 4/15/2016 0:00 0:00 1:30 1.5 P Torque bolts on the DSA and BOP stack. Install the turn buckles and riser.,Air up the air boots on the riser. 4/15/2016 0:00 1:30 3:00 1.5 P RU BOPE testing equipment. Fill BOP stack and choke manifold with fresh water. MU 2-7/8"doughnut test joint with HT-38 TIW and MU the TD. 4/15/2016 0:00 3:00 4:30 1.5 P Conduct initial BOPE: test 2-7/8"x 5"VBR's (upper and lower pipe rams) to 250/3000 psi with 2-7/8"and 3-1/2"test joints; test annular to 250/3000 with 2-7/8" and 3-1/2"test joints; conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Bob Noble via email on 4/13/16 at 09:36 hours.Tests: 1) Lower Pipe Rams with 2-7/8"test joint, Upper IBOP(Passed) 2) Upper Pipe Rams with 2-7/8"test joint, Lower IBOP, 2" Demco, Chokes 1, 2, 3, &16 (Passed) 3) Upper Pipe Rams with 2-7/8"test joint, HCR Kill, HT-38 TIW, Chokes 4, 5, &6 (Passed)4) Upper Pipe Rams with 2-7/8"test joint, Manual Kill, Chokes 7, 8, &9 (Passed) 5) Super Choke and Manual Adjustable Choke (Passed) 6) Upper Pipe Rams with 2-7/8" test joint, Manual Kill, Chokes 8, 10, & 11 (Passed) 4/15/2016 0:00 4:30 6:00 1.5 T Test: 7) Annular with 2-7/8"test joint, Manual Kill, Chokes 8, 12, & 13 (Passed) Note: Annular failed the high pressure test and retest passed. • • 4/15/2016 0:00 6:00 11:00 5 P Tests: 8) Blind Rams, Manual Kill, HT-38 Dart Valve, Outer Test Spool, Chokes 8, 12, & 13 (Passed) 9) Blind Rams, Manual Kill, Inner Test Spool, Chokes 8, 12, & 13 (Passed) 10) Annular with 3-1/2"test joint, Manual Kill, 3-1/2" EUE 8rd TIW, Choke 15 (Passed) 11) Upper Pipe Rams with 3- 1/2"test joint, 3-1/2"EUE 8rd TIW, Choke 14 (Passed) 12) Upper Pipe Rams with 3-1/2"test joint, 3-1/2"EUE 8rd TIW, Manual Choke (Passed) 13) Upper Pipe Rams with 3-1/2"test joint, 3-1/2"EUE 8rd TIW, HCR Choke (Passed) 14) Lower Pipe Rams with 3-1/2"test joint, 3-1/2" EUE 8rd TIW (Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure = 3000 psi Accumulator Pressure After Closer= 1650 psi Pressure Gain of 200 psi = 10 seconds Full System = 88 Seconds Average N2 (5 Bottles) = 1961 psi 4/15/2016 0:00 11:00 12:00 1 P Pull blanking plug with 3-1/2"test joint and lay down the test joint. Drain the BOP stack and gas buster. Blow down lines, choke manifold, and BOPE testing equipment. RD BOPE testing equipment. 4/15/2016 0:00 12:00 12:30 0.5 P Check for pressure under BPV(no pressure) and pull 3" ISA BPV with dry rod. 4/15/2016 0:00 12:30 13:00 0.5 P RU 3-1/2"tubing elevators, MU landing joint, MU 3-1/2" EUE 8rd TIW, and MU TD. 4/15/2016 0:00 13:00 13:45 0.75 P PJSM. Attempt to BOLDS but LDS were tight. RD landing joint with 3-1/2" EUE 8rd TIW. RU 3 pup joints for landing joint, MU 3-1/2" EUE 8rd TIW, and MU the TD. 4/15/2016 0:00 13:45 14:00 0.25 T BOLDS and unseat the tubing hanger at 50K. Establish PU parameters 50K to 100K. Set torque limit to 2200 ft-lbs. Rotate 1 turn to the right and work torque down. Rotate an additional 2-1/4 turns to right and work torque down. Unable to get the tubing to rotate with max allowed torque. Call out for SLB DSL(digital slickline). 4/15/2016 0:00 14:00 15:00 1 T Wait for SLB DSL to arrive. SimOps: Continue to work the tubing attempting to rotate to the right to release the K-22 anchor from the SAB-3 packer. 4/15/2016 0:00 15:00 15:30 0.5 T Set the landing joint in the slips with 75K. Break out the TD, crossover, and 10' pup joint from landing joint. MU 3-1/2" EUE 8rd TIW. 4/15/2016 0:00 15:30 20:00 4.5 T Spot up SLB DSL unit. PJSM with both crews. Bring tools and equipment to the rig floor. RU SLB DSL. 4/15/2016 0:00 20:00 21:00 1 T DSL damaged. Cut DSL and re head. MU 2" bailer. 4/15/2016 0:00 21:00 23:00 2 T RIH with 2" bailer and tag top of sand at 6262'ORKB. Activate bailer and POOH. 4/15/2016 0:00 23:00 23:30 0.5 T Bailer at surface and did not recover any sand. Break out 2" bailer and MU new 2" bailer. 4/15/2016 0:00 23:30 0:00 0.5 T RIH with new 2" bailer. 4/16/2016 0:00 0:00 0:30 0.5 T Continue to RIH with new 2" bailer.Tag sand at 6262'ORKB, activate bailer, and POOH. 4/16/2016 0:00 0:30 0:45 0.25 T Bailer at surface and recover approximately .5 gallon of river sand. Break out 2" bailer and MU 1-3/4" bailer. 4/16/2016 0:00 0:45 1:15 0.5 T RIH with 1-3/4" bailer. Tag sand at 6264' ORKB, activate bailer, and POOH. 4/16/2016 0:00 1:15 1:30 0.25 T Bailer at surface and 1 gallon of river sand. Break out 1-3/4" bailer and MU 2" bailer. 4/16/2016 0:00 1:30 21:15 19.75 T RIH with 2" bailer, activate bailer, and POOH. Recovered 1 gallon of river sand. RIH with 1-3/4" bailer 21 times recovering .75 to 1.5 gallons of sand each run. Recovering river sand down to 6270' SLM (6300'ORKB), clean frac sand from 6270' - 6278' SLM (6300' -6308' ORKB), and dirty frac sand from 6278' -6290' SLM (6308' - 6320'ORKB). On run #25 tagged sand at 6281' SLM (6311' ORKB). Sand is coming in from the IA through the open GLM at 6297'ORKB into the tubing. RD SLB DSL off to the side. • • 4/16/2016 0:00 21:15 22:30 1.25 T RU circulating equipment. Circulate 1.5 hole volumes; ICP at 2 BPM = 600 psi and FCP at 4 BPM = 1030 psi. Sand recovered across the shakers at bottoms up. Blow down and RD circulating equipment. 4/16/2016 0:00 22:30 0:00 1.5 T RU SLB DSL. RIH with 1-3/4" bailer 2 times recovering 1.5 gallons of dirty frac sand each time down to 6295' SLM (6325' ORKB). 4/17/2016 0:00 0:00 6:30 6.5 T RIH with 1-3/4" bailer 4 times recovering 1 to 1.5 gallons of dirty frac sand each time down to 6303'SLM (6333'ORKB). RIH with 1-3/4" bailer 4 times recovering .5 to 1 gallons of silty/frac sand each time down to 6308' SLM (6338'ORKB). RIH with 2-1/4" bailer(drift run for the jet cutter)to 6307' SLM (6337' ORKB). Correlate with CCL and true tag depth is ORKB. 4/17/2016 0:00 6:30 ? 11:00 4.5 ? T MU and RIH with 2-1/8" Power Jet Cutter. Correlate and tie into GLM at 6297'ORKB. Cut the tubing at 6314' ORKB and POOH. Confirmed cutter fires at surface. RD SLB DSL off to the side. PU on the tubing (85K) and confirmed that the tubing was free. RD SLB DSL.and offload equipment from the rig floor. 4/17/2016 0:00 11:00 12:00 1 T RU circulating equipment. Circulate 1.5 hole volumes at 5 BPM (ICP= 1250 psi and FCP = 1150 psi) while reciprocating the tubing. 5 gallons of sand recovered across the shakers at bottoms up. Blow down and RD circulating equipment. PU = 80K. 4/17/2016 0:00 12:00 12:30 0.5 P Bring Weatherford power tubing tongs, 3-1/2" handling equipment, and 2-7/8" handling equipment to the rig floor. RU Weatherford to pull 3-1/2" x 2-7/8" completion. 4/17/2016 0:00 12:30 13:45 1.25 P PJSM. Pull the tubing hanger to the rig floor and lay down. POOH laying down 3-1/2" x 2-7/8" tubing to 5717' RKB 4/17/2016 0:00 13:45 14:00 0.25 P Kick while tripping drill: well secured in 45 seconds and CRT = 73 seconds. AAR with crew. 4/17/2016 0:00 14:00 14:30 0.5 P Service and DOMS inspection on the TD. 4/17/2016 0:00 14:30 21:30 7 P Continue to POOH laying down 3-1/2"x 2-7/8"tubing from 5717' RKB to surface. Recovered 192 joints of 3-1/2"tubing, 7 joints of 2-7/8"tubing, 2.812" DS nipple, 4 KBMM GLM's and cut joint = 7.40'. Hole found in cut joint 2.12'from the top of the joint(6306.01'ORKB). Clean and clear the floor. 4/17/2016 0:00 21:30 22:00 0.5 P MU wear ring running tool, install the wear ring, and lay down wear ring running tool. 4/17/2016 0:00 22:00 22:15 0.25 P PJSM for PU and MU cleanout assembly with dress off shoe. 4/17/2016 0:00 22:15 0:00 1.75 P PU and MU BHA#1 -cleanout assembly with dress off shoe. 4/18/2016 0:00 0:00 0:15 0.25 P Kick while tripping drill: well secured in 41 seconds and CRT = 99 seconds. AAR with crew. 4/18/2016 0:00 0:15 6:00 5.75 P RIH with BHA #1 - cleanout assembly with dress off shoe on 3-1/2" PH-6 work string to 5543' RKB (PU = 95K and 50 =.8.5K). 4/18/2016 0:00 6:00 6:30 0.5 P Service and DOMS inspection on the TD. Derrick inspection. 4/18/2016 0:00 6:30 8:00 1.5 P Continue RIH with BHA #1 from 5543'to 6294' RKB. 4/18/2016 0:00 8:00 8:30 0.5 P MU the TD and establish parameters. PU = 105K, SO = 85K, rotating weight = 90K, and free torque = 2000 ft-lbs. SPR with mud pump #2: 2 BPM = 280 psi and 3 BPM = 660 psi. Tag the top of the tubing stub at 6295' RKB. Bring the pumps up to 5 BPM = 1800 psi, rotate at 50 RPM, and 7_7/Q" 4/18/2016 0:00 8:30 9:00 0.5 P Wash over tubing stub cleaning out sand at 5 BPM = 1750 psi down to 6320' RKB. 4/18/2016 0:00 9:00 10:00 1 P Pump 40 bbl hi vis sweep and circulate the well clean at 8 BPM = 39QQpsi (pumped 228 bbls). • 4/18/2016 0:00 10:00 11:00 1 T Close the blind rams. Attempt to PT the 5-1/2" casing and SAB-3 packer/PXN plug to 2500 psi but unable to get the pressure above 2450 psi pumping at 0.8 BPM. Shut down the pumps and the pressure bleed off to 1800 psi in 15 minutes. Blow down the TD. Notified town engineer. Attempt to pressure test again to verify IC packoff integrity but still unable to get the pressure above 2400 psi while continuously pumping. Shut down the pumps and the pressure bleed down to 2000 psi in 10 minutes. Bleed 4/18/2016 0:00 11:00 11:30 0.5 P Blow down pressure testing lines. PJSM. Install stripping rubbers and air slips. 4/18/2016 0:00 11:30 14:30 3 P TOOH with BHA #1 from 6320' to 230' RKB. 4/18/2016 0:00 14:30 17:00 2.5 P Lay down BHA #1 - cleanout assembly with dress off shoe. Clean and clear the ria floor. 4/18/2016 0:00 17:00 18:00 1 T PJSM. PU and MU BHA #2 -test packer assembly. 4/18/2016 0:00 18:00 22:45 4.75 T TIH with BHA #2 to 6285' RKB. 4/18/2016 0:00 22:45 23:00 0.25 P Kick while tripping drill: well secured in 37 seconds and CRT = 81 seconds. AAR with crew. 4/18/2016 0:00 23:00 23:15 0.25 T Set the test packer with center of element at 6281' RKB. 4/18/2016 0:00 23:15 23:45 0.5 T Close the upper pipe rams and pressure up on the IA to 2500 psi for 10 minutes to PT the 5-1/2" casing from 6281" RKB to surface (good test). Bleed off the pressure and open the upper pipe rams. Pressure up on the DP to test the 5-1/2" casing and SAB-3 packer/PXN plug combination to 2500 psi but unable to get the pressure above 2400 psi pumping at 1 BPM. Bleed the pressure off. The 5-1/2" casing leak likely at the same depth as the hole 4/18/2016 0:00 23:45 0:00 0.25 T Release the test packer and manipulate back into the runnino position. 4/19/2016 0:00 0:00 3:00 3 T POOH laying down 3-1/2" PH-6 work string from 6285' to 2920' RKB (PU = 65K and SO = 60K). 4/19/2016 0:00 3:00 4:30 1.5 T TOOH standing back PH-6 work string from 2920' to surface. 4/19/2016 0:00 4:30 5:00 0.5 T Lay down BHA #2 -test packer assembly. 4/19/2016 0:00 5:00 5:30 0.5 T PU and MU BHA #3 - 'G' lock-set RBP assembly. 4/19/2016 0:00 T TIH with BHA#3 4/19/2016 0:00 3:00 4:30 1.5 T TOOH standing back PH-6 work string from 2920' to surface. 4/19/2016 0:00 4:30 5:00 0.5 T Lay down BHA #2 - test packer assembly. 4/19/2016 0:00 5:00 5:30 0.5 T PU and MU BHA #3 - 'G' lock-set RBP assembly. 4/19/2016 0:00 T TIH with BHA#3 • • prDi9 I32-, Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Tuesday, April 19, 2016 2:30 PM To: 'Guzman, Diana' Subject: RE:CPAI KRU 1Q-26(PTD 195-132) - RWO Scope Change Notification Follow Up Flag: Follow up Flag Status: Flagged Diana, Since now we are dealing with PC leaks, a sundry 10-403 should be provided. Please prepare and submit indicating that verbal approval has been granted on the 10-403 form. Thanx, Victoria Victoria Loepp 2016 Senior Petroleum Engineer cApSED APR 2 9 State of Alaska ' Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�.alaska.00v CONFIDENTIALTIY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Guzman, Diana [mailto:Diana.Guzman@conocophillips.com] Sent: Tuesday, April 19, 2016 2:20 PM To: Loepp, Victoria T(DOA) Subject: RE: CPAI KRU 1Q-26 (PTD 195-132) - RWO Scope Change Notification Victoria, Just for clarification, CPAI did not submit a sundry for the KRU producer 1Q-26 since the original scope was only to pull and replace the tubing.The leak was found during the rig workover itself.As I mentioned we're not able to determine if it's a packer or a casing leak due to the tubing stub above the packer. Please let me know if the approval with the emails is sufficient or if you want me to submit a retroactive sundry. Thank you, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. 1 • • Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,April 19,2016 2:07 PM To:Guzman, Diana<Diana.Guzman@conocophillips.com>;Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Subject: [EXTERNAL]RE: CPAI KRU 1Q-26(PTD 195-132) -RWO Scope Change Notification Diana, Approval is granted to proceed as you have outlined below. Please include this approval with your copy of the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.aov CONFIDENTIALITY NOTICE: I his e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Guzman, Diana [mailto:Diana.Guzman@conocophillips.com] Sent: Tuesday, April 19, 2016 11:39 AM To: Loepp, Victoria T(DOA); Schwartz, Guy L(DOA) Subject: FW: CPAI KRU 1Q-26 (PTD 195-132) - RWO Scope Change Notification Importance: High All, I apologize if this email is a duplicate. I got a notification that the original email didn't go through. Thank you, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 2 • Cell:305-332-6332 Fax:918-662-1893 From:Guzman, Diana Sent:Tuesday,April 19, 2016 9:17 AM To: 'Schwartz, Guy L(DOA)'<guv.schwartz@alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Herbert, Frederick 0<Frederick.O.Herbert@conocophillips.com>; Rauchenstein, Rock D <Rock.D.Rauchenstein@conocophillips.com>; Buck, Brian R<Brian.R.Buck@conocophillips.com>; Nabors 7ES Company Man<n2364@conocophillips.com>;Cookson,John<John.Cookson@conocophillips.com> Subject: RE:CPAI KRU 1Q-26 (PTD 195-132)- RWO Scope Change Notification Good morning Victoria and Guy, This is an update of the workover operations on 1Q-26.As planned we TIH with a test packer. We set the test packer at 6281' (center of element) and tested the IA to 2500 psi. We got a good test from 6281'to surface. We did however failed our test against the existing SAB-3 packer/PXN plug combo. Once again we were unable to pressure up above 2400 psi. Since we have the tubing stub at 6314' we can't get any closer to determine if the packer is leaking or the casing. My assumption is that the 5/2" casing is leaking since it's about the same depth where the 27/8" was leaking. As agreed, we will stack a packer at—6214'. I confirmed we have a good cement bong over this interval based on the SLB Cement Bond Log dated 24-Oct-1995. I attached the log for your review. We're currently done with the testing and getting ready to perform an IC packoff change. We will be running with the stacked packer later this afternoon. I also attached the following for your review: • Workover time log summary(April 12—Present) • Final proposed casing leak repair schematic. • Test packer run PT chart Please let me know if you approve of this scope change or if you have any questions. Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday,April 18,2016 4:47 PM To:Guzman, Diana <Diana.Guzman@conocophillips.com> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: [EXTERNAL]RE: CPAI KRU 1Q-26(PTD 195-132)- RWO Scope Change Notification 3 • • Diana, You have verbal approval to stack an extra packer in order to isolate a casing leak in well 1Q-26(oil producer). A sundry is not required as follow-up for this change of workscope. I will file this email in our system as documentation... if casing repairs other than a simple stacker packer are required a sundry may be needed... Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.aov). From: Guzman, Diana [mailto:Diana.Guzman@conocophillips.com] Sent: Monday, April 18, 2016 4:38 PM To: Schwartz, Guy L(DOA) Cc: Loepp, Victoria T(DOA) Subject: FW: CPAI KRU 1Q-26 (PTD 195-132) - RWO Scope Change Notification Importance: High Good afternoon Guy, I am sorry to bother you but I haven't heard back from Victoria yet. I tried to follow up with a phone call but I'm not sure if she's in today. N7ES should be running with the stacked packer this evening and I'm trying to avoid having them on standby if possible. Thank you, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 From:Guzman, Diana Sent: Monday,April 18, 2016 2:17 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Nabors 7ES Company Man<n2364@conocophillips.com>; Buck, Brian R<Brian.R.Buck@conocophillips.com>; Rauchenstein, Rock D<Rock.D.Rauchenstein@conocophillips.com>; Herbert, Frederick 0 <Frederick.O.Herbert@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com> Subject:CPAI KRU 1Q-26(PTD 195-132)- RWO Scope Change Notification Importance: High Good afternoon Victoria, 4 • • This is a preemptive email to request approval for a work scope change on the rig workover of the KRU 1Q-26 Producer with PTD 195-132. The initial purpose of the workover on 10-26 was to repair a tubing leak at 6257'. Due to the K-22 anchored seal assembly a tubing cut was required. We had to bail—61' of sand in the tubing to get to our cutting depth at 6314'.We cut the 2%s" tubing and POOH with the upper completion after circulating the hole clean. We proceeded to run in the hole with a cleanout BHA to clean the 5%2" casing and dress off the tubing stub at 6314'. Even though we had a passing CMIT TxIA prior the workover, due to the unexpected sand,we decided to confirm the integrity of the 5 %2" casing and existing packer at 6342'. We pressure tested against the PXN plug in the tubing tail at 6353'.We were only able to get to 2450 psi and noticed the pressure bled down to 1800 psi in less than 10 minutes. I'm requesting approval to stack a packer at a TBD depth to either fix a packer or casing leak.The new packer depth will be determined depending the test packer run results.We won't get the results of the test packer until later this afternoon.We anticipate to be running in the hole with our new stacked packer this evening or early morning tomorrow. I attached the following for your review: • 151-5%2" casing PT chart • 2"d 5%2" casing PT chart (after confirming the surface equipment was working properly). • Workover time log summary(April 12—Present) • Schematics for 1Q-26 o Proposed casing leak repair. o Current o Pre-rig General Well info: Well Type: Producer MASP: 2134 psi using 0.1 psi/ft gradient(Most recent SBHP=2753 psi on 8/7/15) Reservoir Pressure/TVD: 2753 psi/6194'ND(8.5 ppg)on 8/7/15 Wellhead type/pressure rating: FMC Gen IV/5M psi TH,3M Csg Hd. TIFL/MIT results: CMIT—T x IA to 2500 psi passed April 4,2016 CMIT—DDT to 0 psi passed on April 4,2016 MIT-OA to 1800 psi passed April 7,2016 OA—DDT to 0 psi April 7,2016 Current operations:TOOH with cleanout BHA on DP Plan forward: PU and MU a test packer BHA to identify the leak location. Victoria, due to the original workover scope and well type, no sundry was submitted for 10-26. Please let me know how you want me to proceed and if you need me to submit anything else besides this notification and an update once we determine the leak type. I await your approval for the new scope on 1Q-26. If you have any questions or require any other documentation do not hesitate to contact me. Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 5 S Durati Date From To on Time Activity 4/12/2016 0:00 6:00 16:00 10 T Wait for the well house to be removed from 1Q-26 due to high winds. SimOps: Finish the PM on the draw works and reinstall guards. Change the oil in the bridge cranes. Clean suction screens on both mud pumps. Inspect the tires and movina system. Chanae oil in the agitators. 4/12/2016 0:00 16:00 18:00 2 P RD all the lines in the interconnect. Bridle up the blocks. RD the berming. Blow down the steam and water in the pits. 4/12/2016 0:00 18:00 22:00 4 P PJSM. Jack up the pits, pull the cutting box and mats. Pull the pits away from the sub and install the jeep. Load up the shop and satellite office. Move the pits, shop, and satellite office from 1C pad to 10 oad. 4/12/2016 0:00 22:00 23:00 1 P Pull the sub off well 1C-102, move to the end of the pad, and stage with the wind at the back of the sub. 4/12/2016 0:00 23:00 0:00 1 P Clean up the cellar, roll up the herculite, load rig mats, and clean up around well 1C-102. 4/13/2016 0:00 0:00 1:30 1.5 P Pull the derrick pins and lay over the derrick. 4/13/2016 0:00 1:30 2:00 0.5 P Move the sub to the entrance of 1C pad. 4/13/2016 0:00 2:00 5:00 3 P Move the sub 5.5 miles from 1C pad to the Oliktok Y. 4/13/2016 0:00 5:00 6:30 1.5 P Wait for field wide change out. 4/13/2016 0:00 6:30 8:30 2 P Move the sub 2.6 miles from Oliktok Y to 1Q pad. 4/13/2016 0:00 8:30 9:00 0.5 P Move the sub to the middle of the pad and stage with the wind at the back of the sub. 4/13/2016 0:00 9:00 11:00 2 P PJSM. Raise and pin the derrick. Hang the tree in the cellar. 4/13/2016 0:00 11:00 12:00 1 T Wait for the flow lines to be removed from well 1Q-26 and the well prep to be finished around the well. SimOps. Raise the cattle chute. Bridle down the blocks, hang bridle lines in the derrick. and pin the blocks to the TD. 4/13/2016 0:00 12:00 14:00 2 T Wait for the flow lines to be removed from well 1Q-26 and the well prep to be finished around the well. SimOps. Hang the rig tongs and set up the rig floor. 4/13/2016 0:00 14:00 18:00 4 T Wait for the flow lines to be removed from well 1Q-26 and the well prep to be finished around the well. SimOps. Grind edges of hammer unions. Clean and organize the sub. Perform general maintenance on the sub. 4/13/2016 0:00 18:00 18:30 0.5 P Move the pits near well 1Q-26. 4/13/2016 0:00 18:30 19:30 1 P Set mats around well 1Q-26 and lay out herculite around the well. 4/13/2016 0:00 19:30 21:30 2 P PJSM. Spot the sub over well 1Q-26. Set mats, lay out herculite in front of the sub, and set the sub down. 4/13/2016 0:00 21:30 0:00 2.5 P PJSM. Spot the pits to the sub, set rig mats, lay down herculite for the pits/cuttings box, and spot the cutting tank. 4/14/2016 0:00 0:00 4:00 4 P RU berming around the sub, pits, and cuttings box. Hook up the interconnect. RU steam, water, and air in the pits. Swap the pits to rig generators. Connect parts house and mud shack to rig power. Rig accepted at 04:00 hours on 4/14/16. 4/14/2016 0:00 4:00 7:00 3 P Load the pits with 8.8 ppg seawater. RU circulating liner for the well kill operation. 4/14/2016 0:00 7:00 8:30 1.5 P PU the lubricator and make up crossover. RU lubricator to the tree and PT to 1500 psi (good test). Pull 3" ISA BPV and RD the lubricator. 4/14/2016 0:00 8:30 9:00 0.5 P RU circulating lines to the tree through the choke manifold to the kill tank. Blow steam and air through line to the kill tank and check connections. PT lines to 3000 psi (good test). Blow down lines. 4/14/2016 0:00 9:00 12:00 3 P PJSM. Circulate 150 bbls of 8.8 ppg seawater down the tubing taking return out the IA to the kill tank at 1 BPM (ICP = 650 psi and FCP = 800 psi)getting clean 8.8 ppg seawater at surface. • 4/14/2016 0:00 12:00 13:00 1 P Bleed off the pump pressure. Install low pressure gauges on the tubing and IA. Monitor the well pressures for 30 minutes; 25 psi on the tubing and IA. Bleed both tubing and IA to 0 psi. Monitor the well pressures; tubing = 0 psi and IA = 0 psi. Bleed IA to 0 psi. Both tubing and IA slightly dripping. 4/14/2016 0:00 13:00 16:00 3 T Wait on weather due to field wide phase 3 conditions. SimOps: Continue to observe the well for flow for 30 minutes and the well is static. 4/14/2016 0:00 16:00 16:30 0.5 P RU to reverse circulate down the IA taking returns out the tubing through the gas buster to the pits. Reveres circulate 31.5 bbls at 1 BPM = 880 psi. 4/14/2016 0:00 16:30 17:00 0.5 P Bleed off the pump. Observe the well for flow for 30 minutes and the well is static. 4/14/2016 0:00 17:00 17:30 0.5 P Close in the well, blow down all circulating lines, and secure the cellar. 4/14/2016 0:00 17:30 18:30 1 P Hold an appreciation dinner for both rig crews for excellent work and safety record. 4/14/2016 0:00 18:30 19:30 1 P RD all circulating lines and install secondary annulus valve. 4/14/2016 0:00 19:30 20:00 0.5 P Install 3" ISA BPV with dry rod. Pressure up on the IA to 1000 psi to PT the BPV from below in the direction of flow for 10 minutes (good test). 4/14/2016 0:00 20:00 22:00 2 P RU wire slings to the TD and RU slings to the tree. ND the tree and tubing head adapter. Pull the tree free with the TD. RU the bridge crane to the tree. Lay down the tree and tubing head adapter. Clean and inspect the tubing hanger lift threads. Install the blanking plug (8 right hand turns). 4/14/2016 0:00 22:00 0:00 2 P NU the DSA and NU the BOP stack. 4/15/2016 0:00 0:00 1:30 1.5 P Torque bolts on the DSA and BOP stack. Install the turn buckles and riser. Air up the air boots on the riser. 4/15/2016 0:00 1:30 3:00 1.5 P RU BOPE testing equipment. Fill BOP stack and choke manifold with fresh water. MU 2-7/8" doughnut test joint with HT-38 TIW and MU the TD. 4/15/2016 0:00 3:00 4:30 1.5 P Conduct initial BOPE: test 2-7/8"x 5"VBR's (upper and lower pipe rams) to 250/3000 psi with 2-7/8"and 3-1/2"test joints; test annular to 250/3000 with 2-7/8"and 3-1/2"test joints; conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Bob Noble via email on 4/13/16 at 09:36 hours.Tests: 1) Lower Pipe Rams with 2-7/8"test joint, Upper IBOP (Passed) 2) Upper Pipe Rams with 2-7/8"test joint, Lower IBOP, 2" Demco, Chokes 1, 2, 3, &16 (Passed) 3) Upper Pipe Rams with 2-7/8"test joint, HCR Kill, HT-38 TIW, Chokes 4, 5, &6 (Passed) 4) Upper Pipe Rams with 2-7/8"test joint, Manual Kill, Chokes 7, 8, &9 (Passed) 5) Super Choke and Manual Adjustable Choke (Passed) 6) Upper Pipe Rams with 2-7/8" test joint, Manual Kill, Chokes 8, 10, & 11 (Passed) 4/15/2016 0:00 4:30 6:00 1.5 T Test: 7) Annular with 2-7/8"test joint, Manual Kill, Chokes 8, 12, & 13 (Passed) Note: Annular failed the high pressure test and retest passed. • • 4/15/2016 0:00 6:00 11:00 5 P Tests: 8) Blind Rams, Manual Kill, HT-38 Dart Valve, Outer Test Spool, Chokes 8, 12, & 13 (Passed) 9) Blind Rams, Manual Kill, Inner Test Spool, Chokes 8, 12, & 13 (Passed) 10)Annular with 3-1/2"test joint, Manual Kill, 3-1/2"EUE 8rd TIW, Choke 15 (Passed) 11) Upper Pipe Rams with 3- 1/2"test joint, 3-1/2"EUE 8rd TIW, Choke 14 (Passed) 12) Upper Pipe Rams with 3-1/2"test joint, 3-1/2"EUE 8rd TIW, Manual Choke (Passed) 13) Upper Pipe Rams with 3-1/2"test joint, 3-1/2" EUE 8rd TIW, HCR Choke (Passed) 14) Lower Pipe Rams with 3-1/2"test joint, 3-1/2"EUE 8rd TIW (Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure = 3000 psi Accumulator Pressure After Closer= 1650 psi Pressure Gain of 200 psi = 10 seconds Full System = 88 Seconds Average N2 (5 Bottles) = 1961 psi 4/15/2016 0:00 11:00 12:00 1 P Pull blanking plug with 3-1/2" test joint and lay down the test joint. Drain the BOP stack and gas buster. Blow down lines, choke manifold, and BOPE testing equipment. RD BOPE testino equipment. 4/15/2016 0:00 12:00 12:30 0.5 P Check for pressure under BPV(no pressure)and pull 3" ISA BPV with dry rod. 4/15/2016 0:00 12:30 13:00 0.5 P RU 3-1/2"tubing elevators, MU landing joint, MU 3-1/2" EUE 8rd TIW, and MU TD. 4/15/2016 0:00 13:00 13:45 0.75 P PJSM. Attempt to BOLDS but LDS were tight. RD landing joint with 3-1/2" EUE 8rd TIW. RU 3 pup joints for landing joint, MU 3-1/2" EUE 8rd TIW, and MU the TD. 4/15/2016 0:00 13:45 14:00 0.25 T BOLDS and unseat the tubing hanger at 50K. Establish PU parameters 50K to 100K. Set torque limit to 2200 ft-lbs. Rotate 1 turn to the right and work torque down. Rotate an additional 2-1/4 turns to right and work torque down. Unable to get the tubing to rotate with max allowed torque. Call out for SLB DSL(digital slickline). 4/15/2016 0:00 14:00 15:00 1 T Wait for SLB DSL to arrive. SimOps: Continue to work the tubing attempting to rotate to the right to release the K-22 anchor from the SAB-3 packer. 4/15/2016 0:00 15:00 15:30 0.5 T Set the landing joint in the slips with 75K. Break out the TD, crossover, and 10' pup joint from landing joint. MU 3-1/2" EUE 8rd TIW. 4/15/2016 0:00 15:30 20:00 4.5 T Spot up SLB DSL unit. PJSM with both crews. Bring tools and equipment to the rig floor. RU SLB DSL. 4/15/2016 0:00 20:00 21:00 1 T DSL damaged. Cut DSL and re head. MU 2" bailer. 4/15/2016 0:00 21:00 23:00 2 T RIH with 2" bailer and tag top of sand at 6262'ORKB. Activate bailer and POOH. 4/15/2016 0:00 23:00 23:30 0.5 T Bailer at surface and did not recover any sand. Break out 2" bailer and MU new 2" bailer. 4/15/2016 0:00 23:30 0:00 0.5 T RIH with new 2" bailer. 4/16/2016 0:00 0:00 0:30 0.5 T Continue to RIH with new 2" bailer.Tag sand at 6262'ORKB, activate bailer, and POOH. 4/16/2016 0:00 0:30 0:45 0.25 T Bailer at surface and recover approximately .5 gallon of river sand. Break out 2" bailer and MU 1-3/4" bailer. 4/16/2016 0:00 0:45 1:15 0.5 T RIH with 1-3/4" bailer.Tag sand at 6264'ORKB, activate bailer, and POOH. 4/16/2016 0:00 1:15 1:30 0.25 T Bailer at surface and 1 gallon of river sand. Break out 1-3/4" bailer and MU 2" bailer. 4/16/2016 0:00 1:30 21:15 19.75 T RIH with 2" bailer, activate bailer, and POOH. Recovered 1 gallon of river sand. RIH with 1-3/4" bailer 21 times recovering .75 to 1.5 gallons of sand each run. Recovering river sand down to 6270' SLM (6300'ORKB), clean frac sand from 6270' - 6278' SLM (6300' -6308'ORKB),and dirty frac sand from 6278' - 6290' SLM (6308' -6320'ORKB). On run #25 tagged sand at 6281'SLM (6311'ORKB). Sand is coming in from the IA through the open GLM at 6297'ORKB into the tubing. RD SLB DSL off to the side. • • 4/16/2016 0:00 21:15 22:30 1.25 T RU circulating equipment. Circulate 1.5 hole volumes; ICP at 2 BPM = 600 psi and FCP at 4 BPM = 1030 psi. Sand recovered across the shakers at bottoms up. Blow down and RD circulatina equipment. 4/16/2016 0:00 22:30 0:00 1.5 T RU SLB DSL. RIH with 1-3/4" bailer 2 times recovering 1.5 gallons of dirty frac sand each time down to 6295' SLM (6325'ORKB). 4/17/2016 0:00 0:00 6:30 6.5 T RIH with 1-3/4" bailer 4 times recovering 1 to 1.5 gallons of dirty frac sand each time down to 6303' SLM (6333' ORKB). RIH with 1-3/4" bailer 4 times recovering .5 to 1 gallons of silty/frac sand each time down to 6308' SLM (6338'ORKB). RIH with 2-1/4" bailer(drift run for the jet cutter) to 6307' SLM (6337'ORKB). Correlate with CCL and true tag depth is 6334'ORKR. 4/17/2016 0:00 6:30 11:00 4.5 T MU and RIH with 2-1/8" Power Jet Cutter. Correlate and tie into GLM at 6297'ORKB. Cut the tubing at 6314'ORKB and POOH. Confirmed cutter fires at surface. RD SLB DSL off to the side. PU on the tubing (85K) and confirmed that the tubing was free. RD SLB DSL and offload equipment from the ria floor. 4/17/2016 0:00 11:00 12:00 1 T RU circulating equipment. Circulate 1.5 hole volumes at 5 BPM (ICP = 1250 psi and FCP = 1150 psi) while reciprocating the tubing. 5 gallons of sand recovered across the shakers at bottoms up. Blow down and RD circulating equipment. PU = 80K. 4/17/2016 0:00 12:00 12:30 0.5 P Bring Weatherford power tubing tongs, 3-1/2" handling equipment, and 2-7/8" handling equipment to the rig floor. RU Weatherford to pull 3-1/2"x 2-7/8" completion. 4/17/2016 0:00 12:30 13:45 1.25 P PJSM. Pull the tubing hanger to the rig floor and lay down. POOH laying down 3-1/2" x 2-7/8" tubing to 5717' RKB 4/17/2016 0:00 13:45 14:00 0.25 P Kick while tripping drill: well secured in 45 seconds and CRT = 73 seconds. AAR with crew. 4/17/2016 0:00 14:00 14:30 0.5 P Service and DOMS inspection on the TD. 4/17/2016 0:00 14:30 21:30 7 P Continue to POOH laying down 3-1/2" x 2-7/8"tubing from 5717' RKB to surface. Recovered 192 joints of 3-1/2" tubing, 7 joints of 2-7/8" tubing, 2.812" DS nipple, 4 KBMM GLM's and cut joint = 7.40'. Hole found in cut joint 2.12'from the top of the joint(6306.01'ORKB). Clean and clear the floor. 4/17/2016 0:00 21:30 22:00 0.5 P MU wear ring running tool, install the wear ring, and lay down wear ring running tool. 4/17/2016 0:00 22:00 22:15 0.25 P PJSM for PU and MU cleanout assembly with dress off shoe. 4/17/2016 0:00 22:15 0:00 1.75 P PU and MU BHA #1 -cleanout assembly with dress off shoe. 4/18/2016 0:00 0:00 0:15 0.25 P Kick while tripping drill: well secured in 41 seconds and CRT = 99 seconds. AAR with crew. 4/18/2016 0:00 0:15 8:00 7.75 P RIH with BHA#1 -cleanout assembly with dress off shoe on 3-1/2" PH-6 work string to 6,294-ft. 4/18/2016 0:00 8:00 9:00 1 P MU Top drive and obtain parameters 105K up wt, 85K do wt, 90K RWT @ 2k Free torque @ 60 rpms. SPR's 2 bpm @ 280 psi 3bpm @660 4/18/2016 0:00 9:00 10:45 1.75 P dress off 2-7/8 Tbg stub with 4-3/4"OD x 2-15-16" ID sizing shoe© 6,295-ft(6,306-ft ORKB) continue to wash down to upset 25 -ft down tube. Pick up off the top of stub and increase Circ. rate to 10 bpm and clean hole. while reciorocatina work strina. 4/18/2016 0:00 10:45 11:30 0.75 P Close rams and pressure test from clean out depth of 6,335- ft to surface. pumping away at 1 bpm @ 2,445 psi. Shut down pump and pressure bled back to 1,800 psi over 25 minutes. Notify Town engr. Pressure up again to verify not leakina at casino wellhead oackoff. 15 M• - • 0 -----....„„., , . ,-- --- tA3* 0 . 000i '• , - ,... -„, . XV 5 -----*• - . 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I Date: April 18,2016 I Drawn By: Diana Guzman _____,___. , : .:,,.._ .,. :. _. - - >"--" 1 / /i p°r -... '• / ,..,--"" . . --___. /0 • / . �� --:_../°C ,„ '-, ‘....\-\-- \ , ,\.,\‘,57:_\ RaAppsJ •% // o aJ 0off °p09' 1 . _ \ /. ..,;) GED,...9.0. 40:00".s... , i O `ri % . ., . ,, . , ,, . .. . .:\ . . . \ . _ Ni SO�4 a , I j o # • (49_____1,':-..._ '* ' :*1 :.Ix,' 4p°0 � fp r , l'il'///1\111.///'/'\:::%/'• • ,___:_:_°°° i. j o / ai .. :,,,,..'„_\\\,"..:'\-___\'‘'''' _. , - _ . ,. ...\- .. . -r' '' . ' ' / • \-:-._ _.,\. Jo ___ . _� O }w W 0E —.NN1. KUP PROD 1Q-26 ConocoPhillips OAWell Attributes Max Angle&MD TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status no/("1 MD(ftKB) Act Btm(ORB) CoriocciPhiwpc 500292259000 KUPARUK RIVER UNIT PROD 31.89 4231,66 7,010.0 .« --- Comment H25(ppm) Date Annotation End Date KB-Gid(ft) Rig Release Date 10-2212rz20152:49:00 PM SSSV:NIPPLE 90 11/5/2014 Last WO: 9/23/1995 Vertical schematic(actual) Annotation Depth(65(B) End Date Annotation Last Mod By End Date Last Tag:RKB 6,528.4 9/17/2015 Rev Reason:SET PLUG lehallf 12/2/2015 Casing Strings HANGER;362 =`rAMIN Casing Description OD lin) ID(in) Top(RKB) Set Depth(81(8) Set Depth(ND)...WI/Len(I...Grade Top Thread I CONDUCTOR 16 15.062 40.9 121.0 121.0 62.50 H-40 WELDED Casing Description 'OD(In) ID(in) Top 011413) Sat Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 7 5/8 6.875 40.9 3,809.2 3,715.7 29.70 L-80 LTC al 14 Casing Description OD(in) ID(In) 'Top(RKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(1...Grade Top Thread PRODUCTION 51/2 4.950 33.3 6,992.8 6,533.4 15.50 L-80 LTC-MOD CONDUCTOR;40.9-121.0 s-'Tubing Strings Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 3.5x2.875 3 1/2 2.992 36.3 6,362.8 5,960.0 9.30 L-80 EUE8RDMOD NIPPLE;509.7 _ Completion Details ® Nominal ID Top(ftK6) Top(TVD)(ftKe) Top Incl(°) item Dee Com (in) 36.3 36.3 0.10 HANGER FMC GEN IV TUBING HANGER 3.500 509.7 509.7 1.26 NIPPLE CAMCO OS LANDING NIPPLE;2.856"NO GO 2.812" 2.812 GAS LIFT;2,4891 6,341.7 5,940.8 24.41 PACKER BAKER SAB-3 PERMANENT PACKER w/K-22 3.000 111 ANCHOR SEAL 6,352.9 5,951.0 24.35 NIPPLE CAMCO XN NIPPLE(2.31'x 2.25"NO GO) 2.250 6,362.1 5,959.4 24.38 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Ind Top(RKB) (ftKB) (°) Des Com Run Date ID(in) 6,353.0 5,951.1 24.35 PLUG PXN PLUG 11/16/2015 6,528.4 6,110.6 24.88 CEMENT DUMP BAIL 10 GAL CEMENT 9/7/2015 SURFACE;40.9-3,8092------+ ' - 6,539.0 6,120.2 24.91 SAND DUMP BAIL SAND TO 6539' 9/3/2015 6,557.0 6,136.5 24.96 SAND DUMP BAIL 2000#OR FIVER SAND ON TOP OF 8/31/2015 IBP x06609' GAS LIFT;4,250.4 6,602.0 6,177.3 25.10 PLUG 2.13"IBP 7/7/2015 0.000 6,900.0 6,448.4 23.73 FISH GLV 1"GLV LOST IN CASING,EXACT DEPTH 8/16/2004 0.000 UNKNOWN Perforations&Slots Shot Dens GAS LIFT;2509.4 Top(ND) Btm(TVD) (Shetntf Top(ftKB) Bfm(0K6) (ftKB) (ftKB) Zane Date t) Type Com 6,417.0 6,432.0 6,009.4 6,023.0 C-4,10-26 8/13/2005 6.0 APERF 2'PJ,60 deg phase,0 deg orient 6,417.0 6,432.0 6,009.4 6,023.0 Com,10-26 1/6/2006 6.0 RPERF 2'HJ,60 deg.phase 6,445.0 6,467.0 6,034.8 6,054.8 C-4,C-3,10- 8/13/2005 ' 6.0 APERF 2"PJ,60 deg phase,0 26 deg orient GAS LIFT;6,297.3 6,507.0- 6,522.0' 6,091.1- - 6,104.8-C-1,10-26 8/13/2005 6.0 APERF 2"PJ,60 deg phase,0 deg orient 6,696.0 6,726.0 6,262.4 6,289.7 A-3,10-26 1/21/1996 8.0 IPERF 180 deg.phasing; Oriented(+/-)F/Btm Side;2 1/8"EnerJet PACKER;6,341.7ill Stimulations&Treatments Min Top Max Wm NIPPLE;8,332.9 Depth Depth Top(TVD) Etre(TVD) (RKB) OMB) (81(8) (RKB) Type Date Com PLUG;8,3530 6,417.0 6,432.0 6,009.4 6,023.0 CSAN D FRAC 1/7/2006 PLACED 155M#16/20 CARBOLITE rJ THE FORMATION,9 PPA ON PERFS,100%OF DESIGN. SAW TSO-55 MINUTES INTO FRAC,WELL WAS PRESSURING UP AT END OF JOB.FLUSI-ED TO SOS;6,362.1 COMPLETION. Cement Squeezes Top(TVD) Wm(190) Top(MB) Btm(01(6) (ftKB) (ft60) Des Start Date Com RPERF;6,417.0-6,432.0 6,651.0 6,992.0 6,221.6 6,532.7 Cement Plug 5/19/2015 5BBL pumped,dropped 5/8"ball,15.8 ppg C-SAND FRAC;6,417.0 APERF;6,417.0-6,132.0 1 1 Mandrel Inserts St ' on Top Valve N Top(RKB) 10(B)D) Latch Make Model OD(in) Sere Type yPori Size TRO n i) Run Date Corn 1 2,489.7 2,487.0 CAMCO KBMM ' 1 GAS LIFT GLV BK 0.188 1,273.0 2/3/2012 APERF;6,445.0-6,467.0---/-•-•_ 2 4,250.4 4,092.3 CAMCO KBMM 1 GAS LIFT OV BK 0.250 0.0 9/19/2015 3 5,509.4 5,196.2 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0,0 9/19/2011 4 6,297.3 5,900.4 CAMCO KBMM 1'GAS LIFT DMY BK 0.000 0.0 6/15/2015 EXT APERF;6,607.0-6,522.0 HI- - SEAL PKG CEMENT;6,5284 = Notes:General&Safety End Date Annotation SAND;6,539.0 1/15/2010 'NOTE:DRIFTED TBG w/2.345"gauge to 8353'RIB SAND;6,557.0 10/13/2010 NOTE:View Schematic w/Alaska Schematic9.0 PLUG;6,602.0 11 vvv, (PERF;6,696.0-6,7260- i FISH;8,900.0 ^V V' W W WN Nils PRODUCTION;33.3-6,9928 • • ConocoPhillipsL 1 Q-26 Proposed Completion 2'/a"GL Completion Casing Leak Repair 16"62.5#, H-40 to 121'MD -► 2'/8"x 1" KBG 2-9 Manerr'l • 2'/8"x 1" KBG 2-9 Mandrel 7 5/a"29.7#,L-80 to 3809'MD ► I. MI 2'/8"x 1" KBG 2-9 Mandrel 1111 2'/a"x 1" KBG 2-9 Mandrel GLM# Depth-ft TVD Depth-ft MD Valve Type I 1 2,500 2,503 Dummy . 2'/8"x 1"KBG 2-9 Mandrel 2 3,700 3,796 SOV(IA to Tbg shear) 3 4,600 4,831 Dummy 4 5,300 5,625 Dummy 2'/8"6.5#L-80 8rd EUE Tbg 5 5,782 6,166 Dummy Baker Locator&Seals lir Baker PBR Baker 2'/8"x 5 1/2" Packer @-TBD' 1111 2.31" DS Nipple Profile with a aid I\ Casing Leak @-TBD' -- ' j I CA-2 in place irt 6314'MD-Tubing Cut I I 2'/8" Poor Boy Overshot and 1/2" muleshoe **Tubing Cut Performed on rig** _ Baker SAB-3 Permanent Packer w/ '81111111111-: K-22 Anchor Seal I2.31"x 2.25"NO GO XN Nipple Profile w/a PXN Plug Baker Shear Out Sub Date ! Cement Well Pert Top MD Btm MD Zone 10-26 1/6/06 6417 6432 C-4 INTERVAL I 2000#of River Sand 1Q-26 8/13/05 6445 6467 C-4 INTERVAL l►�,, 2.13"IBP 1Q-26 8/13/05 6445 6467 C-3 INTERVAL :,: 10-26 8/13/05 6507 6522 C-1 INTERVAL 10-26 1/21/96 6696 6726 A-3 INTERVAL = . Fish-GLV 1" Exact Depth unknown 51/2" 15.5#, L-80 to 6993'MD-� .-:-:-:-4/1-..: :: : :' Date: April 18,2016 Drawn By: Diana Guzman Pry g5--/32 • Loepp, Victoria T (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, November 17, 2015 9:06 AM To: Loepp, Victoria T (DOA) Cc: NSK Problem Well Supv; Senden, R.Tyler Subject: RE: 1Q-26 Request to flow with known tubing leaks for production information.(PTD 195-132) Follow Up Flag: Follow up Flag Status: Flagged Victoria, The production test has been completed and the well has been secured with a plug set in the XN nipple @ 6352'. Please let me know if you have any question. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7224 Pager(907) 659-7000 pgr. 909 AliSCANNED SEP:2 0 2016 WELLS TEAM From: Loepp, Victoria T(DOA) [ fto:victoria.loepp@alaska.goA Sent: Saturday, October 10, 2015 4:20 PM To: NSK Problem Well Supv Subject: [EXTERNAL]Re: 1Q-26 Request to flow with known tubing leaks for production information. Approval is granted to flow 1Q-26 for up to 30 days for the purpose of a production test. We will revisit an extension of the production testing near the end of this approved period of testing. Victoria Sent from my iPhone On Oct 10,2015,at 4:04 PM, NSK Problem Well Supv<n1617c conocophillips.com>wrote: Victoria, I am following up on this request Dusty sent to you 2 weeks ago. Is there any more information that you would need from us before making your decision? Thanks Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 1 S From: NSK Problem Well Supv Sent: Friday, September 25, 2015 10:14 AM To: 'victoria.lo pp@alaska.gov' Cc: Senden, R. Tyler; Cookson, John Subject: 1Q-26 Request to flow with known tubing leaks for production information. Victoria- CPAI is seeking permission to put Kuparuk producer 10-26(PTD#195-132) online with lift gas for a production test with known tubing leaks at 6257' and 6306'. This production test is necessary to identify the performance of the C-Sands prior to performing rig operations. Without this information,a wasted, high-cost workover could be performed and multiple rig workovers could be required. A 30 day period is requested to obtain sufficient production information from the Cl-Sand and C4-Sand. Depending on the outcome of the production test period CPAI would like the option to isolate the Cl-Sand from the C4 Sand and extend the production period for an additional 30 days. Kuparuk producer 1Q-26 is a 245 BOPD,90%water cut well that has produced from commingled A,C and C-Sands with a remaining resource of approximately 500 MBO. There is a great deal of uncertainty regarding the production splits from the three sands but it is likely that the C-Sands (in particular,the C4 -Sand) are less mature and contain the bulk of the remaining resource. In late 2014,the well began producing rocks(identified as A-Sand sourced) and was shut-in. A bridge and cement plug has been placed over the A-Sand to prevent rock influx and enable a production test of the C- Sands. Subsequently,the two tubing leaks were identified at 6257' and 6306', but an effective patch is prevented by the mixed 31/2" and 2 7/8"tubing string. The well passed a CMIT to 2500 psi which proves the production casing and production packer integrity. Attached is a copy of the well bore schematic,the tubing tally to reference the leak locations in relations to the 31/2" and 2 7/8"tubing string, and the MIT form for the diagnostic CMIT-TxIA. If you have any questions or concerns please feel free to contact us as needed. Cheers, Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907) 943-0450 <image001.png> 2 • � � / /5---/32- Loepp, /S—/32Loepp, Victoria T (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, October 10, 2015 4:24 PM To: Loepp,Victoria T (DOA) Subject: RE: 1Q-26(PTD 195-132) Request to flow with known tubing leaks for production information. Follow Up Flag: Follow up Flag Status: Flagged SCANNED From: Loepp, Victoria T(DOA) [mailto:victoria.loepo@ alaska.gov] Sent: Saturday, October 10, 2015 4:20 PM To: NSK Problem Well Supv Subject: [EXTERNAL]Re: 1Q-26 Request to flow with known tubing leaks for production information. Approval is granted to flow 10-26 for up to 30 days for the purpose of a production test. We will revisit an extension of the production testing near the end of this approved period of testing. Victoria Sent from my iPhone On Oct 10,2015,at 4:04 PM, NSK Problem Well Supv<n1617@conocophillips.com>wrote: Victoria, I am following up on this request Dusty sent to you 2 weeks ago. Is there any more information that you would need from us before making your decision? Thanks Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 From: NSK Problem Well Supv Sent: Friday, September 25, 2015 10:14 AM To: 'victoria.Ioepp@alaska.gov' Cc: Senden, R. Tyler; Cookson, John Subject: 1Q-26 Request to flow with known tubing leaks for production information. Victoria- CPAI is seeking permission to put Kuparuk producer 1Q-26 (PTD#195-132)online with lift gas for a production test with known tubing leaks at 6257'and 6306'. This production test is necessary to identify the performance of the C-Sands prior to performing rig operations. Without this information, a wasted, high-cost workover could be performed and multiple rig workovers could be required. A 30 day period 1 • • is requested to obtain sufficient production information from the Cl-Sand and C4-Sand. Depending on the outcome of the production test period CPAI would like the option to isolate the Cl-Sand from the C4 Sand and extend the production period for an additional 30 days. Kuparuk producer 1Q-26 is a 245 BOPD,90%water cut well that has produced from commingled A, C and C-Sands with a remaining resource of approximately 500 MBO. There is a great deal of uncertainty regarding the production splits from the three sands but it is likely that the C-Sands(in particular,the C4 -Sand)are less mature and contain the bulk of the remaining resource. In late 2014,the well began producing rocks(identified as A-Sand sourced) and was shut-in. A bridge and cement plug has been placed over the A-Sand to prevent rock influx and enable a production test of the C- Sands. Subsequently,the two tubing leaks were identified at 6257'and 6306', but an effective patch is prevented by the mixed 3%z" and 2 7/8"tubing string. The well passed a CMIT to 2500 psi which proves the production casing and production packer integrity. Attached is a copy of the well bore schematic,the tubing tally to reference the leak locations in relations to the 3%z" and 2 7/8"tubing string, and the MIT form for the diagnostic CMIT-TxIA. If you have any questions or concerns please feel free to contact us as needed. Cheers, Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907) 943-0450 <image001.png> 2 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COOSSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations pr, Fracture Stimulate r Pull Tubing fl Operations Shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Acpprgveri Program r for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well Other ig kir Rock CorttpI [- ser //3/71rr7, 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 195-132 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-22590-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25641 KRU 1Q-26 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7010 ' feet Plugs(measured) 6528', 6602', 6651' true vertical 6549 feet Junk(measured) 6900' Effective Depth measured 6904 a feet Packer(measured) 6342 true vertical 6452 feet (true vertical) 5941 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 3768 7.625 3809 3716 PRODUCTION 6960 5.5 6993 6533 RECEIVED sug*EV NV `7, 201 SEP 2 4 2015 Perforation depth: Measured depth: 6417-6432,6445-6467,6507-6522,6696-6726 True Vertical Depth: 6009-6023,6035-6055,6091-6105,6261-6289 AOGCC Tubing(size,grade,MD,and TVD) 3.5x2.875, L-80,6363 MD, 5960 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER SAB-3 PERMANENT PACKER W/K-22 ANCHOR SEAL @ 6342 MD and 5941 TVD NIPPLE-CAMCO DS LANDING NIPPLE;2.856"NO GO 2.812"@ 510 MD and 510 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations pr Exploratory E Development pr Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-105 Contact John Cookson a,265-6547 Email John.Cookson(u�conocophillips.com Printed Name Jt. n Cookso Title Principal Drillsite Petroleum Engineer Signature / Phone:265-6547 Date 61/23/1� Vr` c /Zq/ts le e g/2., ./--- RBDMS t Form 10-404 Revised 5/2015 g 3 Submit Original Only 1.- it KUP PROD • 1Q-26 ConocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) Gomco /hp, 500292259000 KUPARUK RIVER UNIT PROD 31.89 (231.66 7,010.0 -.- Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date 10-26,9/2220158:58:40 AM SSSV:NIPPLE _ 90 11/5/2014 Last WO: 9/23/1995 Vesical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ........................................................... Last Tag:RKB 6,528.4 9/17/2015 Rev Reason: DUMP BAIL SAND/CEMENT,GLV hipshkf 9/22/2015 C/O TAG Casing Strings HANGER;36.3 lila-..i- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 40.9 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread • SURFACE 75/8 6.875 40.9 3,809.2 3,715.7 29.70 L-80 LTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread PRODUCTION 51/2 4.950 33.3 6,992.8 6,533.4 15.50 L-80 LTC-MOD CONDUCTOR;40.9-1210-4 :Tubing Strings Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 3.5x2.875 'String 3 1/21 2.9921 36.31 6,362.81 5,960.01 9.301 L-80 I EUE8RDMOD NIPPLE,599.7 ?' Completion Details I Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 36.3 36.3 0.10 HANGER FMC GEN IV TUBING HANGER 3.500 509.7 509.7 1.26 NIPPLE CAMCO DS LANDING NIPPLE;2.856"NO GO 2.812" 2.812 GAS LIFT;2,489.7 6,341.7 5,940.8' 24.41 PACKER BAKER SAB-3 PERMANENT PACKER w/K-22 3.000 ANCHOR SEAL 6,352.9' 5,951.0 24.35 NIPPLE CAMCO XN NIPPLE(2.31"x 2.25"NO GO) 1 2.250 6,362.1 5,959.4 24.38 SOS BAKER SHEAR OUT SUB 2.441 I .' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl t Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) ( 6,528.4 6,110.6 24.88 CEMENT DUMP BAIL 10 GAL CEMENT 9/7/2015 6,539.0 6,1202 24.91 SAND DUMP BAIL SAND TO 6539' 9/3/2015 SURFACE;40.9-3809.2-' ` 6,557.0 6,136.5 24.96 SAND DUMP BAIL 2000#OR FIVER SAND ON TOP OF '8/312015 IBP @6609' I6,602.0 6,177.3 25.10 PLUG 2.13"IBP 7/7/2015 0.000 I. 6,900.0 6,448.4 23.73 FISH GLV 1"GLV LOST IN CASING,EXACT DEPTH 8/16/2004 0.000 GAS LIFT;4,250.4 - UNKNOWN Perforations&Slots Shot Dens I Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (RKB) (RKB) Zone Date t) Type Com GAS LIFT;5,509.4 III 6,417.0 6,432.0 6,009.4 6,023.0 C-4,1Q-26 8/13/2005 6.0 APERF 2"PJ,60 deg phase,0 deg orient 1. I 6,417.0 6,432.0 6,009.4 6,023.0 C-4,1Q-26 1/62006 6.0 RPERF 2"HJ,60 deg.phase 6,445.0 6,467.0 6,034.8 6,054.8 C-4,C-3,10- 8/13/2005 6.0 APERF 2"PJ,60 deg phase,0 26 deg orient 6,507.0 6,522.0 6,091.1 6,104.8 C-1,1Q-26 8/13/2005 6.0 APERF 2"PJ,60 deg phase,0 II deg orient GAS LIFT;6,297.3 6,696.0 6,726.0 6,262.4 6,289.7 A-3,10-26 121)1996 8.0 IPERF 180 deg.phasing; IOriented(1-1-)F/Btm Side;2 1/8"EnerJet IStimulations&Treatments PACKER;6,341.7 Min Top Max Btm I, Depth Depth Top(TVD) Btm(ND) (RKB) (ftKB) (RKB) (ftKB) Type Date Com 6,417.0 6,432.0 6,009.4 6,023.0 C-SAND FRAC 1/7/2006 PLACED 155M#16/20 CARBOLITE IN THE NIPPLE;6,352.9 FORMATION,9 PPA ON PERFS,100%OF DESIGN. SAW TSO`55 MINUTES INTO FRAC,WELL WAS PRESSURING UP AT END OF JOB. FLUSHED TO COMPLETION. SOS;6,362.1 I Cement Squeezes Top Top(TVD)I Bt( (ND) (ftKB) Btm(ftKB) (ftKB ftKB Des Start Date Com 6,651.0 6,992.0 6,221.6 6,532.7 Cement Plug 5/19/2015 5BBL pumped,dropped 5/8"ball,15.8 ppg APERF;6,417.06,432.0 Mandrel Inserts RPERFC-SAN 6,417.0-6,432.0 o C-SAND FRAC;6,417.0 St atii Top(ND) • Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sero Type Type (in) (psi) Run Date Com 1' 2,489.7 2,487.0 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,273.0 2/3/2012 APERF;6,445.06,467.0 2 4,250.4 4,092.3 CAMCO KBMM 1 GAS LIFT OV BK 0.250 0.0 9/19/2015 - 3 5,509.4 5,196.2 CAMCO KBMM ' 1 GAS LIFT DMY BK 0.000 0.0 9/19/2011 4 6,297.3 5,900.4'CAMCO 'KBMM ' 1 GAS LIFT DMY BK 0.000 0.0 6/15/2015 EXT - HI- APERF;6,507.06,522.0 SEAL PKG Notes:General&Safety CEMENT;6,528.4 == End Date Annotation 1/15/2010 NOTE:DRIFTED TBG w12.345"gauge to 6353'RKB SAND;6,539.0 10/13/2010 NOTE:View Schematic w/Alaska Schematic9.0 SAND;6,557.0 nn PLUG;6,602.0 r////8 IPERF;6,696.0-6,726.0- VWIIIIIW� FISH;6,900.0 PRODUCTION;33.3-6.992.8 • 1Q-26 WELL WORK SUMMARY DATE SUMMARY 4/4/2015 TAG FILL W/2.25"GAUGE RING @ 6262'SLM; LEAK DETECT W/HOLEFINDER SET @ 6252' SLM. FAILED P.T. W/SLOW COMMUNICATION TO IA&WING LEAKING. UNABLE TO SET HOLEFINDER ANYWHERE ELSE. IN PROGRESS. 4/5/2015 LEAK DETECT W/HOLEFINDER POSS. LEAK BETWEEN 6280' RKB &5430' RKB. ATTEMPT TO REPEAT UNABLE TO PASS 5430' RKB, ATTEMPT TO ROLL PUMP &TBG PRESSURED UP. BLEED IA FROM 2200 TO 1400 W/HOLEFINDER IN LUBRICATOR PASS MITT. JOB COMPLETE. 4/24/2015 RAN 2.63"OD VENTURI BASKET WITH MULE SHOE BOTTOM, SAT DOWN AT 2440' CTMD (GLM 2490' RKB), UNABLE TO SLIP BY. REMOVED BASKET AND MULE SHOE BOTTOM. RAN 2.20"JSN AND DRIFTED BY TO 2537'CTMD. IN PROGRESS. 4/25/2015 CTU 4: GOOSENECK SUSTAINED DAMAGE AFTER BEING RIGGED UP TO THE WELL. HAD TO SET INJECTOR BACK DOWN ON THE DECK AND REPLACE GOOSE NECK. RESTART JOB IN THE MORNING. 4/26/2015 RAN 2.63"OD VENTURI, SAT DOWN AT 2229' CTMD, WORKED DOWN TO 2237'CTMD. PULLED OUT TO INSPECT, 8 FT VENTURE BARREL PACKED FULL WITH ASPHALTINES. RAN 2.20"JSN, SAT DOWN AT MULTIPLE DEPTHS, FINAL DEPTH WAS 6265' CTMD. RAN LOW ON FLUIDS, NOT ABLE TO GET MORE TO CONTINUE JOB. JOB IN PROGRESS 4/27/2015 RAN 2.2"OD JUNK MILL& MOTOR, DRY TAGGED AT 6290' CTMD. CLEANED OUT USING SLICK DIESEL& DIESEL GEL SWEEPS TO 6656'CTMD, DID NOT GO DEEPER. SAW SOME LIGHT MOTOR WORK AT 6506'CTMD. 5/5/2015 DRIFTED TBG &TAGGED @ 6658' SLM. IN PROGRESS 5/6/2015 CALIPER CSG UP INTO TBG FROM 6663' RKB-6208' RKB (GOOD DATA); MEASURE BHP @ 6572' RKB (3512 PSI). READY FOR CTU. 5/13/2015 (AC EVAL): PUMPED 14.5 BBLS OF DIESEL DOWN IA. 5/13/2015 PUMP 30BBLS DWN IA FOR FP (JOB COMPLETE) 5/17/2015 RIH WITH CMT BHA, TAG AT 6661' CORRECT TO 6663' SL RKB, LAY IN 5 BBLS CEMENT TO 6450', DROP 5/8" BALL, CLEAN OUT DOWN TO 6565' RKB, CLEAN UP TO 6450'4 TIMES, CHASE OUT OF HOLE AT 80%, WELL FREEZE PROTECTED **** LET SET FOR 48 HRS BEFORE SLICK LINE TAG***** 5/19/2015 ENCOUNTERED OBSTRUCTION @ 2424' SLM WITH 2.67" SWAGE. TAGGED 2.25"XN @ 6352' RKB. BRUSHED TBG FROM 2424-2500' SLM &6325'-6362' RKB. TAGGED CMT @ 6651' SLM; RETRIEVED 4 SMALL ROCKS. SET 2.25" PXN PLUG BODY @ 6352' RKB. IN PROGRESS. 5/20/2015 SET PRONG IN PXN PLUG @ 6352' RKB. COMBO MIT TO 3000 PSI, PASSED. COMPLETE. 5/23/2015 T-LLR: ESTABLISHED A LLR OF 8.75 GPM AT 1150 PSI. 6/2/2015 HARDLINE CREW INSTALLED JUMPER ON IA. RAN LDL, APPEARS LEAK IS @ GLM STATION#4, 6306' RKB. IN PROGRESS. 6/3/2015 PULLED 1" DGLV FROM ST#4 @ 6297' RKB. VALVE LOOKED GOOD.SOME ASPHALTENES AROUND LATCH. ATTEMPTED SETTING 1" DFGLV IN ST#4 @ 6297' RKB. LOST JAR ACTION WHILE SETTING. LRS PUMPED ON TBG &ON IA WHILE WORKING WIRE. NO JAR ACTION OR MOVEMENT. DROPPED 1 7/8" CUTTER BAR.RECOVERED ALL WIRE.RETURN IN AM TO FISH TOOLS. IN PROGRESS. 6/4/2015 PULLED CUTTER BAR FROM 6208'SLM. FISHED 1.5"TOOL STRING W/KOT FROM 6214'SLM. VALVE SET,ARM PINS SHEARED. RAN IN TO PULL CATCHER, S/D @ 6288' SLM. RECOVERED FISHING NECK OFF CATHCER. BROKE AT THREADS. RAN 2.25" BULL DOG SPEAR.S/D @ 6287' SLM. RECOVERED CATCHER(empty). IN PROGRESS 6/5/2015 SET 2.5"AVA STYLE CATCHER @ 6290' SLM. PULLED 1" BK-DGLV(ended packing) FROM ST#4 @ 6297' Rle SET 1" BK-DGLV(high sealability packing) IN ST#4 @ 6297' RKB. LRS PERFOMED MIT-T,IA STARTED TRACKING. PULLED 2.5"AVA STYLE CATCHER FROM 6288' SLM (empty). RDMO. JOB COMPLETE. 7/5/2015 BAIL FILL; PULL PXN PLUG @ 6352' RKB; DRIFT W/ 10'X 2 1/8" OD &TAGGED FILL @ 6393' SLM. IN PROGRESS (READY FOR CTU). 7/7/2015 RIH WITH 2.0" DJN, DID NOT TAG ANY FILL, MADE IT TO KNOWN TAG AT 6650', PUMP A 10 BBL GEL PILL CHASE OUT OF HOLE WITH SLICK SEAWATER, RIH WITH 2.13" IBP, SET AT 6602' RKB MID ELEMENT AT 6609' RKB. FREEZE PROTECT WELL. **** IN PROGRESS**** 7/11/2015 RAN 2" DUMP BAILER TO 6007' SLM, UNABLE TO WORK PAST. IN PROGRESS. 7/12/2015 DUMP BAILED - 5' SAND ON IBP @ 6609' RKB (LIGHT DRAG FROM 4300' TO 4100' SLM). IN PROGRESS. 7/13/2015 CONTINUE DUMP BAIL SAND @ 6619' SLM. AFTER A DOZEN DUMP RUNS, NO APPARENT FILL IN TBG. RAN 2.20" LIB TO 6619' SLM. IN PROGRESS. 7/14/2015 MADE MULTIPLE LIB RUNS TO 6616' SLM; RESULTS INCONCLUSIVE. JOB SUSPENDED. 8/5/2015 RAN 2.0" BLIND BOX AND SAT DOWN IN TBG @ 5362' SLM. RAN 1.75" SAMPLE BAILER AND SD IN TBG @ 5362' SLM; RECOVERED FULL BAILER OF MEDIUM DENSITY TAR/PARAFFIN. RAN 1.75"x5' DRIVE DOWN BAILER AND WORKED TO 5729' SLM (RECOVERED FULL BAILER OF SAME). RAN 1.90" GAUGE RING ON BRUSH; SD IN TBG @ 6116' SLM AND WORKED DOWN TO 6579' SLM. RAN 2.27" GAUGE RING ON BRUSH AND TAGGED NIPPLE @ 6352' RKB. *JOB IN PROGRESS 8/6/2015 RAN 2" BLIND BOX W/GAUGES FOR STATIC AND SD IN TBG @ 6124' SLM. RAN 2.35" GAUGE RING ON BRUSH, SD IN TBG @ 6124' SLM, WORKED TO 6155' SLM. MADE 4 RUNS WITH 1.75" BAILER AND BAIL PARAFFIN FROM 6130' SLM TO 6178' SLM, BROUGHT LRS ONLINE AND BEGAN TO PRESSURE UP TBG. SAW PRESSURE STALL @ 1000#, LRS OFF LINE, RAN IN HOLE AND TAG TD OF 6578.5' SLM. RAN 2.35" GAUGE RING ON BRUSH AND WORKED TIGHT AREAS FROM 6100'-6250' SLM. RAN 2.20" CENTRALIZER W/1.75" BAILER BELOW AND TAGGED TD @ 6578.5' RKB. *JOB IN PROGRESS 8/7/2015 RAN 2" BLIND BOX ON GAUGES AND SAT DOWN IN TBG @ 6304' SLM, RAN 2.20" CENTRALIZER & 1.75" BAILER, SD IN TBG @ 6311' SLM, WORKED DOWN TO 6330' SLM. RAN 2" PUMP BAILER WITH GAUGES ABOVE AND WORKED DOWN TO TD OF 6575' SLM (6651' RKB). PERFORMED 30 MIN SBHPS (6621' RKB @ GAUGE: 2753.2psia, 154.6*F). RAN LDL TOOLSTRING AND DID NOT OBSERVE CROSS-FLOW PAST IBP, LRS CAME ONLINE PUMPING AND ESTABLISHED RATE OF 0.09 BPM @ 1200#, NO FLOW OBSERVED PAST IBP W/LRS PUMPING, LOGGED UP PAST C SAND PERFS, LRS DOWN OFF PUMP. *JOB IN PROGRESS 8/8/2015 TAGGED TD OF 6595' SLM W/2" PUMP BAILER. RAN LDL TOOLSTRING TO 6615' RKB, DID NOT OBSERVE FLOW PAST IBP, LRS PUMP 0.5 BPM @ 1350#. STILL NO FLOW OBSERVED PAST IBP, LOGGED UP AND DOWN PASSES PAST PERFS FROM 6615'-6250' RKB @ 80 & 120 FPM. MADE FOUR 2" DUMP BAILER RUNS TO 6650' SLM. *JOB IN PROGRESS 8/9/2015 PERFORMED NINE 2"x10' DUMP BAILER RUNS (SAND) ON TOP OF IBP, TIED IN WITH SLB CBL DATED 10/24/95, TAGGED TD @ 6651' RKB (*NO CHANGE FROM PRIOR TD TAG DEPTH). CONFER W/CWG REP, RIGGED DOWN. WELL AWAITING FURTHER TROUBLESHOOTING. *JOB COMPLETE 8/31/2015 RIH JET HOT DIESEL FROM 2500' DOWN TO 6600', MAKE 4 PASSES UP TO TUBING TAIL@ 6362'. PUMPED 2,000LBS OF RIVER SAND ON TOP OF IBP @6609'. FINAL TAG DEPTH AT 6551' CTMD. ****READY FOR SLICKLINE TAG***** 9/2/2015 DUMPED BAILED SAND FROM 6519'-6513' SLM EST- 6550' RKB. IN PROGRESS 9/3/2015 DUMP BAILED SAND FROM 6512'-6501' SLM, LOCATED TTL CORECTED TO AN ESTIMATED SAND TOP @ - 6538' RKB. READY FOR DSL TO CONFIRM SAND TOP. 9/7/2015 TAGGED TD @ 6539' RKB, MADE FOUR RUNS DUMP BAILING CEENT (10 gal TOTAL; 2"x20' BAILER). FINAL DEPTH OF 6478' SLM. RIG DOWN A EAD TO NEXT JOB WHILE CEMENT CURE . *JOB COMPLETE 5$3� WELL LOG TRANSMITTAL DATA L GED ro i nog 5 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. May 18, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAY 2 1 2015 RE: Multi Finger Caliper(MFC) : 1Q-26 Run Date: 5/6/2015 . OGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 10-26 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22590-00 ` te° .iUN 2 `61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: . • vOF TJi s THE STATE Alaska Oil and Gas mw f oLAS Conservation Commission A " _= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS SCONE '�`r b '^ Fax: 907 276.7542 eqNN � www.aogcc.alaska goy John Cookson Principal Drillsite Petroleum Engineer �3 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1Q-26 Sundry Number: 315-105 Dear Mr. Cookson: 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, P;44,1`4-c— Cathy P. F erster Chair, Commissioner DATED this 2-ay of March, 2015 Encl. STATE OF ALASKA t A KA OIL AND GAS CONSERVATION COMM.�SION • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request Abandon r Plug for Redrill r •, Perforate New Fbol r Repair w ell r Change Approved Program r Suspend r Rug Perforations 171 Ferforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulatefter casing Ar Other:Plug for Rock Control � 2.Operator Name. 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r . 195-132 , 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-22590-00 - 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exceptions Yes r No r KRU 1Q-26 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25641 - Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7010 . 6549 - 6904' • 6452' • none 6900' Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 121' 121' Surface 3761 7.625" 3809' 3716' RECEIVED Production 6990 5.5 6993' 6533' FEB 242015 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6417-6432,6445-6467,6507-6522,6696-6726 ' 6009-6023,6035-6055,6091-6105,6261-6289 3.5x2.875 L-80 6363 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER SAB-3 PERMANENT PACKER W/K-22 ANCHOR MD=6342 TVD=5941 • NIPPLE-CAMCO DS LANDING NIPPLE MD=510 TVD=510 . 12.Attachments: Description Surrmary of Proposal p, 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r', Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/27/2015 Oil I✓', Gas r WDSPL r Suspended r 16.Verbal Approval: Date. WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Cookson @ 265-6547 Email: John.Cookson@conocophillips.com Printed Name Joh oks jt....._ Title: Principal Drillsite Petroleum Engineer Signature i Phone:265-6547 Date 2/ZLI/20 L- v Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ---2k5 -\d5 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No E" Subsequent Form Required: `0 - ¢e if n APPROVED BY - _/5-- Approved by: / COMMISSIONER THE COMMISSION Date: Ap roved application Is valid tor 12 months trornthe date of approval. Form 10-403(Revised 10 2012 Submit Form an ttachments in Duplicate VTL- 7/z? /� ORIGINAL RBDMSJ r., - ' 7015 Well: 1Q-26, Oil Production Well, Kuparuk Field Sundry Purpose: Squeeze/plugs to control fluid (and rock) movement in zone Background: This well began producing rocks on 11/24/2014 and has been SI since that time. Subsequently, the well was bailed to refusal at 6267' (in the tubing, 95' above the tail). Geologists have identified the rock source as A-Sand. The C4-Sand is expected to provide the majority of the remaining oil production with approximately 200 BOPD anticipated./This work will provide verification of A/C splits and rock source, and A-Sand production could potentially be returned in the future. Procedure Outline • Utilizing coil tubing, fill cleanout into the 5 '/2°casing down to an interval between the A- Sand and C-Sand (see attached schematic) o Cleanout target depth is approximately 6650' RKB • Set cement plug (-50')to isolate A-Sand rock production o Note, if cleanout depth cannot be achieved, the cement plug may be set higher and could potentially cover the Cl-Sand perforations • Obtain caliper from top of cement to above C4-Sand perforations • Obtain C-Sand pressure • Return well to production KUP 1Q-26 ConocoPhillips =/ Well Attributes Max Angle&MD To - Inc. Wellbore APWWI Field Name Well Status Incl(') MD(RKB) Act Btm IRKB) Alaska, 500292259000 KUPARUK RIVER UNIT PROD 31.89 4,231.66 7,010.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date ••• Well Con(q -10-26,5123120138:47:46 AM SSSV:NIPPLE 25 8/14/2012 Last WO: 9/23/1995 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6,677.0 1/4/2011 Rev Reason:WELL REVIEW osborl 5/23/2013 Casing Strings ICasing Description String O... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt..String... String Top Thrd CONDUCTOR 16 15.062 40.9 121.0 121.0 62.50 H-40 WELDED HANGER.36 Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String W0..String...String Top Thrd LLLL����r SURFACE _ 7 5/8 6.875 _ 40.9 3,809.2 3,715.6 _ 29.70 L-80 LTC Casing Description String 0... String ID...Top IRKB) Set Depth(f...Set Depth(ND)...String Wt..String... String Top Thrd iii PRODUCTION 51/2 4.950 33.3 6,992.8 6,533.4 15.50 L-80 LTC-MOD Tubing Strings Tubing Description String 0... String ID...Top(kKB) Set Depth(f...Set Depth(ND)...String Wt..String... String Top Thrd CONDUCTOR. TUBING 3.5x2.875 3 1/2 2.992 36.3 6,362.8 5,960.0 9.30 L-80 EUE8RDMOD 41-121 Completion Details { Top Depth NIPPLE.510 i (TVD) Top Incl Komi.- Top(RKB) 11 81 (') teem Description comment ID 6n) 36.3 36.3 1.15 HANGER FMC GEN IV TUBING HANGER 3.500 --__ 509.7 509.7 1.26 NIPPLE CAMCO DS LANDING NIPPLE;2.856"NO GO 2.812" 2.812 6,341.7 5,940.8 24.32 PACKER BAKER SAB-3 PERMANENT PACKER w/K-22 ANCHOR SEAL 3.000 GAS LIFT, 6,352.9 5,951.0 24.35 NIPPLE CAMCO XN NIPPLE(2.31"x 2.25"NO GO) 2.250 Z490 6,362.1 5,959.4 24.38 SOS BAKER SHEAR OUT SUB 2.441 IL Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 41111Top Depth (ND) Top Incl Top(RKB) IRKB) (') Description Comment _ Run Date ID(in) 6,900.0 6,448.4 23.61 FISH GLV 1"GLV LOST IN CASING,EXACT DEPTH UNKNOWN 8/162004 0.000 Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(RKB)Btm(RKB) (RKB) (RKB) Zone Date (eh- Type Comment SURFACE, A 6,417.0 6,432.0 6,009.3 6,022.9 C-4,10-26 8/13/2005 6.0 APERF 2"PJ,60 deg phase,0 deg orient 41-3.509 6,417.0 6,432.0 6,009.3 6,022.9 C-4,10-26 1/6/2006 6.0 RPERF 2"HJ,60 deg.phase --' 6,445.0 6,467.0 6,034.7 6,054.7 C-4,C-3,1Q-26 8/13/2005 6.0 APERF 2"PJ,60 deg phase,0 deg orient 6,507.0 6,522.0 6,091.0 6,104.6-C-1,10-26 8/13/2005 6.0 APERF 2"PJ,60 deg phase,0 deg orient 0AS LIFT._ ( 6,696.0 6,726.0 6,261.4 6,288.9 A-3,1Q-26 1/21/1996 8.0 IPERF 180 deg.phasing;Oriented(+/-)F/ 4.2 i0 Btm Side;2 1/8"EnerJet Stimulations&Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (N0) (TVD) L (RKB) (RKB) (RKB) (1tKB) Type Date Comment GAS LIFT. {€€� 6,417.0 6,432.0 6,009.3 6,022.9 C-SAND FRAC 1/7/2006 PLACED 155M#1620 CARBOLITE IN THE 5549 C FORMATION,9 PPA ON PERFS,100%OF CCC_._ DESIGN.SAW TSO 955 MINUTES INTO FRAC, WELL WAS PRESSURING UP AT END OF JOB. E--_3 FLUSHED TO COMPLETION. Notes:General&Safety t;,• " M Nr End Date Annotation 1/15/2010 NOTE:DRIFTED TBG w2.345"gauge to 6353'RKB GAS 6.2uF9]T, _ 10/13/2010 I NOTE:View Schematic w/Alaska Schematic9.0 PACKER.6.342 U NIPPLE.6.353 - I I� - SOS,6,362 - RPERF, 6,4178,432 APERF, 6,4178,432 C-SAND FRAC, {- 6.417 APERF, 6,4458,467 - APERF, 6.5078,522 ,.� Mandrel Details Top Depth Top Port S,,, (ND) Incl OD Valve Latch Sloe TRO Run IPERF. - N...Top(RKB) (RKB) (1 Make Model (In) Sery Type Type (in) (psi) Run Date Com... 6.696-6]26-_- - 1 2,489.7 2,487.0 7.60 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,273.0 2/3/2012 2 4,250.4 4,092.3 31.88 CAMCO KBMM 1 GAS LIFT OV BK 0.250 0.0 2/3/2012 - 3 5,509.4 5,196.2 25.32 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 9/192011 FISH,6,900 - 4 6,297.3 5,900.3 24.18 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 9/20/2011 PRODUCTION, 338,%3 j T07,010 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /¢5'"/~.~¢~-- File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Dianna~athan Lowell Dat~7 Is~ [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ • • Page 1 of 1 Regg, James B (DOA) PTh 1S- t3 From: NSK Problem Well Supv [n1617 @conocophillips.com] I , t ° �UCG� z�� "�� Sent: Saturday, December 25, 2010 1:42 PM j To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 1Q -26 (PTD 195 -132) Report of failed TIFL Attachments: 1Q-26 schematic.pdf Tom, Jim, Guy ./ Kuparuk gas lifted producer 1Q-26 (PTD 195 -132) failed a diagnostic TIFL on 12/23/10. The well was SI prior to testing and the TIO was 2050/1925/25. A leaking GLV is suspected. Slickline will troubleshoot and repair if possible. Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 j [� F�' 1 ((( { j ! i`(l` WOWED W S.• !e W Z V Iti 12/28/2010 KRU 1Q-26 P13 195-132 12-25-10 TM Pressures Plot TAN ANNL ANNULUS PRESSURE TRENDS 500. . WELL NAME WLKRU1Q-26 3000. : 3000 ,_, 200 , . 3000. 2700i 3000. 3000. Illf3.. 2400 3000. 2100 I 410 1800 ---',-,_--- \ - -,----_____-____ ___________- - isoo 1200 — -,/ \ \ • 900 - 0 . 600 0. 0. 300 O. - ____________ 4 14.■ , i_ , - 9 . , ' 1 0. PLOT START TIME MINOR TIME PLOT. DURATION 26-SEP-10 13:41 MAJOR TIME WEEK *saitittiat00 HR525 13:41 PICK TIME: • ta' ' 11131111221113111 111111111111 RT • SC TAG MANE DESCRIPTION P-VALIIE LATEST RV WL1Q-26-CHOKE FLOW TUBING CHOKE ??????? IIIPREV WELL DRILLSITE WELL Mr SCRATCH 74 FLOW TUBING PRESSURE 7777777 lq 26 PM SCRATCH_74 FLOW TUBING TEMP 777'277? IIII NEXT WELL Fir AI-P105002-26 GL CASING PRESSURE 777777? Mir 7772777 ENTRY TYPE OPERATOR ilir 2772227 III OPERATOR VERIFIED inf SCRATCH 74 INNER ANNULUS PRES 7777777 Ill SYSTEM AUTO ENTRY Mr SCRATCH_74 OUTER ANNULUS PRES TM??? Mil BOTH • KUP • 1Q 26 Cv Ct ip5 , W A rltn,tel$ y v� :. = VIII r ,, I Ma Anarel& D TD 4 ( Wellbore APIIUWI Field Name W el l Status Incl C) MD (ftKB) Act Btm (ftKB) ry 500292259000 KUPARUK RIVER UNIT PROD 31.89 4,231.66 7,010.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date ... 9rIt *.. r °1012 atuaa SSSV: NIPPLE 120 8/6/2009 Last WO: 9/23/1995 LL✓' ., jhealat1F Aduffi' , ..' Annotation - De p th (RKB) End Date Annotation Last Mod By End Date Las�tt T{a SL .y M y' 6,703.0 1/30/2010 Rev Reason: GLV C /O, TAG Imosbor 2/1/2010 dititi = Strinq -.s _ _'$ t ? 4 . - i li d . -rs String OD String ID " Set Depth Set Depth (ND) String Wt String T CONDUCT1 Casing Description (in) (in) Top (RKB) (ftKB) (ftKB) (Ibs/It) Grade String Top lb"' OR, i CONDUCTOR 1 15. 0 . 0 121.0 121.0 62.50 H -00 121 SURFACE 75/8 6.151 0.0 3,809.0 3,715.4 29.70 L -80 P RODUCTION 51/2 4.767 0.0 6,993.0 6,533.6 15.50 L -80 NIPPLE,510 t bintt8 i ng'$, 0 V s h t r.:>a` ,'w , � , String OD String ID z Set Depth Set Depth (ND) Str ng Wt String V -a O Tubing Description (in) (In) Top (ftKB) (RKB) (ftKB) Ps/ft) Grade String Top Thrd TUBING 3 1/2 2.992 0.0 2,458.0 2,455.6 9.30 L -80 ABM EUE En au TUBING 2 7/8 2.441 2,458.0 2,528.0 2,525.0 6.50 L -80 ABM EUE TUBING 31/2 2.984 2,528.0 4,218.0 4,064,8 9.30 L -80 ABM EUE GAS LIFT, TUBING 27/8 2.441 4,218.0 4,288.0 4,124.2 6.50 L -80 ABM EUE 2,a90 >` TUBING 31/2 2.984 4,288.0 5,478.0 5,167.8 9.30 L-80 ABM EUE TUBING 27/8 2.441 5,478.0 5,548.0 5,239.9 6.50 L -80 ABM EUE TUBING 3 1/2 2.984 5,548.0 6,265.0 5,870.8 9.30 L -80 ABM EUE TUBING 2 7/8 2,441 6,265.0 6,363.0 y 5,960.2 6.50 L -80 ABM EUE SURFACE, Qth r 1.Ql'e All': J ewelry. 7u bin t R un Ot. R e t rieva b l e - , , , e tYm ' -7 = „h„,- ry=,: . +r ` i r,., ' 4r , 3.609 Top Depth ' Top (ftKB) (RKB) ( °) Description Comment Run Dete ID (in) I 510 510.0 1.26 NIPPLE Camco 'DS' landing Nipple; 2.856" NO GO 2.812" 12/25/1995 2.812 2,490 2,487.3 7.60 GAS LIFT CAMCO/KBMM /1 /GLV /BK/.156 /1254 / Comment: STA 1 1/31/2010 2.371 GAS LIFT, 4,250 4,091.9 31.88 GAS LIFT CAMCO /KBMM /1 /GLV /BK/.156 /1267 /Comment: STA2 1/31/2010 2.371 4'250 5,509 5,195.8 25.32 GAS LIFT CAMCO/KBMM /1 /GLV /BK/.188/1308/ Comment: STA 3 1/31/2010 2.371 6,297 5,900.0 24.18 GAS LIFT CAMCO/KBMM /1 /OVBK/.25/ /Comment: STA4 1/31/2010 2.371 es 6,342 5,941.1 24.32 PACKER Baker 'SABL -3' PACKER w/ K -22 Anchor Seal 12/25/1995 3.000 6,353 5,951.1 24.35 NIPPLE Camco 'XN' Nipple NO GO 12/25/1995 2.250 6,362 5,959.3 24.38 SOS Baker 12/25/1995 2.441 6,363 5,960.2 24.38 TTL ELMD TTL@ 6365' ON SWS PERF 1/6/06 12/25/1995 2.441 6,900 6,448.4 23.61 FISH GLV 1" GLV LOST IN CASING, EXACT DEPTH UNKNOWN 8/16/2004 GAS LIFT. -�. d ` :, r ii - 4 ' t Twi 5,509 Nt_ f erf©rattc +_ . o?tS 1 ; g, o- ,. 1iti'} , s - Shot Top (ND) Btm (ND) Dens Top (RKB) Btm (RKB) (RKB) (RKB) Zone Date (sh. Type Comment 6,417 6,432 6,009.3 6,022.9 C-4, 1Q-26 8/13/2005 6.0 APERF 2" PJ, 60 deg phase, 0 deg orient 6,417 6,432 6,009.3 6,022.9 C-4, 1Q -26 1/6/2006 6.0 RPERF 2" HJ, 60 deg. phase 6,445 6,467 6,034.7 6,054.7 C -4, C -3, 1Q-26 8/13/2005 6.0 APERF 2" PJ, 60 deg phase, 0 deg orient 6,507 6,522 6,091.0 6,104.6 C -1, 10 -26 8/13/2005 6.0 APERF 2" PJ, 60 deg phase, 0 deg orient GAS 6LI2xFT, 7 6 6,726 6,261.4 6,288.9 A -3, 1Q -26 1/21/1996 8.0 IPERF 180 m deg. e; ph 2 asing 1/8 EnerJe Oriented t ( +/) F/ Bt Sid 5timu(atl ©ns'4'Treatments •'. Bottom ' `+ Min Top Mac Btm Top Depth Depth , , Depth Depth (ND) (ND) PACKER. 6.342 ,� (ftKB) (RKB) (ftKB) (RKB) Type Date Comment 6,417.0 6,432.0 6,009.3 6,022.9 C -SAND FRAC 1/7/2006 PLACED 155M # 16/20 CARBOLITE IN THE FORMATION, 9 PPA ON PERFS, 100% OF DESIGN. SAW TSO "55 MINUTES INTO FRAC, WELL WAS PRESSURING UP AT END OF JOB. NIPPLE, 6,353 FLUSHED TO COMPLETION. t+talii 03eneral' "d fY Via..... , . < ,i ' - End Data Annotation 1/15/2010 NOTE: DRIFTED TBG w12.345" gauge to 6353' RKB SOS, 6,362 TTL, 6,363 RPERF, 6,4176,432 APERF, 6,4176,432 g C-SAND FRAC, -.-k -- .. 6,417 -^. APERF, 6,445-,467 APERF, = - '•'_" -- 6,507 -6.522 - . '" IPRF, 6,6966 I FISH, 6,900 PRODUCTION. 6.993 TD, 7,010 STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS~N REPORT OF SUNDRY WELL OPERATIONS RECEIVED FEB 2 2 2010 1. Operations Performed: Abandon ]`~` Repair w ell ~""', Plug Pbrforations ~' Stimulate Gorrxnlsf+l AI8$I(8 ~~ ~8g EQ!!S . After Casin Pull Tubin Perforate New Pbol Waiver g 9 ~ ~ ~~ Time Extension I~ hOta{}9 " C Change Approved Program ""` Operat. Shutdown ~ " Perforate ~ Re-enter uspended Well 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development - Exploratory "'"" 195-132 3. Address: Stratigraphic ~ Service ]® .API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22590-00 7. Prop~ty Designation: `` 8. Well Name and Natnber: \ ADL 25641 1 Q-26 ..Field/Pool(s): Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7010 feet Plugs (measured) None true vertical 6549 feet Junk (measured) 6900 Effective Depth measured 6904' feet Packer (measured) 6342 true vertical 6452' feet (true verucal) 5941 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 121 121' SURFACE 3768' 7.625 3809 3715' PRODUCTION 6952' 5.5 6993 6534' w~ ;s"~'"~ ~ ~ ' ' ' ' Perforation depth: Measured depth: 641 T-6432 -6726 ' , 6445 -6467, 6507-6522 , 6696 True Vertical Depth: 6009'-6023', 6035'-6055', 6091'-6105', 6261'-6289' Tubing (size, grade, MD, and TVD) 3.5 x 2.875, L-80, 6363 MD, 5960 TVD Packers 8~ SSSV (type, MD, and TVD) NIPPLE - CAMCO'DS' LANDING NIPPLE; 2.856" NO GO 2.812" @ 510 MD and 510 TVD PACKER -BAKER 'BABE-3' PACKER W/ K-22 ANCHOR SEAL @ 6342 MD and 5941 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 6417'-6726' Treatment descriptions including volumes used and final pressure: 680 bblS Of Seawater 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 36 495 299 -- 193 Subsequent to operation 75 1045 990 -- 169 13. Attachments Well Class after proposed work: Copies of Logs and Surveys run Exploratory "' Development Service Well Status after work: Oil Gas WDSPL Daily Report of Well Operations XXX GSTOR WAG GASINJ WINJ SPLUG 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: none contact John Peirce ~ 265-6471 Printed Name John Peirce Title Wells Engineer Signature ~ ~ Phone: 265-6471 Date ~~ Z - -' D i ~~~ Form 10-404 Revised 7/2009 RBDMS FEB 2 2 210 ~~~ Submit Original -Only r~ 1Q-26 Well Events Summary DATE SUMMARY 1/15/10 GAUGE TBG 2.345" TO 6353' R ,SET 2.31" CAT SV @ SAME. SET 2.25" A CATCHER @ 6353' RKB. IN PROGRESS. 1/16/10 PULLED OV @ 4250' RKB & GLV @ 2490' RKB, SET DV @ 2490' RKB, UNABLE TO SET DV @ 4250' RKB, DROPPED AND RECOVERED DV FROM 4250' RKB IN CATCHER, RERAN CATCHER. IN PROGRESS. 1/17/10 SET DV @ 4250' RKB, TESTED TBG STRING; GOOD, PULLED DV @ 5509' RKB, CIRC. 114 BBLS DIESEL DN TBG UP IA TO PROD. PERFORMED CMITIA TO 2000 PSI, GOOD. SET DV @ 5509' RKB; UNABLE TO GET PASSING TEST TO 2000 PSI. IN PROGRESS. 1/18/10 MIT-T 2000 PSI GOOD. PULLED CATCHER & 2.31" CAT SV @ 6353' RKB. READY FOR HPBD. 1/25/10 PUMPED HPBD. INJECTED A TOTAL OF 680 BBL OF 50 DEG SEAWATER AT A FINAL INJECTION RATE OF 13.3 BPM @ 2200 PSI. FREEZE PROTECT WELL WITH 20 BBL OF METHANOL. ~C~f1C~C)~1i~~1~S ~~~ i .+. ~rskn It i;. ... _y7~lc 6}y ,7g~g6, g(trzo^,o~ziixnr.l _.- - - S4xmatic-Actual CONDUCTOR. l I 721 NIPPLE, 510 , GAS LIFE SURFACE._ 3,609 GAS LIFT, 4,250 BAS LIFE, 5,509 PACKER. 6,342 NIPPLE, 6,353 sos. c.~c. TTL, 6.363 - RPERF, _ 6.67 7-6,432 RPERF. 6417-6,032 C-SAND FRAC. 6,41] RPERF, 6,d45-6.46] APERF, 6.50]-6.522 (PERF, _ _ 6,696-6,726 FISH, 6,900 -- PRODUCTION. _ 6,993 \ TD. ],010 KUP Attributes m _ Max / e APINWI Fieltl Name Well Status Inc! (°) 292259000 KUPARUK I.IVI F: UNF( PROD ~I 31.89 nt IH2S (ppml (Date Annotation' End Date NIPPLE i 120 8/6/2009 Last WO: I io Depth (flKB) 'End Date (Annotation n g JI_M 6.703.0 ~ 773072010 Rev Reason: GLV C/O. TAG In Sirinnc 1 Q-26 9!23/7995 String OD String ID Set Depth Set Depth (ND) 'I-String Nit String j Casing D escription (in) tin) Top (flKB) (flKB) (flKB) ! (Ibslft) Grade ~ Siring TOp Thrd CONDUC TOR 16 15.0 fit 0.0 121.0 121.01 6250!H-00 SURFACE 75/8 61'51 0.0 3,8090 3,7154' 29.70~L-80 'I PRODUCTION ' 51/2 4 67 00 6,993.0 6,533.6' 15.50'L-80 Tubing Strings -. I __ _ Skiing OD viny ID Set Depth Set Depth (ND) ', String Wt String '' Tubing D escription (inl lint Top (ftK6) (flKB) (flKB) I (Ibs/H) Gratle String Top Thrd TUBING 31i2 2952 0.0 2,458.0 24556 9.30 L-SO ABM EUE TUBING 27/8 2941 24580 2,528.0 2,525.0 6.50 L-80 ABM EUE TUBING 3 12 2984 2,528.0 4,218 0 4,1764 8 9.30 L-80 ABM EUE TUBING 2 7/8 2941 4,218.0 4,288.0 4,124.2 6.50 L-80 ABM EUE TUBING 3 1/2 2984 - 4,288 0 5,478.0 5,167.8 9.30 L-80 ABM EUE TUBING 2 7/8 2.441 5,478 0 5,548.0 5,239.9 6.50 L-80 ABM EUE TUBING 3 i/2 ~ 2984 5,548.0 6,265.0 5,870.8 9.30 L-80 ABM EUE TUBING 2 718 -- "L441 fi,265.0 6,363.0 5,960.2 6.50 L-80 ABM EUE Other I n Hole (All Jew glry; Tubin Run & Retrievable Fish, etc.) Top Depth _ _ , (TVD) Top Inc! ' Top (NKB) (ryK81 (°) Description Comment Run Date ID (in) 510 510.0 1.2fi NIPPLE Camco'DS' landing Nipple; 2.856" NO GO 2.812" 12/25/1995 2.812 2,490 2,487.3 7.60 GAS LIFT CAMCOlKBMM/1/GLV/BK/.15617254/ Comment: STA 1 1/31/2010 12.371 4,250 4,091.9 31.88 GAS LIFT CAMCO/KBMM/71GLV/BK/.1 56 /1 26 71 Comment: STA 2 1/31!2010 ~ 2-371 5,509 5,195.57 25.32 GAS UIF' CAMCOIKBMM/1/GLV/BK/.1 88 /1 30 81 Comment: STA3 1!31/2070 ',2.371 6,297 5,90U.O 24.18 GAS LIFT ICAMCO/KBMM/1/OV/BK/-25//Comment: STA4 1/31/2010 12.371 6,342 5,941.1 24.32 PACKER Baker'SABL-3' PACKER wl K-22 Anchor Seal 72/25/1995 3.000 6,353 5,951.7 24.35 NIPPLE ~ICamco'XN' Nipple NO GO 12125/1995 2.250 6,362 5,959.3 24.38 SOS IlBaker 12/25/1995 2.441 6,363 5 960.2 24.38' 1 f L ELMD TTL@ 6365' ON SWS PERF 1/6/06 12!25/1995 2.441 fi,90C1 fi 448.4 23.61 ~~ RSFI GLV 1" GLV LOST IN CASING. EXACT DEPTH UNKNOWN 8/16/2004 Ipertora _ - tions 8y - _ i. Slots --_- I _- - I I _. - --- ~ Shot- Top (TVD) Bim TVDi Dens i, (Top (flKB) Btm (kK6) (flKB) IIIKBI Zone Date (ski... Type I Comment I 6,417 6,432 6,009.3 «;,,0229 C-0, 10-268/13/2005 6.0 RPERF 2" PJ, 60 deg phase, 0 deg orient 6,477 6,432 6,009.3 6.022.9 C-0, 10-26 ~ 1/612006 G.0 RPERF 2" HJ, 60 deg. phase 6,445 6,467 6,034.7 6,0547 C-0, C-3, 70-26 75/13/2005 6.0 RPERF 2" PJ, 60 deg phase, 0 deg orient 6,507 6,522 6,091.0 r?.,104 C-1, 10-26 '8/7312005 6-0 APERF 2" PJ, 60 deg phase, D deg orient I' 6,696 6.726 6,261.4 ~.2887l3 A-3, 10-26.1/21/1996 8.0 (PERF 180 deg. phasing; Oriented (+/_~ F! I ' .. Btm Side; 2 1/8" EnerJet ~ , lStimula tion§ & Treatme _ nts 6onom ~ _ -,` - Min Top Maz Btrn Top Depth Depth Depth Depth (ND) (TVD) (ft KBJ (flKB) (ftKe) INKB) Type Data ~ Comment 6,417.0 6,432.0 6,009.3 6, U229 CSAND FRAC 1/7/2006 PLACED 155M # 16!20 CARBOLITE IN THE I I FORMATION, 9 PPA ON PERFS, 700 % OF DESIGN. SAW TSO'S5 MINUTES INTO FRAC, WELL WAS PRESSURING UP AT END OF JOB. 1 FLUSHED TO COMPLETION. Notes: General 8 Safet Endoate - Annotation _ 1/15/2010 NO TE: DRIFTED TBG w2.345" gauge to 6353' RKB C7 ~/ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ;~ ; _r~ ~~5~ ~32- Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 29, 2008 and the corrosion inhibitor/sealant was pumped October 17, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~i'~f/~/ ; ~ ~~~~ IVC~ ~ 2(10$ ~ G,~~, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • u ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10122/2008 r; Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-18 190-153 21' 2.80 27" 8/29/2008 6.80 10/17/2008 1 Q-21 195-133 5" NA 5" NA 1.00 10/17/2008 1 Q-22 195-140 5" NA 5" NA 1.00 10/17/2008 1 Q-26 195-132 8" NA 8" NA 1.00 10/17/2008 08/09/06 Schlumbel'gel' RECEIVED NO. 3910 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth AUG 1 0 2006 ,~ r;n"---'f\ ;SCAN~'.AED f\UG 1 I,i:. ¿dUG .1J~:î OH 8, Gas Cons. Commission Anchorage Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 /". - <Z -\ t1'5 - !vd Field: Kuparuk Well Job # BL Log Description Color CD Date 1 J-127 11216302 US IT 06/05/06 1 1 D-119 11249924 INJECTION PROFILE 07/05/06 1 2L-321 11235382 LDL 07/24/06 1 2V-13 11235385 SBHP SURVEY 07/26/06 1 1Q-13 11249936 INJECTION PROFILE 08/02/06 1 1 Q-26 11249937 PROD PROFILE W/DEFT 08/03/06 1 1R-14 11235386 PROD PROFILE W/DEFT 08/03/06 1 1G-09 11249938 INJECTION PROFILE 08/04/06 1 3N-16 11235389 SBHP SURVEY 08/05/06 1 1 E-112 11285935 MEM INJECTION PROFILE 08/05/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . RECEIVED 05/18/06 MAY 2 4 2006 Scbbnbel'gel' NO. 3808 ~ C1f & Gas Gens. CommÍ$$ÍÇn A~19ge Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth !"\ r~, 9f\nß \i v l-'~v' Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 'V Field, Kuparuk ,0. 6, \"ëJ Well Color Job # Log Description Date BL CD 1 G-01 (REDO) 11213744 INJECTION PROFILE ì/¡Jd -ì3ò 05/03/06 1 1 Q-26 11258706 PRODUCTION LOG WIDEFT ¡c1 A\-I ~d 05/06/06 1 1A-03 11258708 PRODUCTION LOG W/DEFT , 'Ö" I - 0 ~11" 05/07/06 1 1Y-15A 11216294 PRODUCTION LOG W/DEFT Ic;?( _ I <'.<C. 05/08/06 1 1 A-02 11258709 SBHP SURVEY (' '! <: I "if I - o-=t- \ 05/09/06 1 1 R-13 11258711 INJECTION PROFILE I' ~ è. l'i<'~- ,,,-[-, 05/10/06 1 2M-34 11216296 INJECTION PROFILE tfì: ~ \ C¡ (;~ - iY~ 05/11/06 1 2F-03 11216298 SBHP SURVEY " ~r· l';"~ - i~~ 05/14/06 1 2F-14 11216299 SBHP SURVEY U"¡-i' 17I-~--'~ 05/14/06 1 1A-06 11258712 INJECTION PROFILE ~) I Q.. 141_ liL 05/14/06 1 3Q-11 11216301 LDL t'tG -/"tr7r 05/16/06 1 1J-184 11216297 USIT rj ~(' ;::)('(- n¿¡¿/ 05/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. L!_ffi- ~/6>~(o{, 9 e e e ConocóP'hillips e Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 February 3, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 '.' '. ..u..n::n; r:t:'P n 'l 2UGb ~Ç~D~n~¡¡;w~ t· ~~I.) , Subject: Report of Sundry Well Operations for 10-26 (195-132) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation and stimulation operations on the Kuparuk well 1 0-26. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M{¡iioo~ Wells Group Team Leader CPAI Drilling and Wells MM/skad e e Kt:vt:1 V....u FEB 0 7 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate [] Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate [] Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [] Exploratory D 195-1321 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22590-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 53' 1 Q-26 8. Property Designation: 10. Field/Pool(s): ADL 25641, ALK 2572 Kuparuk River Field I Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7010' feet true vertical 6549' feet Plugs (measured) Effective Depth measured 6699' feet Junk (measured) 6400' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 3768' 7-5/8" 3809' 3715' PROD. CASING 6952' 5-1/2" 6993' 6534' Perforation depth: Measured depth: 6417'-6432',6445'-6467',6507'-6522',6696'-6726' true vertical depth: 6009'-6023',6035'-6055',6091'-6105',6263'-6290' Tubing (size, grade, and measured depth) 3.5" 12-7/8", L-80, 6363' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'SABL-3' WI K-22 ANCHOR SEAL pkr= 6342' Cameo 'OS' nipple @ 510' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none RBDMS 8FL FEB 0 7 ZOD6 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 205 790 1310 -- 208 Subsequent to operation 1057 1510 1987 -- 221 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development [] Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil[] GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Leader :J/t.A Signature u¿ J//~, Phone Date '~() ç:; ...11\1 Prenared bv Sharon Alfsun-Drake 263-4612 ~ o R \ b \ \~ f-\ L . . Form 10-404 Revised 04/2004 Submit Original Only e 1 Q-26 Well Events Summary e Dttmstart Summaryops 01/01/06 11 :00 AM DRIFT TUBING W/2.20" SWAGE TO 6698' RKB, DRIFT TUBING W/20' X 2 1/8" WT BAR TO 6698' RKB, PULL DMY FROM STA- 4 @ 6297' RKB IN PROGRESS 01/02/0606:00 AM PULL DMY @ 6297' RKB (OPEN POCKET), PULL OV @ 5509', PULL GLV's @ 4250' & 2490' RKB, SET DMY's @ STA- 1,2 & 3, SET 2.313" CAT STANDING VALVE @ 6353' RKB IN PROGRESS 01/03/0606:00 AM DISPLACED IA WITH 100 BBL SW & 50 BBL DSL. SET DV @6297' RKB. TEST TBG 3500 PSI, GOOD; IA TO 3500 PSI, GOOD. PULLED CAT SV @ 6353' RKB. 01/05/0606:00 AM PUMPED 34 BBLS OF 2.55 PPA SLURRY OF 20/40 SAND (3800#'s) IN 5-1/2" CASING. SPOTTED IN WITH 1.95" SAND DUMP NZL FROM 6708' RKB TO TOP OF SAND TAG DEPTH OF 6525' RKB. COORELATED DEPTH USING REAL TIME CCL FROM I-COIL DATA. FREEZE PROTECTED WITH DIESEL. 01/06/0607:15 AM PERFORATED 6417 TO 6432 FT WITH A 2" HYPERJET HSD, 6 SPF, 60 DEG PHASING USING RDX CHRAGES, 6.5 GR RDX, 9.5" PENETRATION, 0.33" ENTRANCE HOLE. CCL TO TS = 8.2 FT, STOP DEPTH 6408.8 FT. TAGGED BOTTOM AT 6520 FT. 01/07/0607:00 AM PUMPED C SAND FRAC. PLACED 155M # 16/20 CARBO LITE IN THE FORMATION, 9 PPA ON PERFS, 100% OF DESIGN. SAWTSO -55 MINUTES INTO FRAC, WELL WAS PRESSURING UP AT END OF JOB. FLUSHED TO COMPLETION. 01/08/0608:00 AM PERFORMED A POST-FRAC CLEAN OUT TO 6780' CTD. VERY STRONG RETURNS TO SURFACE THROUGHOUT THE JOB - PUMPED SEAWATER, DIESEL, DIESEL GEL. FREEZE PROTECTED WITH DIESEL. 01/09/0606:00 AM TAGGED @ 6760' RKB, EST. 34' RATHOLE. PULLED DVs FROM STA# 1, 2,3. SET OV IN STA# 3. ATTEMPTED SET GLVs IN STA# 1, 2. IN PROGRESS. 01/10/0606:00 AM TAGGED LATCH @ 2490' RKB, ENSURED GLV SET. SET GLV @ 4250' RKB. TAGGED & CONFIRMED SET. BLED IA DOWN 300 PSI, HOLDING. e ConocoPhillips Ala'a, Inc. 1 Q-26 NIP (510-511. 00:3.500) TUBING (0-2458. 00:3.500. 10:2.992) Gas Lift MandrelNalve 1 (2490-2491, TUBING· (2528-4218, 00:3.500, 102.984) Gas Lift MandrelNalve 2 (4250-4251, TUBING (4288-5478. 00:3.500. 10:2.984) Gas Lift MandrelNalve 3 (5509-5510, TUBING (5548-6265. 00:3.500, 10:2.984) PKR (6342-6343. 00:4.766) NIP (6353-6354. 00:2.875) TUBING (6265-6363, 00:2.875, 10:2.441 ) SOS (6362-6363, 00:2.875) Perf (6417-6432) Perf (6445-6467) Perf (6507-6522) Perf (6696-6726) 6445 - 6467 6035 - 6055 C-4,C-3 22 -, 6507 - 6522 6091 - 6105 C-1 15 ~:\ . ,,'. 6696 - 6726 6263 - 6290 A-3 30 ~ ~ _f. ~~. . . . .i ~~ ~ Q t - ¡---- - f-- - f-- = f= - ¡---- - ¡---- - f-- = f= - f-- - f-- = f= - f-- - ¡---- - f-- - f-- KRU '0-26 API: 1500292259000 SSSV Type: NIPPLE Anç¡le @ TS: 25 deç¡ @_~~1.!5__ Angle @ TD: 24 deg @ 7010 Well Type: I P80D _ _ _ __ _____ Orig,9/23/1995 Completion: Last W/O: Ref LOQ Date: TD: 7010 ftKB Max Hole Anç¡le: 32 deç¡ @ 4232 Rev Reason: TAG FILL Last Update: 12/3/2005 Annular Fluid: Reference Loç¡: Last Taa: 6699 ~ª~nªç¡ Date: 11/20/2005 ~gJ5.trinQ - ALL STRINGS Description Size Top Bottom ï.-Vi5----~ Wt CONDUCTOR 16.000 0 121 I 121 62.50 SUR. CASING 7.625 0 3809 I 3715 29.70 PROD. CASING _____ ____?,!?QQ__ __ ____.__º______ 6993 1 6534 15.50 TubinQ StrinQ - TUBING One Full)_()l~!.ºL?]I~'~Tº_9...QD each side of GLM's Size Top Bottom TVD· Wt ! Grade 3.500 0 2458 2455 9.30 L-80 2.875 2458 2528 2525 6.50 L-80 3.500 2528 4218 4065 9.30 L-80 2.875 4218 4288 4124 6.50 L-80 3.500 4288 5478 5168 9.30 L-80 2.875 5478 5548 5231 6.50 L-80 3.500 5548 6265 5871 9.30 L-80 2.875 6265 ----.!ì}§~___ 5960 6.50 L-80 Perforations Summary Interval TVD 6417 - 6432 6009 - 6023 ------ , , Grade H-40 [ L-80 I L-80 1 Thread ._"'"_._-- Thread ABM EUE ABM EUE ABM EUE ABM EUE ABM EUE ABM EUE ABM EUE ABM EUE ---.--...-..---- .--.-....... ...-".- '"P - ___._..._.. .__ _.___ Zone C-4 Date Type Comment 8/13/2005 APERF 2" PJ, 60 deg phase, 0 deg orient 8/13/2005 APERF 2" PJ, 60 deg phase, 0 deg orient 8/13/2005 APERF 2" PJ, 60 deg phase, 0 deg orient 1/21/1996 IPERF 180 deg. phasing; Oriented (+1-) FI Btm Side; 2 1/8" EnerJet Status Ft : SPF 15 6 6 6 8 'Gas· üftMandrelslValves St MD TVD Man! Man Type V Mfr V Type V OD Latch Mfr 1 2490 2487 Camco KBMM 2 4250 4092 Camco KBMM 3 5509 5196 Camco KBMM 4 6297 5900 Camco KBMM I~thi~ [plug~:~_q~ip,_,~_~~s,t~jEWELRY Depth TVD Type ' Description 510 510-- NIP Cameo 'DS' landina Nipple; 2.856" NO GO 2.812" 6342 5941 PKR Baker'SABL-3' wI K-22 Anchor Seal 6353 5951 NIP Camco 'XN' Nipple NO GO 6362 5959 SOS Baker 6363 5960 TTL L"":¡,,, ""'öL/::APAii Depth 1 Description 6400 IGLV u________ .... .-..-.-----..--- ----.- Port TRO Date i Vlv Run Cmnt 0.156 1283 8/14/2004 0.188 1327 8/16/2004 0.250 0 8/14/2004 0.000 0 8/14/2004 GLV GLV OV DMY 1.0 1.0 1.0 1.0 BK BK BK BK ··__······_7__ . .-----.. ID 2.812 3.000 2.250 2.441 2.441 . .- -- -.--- - . I Comment 11" GLV LOST IN CASING, EXACT DEPTH UNKNOWN 10/31/05 Schlumbepgep NO. 3513 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 SCANNED NOV 2 3 2005 Attn: Helen Warman A TTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk "- Well Job# Log Description Date BL Color CD 1R-16 11015756 PRODUCTION PROFILE 10/24/05 1 2X-10 11015758 PRODUCTION PROFILE 10/26/05 1 1D-128 11015759 INJECTION PROFILE 10/27/05 1 3J-06 11072927 SBHP SURVEY 10/30/05 1 3J-07 A 11072926 SBHP SURVEY 10/30/05 1 2Z-29 11072924 PRODUCTION PROFILE 10/28/05 1 1A-02 11022938 INJECTION PROFILE 10/18/05 1 ./ 1 Q-26 11022937 PRODUCTION PROFILE 10/17/05 1 1G-16 11015753 INJECTION PROFILE 10/21/05 1 2A-08 11015755 INJECTION PROFILE 10/23/05 1 2G-15 11072919 PRODUCTION PROFILE 10/23/05 1 2N-329 11022935 PRODUCTION PROFILE 10/15/05 1 2Z-07 11022936 PRODUCTION PROFILE 10/16/05 1 3G-02 11056697 PRODUCTION PROFILE 09/20/05 1 2B-03A 11015749 PRODUCTION PROFILE 10/05/05 1 3N-09 (REDO) 11015722 PRODUCTION PROFILE 08/29/05 1 ~ 2C-04 11022934 INJECTION PROFILE 10/14/05 1 '~M-07 (REDO) 11015737 INJECTION PROFILE 09/26/05 1 2A-01A 11072922 INJECTION PROFILE 10/26/05 1 1 R-1 0 11015757 INJECTION PROFILE 10/25/05 1 2Z-08 11072920 INJECTION PROFILE 10/24/05 1 1 E-170 11015750 USIT 10/19/05 1 1J-154 11022931 US IT 10/12/05 1 2F-03 11015763 INJECTION PROFILE 10/31/05 1 SIGNED: L~ OM DATE: )R t1J~" ^ (\\>- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. q-rc__~{ r ) ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 September 1, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED SEP 0 6 2005 Alaska Oil & Gas Cons. Commission tmrr.:horage Subject: Report of Sundry Well Operations for 1 Q-26 (195-132) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the Kuparuk well 1 Q-26. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, J/!-J 4~ Mike Mooney Wells Group Team leader CP AI Drilling and Wells SÇ^NNEf:~ SEP 0 iT 2005 M M/skad Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 41', Pad 53' 8. Property Designation: ADL 25641, ALK 2572 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casi ng Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: ') STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION SE REPORT OF SUNDRY WELL OPERATIONS P 0 6 2005 Stimulate 0 .Alaska Oil c&tt~9S ConU:;mmnissimi Waiver 0 Time EAlRohorag[] o ) Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Operat. ShutdownD Re-enter Suspended Well 5. Permit to Drill Number: 195-132 1 6. API Number: 50-029-22590-00 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Exploratory 0 o Service 9. Well Name and Number: 1 Q-26 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 7010' feet true vertical 6549' feet measured 6711' feet true vertical feet Length Size MD 80' 16" 121' 3768' 7-5/8" 3809' 6952' 5-112" 6993' Plugs (measured) Junk (measured) 6400' TVD Burst Collapse 121' 3715' 6534' Measured depth: 6417'-6432',6445'-6467',6507'-6522',6696'-6726' true vertical depth: 6009'-6023',6035'-6055',6091'-6105',6263'-6290' Tubing (size, grade, and measured depth) 3.5" 12-7/8", L-80, 6363' MD. RBDMS BFL 5EP 062005 Packers & SSSV (type & measured depth) pkr= BAKER 'SABL-3' WI K-22 ANCHOR SEAL pkr= 6342' Cameo 'OS' nipple @ 510' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure Prior to well operation 298 754 1112 210 Subsequent to operation 461 2960 1390 217 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAG 0 GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA it C.O. Exempt: Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney ¡¡¡-J- if 0Øt'~ Title Phone Wells Group Team Leader Date 1/2/{)~ Prepared b%h~ron Allsup-Drake 263-4612 ORIGINAL Form 10-404 Revised 04/2004 Submit Original Only ') ConocoPhillips AlasJa, Inc. NIP (510-511, 00:3.500) TUBING (0-2458, 00:3.500, 10:2.992) Gas Lift MandrelNalve 1 (2490-2491, TUBING (2528-4218, 00:3.500, 10:2.984) Gas Lift MandrelNalve 2 (4250-4251, TUBING (4288-5478, 00:3.500, 10:2.984) Gas Lift MandrelNalve 3 (5509-5510, TUBING (5548-6265, 00:3.500, 10:2.984) PKR (6342-6343, 00:4.766) NIP (6353-6354, 00:2.875) TUBING (6265-6363, 00:2.875, J 10:2.441 ) SOS (6362-6363, 00:2.875) Perf (6417 -6432) Perf (6445-6467) Perf (6507 -6522) Perf (6696-6726) KRU ~-26 API: 500292259000 SSSV Type: NIPPLE Well Type: PROD Orig 9/23/1995 Completion: Last W/O: Ref Log Date: TD: 7010 ftKB Max Hole Angle: 32 deg @ 4232 Angle @ TS: 25 deg @ 6415 Angle @ TD: 24 deg @ 7010 Annular Fluid: Reference Log: Last Tag: 6711 Last Tag Date: 81712005 Casing String - ALL STRINGS Description Size Top Bottom TVD Wt CONDUCTOR 16.000 0 121 121 62.50 SUR. CASING 7.625 0 3809 3715 29.70 PROD. CASING 5.500 0 6993 6534 15.50 Tubing String- TUBING (One Full Joint of 2 7/8" Tbgon each side of GLM's) Size Top Bottom TVD Wt Grade 3.500 0 2458 2455 9.30 L-80 2.875 2458 2528 2525 6.50 L-80 3.500 2528 4218 4065 9.30 L-80 2.875 4218 4288 4124 6.50 L-80 3.500 4288 5478 5168 9.30 L-80 2.875 5478 5548 5231 6.50 L-80 3.500 5548 6265 5871 9.30 L-80 2.875 6265 6363 5960 6.50 L-80 PérfÓrátiOhs SUm måfy Interval TVD 6417 - 6432 6009 - 6023 Rev Reason: PERFS Last Update: 8/22/2005 Date Type Comment 8/13/2005 APERF 2" PJ, 60 deg phase, 0 deg orient 8/13/2005 APERF 2" PJ, 60 deg phase, 0 deg orient 8/13/2005 APERF 2" PJ, 60 deg phase, 0 deg orient 1/21/1996 IPERF 180 deg. phasing; Oriented (+1-) FI Btm Side; 2 1/8" Ener Jet Zone C-4 Status Ft SPF 15 6 ,..~ 6445 - 6467 6035 - 6055 C-4,C-3 22 6 6507 - 6522 6091 - 6105 C-1 15 6 .! !s. I 6696 - 6726 6263 - 6290 A-3 30 8 *-~ - Port TRO Date Vlv Run Cmnt 0.156 1283 8/14/2004 0.188 1327 8/16/2004 0.250 0 8/14/2004 0.000 0 8/14/2004 ID 2.812 3.000 2.250 2.441 2.441 Gas Lift Mandrels/Valves St MD TVD Man Man Type V Mfr Mfr 1 2490 2487 Camco KBMM 2 4250 4092 Camco KBMM 3 5509 5196 Camco KBM M 4 6297 5900 Cameo KBMM 0ther.··.· :pIÜgS,åquiþ. ..etc;)·.·-JEWELRY Depth TVD Type 510 510 NIP 6342 5941 PKR 6353 5951 NIP 6362 5959 SOS 6363 5960 TTL Fish- FISH Depth I 6400 GLV V Type VOD Latch GLV 1.0 BK GLV 1.0 BK OV 1.0 BK DMY 1.0 BK Grade H-40 L-80 L-80 Thread Thread ABM EUE ABM EUE ABM EUE ABM EUE ABM EUE ABM EUE ABM EUE ABM EUE Description Cameo 'DS'landing Nipple; 2.856" NO GO 2.812" Baker'SABL-3' wI K-22 Anchor Seal Cameo 'XN' Nipple NO GO Ba ker Description I Comme~ 1" GLV LOST IN CASING, EXACT DEPTH UNKNOWN ) 1Q-26 Well Events Summary ) Date Summary 08/07/05 DRIFTED TBG W/10' X 2.125". TAGGED FILL @ 6711' RKB. EST 15' FILL. JOB COMPLETE. [Tag] 08/13/05 PERFORATION - 2.0" HMX 6SPF, 60 AVI PHA. / INTERVALS 6417'-6432', 6445'-6467',6507'-6522' / DID NOT TAG / TIE IN LOG: SLB, PERFORATION RECORD, 21-JAN-1996 [Perf] MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner DATE: May 17, 2001 THRU: Tom Maunder, P. i. Supervisor FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit lQ Pad May 17 ,.2001: i traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Bamdt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, the SSV on 1Q-05 would not pass the DP test. The valve was serviced & would not pass the re-test. Well 1Q-05 is shut in until repaired & re-tested. The AOGCC test report is attached for reference. I inspected 20 well houses on lQ Pad w/no problems witnessed. s,.U, MMARY: t witnessed SVS testing in Kuparuk River Field. 15 wells, 30 components tested. 1 failure witnessed. 3.33% failure rate. 20 well houses inspected. Attachments: SVS KRU lQ 5-17-01jc c,c; NON-CONFI,DENTIAL SVS KRU 1Q 5-17-0 ljc Alasl~a Oil and Gas Conservation Commis~.oa Safety Valve System Test Report Operator: _P,hillips Alaska Operator Rep: Ernie Barndt AOGCC Rep: John ,C ,,risp Submitted By: John Crisp Date: Field/Unk/Pad: ,up~,Riv. e.r ,Unit lQ Pad Separator psi: LPS ..... 85. HPS 5/17/01 . [ I [ I I I :- r[. ~: ! I~: . -. . I.. I l[ Ill I I. ~ !: ~ ~: :- ~SV:- ~ SS$~: '!,-~:-?ReteSt?~.. ~ Well,. ~ei::i~-:~:!~ Well Pe~it Separ Set ~ Test Test Test Date off, WAG, Gm J, Number Number PSI PSI T~p Code Code Code Passed G~ or CY~e ,,'iQ-02A195~b~0 .... ~Q-03 ~84:330 ' ~ ' ' 70 ' "6~'~ 'e .......... oI~ ~IQ-0~ 1842340 85 60 55 P ~ , , p ...... OIL lQ-05 ~842170 85 70 54 P 4 OIL] [,19-,06 , !842080 85 60 55 , P , P ....., OIL.., . ~Q-09 1841920 3750 2000 , 1900 P P ..... WAG . ~IQ-10 .,,1841980 ,. 85 . 70.. , 62 e .... .p ..... 0IL !Q- ~ ~ , ~,841990 .......... lQ-12 1841930 ., , ,, , , , , , , - i , , ,, :~q-~ ~85o~60 ........ 1Q-l,6 ,. 1850470 .... 85' 70 "'~ P .... P ...... oil 1Q-205 1951560 ,, 85 70 60 p P ...... 0I~ lQ-21 .,1951330 [ ........ 1Q-22 ,,.1951400 8'5 70 55 P e I. OIL i ,, , , , . ,, , - ,. ~. , , ,, 1Q-23 1951410 85 70 56 e P OIL 1,Q-26, 1951320 ", 85 ,.'. ,~0 52 , e" P ,,, ' ' , OIL 1Q-08 1970930 3750 2000 1850 e e WAG lQ-13 " 1850446 3750 ' 2000 1850 e 'P ....... WAG 1Q714 1850450 , 3750 2qbo ~850 e P "~AG 1Q-24 1951210 3750 2000 2100 P P WA~ ,,, , . , , ,. ,. ~ ~ , , , , , , Wells: 15 Components: 30 Failures: 1 Failure Rate: 3.33% Remarks: 1Q-05 was serviced & re-tested, re-test failed & well was shut in for repairs. RJF 1/16/01 Page 1 ofl SVS KRU lQ 5-17-01jc ARCO Alaska, Inc, Post Office Box ,u0360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 9, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular Injection during the first quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-315 25326 100 0 25426 See Note #1 below25426 2L-325 8397 100 0 8497 11883 20380 2N-321A 27507 100 0 27607 0 27607 3K-23 15 0 0 15 0 15 3K-25 4202 100 0 4302 0 4302 1C-15 16695 100 0 16795 0 16795 2L-313 8554 100 0 8654 0 8654 Note #1: Well # 2N-315. The previously reported volume of 220 barrels was pumped into this annulus during the drilling of the well. This was the volume required to flush and freeze protect the annulus during initial drilling operations, not a volume ~'disposal./luids injected prior to the receipt attthorization.i'br annular injection. Total Volumes into Annuli for which Injection Authorization Expired during the quarter Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus 1C-12 34995 100 0 35095 Open, Freeze Protected 1C-13 26800 I 100 0 26900 Open, Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO's, we would like to repeat and supplement information we provided with our letter of February 26,1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26th letter, and are only reported here again for the sake of clarity. ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company AFt3B-6003-C qS--I 3 7--- Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two Total Total h(1) Total h(2) Total h(3) Volume Current Status of Well Name ! Volume Volume Volume Injected Annulus I 16749 100 0 16849 Open, Freeze Protected 2A-22 ! 2F-19 ! 20725 100 0 20825 Open, Freeze Protected 3K-27 37173 100 0 37273 Open, Freeze Protected 3K-26Il 33970 100 0 34070 Open, Freeze Protected 1E-31 ] 33645 100 0 33745 Open, Freeze Protected 1E-32Il 45205 100 0 45305 Open, Freeze Protected i 6245 100 0 6345 Open, Freeze Protected 3Q-22 , 1Q-24 ! 23158 1 oo 0 23258 Open, Freeze Protected 1Q-26 i 25931 ] 100 0 26031 [ Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files ,/," !') .. D ,'" Z ',_ Y ".,,'t E l... L n..., ,::,. :; / ,:.': ,:.:, H H E N T S ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 28, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1Q-26 (Permit No. 95-132) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1Q-26. If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad RECEIVED 3 0 1 196 NasV, a 011 & Cas Cons. Commission Anchorage STATE OF ALASKA ALA$,,A OIL AND GAS CONSERVATION COMMI,.....!ON WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS E~ SUSPENDED [~ ABANDONED [] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-132 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22590 4 Location of well at surface 9 Unit or Lease Name 1547' FNL, 1313' FEL, Sec. 26, T12N, R9E, UM i"?{;; ;~:::. L:::;::~: ' !i.;,-' ~'.-",'(';;?.;~-;~::.Kuparuk River Unit At Total Depth At Top Producing Interval ! ~~,~_.ii }ii~(('~"~ i i!:} .. i~:i:~-.'.,: ......, .d:,,., ~ 10 Well Number1Q_26 . 11 Field and Pool 2431' FNL, 426' FWL, Sec. 25, T12N, R9E, UM ..... KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) ' ~"1': 8"Lease Designation and Serial No. / RKB 41' Pad 53' J ADL 25641 ALK 2572 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. J 15 Water Depth, if offshore 16 No. of Completions September 18, 1995 September 22, 1995 21-Jan-96 (perrd)I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 12o Depth where SSSV set I 21 Thickness of permafrost 7010' MD & 6549' TVD 6904'MD&6452'TVD YES xL~ NO ~I NA feetMDJ =1380'ss APPROX 22 Type Electric or Other Logs Run ARC5/GR, GR/CCL/CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE W'T GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 151.53# X-65 SURF. 121' 24" 175 sx AS I 7.625" 29.7# L-80 SURF. 3809' 9.875" 600 sx AS III Lead, 300 sx Class G Tail 5.5" 15.5# L-80 SURF. 6993' 6.75" 175 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD inlerval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" x 2-7/8" 6363' 6342' 6696-6726' MD 8 spf 6263'-6290' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6696'-6726' 158491 # w/1 l#ppa of #10/14 @ perfs (10000# of #20/40, 135101 # of #12/18, 13840# of #10/14), 151741 # in formation & 7200# in wellbore 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ¢ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) 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. RECEIVED 0 R I GI NA L Naska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARY, ERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6415' 6007' Bottom Kuparuk C 6522' 6105' Top Kuparuk A 6661' 6231' Bottom Kuparuk A 6800' 6357' 31. LIST OF A'I-I-ACHMENTS Daily Drillin~l History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. 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 10-407 2/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:lQ-26 RIG:NO RIG WELL ID: AK8325 AFC: AK8325 TYPE' -- STATE'ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: START COMP: BLOCK' FINAL' WI: 55% SECURITY'0 AFC EST/UL:$ 1090M/ API NUMBER' 50-029-22590-00 OM 09/19/95 ( 1) TD. 3148' (3148) SUPV' JT DAILY: 09/20/95 (2) TD' 3148' ( 0) SUPV:JT DAILY: 09/21/95 ( 3) TD' 4755' (1607) SUPV: JT DAILY: 09/22/95 ( 4) TD' 6788' (2033) SUPV'JT DAILY: 09/23/95 (5) TD: 7010' (222) SUPV:RLH DAILY: 09/24/95 ( 6) TD: 7010' ( 0) SUPV'RLH DAILY: MW- 10.0 PV/YP' 20/14 DRILLING Move rig from lQ-20. Drill from 121' to 3148'. $132,612 CUM: $132,612 ETD: $0 EFC' AP IWL: 9. 6 $1,222,612 MW: 10.0 PV/YP: 18/15 APIWL: 9.4 PERFORMING TOP JOB Drilled from 3148' to 3820'. Run casing. Cement. $148,806 CUM: $281,418 ETD: $0 EFC: $1,371,418 MW: 8.4 PV/YP: 3/ 2 APIWL: 20.0 DRILLING Test casing. Drill cement and 10' new formation. Drilled from 3830' to 4755'. $1~5,764 CUM: $407,182 ETD: $0 EFC' $1,497,182 MW: 11.0 DRILLING Drilled from 4755' to 6788'. $83,661 CUM: $490,843 ETD: PV/YP: 23/11 APIWL: 5.4 $0 EFC' $1,580,843 MW: 11.0 PV/YP: 24/12 APIWL: 5.0 RUNNING 5.5" CASING Directional drill 6.75" hole from 6788' to 7010' Run 5.5" casing. $98,840 CUM: $589,683 ETD: $0 EFC: $1,679,683 11.0 PV/YP: 24/12 APIWL: 5.0 Cement 5.5" casing. CIP at 1128 hfs protect annulus. $706,584 ETD: $0 EFC: $1,796,584 MW' RIG RELEASED Run casing to 6960' 9/23/95. Freeze $116,901 CUM' _e' 2/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 2 REMEDIAL AND COMPLETION OPERATIONS WELL'lQ-26 RIG:NO RIG WELL ID' AK8325 AFC' AK8325 TYPE' STATE:ALASKA AREA/CNTY' NORTH SLOPE EAST FIELD' KUPARUK RIVER UNIT SPUD' START COMP' BLOCK' FINAL: WI: 55% SECURITY:0 AFC EST/UL:$ 1090M/ OM API NUMBER: 50-029-22590-00 12/25/95 ( 7) TD: 7010' PB: 6904' SUPV:BP DAILY: 12/26/95 { 8) TD' 7010' PB' 6904' SUPV'BP DAILY: FUNCTION TESTING BOPS MW' 0.0 Move rig from 1Q-23 to 1Q-26. Accept rig 0400 hfs, 12/25/95. N/D tree, N/U BOPs. Function test BOPs. SW $15,902 CUM: $722,486 ETD: $0 EFC' $1,812,486 RIG RELEASED MW: 0.0 Pressure test casing to 3500 psi, OK. Run 2-7/8" x 3-1/2" completion. Pressure tubing to 2500 psi for 30 min to set packer and test tbg. Bleed tbg pressure to 500 psi and pressure annulus to 2500 psi for 15 min. Pressure tubing to 4000 psi to shear ball - no indication of shear-out. Bleed off tbg pressure and pressure up annulus to shear dump-kill valve. Sheared at 3200 psi. Freeze protect annulus. Test tree to 250/5000 psi, test packoff to 5000 psi. Secure well, RDMO. Rig released @ 0400, 12/26/95. $104,723 CUM: $827,209 ETD: $0 EFC: $1,917,209 End of WellSummary for Well:AK8325 .~CO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~. K1(1Q-26(W4-6)) WELL JOB SCOPE JOB NUMBER 1 Q-26 PERFORATE, PERF SUPPORT 1 231951859.4 UNIT NUMBER DATE 01/21/96 DAY 3 DAILY WORK PERF "A" SAND OPERATION COMPLETE ISUCCESSFUL IKEYPERSON YES YES SWS-WARNER · SUPERVISOR CHANEY DALLY SUMMARY "A" SAND PERF'D @ 6696' - 6726' W/30' OF 2-1/8" ENERJET GUNS- BIG HOLE CHGS-8 SPF. ORIENTATION IS SET AT +90 DEGREES AND -90 DEGREES FROM THE BTM SIDE OF HOLE, 180 DEGREE PHASING (TWO RUNS). ALL SHOTS FIRED AND WHTP INCREASED TO 100 PSI. TIME 16:30 19:00 LOG ENTRY MIRU SWS AND HELD SAFETY MTG(WENT OVER PSI RATING OF EQUIP. AND OTHER ACTIVITIES GOING ON THE PAD. ALSO 4 PEOPLE ON LOCATION/. PT'D TO 3500 PSI. RIH W/CCL, MPD, AND 30' OF 2-1/8" ENERJET GUNS- BIG HOLE CHGS - 4 SPF. ORIENTATION IS SET AT +90 DEGREES FROM THE BTM SIDE OF HOLE. DEPRESSURED TBG TO 0 PSI, TIED IN AND PERF'D @ 6696' - 6726'. POOH. NO PRESSURE CHANGE WHEN GUN FIRED. 21:00 ON SURFACE, ALL SHOTS FIRED. TBG. PSI INCREASED TO 100 PSI. 22:00 23:30 RIH W/CCL, MPD, AND 30' OF 2-1/8" ENERJET GUNS- BIG HOLE CHGS-4 SPF. ORIENTATION IS SET AT -90 DEGREES FROM THE BTM SIDE OF HOLE. TIED IN AND PERF'D ~ 6696'- 6726'. POOH. ON SURFACE, ALL SHOTS FIRED. 00:30 RDMO SWS, WELL SECURED AND NOTIFIED DSO OF STATUS. ~G~ NO, 1 . .. - ~AT£: ............... ~£~C"HU~ER ........ ~ ?r ..... ~-' - - ~ TI£IN POIHTiTIP) TRU£ U~RT IHC~IHATIOH AZIMUTH LATITUO£(H/-~ 121,00 121,00 0o00 0,00 0,00 MEASURED DEPTH ft !11o00 461,00 ~46.43 1764.44 2415,14 25!i,04 ~602,v~ 2695.93 27~9,3~ 2974,72 3067,!6 D~PTH f~ 0,0 12!,00 240.0 4~0,17 385,4 ~46,24 461,2 1207,41 456.8 465,1 1~5.6 ?3,9 93.4 92,5 3,27 !,25 4,~ !,34 -3,00 !,17 . 2412.26 32,I1 2508.18 ' 42,23 7.61 259~-,37 ' 53,61 7,65 2591,42 6~,t4 7,90 _ 27~,3.~J0 80,20 9.44 2875,I0 ---'97,'63 29~4,93 1I~,I0 14,6~ 3053.65 145,0~ AZZMUTH 354,14 175,42 1~7,6B 121,29 !0~,0~ N/-~ !2,53 -!,~ · -4~ ~ '47,7~ '4~.3! 119.47 -60.79 116,I5 -79,41 113,45 E/-W ,,~ 3,71 ~8.00 0.4~ 0,~5 1.10 ~.94 35,02 I?l,~ 0,14 13,48 47.20 163,41 2,03 23,53 52,2! 153.75 4,15 35,45 60,73 i44,2~ I.~0 47,1& 71.6~ 128,~0 2,35 3345.!3 3435,2~ 3528,3! 3738, Id 3954,31 423I,~6 277.4 4508-.&2 -277.0 43I!,~27' 842~I0 47~3,79 275,2 4547;80. 9~3,!6 .._. .... 5243.07 !$5.5 4955,5! 1193,~9 5521,92 278,9 5207,50 1313,I0 5794,83 ?,72.9 5450,47 '- '1~37,22 &072,57 27B,~ , 5698,03 I565,19 &352,5! 27~;9 5950°66: 1683,15 ·', _,;L._-C~: ." .-. 6'~ ~ 279,8 6204.72 1799.62 592!,71 289,~ 6468.27 !9!6,36 PRO~CT~D 90 TD 7010,00 ~,2 &5~9,17 .. 92,7 3310.40- 250,92 25°67 t14.49 90,[ 33?0,90-~ 29!,47 27,$2 H4,42 93,0 3472.72: 335.76 29.'04 I16;6! _ :-_-~_ ;,;r - _'; ' - . ._ . - : '_ -_ ~ . 216,1 3~40.00 55!.50 31.20 115,00 -t33.50 -150.30 ''~ ~0 ' ~ 17 _ 26,4~ 1!I.::"~ . - 25,40 ,~: !I7,i4 2445 123,30 23.M 23.6! '432,71 -4~0.56 '-512.!9 ,564,3~ '-622,91 · _ · !22.t4 =804,1S 123,~& -86~.74 !739.62 145,79 178.4~ 2i3,92 3~4,~5 485,i2 6:6,Y4 75Io2~ 1002.70 59,43 55,01 1~,65 1.65 74,6! !01,90 !32.93 2.99 93.61 I22,76 130,31 2,~3 !I7,24 I47.96 127,~9 3.65 125,20 3.74 17~,42 252,16 440,90 983,16 !!12.~1 "!iOq.~ 1313.22 1437,20 15~5,24 16~3.1~ i799,65 1918.48 I23,36 12I,k7 !20 ~" 119,26 118,48 I16,t! !!5,41 !15,45 115,6e I15,~5 !16,1I 116,54 11~.94 117,07 i~ 77 I~95.30 I408,67 I511,35 · :,-"10,27 2,73 1,84 2,39 1.72' 0,83 O 1.38 1,22 !,21 ARCO Alaska, inc. Date: December 26, 1995 Transmittal #: 9311 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. All items below include BOTH Blueline and Sepia. 2A-i 8 CBL 1 0/15/95 2T-32 CBL 10/19/95 2T-36 CBL 1 0/20/95 1 Q-26 CBL 1 0/24/95 1 Q-23 CBL 1 0/24/95 5800-6655 13130-13636 14990-15325 5900-6885 87OO-9866 Acknowledge' , Date' DISTRIBUTION: q~ [''' ~'~""- Sharon AIIsup-Drake DS Development ATO-1 205 Larry Grant (+sepia) AOGCC 3001 Porcupine Ddve Anchorage,-AK 99501 RFCEIVED Anchorage Erickson/Zuspan NSK Central Files NSK-bo× 69 ,',,~AR 2 9 '1996 ~aska Oil & Gas Cons, commission Anchorage ARCO Alaska, Inc. Date- December 26, 1995 Transmittal #: 9310 RETURN TO: ARCO Alaska, Inc. Attn.' Julie Nash Kuparuk Operations File Clerk ATO-1119 B' P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 'fj':~,(, 2T-27 CDR 04/17/95 REF #50-103-20217 r 2T-32 CDN 04/30/95 REF #50-103-20218-00 ,f,¢'-' w.. ~f ~2T-32 CDR 04/30/95 REF #50-103-20218-00 ,/I'-~-? 2T-30 CDR 05/12/95 REF #50-103-20219-00 5~ ~"'~'7--c'f. 2V-06 TDTP 06/11/95 REF #95219 ¢,F-~'~ 2T-31 CDR 0713/95 REF #50-103-20226-00 ~2T-36 CDR 07/25/95 REF #50-103-20228-00 >J-2T-36 ¢/~.~ ~ CDN 07/25/95 REF #50-103-20228-00 tF2T-38 CDR 08/03/95 REF #50-103-20229-00 ~'--I ~ % )._2T-38 CDN 08/03/95 REF #50-103-20229-00 ~F'-lo~ 2T-37 CDR 08/10/95 REF #50-103-20227-00 ~__~ 1Q-24 ARC5 Array Resistivity Comp. 08/30/95 4206-7270 ~_ ~3× 1 Q-26 ARC5 Array Resistivity Comp. 09/22/95 3820-7010 ~-~ ~ ~ 1 Q-23 ARC5 Array Resistivity Comp. 09/30/95 5156-9982 Acknowledged: DISTRIBUTION: Mr. Vernon E. Pringle jr. DeGioyler and MacNaughton One Energy Square Dallas, TX 75206 Erickson/Zuspan NSK Central Files NSK 69 Sharon AIIsup-Drake DS Development ATO - 1205 LarrYGrant .AOGCC"~. 3001 .Porcupine Ddve Anchorage, AK Date: RECEIVED DEC 2. 7 1995 &!aska 0il & G~s Cons. Commi~ion Anchor~tge Clifton Posey Geology ATO - 1251 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie ~NNO. 9894 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 I 1/1 7/95 LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 1Q-26 95360 ARC5 950922 I 1 I SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Commission ~KA OIL AND GAS CONSERVATION CO~*IISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 7, 1995 Mike Zanghi, Ddg Engr Supv ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99519-6612 Re: Kuparuk River Unit 1Q-26 ARCO Alaska Inc. Permit No 95-132 Surf Loc 1547'FNL, 1313'FEL, Sec. 26, T12N, R09E, UM Btmhole Loc 2395'FNL, 413'FWL, Sec. 25, T12N, R09E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting ddiling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before ddlling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector 659-3607. Yours very truly, Russell A. Dougla~ Commissioner BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA AI_,-,~KA OIL AND GAS CONSERVATION COMMIS,.,,ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r~ I b Type of Well Exploratory r~ Stratigraphic Test [~] Development Oil X Re-Entry r-I Deepen r~ Service [~ Development Gas [~] Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 53' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25641, ALK 2572 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25.025) 1547' FNL, 1313' FEL, Sec. 26, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2264' FNL, 147' FWL, Sec. 25, T12N, R9E, UM 1Q-26 #U-630610 At total depth 9. Approximate spud date Amount 2395' FNL, 413' FWL, Sec. 25, T12N, R9E, UM 9/8/95 ..,_,( $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property ¥fl) 15. Proposed depth (MDand TVD) property line 1Q-08 ,,,%,$..~,, 6963 MD 2264 ~ TD feet 14.5' @ 400' MD feet 2560 ,~o~.~ 6490' TVD,5~" feet 16. To be completed for deviated wells 17. Anticipated pressure (se~ 20 AAC 25.035(e)(2)) Kickoff depth 2500' feet Maximum holeangle 28.78° Maximum surface 2193~ pslg At total depth (TVD) 3300 pslg 1~. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Weight Grade Couplin~l Len~lth MD '[VD MD TVD (include sta~le data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 9.875" 7.625" 29.7# L-80 LTC 3743' 41' 41' 3784' 3704' 600 Sx Arcticset III & HF-ERW 300 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOE 6249' 41' 41' 6290' 5900' HF-ERW 6.75" 3.5" 9.3# L-80 EUE8rdM 673' 6290' 5900' 6963' 6490' 230SxClassG Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat [-I BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis r~ Seabed report ["! 20 AAC 25.050 requirements X 21. I hereby certify tt'jatj, j~ ,~the~[f°reg°ingfisf true and correct to the best of my knowledge.. Title Date Signed ~v ~. / -.' -"'~_ Drill Site Develop. Supv. ,--'- CommissionUse Only Permit Number I A~l'number I Approval~::~te I See cover letter for 9S'--/m2~ I~o-o~,~ -.-, ~ ~ ,~?(::~ - 7---' ?%--'- other requirements Con(~itions o~ approval Samples required E~] Yes ~' No Mud Icg required D Yes ~ No Hydrogen sulfidemeasures ~;~ Yes [~ No Directional survey required [~ Yes r'~ No Required working pressure forBOPE D 2M ~ 3M D 5M [~ 10M E~ 15M Other: RUSSEL~.0RIGINALA.SIGNED BY' ~/7 DOUG~ by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 , iolicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1Q-26 · = . . Si J . 1 1 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (3,784')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (6,963') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement tapered 5-1/2" x 3-1/2" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test tapered 5-1/2" x 3-1/2" casing to 3500 psi. Run completion assembly. Pressure test SBE/XO. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well 1Q-26 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes- Weight up to TD 11.1 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,193 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 1Q-26 is 1Q-08. As designed, the minimum distance between the two wells would be 14.5' @ 400' MD. Annular Pumping Activities: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1Q-26 surface/production casing annulus will be filled with diesel after setting the 5-1/2" x 3-1/2" tapered casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 1Q-26 be permitted for annular pumping occurring as a result of the drilling project on DS lQ, per proposed regulations 20 AAC 25.005 (k). Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Surface casing will be set in the Creatceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. Generally, the surface casing shoe is set 200' vertical below the base of the West Sak into the heart of the shales. Drilling Area Risks: Risks in the 1Q-26 ddlling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation matedal (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of ~ ppg will provide sufficient overpressure to safely ddll, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. I I X/ 500 '300 600 900 1200_ 1 SO0. 1800_ _ 2iOOJ _ 2400_ _ 2700_ 3000_ 3300] _ 3600_ _ 3900_ _ ¢2O0_ 45001 48001 _ 5100_ _ 5400_ 5700_ _ 6000_ _ 6300_ _ 6000_ RKI~ ELEVATION: 94' ARCO ALASKA, Inc. Structure : Pad lQ Well : 26 Field : Kuparuk River Unit Location : Nodh Slope, Alaska · E a s t > 150 0 150 300 450 600 750 900 1050 1200 I I I I I ~?~ I I I I I I [ ! I I I I I .~d;' c~o SURFACE LOCATION: ~..~.oq e& ~.c~ 1547' FNL, 1313' FEL %'""'-...... ~.OLo~ 9o SEC. 26, T12N, R9E B/ PERMAFROST TVD=1594 ~. "-...............~_.~,o T/ UGNU SNDS TVD=2394 KOP TVD=2500 TMD=2500 DEP=O 3.00 6,00 BUILD 3 OEG / lOO, 9.00 12.oo 15.oo T/ W SAK SNDS TVD=2989 TMD=2995 DEP=64 18.oo 21.0o 27.00 EOC TVD=3420 TMD=5459 OEP=236 B/ W SAK SNDS Tv'D=3504 TMD=3556 DEP=282 ~] 7 5/8" CSG PT TVD=3704 TMD=3784 DEP=392 K-lO WD=4649 TMD=4862 DEP=911 K-5 TVD=5319 TMD=5627 DEP=1279 TARGET LOCATION: 2264' FNL, 147' FWL SEC. 25, T12N, R9E 'fARG'E'r- TVD = 5951 TMD=6348 DEP= 1627 SOUTH 717 EAST 1460 1350 1500 1650 1800 I I I I I I I S 63.84 DEG E 627' (TO TARGET) HRZ Midpoint TVD=5784 TMD=6157 DEP=1535 _ AVERAGE ANGLE 28.78 DEG TARGET - T/ ZONE D TVD=595t TMD=6348 DEP=1627 ~T/ ZONE C TV0=5986 TMD=6388 DEP=1646 ~T/ ZONE B TVD=6079 TMD=6494 DEP=1697 ~ ~T/ ZONE A Tv'D=6196 TMD=6627 DEP=1761 B/ KUP SNDS TVD=6515 TMD=6763 DEP= k XxxT/ A5 SNDS TVD=6224 TMD=6659 DEP=1777 rD - / t/2" CSG PT TVD=6490 TMD=6963 DEP=1923~ I I I I I I I I I I I I I I I i 500 0 300 600 900 1200 1500 1800 21 O0 Scale 1 : 150.00 Vertical Section on 116.16 azimufh with reference 0.00 N, 0.00 E fram sial ~26 J 150 _ _ 0 _ _ 150 _ _ 300 _ _ 450 _ 600 _ _ 750 _ _ 900 _ TO LOCATION: 2395' FNL, 413' FWL SEC. 25, T12N, R9E Created by : jonea For: D PETRASH iOate plotted : 15-Au9--95 !Plot Reference i~ 26 Vereion iii5. jCoordinates ore in feet reference ~lot ~26. iTrue Vertical Depths are reference RKB (Porker ~245). iCreoted by : joneo For: D !Oote plotted : 15-Aug-g5 Plot Reference is 26 Version ~5. iCoordinotes ore in feet reference slot ~26. iTrue Verticol Depths ore reference RKB (Parker ARCO ALASKA, Inc. Structure : Pod lQ Well : 26 Field : Kuporuk River Unit Locotion : Norlh Slope, Alosko~ 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 O ,...: 6o 60 .. ,-' 4.0 40 -- 0 0 2O O 20 40 60 I 8o 1 O :oo 120_ _ 140_ _ 160_ 180 200_ _ 220_ _ 240_ ooo 2200 240o 60 0 80 0 L2800 000 280[ I ~ ~ ~ ~ ~ t ! I I I I I I I I I I ~ I I I I I I I I I I I 20 0 210 410 610 80 1 O0 120 140 160 180 200 220 240 260 280 300 Scale1' 10.00 East --> I 140 _180 _200 _220 _ _240 _ _260 _ 280 iCrec~ted by : jon~= For: D PET~H !Dote ~ott. ed: 15-Aug-95 ?lot Reference is 26 Version {5. , iCoordinetes ore in feet reference slot f~26. iTrue Vertical Depths ore reference RKB (Porker ~1245). AR, CO ALASKA, Inc. Structure : Pad lQ Well : 26 Field : Kuparuk River Unit Location : North Slope, Alaska 0 0 c5 ~2o ~ 8O 4O ~co,~ ~. ~o.oo E a s t > 280 520 560 400 440 480 520 560 600 640 680 720 760 800 840 880 920 80 160 - 200 _ -- -- -- 320 _ _ 360 _ 400 _ 440 _ 480 _ 520 t 560 240 280 I I I I I I I i I I J I I J I I J I I t I J 280 520 360 400 440 480 520 560 600 640 680 · o.oo E a st -- > i I I I I I I I I I I 720 760 800 840 880 920 _ 120 _ _ 80 _ _ 40 _ _ 0 _ 40 120 0 160 200 ~ 240 J 280 V 320 360 4OO 480 520 560 440 .UPARUK RIVER UNi'. 20" DIVERTER SCHEMATIC 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"-2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 7 6 5 4 I3 13 5/8" 5000BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2- ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WiTH WATER. 2- CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURETO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. ~ CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8, OPEN TOP PIPE RAMS AND CLOSE BO~-FOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3(X)0 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TESTTO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12_ TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRIllING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL A~ODATE 3-1/2" TO 5-1/2" PIPE ODS. 1. 16" - 2000 PSI STARTING HEAD 2- 11"-3000 PSI CASING HEAD 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8"-~ PSI DRLG SPOOLW/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR WELL PERMIT CHECKLIST COMPANY . .-'~/"'"'i ~ INIT CLASS ~,/ ./'-~D~ ~ · WELL NAME GEOL AREA UNIT# PROGRAM: exp [] ,,,, devy redrll [] aery [] ON/OFF SHORE ~ ADMINISTRATION 3. 4. 5. 6. '7° 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included Operator only affected party .......... .... Operator has appropriate bond in force .......... Y Permit can be issued without conservation order .... I Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ....... ~YI ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ .~. N 16. CMT vol adequate to circulate on conductor & surf csg.~y N 17. CMT vol adequate to tie-in long string to surf csg . . . 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~N 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate ............. .~ N 26. BOPE press rating adequate; test to ~ ;s;g'~,~ N 27. Choke manifold complies w/kPI RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... ~N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis Qf shallow gas zones ........ 33. Seabed condition survey (if off-shore) ....... /. Y N - 34. Contact name/phone for weekly progress reports . . /.. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: Z HOW/jo - A:'d::ORMSk:heklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER · ........ SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : 1Q-26 FIELD NAME : KUPARUK BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292259000 REFERENCE NO : 95360 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-NOV-1995 13:41 **** REEL HEADER **~ SERVICE NAME : EDIT DATE : 95/ll/14 ORIGIN : FLIC REEL NAME : 95360 CONTINUATION ~ : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 1Q-26, API #59-029-22590-00 **** TAPE HEADER SERVICE NAME : EDIT DATE : 95/~/~4 ORIGIN : FLIC TAPE NAME : 95369 CONTINUATION ~ : PREVIOUS TAPE COMMENT : ARCO ALASKA INC., KUPARUK 10,-26, AP1 #59-929-22599-99 TAPE HEADER Kuparuk MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 1Q-26 599292259990 Arco Alaska Inc. SCHLUMBERGER WELL SERVICES [4-NOV-95 BIT RUN 1 BIT RUN 2 BIT RUN 3 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 9) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 95369 95369 95369 NICOLS/NUTTE NICOLS/NUTTE NICOLS/NUTTE TRANTHAM TRANTHAM TRANTHAM 1ST STRING 2ND STRING 26 12N 9E 1547 1313 94.99 94. ~9 52.79 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.759 7.625 3899.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-NOV-1995 13:41 3RD STRING PRODUCTION STRINQ REMARKS: Well drilled 20-SEP through 22-SEP-95 with ARC5 on!¥. All data was collected in a single bit run. No MAD da%a was collected. $ $ **** FILE HEADER FILE NAME : EDIT .~01 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: ~.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 38e0.0 7010.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MWD 88888.0 88887 6795.0 6794 6726.5 6725 6500.0 6498 6412.0 6410 6354.5 6355 6317.5 6317 6242.5 6241 6217.5 6217 6186.0 6184 6152.5 6151 6108.0 6107 6038.5 6038 5967.5 5966 1~0.0 99 $ MERGED DATA SOURCE .5 .5 .0 5 5 5 5 .5 .0 .5 .0 .5 .0 LIS Tape Verification Listing Schlumberger Alaska Comput|ng Center 14-NOV-lg95 15:41 LDWG TOOL CODE Blt RUN NO. MERGE TOP MERGE BASE $ REMARKS: The depth adjustments shown above reflec% the MWD GR to the cbt GR logged by SWS 24-0CT-95. All other MWD curves were carried with the GR. $ LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 $ 73 36 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT ~5 66 68 16 66 0 66 0 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 API AP1 FILE NUMB NUMB SiZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 ~Oe ~ ~ [ 1 1 4 68 ~0~0000000 ROP MWD F/HR 00 00~ 0~ 0 1 1 1 4 68 00~000~000 FET MWD HR 00 00~ 00 0 1 1 1 4 68 GR MWD GAPI 00 000 00 0 1 1 1 4 68 0~00000~00 RPXX MWD OHMM 00 000 ~0 0 1 1 1 4 68 00~0000~0 RPX MWD OHMM 00 00~ 00 0 I 1 1 4 68 ~0000000~0 RPS MWD OHMM 00 000 00 0 [ 1 1 4 68 0000ee0000 RPM MWD OHMM 00 000 00 0 1 1 1 4 68 00~00e0000 RPD MWD OHMM 00 000 00 0 I 1 I 4 68 0000000000 LIS Tape Veri{ica%ion L|s%ing Schlumberger Alaska Computing Cen~er ** DATA ** DEPT. 7~09.500 RPXX.MWD 2,659 RPD.MWD 2.671 DEPT. 3800.000 RPXX.MWD [000.000 RPD.MWD 1.306 ROP.MWD RPX.MWD ROP.MWD RPX.MWD 14-NOV-1995 ~3:41 104.211 FET.MWD 2.694 RPS.MWD 0.221 FET.MWD 9.253 RPS.MWD 0.542 GR.MWD 2.697 RPM.MWD 0.378 GR.MWD 2.378 RPM.MWD PAGE: 77.348 2.680 44.961 1.672 ** END OF DATA **** FILE TRAILER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : ~01C01 DATE : 95/11/14 MAX REC SIZE : 1e24 FILE TYPE : LO LAST FILE : **** TAPE TRAILER SERVICE NAME : EDiT DATE : 95/11/14 ORIGIN : FLIC TAPE NAME : 95360 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 1Q-26, API #50-029-22590-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/11/14 ORIGIN : FLIC REEL NAME : 95360 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC.~ KUPARUK 1Q-26, API ~50-~29-2259~-00
