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184-131
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EC (1. > > > > 0 M1 Y Y Y Y Y u C on m r 04 c, X n N 0 _ K NOM p M M o h 1� �) O O O O O LU Q O O O O O C.) 13 > 5 0 0 0 0 f6 WCD w C:10000 C x N f6 u - y Cr ro o r O O C O O O O O M c`') M N I- N jA E N N N N CO O M '- ,- 1A V 0.0 N 0 0 0 M 0 N N N N N N L M M M CA CA N p O O O N N Q1 O O L L rms O O O O (0 0. 0 co opo u> u> u� u� �n u c CID w 3 'ro 0J m_ 0) 1126 Z Cn E 0) Ce C C pp W ` a) N 2 a 0 a a a a in .- a) a 7 u as Z oo Y r r E a 0_ N A N.N. Z N N N r U' yJj N N N N = - z CJ !0 O C/3 a Q 3 L L v co H a a Q STATE OF ALASKA ALIIL OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well CI Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development I] Exploratory❑ 184-131 3.Address: P. O. Box 100360,Anchorage, Stratigraphic❑ Service❑ 6.API Number: Alaska 99510 50-029-21162-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 2G-15 ADL 25667 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 6,997 feet Plugs measured None RECEIVED true vertical 6,346 feet Junk measured None Effective Depth measured 6,900 feet Packer measured 5762, 6394 feet SEP 0 6 2017 true vertical 6,277 feet true vertical 5499, 5926 feet AOG CC Casing Length Size MD ND Burst Collapse CONDUCTOR 70 feet 16 " 105' MD 105 TVD SURFACE 2,693 feet 9 5/8" 2,727' MD 2726 TVD PRODUCTION 6,950 feet 7 " 6,983' MD 6336 TVD Tubing(size,grade,measured and true vertical depth) 3.5" L-80 6,680' MD 6,122'TVD Packers and SSSV(type,measured and true vertical depth) FHL PACKER-PACKER,BAKER,4762 FHL 5,762'MD 5,499'TVD FHL PACKER-PACKER,BAKER,47B2 FHL 6,394' MD 5,926'TVD SSSV -NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A C Treatment descriptions including volumes used and final pressure: SCANNED DE 20 ' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN - - - - Subsequentto operation: 197 289 1208 958 169 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory ❑ Development El Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas LI WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ 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: 317-365 Contact Name: Ron Phillips Authorized Name: Ron Phillips Contact Email: Ron.L.Phillips@cop.com Authorized Title: Senior Wells Engineer //� 40/A) / Contact Phone: (907)265-6312 Authorized Signature: 4'• CDIA4 Date: /�j/A) i 7 Iryz 1007/17_ - 7 2017 / Form 10-404 Revised 4/2017 "0�j' toq` ' �, RBDMS i,1 SLd Submit Original Only • i Operations Summary (with Timelog Depths) 3 . 2G-15 thiilli Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time bur{hr) Phase Op Code Activity Code Time P-T-Xi {ftKB)', End Depth MKS) 7/20/2017 7/20/2017 2.00 MIRU MOVE RURD P PJSM. Skid the rig floor into drilling 0.0 0.0 15:00 17:00 position. 7/20/2017 7/20/2017 1.50 MIRU MOVE MOB P PJSM. Pull off well 2T-06 and stage 0.0 0.0 17:00 18:30 on the pad for booster install. 7/20/2017 7/20/2017 2.50 MIRU MOVE RURD P Install the front and rear booster. 0.0 0.0 18:30 21:00 Install the rear drivers cab. 7/20/2017 7/20/2017 2.50 MIRU MOVE MOB P Move the rig 1 mile from 2T pad to F 0.0 0.0 21:00 23:30 pit. 7/20/2017 7/21/2017 0.50 MIRU MOVE WAIT P PU mat from 2T pad to F pit. 0.0 0.0 23:30 00:00 7/21/2017 7/21/2017 2.50 MIRU MOVE WAIT P Continue to PU mats from 2T pad to F 0.0 0.0 00:00 02:30 pit. Finish laying out mat from F pit to 2A pad. 7/21/2017 7/21/2017 2.00 MIRU MOVE MOB P Move the rig 1.1 miles from F pit to 2A 0.0 0.0 02:30 04:30 pad. SimOps: Lay mats from 2A pad to four corners. 7/21/2017 7/21/2017 7.50 MIRU MOVE WAIT P PU mats from F pit to 2A pad. Lay 0.0 0.0 04:30 12:00 mat from 2A pad to four corner. Lay mats over culverts from four corners to 2B pad. 7/21/2017 7/21/2017 5.00 MIRU MOVE MOB P Move the rig 2.6 miles from four 0.0 0.0 12:00 17:00 corners to 2B pad. 7/21/2017 7/22/2017 7.00 MIRU MOVE WAIT P PU mats from 2A pad to four corners. 0.0 0.0 17:00 00:00 PU mats from four corners to 2B pad. Lay mats over culverts from 2B pad to 2G access road entrance. Lay mats from 2G access road entrance to 2G pad. PU mats used for CDR3 rig move and haul to 2G access road entrance. 7/22/2017 7/22/2017 4.00 MIRU MOVE WAIT P Continue to lay mats from 2G access 0.0 0.0 00:00 04:00 road entrance to 2G pad. PU mats used for CDR3 rig move and haul to 2G access road entrance. 7/22/2017 7/22/2017 1.00 MIRU MOVE MOB P Move the rig 0.3 miles from 2B pad to 0.0 0.0 04:00 05:00 2G access road entrance. Turn off the spine road onto 2G access road. 7/22/2017 7/22/2017 1.00 MIRU MOVE WAIT P Finish laying out mat on 2G access 0.0 0.0 05:00 06:00 road to 2G pad. 7/22/2017 7/22/2017 3.00 MIRU MOVE MOB P Move the rig down 2G access roadto 0.0 0.0 06:00 09:00 the end of the mats. 7/22/2017 7/22/2017 5.00 MIRU MOVE WAIT P Double stack the mats behind the rig. 0.0 0.0 09:00 14:00 SimOps: Needle gun through out the rig. Work on MP2's. 7/22/2017 7/22/2017 1.00 MIRU MOVE MOB P Back the rig up onto double stacked 0.0 0.0 14:00 15:00 mats. 7/22/2017 7/22/2017 1.00 MIRU MOVE WAIT P Lay out mats in front of the rig. 0.0 0.0 15:00 16:00 SimOps: Needle gun through out the rig. Work on MP2's. 7/22/2017 7/22/2017 0.50 MIRU MOVE MOB P Back the rig up onto double stacked 0.0 0.0 16:00 16:30 mats. Page 1/20 Report Printed: 8/14/2017 • • Operations Summary (with Timelog Depths) )4 s 2G-15 CanocoPhitiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time< End Time Dur(hr) Phase Op Code Activity Code' Time P-T-X Operation (ftKB) End Depth(ftKB) 7/22/2017 7/22/2017 0.50 MIRU MOVE WAIT P Lay out mats in front of the rig. 0.0 0.0 16:30 17:00 SimOps: Needle gun through out the rig. Work on MP2's. 7/22/2017 7/22/2017 0.50 MIRU MOVE MOB P Back the rig up onto double stacked 0.0 0.0 17:00 17:30 mats. 7/22/2017 7/22/2017 3.50 MIRU MOVE WAIT P Lay out mats in front of the rig. 0.0 0.0 17:30 21:00 SimOps: Needle gun through out the rig. Work on MP2's. 7/22/2017 7/22/2017 2.50 MIRU MOVE MOB P Move the rig to 2G pad. 0.0 0.0 21:00 23:30 7/22/2017 7/23/2017 0.50 MIRU MOVE RURD P Remove the rear booster. 0.0 0.0 23:30 00:00 7/23/2017 7/23/2017 0.50 MIRU MOVE RURD P Continue to remove the rear booster. 0.0 0.0 00:00 00:30 7/23/2017 7/23/2017 0.50 MIRU MOVE MOB P Move the rig down 2G pad and the 0.0 0.0 00:30 01:00 rear sunk into the pad. 7/23/2017 7/23/2017 2.00 MIRU MOVE WAIT T Place dunnage under the rear tires,jar 0.0 0.0 01:00 03:00 up and put mats under the rear of the rig. Install the rear booster. Back the rig out of the hole. Attempt to move the rig forward to the rig mats over the pipeline crossing and the front driller side tires sunk into the pad. 7/23/2017 7/23/2017 2.00 MIRU MOVE WAIT T Place dunnage under the front tires, 0.0 0.0 03:00 05:00 jar up and put mats under the front of the rig. Lay mats behind the rig. Back up onto the mats and remove the front booster. SimOps: Lay mats from the rig to well 2G-15. 7/23/2017 7/23/2017 1.00 MIRU MOVE MOB P Move the rig on mats around to well 0.0 0.0 05:00 06:00 2G-15. 7/23/2017 7/23/2017 1.00 MIRU MOVE RURD P Remove the rear booster. 0.0 0.0 06:00 07:00 7/23/2017 7/23/2017 2.00 MIRU MOVE MOB P Spot the rig over well 2G-15 and shim 0.0 0.0 07:00 09:00 the rig. 7/23/2017 7/23/2017 1.00 MIRU MOVE RURD P Skid the rig floor into drilling position. 0.0 0.0 09:00 10:00 7/23/2017 7/23/2017 3.00 MIRU MOVE RURD P Extend out the drag chain chute. RU 0.0 0.0 10:00 13:00 lines under the rig floor. Spot and berm the cutting tank. RU the beaver slide. *Rig accepted at 13:00 hours.* 7/23/2017 7/23/2017 3.00 MIRU WELCTL RURD P Load the pits with 14.1 ppg mud. RU 0.0 0.0 13:00 16:00 circulating lines in the cellar. 7/23/2017 7/23/2017 0.25 MIRU WELCTL SFTY P PJSM for pressure testing lines and 0.0 0.0 16:00 16:15 RU to pull BPV. 7/23/2017 7/23/2017 0.75 MIRU WELCTL SEQP P PT all circulating lines to 4000 psi 0.0 0.0 16:15 17:00 (good test). 7/23/2017 7/23/2017 2.00 MIRU WELCTL MPSP P RU the lubricator,PT to 1000 psi 0.0 0.0 17:00 19:00 (good test),pull the 3"H BPV and RD the lubricator. Page 2/20 Report Printed: 8/14/2017 • • °° Operations Summary (with Timelog Depths) 0,14 2G-15 Phillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK€) End Depth(ftKE) 7/23/2017 7/23/2017 1.25 MIRU WELCTL CIRC P Line up to pump seawater from the 0.0 0.0 19:00 20:15 truck. Reverse circulate 25 bbls of seawater down the IA taking returns up the tubing to the kill tank at 6 BPM =2130 psi. Circulate 260 bbls down the tubing taking returns up the IA to the kill tanks at 5.5 BPM=1660 psi. 7/23/2017 7/23/2017 1.25 MIRU WELCTL RURD P Load the pits with the second truck of 0.0 0.0 20:15 21:30 14.1 ppg mud. 7/23/2017 7/23/2017 1.00 MIRU WELCTL KLWL P Circulate 14.1 ppg mud down the 0.0 0.0 21:30 22:30 tubing taking returns up the IA to the kill tanks staging the pumps up to 6 BPM=1810 psi. Pumped 250 bbls and returned 250 bbls in the kill tank. 7/23/2017 7/23/2017 0.50 MIRU WELCTL OWFF P Observe the well for flow for 30 0.0 0.0 22:30 23:00 minutes and the well is static. 7/23/2017 7/23/2017 0.50 MIRU WHDBOP MPSP P PU and MU the dry rod,install the 3" 0.0 0.0 23:00 23:30 HP BPV and lay down the dry rod. Attempt to PT to 1000 psi but pumping away at 3.5 BPM=750 psi. Increased rate to 4.5 BPM=1000 psi. Pumped a total of 8 bbls. The gauge above the BPV remained at 0 psi. 7/23/2017 7/24/2017 0.50 MIRU WHDBOP NUND P Blow down all circulating lines. 0.0 0.0 23:30 00:00 7/24/2017 7/24/2017 0.50 MIRU WHDBOP NUND P RD all circulating lines. 0.0 0.0 00:00 00:30 7/24/2017 7/24/2017 2.00 MIRU WHDBOP NUND P ND the tree and ND the tubing head 0.0 0.0 00:30 02:30 adapter. Install the plug off tool into the HP BPV. Function the LDS. Tubing head adapter look good. The tubing hanger neck has corrosion pitting above the sealing surface but the lift threads are good(9-1/4 turns). 7/24/2017 7/24/2017 3.50 MIRU WHDBOP NUND P NU the DSA's and remove the spacer 0.0 0.0 02:30 06:00 spool from the bottom of the BOP stack. NU the BOP stack and NU the kill line. 7/24/2017 7/24/2017 3.00 MIRU WHDBOP NUND P Continue to NU the BOP stack, 0.0 0.0 06:00 09:00 Center the BOP stack,install the riser and air up the air boot. Obtain RKB measurements. 7/24/2017 7/24/2017 0.50 MIRU WHDBOP RURD P RU BOPE testing equipment. 0.0 0.0 09:00 09:30 • Page 3/20 Report Printed: 8/14/2017 • IIP 0. ~' Operations Summary (with Timelog Depths) 0 2G-15 co hitiilps Rig: DOYON 14 Job: RECOMPLETION Time Lag Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-7-x Operation (#tKB) End Depth(ftKB) 7/24/2017 7/24/2017 6.00 MIRU WHDBOP BOPE P Conduct initial BOPE test: test 2-7/8" 0.0 0.0 09:30 15:30 x 5"VBR's(upper pipe rams)to 250/4000 psi with 3-1/2"and 4"test joints;test 2-7/8"x 5"VBR's(lower pipe rams)to 250/4000 psi with 3-1/2" and 4"test joints;test annular to 250/2500 with 3-1/2"and 4"test joint; conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Matt Herrera via email on 7/22/17 at 06:17 hours. Tests: 1) Annular with 3-1/2"test joint,choke valves 12, 13&14 to 250/2500 psi (Passed) 2) 2-7/8"x 5"VBR's(lower pipe rams) with 3-1/2"test joint(Passed) 3) 2-7/8"x 5"VBR's(upper pipe rams)with 3-1/2"test joint,choke valves 12, 13&14,3"Demco,upper IBOP(Passed) 4) Lower IBOP,kill HCR,choke valves 9&11 (Passed) 5) Manual kill,4"HT-38 FOSV,choke valves 5,8&10(Passed) 6) 4"HT-38 dart valve,choke valves 4,6&7(Passed) 7) Choke valve 2(Passed) 8) Blind rams,choke valves 1 &3 (Passed) 9) Super choke and manual choke (Passed) 10) 2-7/8"x 5"VBR's(lower pipe rams)with 4"test joint(Passed) 11) Annular with 4"test joint,choke HCR,manual kill to 250/4000 psi (Passed) 12) 2-7/8"x 5"VBR's(upper pipe rams)with 4"test joint,choke HCR (Passed) 13) 2-7/8"x 5"VBR's(upper pipe rams)with 4"test joint,manual choke (Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3100 psi Accumulator Pressure After Closer= 1700 psi Pressure Gain of 200 psi=43 seconds Full System=212 Seconds Average N2(6 Bottles)=2066 psi 7/24/2017 7/24/2017 0.50 MIRU WHDBOP RURD P RD BOPE testing equipment. Blow 0.0 0.0 15:30 16:00 down all line and suck out the BOP' stack. 7/24/2017 7/24/2017 0.50 COMPZN RPCOMP RURD P RU 3-1/2"tubing elevators and RU 3- 0.0 0.0 16:00 16:30 1/2"power tubing tongs. 7/24/2017 7/24/2017 0.50 COMPZN RPCOMP MPSP P PUand MU dry rod. Pull the plug off 0.0 0.0 16:30 17:00 tool and 3"HP BPV Page 4/20 Report Printed: 8/14/2017 s • 4 Operations Summary (with Timelog Depths) 0 ' 2G-15 ConocaPhiiiips • Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code` Time P-T-X Operation (MKS) End Depth(5KB) 7/24/2017 7/24/2017 0.50 COMPZN RPCOMP PULL P MU the landing joint with crossover to 0.0 6,333.0 17:00 17:30 the top drive and MU the top drive. BOLDS,pull the tubing hanger free at 100K and PU 5'(PU=94K). 7/24/2017 7/24/2017 1.00 COMPZN RPCOMP CIRC P Establish circulation at 3 BPM=540 6,333.0 6,333.0 17:30 18:30 psi and circulate one hole volume at 7 BPM=1360 psi. Observe the well for flow and the well is static. 7/24/2017 7/24/2017 0.75 COMPZN RPCOMP PULL P Pull the tubing hanger to the rig floor 6,333.0 6,296.0 18:30 19:15 and lay down the tubing hanger. 7/24/2017 7/24/2017 4.00 COMPZN RPCOMP PULL P POOH laying down 3-1/2"tubing to 6,296.0 4,549.0 19:15 23:15 4549'MD. 7/24/2017 7/24/2017 0.50 COMPZN RPCOMP CIRC P Pump 17 bbl 15.1 ppg dry job followed 4,549.0 4,549.0 23:15 23:45 by 9 bbls of 14.1 ppg mud. Blow down the top drive. 7/24/2017 7/25/2017 0.25 COMPZN RPCOMP PULL P Continue POOH laying down 3-1/2" 4,549.0 4,362.0 23:45 00:00 tubing from 4549'to 4362'MD. 7/25/2017 7/25/2017 4.50 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 4,362.0 0.0 00:00 04:30 tubing removing jewelry to surface. Recovered 198 joints,4 GLM's, 1 . Nipple(2.875"DS)and cut joint= 16.33'. The outside of the tubing (joints#80-#163)are coated with resin. Heavy corrosion on the collars of joint#182-#187. 7/25/2017 7/25/2017 0.50 COMPZN RPCOMP RURD P RD 3-1/2"elevators and RD 3-1/2" 0.0 0.0 04:30 05:00 power tubing tong. Clean and clear the floor. Mobilize wear ring and wear ring running tool to the rig floor. Unload the pipe shed of old tubing. Load the pipe shed with six 4-3/4" DC's,strap and tally. 7/25/2017 7/25/2017 0.50 COMPZN RPCOMP RURD P PU and MU wear ring running tool to a 0.0 0.0 05:00 05:30 joint of DP,install the wear ring, RILDS,lay down the wear ring running tool and lay down the joint of DP. 7/25/2017 7/25/2017 0.50 COMPZN RPCOMP RURD P Mobilize fishing equipment to the rig 0.0 0.0 05:30 06:00 floor. 7/25/2017 7/25/2017 0.75 COMPZN RPCOMP RURD P Mobilize DP air slips to the rig floor. 0.0 0.0 06:00 06:45 Break out 3-1/2"EUE 8rd crossover on FOSV. 7/25/2017 7/25/2017 1.25 COMPZN RPCOMP BHAH P PU and MU BHA#1 -Overshot 0.0 220.0 06:45 08:00 assembly for 3-1/2"tubing. 7/25/2017 7/25/2017 4.00 COMPZN RPCOMP PULD P RIH with BHA#1 on 4"DP from the 220.0 4,515.0 08:00 12:00 pipe shed to 4515 MD. 7/25/2017 7/25/2017 0.50 COMPZN RPCOMP CIRC P Circulate bottoms up at 7 BPM=1300 4,515.0 4,515.0 12:00 12:30 psi and got back plastic coating from the outside of the tubing over the shakers. 7/25/2017 7/25/2017 2.50 COMPZN RPCOMP PULD P Continue to RIH with BHA#1 on 4"DP 4,515.0 6,316.0 12:30 15:00 from the pipe shed from 4515'to 6316' MD(PU=140K and SO=102K). 7/25/2017 7/25/2017 1.00 COMPZN RPCOMP CIRC P Circulate and condition the mud at 8 6,316.0 6,316.0 15:00 16:00 BPM= 1950 psi. 7/25/2017 7/25/2017 0.50 COMPZN RPCOMP FISH P Wash down from 6316'MD to tag at 6,316.0 6,337.0 16:00 16:30 6332'MD with 10K down. Rotate over the tubing stub,wash down to 6337' MD,set 10K down,PU to 180K and the fish is free. Page 5/20 Report Printed: 8/14/2017 p ' • I • Operations Summary (with Timelog Depths) ed,..,- ti 2G-15 +Conotccie itiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Cade Activity Code; Time P-T-X Operation (ftKB) End Depth(ftKBI, 7/25/2017 7/25/2017 0.25 COMPZN RPCOMP CIRC P Circulate bottoms up at 8 BPM=1170 6,337.0 6,337.0 16:30 16:45 psi. 7/25/2017 7/25/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow and the well 6,337.0 6,337.0 16:45 17:00 is static. 7/25/2017 7/25/2017 3.50 COMPZN RPCOMP TRIP P TOOH with BHA#1 from 6337'to 220' 6,337.0 200.0 17:00 20:30 MD. 7/25/2017 7/25/2017 0.50 COMPZN RPCOMP BHAH P Lay down BHA#1 -Overshot 220.0 0.0 20:30 21:00 assembly for 3-1/2"tubing. 7/25/2017 7/25/2017 1.00 COMPZN RPCOMP PULL P Lay down GLM fish. Recover upper 59.0 0.0 21:00 22:00 cut joint=14.92',GLM with 10'pups and lower cut joint= 14.93'. No resin on recovered fish. 7/25/2017 7/25/2017 0.50 COMPZN RPCOMP RURD P Clean the rig floor. 0.0 0.0 22:00 22:30 • 7/25/2017 7/25/2017 0.50 COMPZN RPCOMP BHAH P PU and MU BHA#2-Overshot 0.0 220.0 22:30 23:00 assembly for 3-1/2"tubing. 7/25/2017 7/26/2017 1.00 COMPZN RPCOMP TRIP P TIH with BHA#2 from 220'to 2873' 220.0 2,873.0 23:00 00:00 MD. 7/26/2017 7/26/2017 2.00 COMPZN RPCOMP TRIP P Continue to TIH with BHA#2 from 2,873.0 6,285.0 00:00 02:00 2873'to 6285'MD. 7/26/2017 7/26/2017 0.25 COMPZN RPCOMP FISH P PU a single joint of DP and RIH to 6,285.0 6,394.0 02:00 02:15 6316'MD. Obtain parameters: PU= 140K,SO=103K and 2.3 BPM=560 psi. Wash down to tag at 6389'MD on the tubing stub and SO to no-go at 6394'MD with 10K down. PU 20K over,SO 10K down and pull to 225K. 7/26/2017 7/26/2017 0.25 COMPZN RPCOMP JAR P Begin jarring at 225K with straight pull 6,394.0 6,365.0 02:15 02:30 to 275K. After 8 jar hits fish pulled free and PU to 6365'MD. 7/26/2017 7/26/2017 0.50 COMPZN RPCOMP CIRC P Circulate a bottoms up at 7 BPM= 6,365.0 6,365.0 02:30 03:00 1020 psi. 7/26/2017 7/26/2017 0.50 COMPZN RPCOMP OWFF P Observe the well for flow and the well 6,365.0 6,365.0 03:00 03:30 is static. SimOps: Post jarring derrick inspection. 7/26/2017 7/26/2017 2.00 COMPZN RPCOMP TRIP P TOOH with BHA#2. 6,365.0 220.0 03:30 05:30 7/26/2017 7/26/2017 0.50 COMPZN RPCOMP BHAH P Lay down BHA#2-Overshot • 220.0 0.0 05:30 06:00 assembly for 3-1/2"tubing. 7/26/2017 7/26/2017 1.50 COMPZN RPCOMP PULL P Lay down fish. Recovered cut joint, 36.0 0.0 06:00 07:30 pup joint and seal assembly. No resin on recovered fish. 7/26/2017 7/26/2017 1.50 COMPZN RPCOMP BHAH P Clean and clear the rig floor. Mobilize 0.0 223.0 07:30 09:00 fishing equipment to the rig floor. PU and MU BHA#3-PBR spear assembly. 7/26/2017 7/26/2017 2.00 COMPZN RPCOMP TRIP P TIH with BHA#3 to 6382'MD(PU= 223.0 6,382.0 09:00 11:00 140K and SO=100K) 7/26/2017 7/26/2017 1.00 COMPZN RPCOMP CIRC P Break circulation at 2 BPM=590 psi 6,382.0 6,382.0 11:00 12:00 and circulate bottoms up at 4 BPM= 1140 psi. Page 6/20 Report Printed: 8/14/2017 A_ i • 0 ,- Operations Summary (with Timelog Depths) 2G-15 ConocoPhitliips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code .Activity Code Time P-T-X Operation (ftKE) End Depth(EKE) 7/26/2017 7/26/2017 0.50 COMPZN RPCOMP FISH V P Wash down at 2 BPM=580 psi to top 6,382.0 6,502.0 12:00 12:30 of the PBR at 6414'MD,pressure increased and shut down the pumps. Engage the spear into the PBR at 6423'MD with 10K down and PU to 175K to confirm engagement. Bleed the jars,straight pull to 240K and the packer pulled free. Pull the poor boy overshot off the tubing stub and PU to 6383'MD(packer swabbing). • 7/26/2017 7/26/2017 0.50 COMPZN RPCOMP OWFF P Allow time for the packer elements to 6,502.0 6,383.0 12:30 13:00 relax while observing the well for flow and the well is static. 7/26/2017 7/26/2017 2.00 COMPZN RPCOMP PMPO P PJSM. Pump out of hole at 0.5 BPM= 6,383.0 5,529.0 13:00 15:00 90 psi from 6383'to 5529'MD. 7/26/2017 7/26/2017 4.00 COMPZN RPCOMP TRIP P TOOH on elevators from 5529'to 223' 5,529.0 223.0 15:00 19:00 MD. 7/26/2017 7/26/2017 0.50 COMPZN RPCOMP BHAH P Lay down BHA#3-PBR spear 223.0 0.0 19:00 19:30 assembly. 7/26/2017 7/26/2017 1.50 COMPZN RPCOMP PULL P Lay down PBR/packer assembly. 86.0 0.0 19:30 21:00 Recovered PRB/packer, 1 joint of tubing,nipple with pups and overshot. No resin on the PBR or packer. 7/26/2017 7/26/2017 1.00 COMPZN RPCOMP BHAH P Mobilize fishing equipment to the rig 0.0 220.0 21:00 22:00 floor. PU and MU BHA#4-Overshot assembly for 3-1/2"tubing. 7/26/2017 7/27/2017 2.00 COMPZN RPCOMP TRIP P TIH with BHA#4 to 4008'MD. 220.0 4,008.0 22:00 00:00 7/27/2017 7/27/2017 1.50 COMPZN RPCOMP TRIP P Continue to TIH with BHA#4 from 4,008.0 6,475.0 00:00 01:30 4008'to 6475'MD. 7/27/2017 7/27/2017 0.50 COMPZN RPCOMP FISH P Obtain parameters: PU=142K,SO= 6,475.0 6,506.0 01:30 02:00 105K and 3 BPM=630 psi. Wash down to tag at 6498'MD with 10K down,PU and no fish. Rotate at 20 RPM=3K ft-lbs free torque,SO over tubing stub and engage overshot at 6506'MD. PU to 175K and bleed the jars. 7/27/2017 7/27/2017 0.25 COMPZN RPCOMP JAR P Begin jarring at 240K with straight pull 6,506.0 6,475.0 02:00 02:15 to 300K. After 6 jar hits seals pulled free,PU 20'with drag,SO and tagged 13'high. PU to 6475'MD. 7/27/2017 7/27/2017 0.50 COMPZN RPCOMP CIRC P Circulate and condition at 8 BPM 6,475.0 6,475.0 02:15 02:45 =1900 psi 7/27/2017 7/27/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow and the well 6,475.0 6,475.0 02:45 03:00 is static. 7/27/2017 7/27/2017 2.25 COMPZN RPCOMP TRIP P TOOH with BHA#4 from 6475'to 220' 6,475.0 220.0 03:00 05:15 MD. 7/27/2017 7/27/2017 0.50 COMPZN RPCOMP BHAH P Lay down BHA#4-Overshot 220.0 0.0 05:15 05:45 assembly for 3-1/2"tubing. 7/27/2017 7/27/2017 0.75 COMPZN RPCOMP PULL P Lay down fish. Recovered cut joint, 36.0 0.0 05:45 06:30 pup joint and seal assembly. 7/27/2017 7/27/2017 0.50 COMPZN RPCOMP RURD P Clean and clear the floor. 0.0 0.0 06:30 07:00 7/27/2017 7/27/2017 3.00 COMPZN RPCOMP SLKL P PJSM. Install Dutch riser,RU HES 0.0 0.0 07:00 10:00 slickline lubricator and PT lubricator to 500 psi(good test). Page 7/20 Report Printed: 8/14/2017 • 0 Operations Summary (with Timelog Depths) ,: 2G-15 CcmocaPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/27/2017 7/27/2017 1.50 COMPZN RPCOMP .•SLKL P RIH with 5'long 2-1/2"OD bailer to 0.0 0.0 10:00 11:30 6547'SLM,bail 2'and POOH. 7/27/2017 7/27/2017 1.50 COMPZN RPCOMP SLKL P Lay down 5'long 2-1/2"OD bailer and 0.0 0.0 11:30 13:00 MU 10'long 2-1/2"OD bailer. RIH to 6548 SLM,bail 2'and POOH. Bailer recovered pieces of metal and barite. MU 10'long 2-1/2"OD bailer. 7/27/2017 7/27/2017 1.00 COMPZN RPCOMP SLKL P RIH with bailer to 6650'SLM,bail and 0.0 0.0 13:00 14:00 POOH. Recovered hard scale. Lay down 2.5"OD bailer and MU 2"OD bailer. 7/27/2017 7/27/2017 1.00 COMPZN RPCOMP SLKL P RIH with bailer to 6550'SLM,bail and 0.0 0.0 14:00 15:00 POOH. Recovered hard scale. 7/27/2017 7/27/2017 0.75 COMPZN RPCOMP SLKL P MU 2.5"OD bailer,RIH to 6550'SLM, 0.0 0.0 15:00 15:45 bail and POOH. Recovered pieces of metal,barite and hard scale. MU 2.5" OD bailer. 7/27/2017 7/27/2017 1.25 COMPZN RPCOMP SLKL P RIH with bailer to 6550'SLM,bail and 0.0 0.0 15:45 17:00 POOH. 7/27/2017 7/27/2017 1.00 COMPZN RPCOMP SLKL P Lay down 2.5"bailer. MU 3.84"OD 0.0 0.0 17:00 18:00 lower swedge and 3.68"upper swedge. RIH to 6533'SLM,POOH and lay down swedges. 7/27/2017 7/27/2017 1.50 COMPZN RPCOMP SLKL P MU 2.5"OD bailer,RIH to 6550'SLM, 0.0 0.0 18:00 19:30 bail and POOH. Recovered nothing but mud. MU 2.5"OD bailer. 7/27/2017 7/27/2017 1.50 COMPZN RPCOMP SLKL P MU 2.5"OD bailer,RIH to 6550'SLM, 0.0 0.0 19:30 21:00 bail and POOH. Recovered nothing but mud. 7/27/2017 7/27/2017 2.00 COMPZN RPCOMP SLKL P Reconfigure the tool string and MU. 0.0 0.0 21:00 23:00 GR spear. RIH to 6550 SLM and POOH. Did not recover the junk catcher. 7/27/2017 7/28/2017 1.00 COMPZN RPCOMP SLKL P Reconfigure the tool string and MU 0.0 0.0 23:00 00:00 2.5"OD bailer and RIH. 7/28/2017 7/28/2017 1.50 COMPZN RPCOMP SLKL P Continue to RIH to 6550'SLM,bail 0.0 0.0 00:00 01:30 and POOH. Recovered nothing but mud. 7/28/2017 7/28/2017 2.00 COMPZN RPCOMP SLKL 'P RD HES slickline and RD the Dutch 0.0 0.0 01:30 03:30 riser. 7/28/2017 7/28/2017 0.50 COMPZN RPCOMP BHAH P PU and MU 2-3/8"mule shoe joint with 0.0 35.0 03:30 04:00 crossovers from 2-3/8"ST-L back to HT-38. 7/28/2017 7/28/2017 3.00 COMPZN RPCOMP TRIP P TIH with 2-3/8"mule shoe joint to 35.0 6,384.0 04:00 07:00 6384'MD 7/28/2017 7/28/2017 0.50 COMPZN RPCOMP PULD P Continue to RIH with 2-3/8"mule shoe 6,384.0 6,510.0 07:00 07:30 joint with DP from the pipe shed from 6384'to 6510'MD 7/28/2017 7/28/2017 1.50 COMPZN RPCOMP WASH P Obtain parameter: PU=140K,SO= 6,510.0 6,348.0 07:30 09:00 102K,rotating weight=12K at 10 RPM=3K ft.-lbs.torque and 3 BPM= 670 psi. Wash down from 6510'to tag at 6537'with 2K down(top of PBR). Continue to wash down to 6550'MD and set 5K down. Rotate at 10 RPM= 3K ft.-lbs.torque but unable to get any deeper. PU 2'off bottom to 6348', MD. 7/28/2017 7/28/2017 0.75 COMPZN RPCOMP CIRC P Circulate bottoms up at 5 BPM=1150 6,348.0 6,348.0 09:00 09:45 psi. Page 8/20 Report Printed: 8/14/2017 • i Operations Summary (with Timelog Depths) 2G-15 CottocoPhifllps Rig: DOYON 14 . Job: RECOMPLETION Time Log Start Depth Start Time End Time Dor(hr); Phase Op Code Activity Code Time P-T-X Operation {5K9) End Depth(&K6) 7/28/2017 7/28/2017 0.25 COMPZN RPCOMP TRIP P TOOH from 6548'to 6384'MD 6,348.0 6,384.0 09:45 10:00 7/28/2017 7/28/2017 1.00 COMPZN RPCOMP PRTS P PJSM. RU pressure testing 6,384.0 6,384.0 10:00 11:00 equipment. Attempt to PT the casing to 2500 psi but pumping away mud at 1 BPM=900 psi. RD pressure testing equipment. 7/28/2017 7/28/2017 1.00 COMPZN RPCOMP SLPC P PJSM. Slip and cut 53'(8 wraps)of 6,348.0 6,348.0 11:00 12:00 drilling line. 7/28/2017 7/28/2017 2.50 COMPZN RPCOMP TRIP P TOOH with 2-3/8"mule shoe joint from 6,348.0 35.0 12:00 14:30 6348'to 35'MD. 7/28/2017 7/28/2017 1.00 COMPZN RPCOMP BHAH P Lay down 2-3/8"mule shoe joint and 35.0 0.0 14:30 15:30 crossovers. Recovered junk catcher sub on the end of the mule shoe. Clean and clear the floor. 7/28/2017 7/28/2017 0.50 COMPZN RPCOMP SLKL P Call for a slickline unit. PU and install 0.0 0.0 15:30 16:00 the Dutch riser. 7/28/2017 7/28/2017 1.00 COMPZN RPCOMP WAIT P Wait for HES slickline to arrive 0.0 0.0 16:00 17:00 SimOps: General housekeeping and MP2's. 7/28/2017 7/28/2017 1.00 COMPZN RPCOMP SLKL P Mobilize HES slickline equipment to 0.0 0.0 17:00 18:00 the rig floor. 7/28/2017 7/28/2017 1.75 COMPZN RPCOMP SLKL P RU HES slickline with lubricator. . 0.0 0.0 18:00 19:45 7/28/2017 7/28/2017 0.25 COMPZN RPCOMP SLKL P PT the lubricator to 500 psi(good test) 0.0 0.0 19:45 20:00 7/28/2017 7/28/2017 1.00 COMPZN RPCOMP SLKL P RIH with prong pulling tool,pull the 0.0 0.0 20:00 21:00 prong,POOH and lay down the prong/pulling tool. 7/28/2017 7/28/2017 1.00 COMPZN RPCOMP SLKL P PU,MU and RIH CA-2 plug pulling 0.0 0.0 21:00 22:00 tool but unable to get into the PBR. POOH. 7/28/2017 7/28/2017 0.25 COMPZN RPCOMP SLKL P Reconfigure the tool string. 0.0 0.0 22:00 22:15 7/28/2017 7/28/2017 0.75 COMPZN RPCOMP SLKL P RIH,pull the CA-2 plug and POOH. 0.0 0.0 22:15 23:00 7/28/2017 7/29/2017 1.00 COMPZN RPCOMP SLKL P Lay down the CA-2 plug and pulling 0.0 0.0 23:00 00:00 tool string. RD the lubricator and RD HES slickline. 7/29/2017 7/29/2017 0.50 COMPZN RPCOMP SLKL P RD the Dutch riser. 0.0 0.0 00:00 00:30 7/29/2017 7/29/2017 1.50 COMPZN RPCOMP BHAH P PU and MU BHA#5-PBR spear 0.0 293.0 00:30 02:00 assembly. 7/29/2017 7/29/2017 2.25 COMPZN RPCOMP TRIP P TIH with BHA#5 to 6452'MD. 293.0 6,452.0 02:00 04:15 7/29/2017 7/29/2017 0.50 COMPZN RPCOMP FISH P Obtain parameter: PU=145K,SO= 6,452.0 6,533.0 04:15 04:45 105K and 2 BPM=500 psi. Wash down to top of the PBR at 6524'MD, shut down the pump,SO to tag at 6533'with 10K down and PU to 178K to engage the spear. 7/29/2017 7/29/2017 2.25 COMPZN RPCOMP JAR P Begin jarring at 230K with straight pull 6,533.0 6,533.0 04:45 07:00 to 350K. Jar down at 50K,straight pull to 350K and pulled free. 7/29/2017 7/29/2017 0.50 COMPZN RPCOMP SFTY P Post jarring derrick inspection. 6,533.0 6,533.0 07:00 07:30 Page 9/20 Report Printed: 8/14/2017 S 3,; Operations Summary (with Timelog Depths) • 2G-15 ConocoPhillips rtk;skae Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code': Time P-T-X Operation (CKB), End Depth(ftKD),. 7/29/2017 7/29/2017 0.50 COMPZN RPCOMP FISH P Make 2 turns to the left,set down 8K, 6,533.0 6,533.0 07:30 08:00 PU and no over pull. Establish circulation at 2 BPM=460 psi,SO to 6533'MD and pressure increased to 510 psi. Turn the pumps off and blow down the top drive. 7/29/2017 7/29/2017 2.50 COMPZN RPCOMP TRIP P TOOH from 6533'to 292'MD. 6,533.0 292.0 08:00 10:30 7/29/2017 7/29/2017 1.50 COMPZN RPCOMP BHAH P Lay down BHA#5-PBR spear 292.0 0.0 10:30 12:00 assembly. 7/29/2017 7/29/2017 1.00 COMPZN RPCOMP PULL P Recovered the packer mandrel. 16.0 0.0 12:00 13:00 Release the spear and lay down the packer mandrel. Clean and clear the floor. 7/29/2017 7/29/2017 4.00 COMPZN RPCOMP WAIT P Wait for fishing tool to arrive from 0.0 0.0 13:00 17:00 Deadhorse to fish parted packer. SimOps: Housekeeping, service/inspect the top drive,blow . down lines to the kill tanks,RD choke house,remove old tree from the cellar, and hang new tree in the cellar 7/29/2017 7/29/2017 1.00 COMPZN RPCOMP BHAH P PU and MU BHA#6-spear 0.0 226.0 17:00 18:00 assembly. 7/29/2017 7/29/2017 2.50 COMPZN RPCOMP TRIP P TIH with BHA#6 to 6480'MD 226.0 6,480.0 18:00 20:30 7/29/2017 7/29/2017 0.25 COMPZN RPCOMP FISH P Obtain parameter: PU=140K,SO= 6,480.0 6,550.0 20:30 20:45 105K and 1 BPM=430 psi. Wash down to top of the PBR at 6538'MD, shut down the pump,SO to tag at 6550'with 15K down and PU to 175K to engage the spear. 7/29/2017 7/29/2017 0.75 COMPZN RPCOMP JAR P Begin jarring at 240K with straight pull 6,550.0 6,550.0 20:45 21:30 to 350K. 7/29/2017 7/29/2017 0.25 COMPZN RPCOMP SFTY P Derrick inspection. 6,550.0 6,550.0 21:30 21:45 7/29/2017 7/29/2017 1.00 COMPZN RPCOMP JAR P Continue to jar at 240K with straight 6,550.0 6,550.0 21:45 22:45 pull to 350K. 7/29/2017 7/29/2017 0.25 COMPZN RPCOMP SFTY P Derrick inspection. 6,550.0 6,550.0 22:45 23:00 7/29/2017 7/30/2017 1.00 COMPZN RPCOMP JAR P Continue to jar at 240K with straight 6,550.0 6,550.0 23:00 00:00 pull to 350K. 7/30/2017 7/30/2017 0.25 COMPZN RPCOMP SFTY P Derrick inspection. 6,550.0 6,550.0 00:00 00:15 7/30/2017 7/30/2017 1.00 COMPZN RPCOMP JAR P Continue to jar at 240K with straight 6,550.0 6,550.0 00:15 01:15 pull to 350K. 7/30/2017 7/30/2017 0.25 COMPZN RPCOMP SFTY P Derrick inspection. 6,550.0 6,550.0 01:15 01:30 7/30/2017 7/30/2017 1.00 COMPZN RPCOMP JAR P Continue to jar at 240K with straight 6,550.0 6,550.0 01:30 02:30 pull to 350K. 7/30/2017 7/30/2017 0.25 COMPZN RPCOMP SFTY P Derrick inspection. 6,550.0 6,550.0 02:30 02:45 7/30/2017 7/30/2017 0.75 COMPZN RPCOMP JAR P Continue to jar at 240K with straight 6,550.0 6,550.0 02:45 03:30 pull to 350K. Notify town engineer and discuss options. Page 10/20 Report Printed: 8/14/2017 S • t' " " Operations Summary (with Timelog Depths) 2G-15 natfps •S.xka Rig: DOYON 14 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(ftK6).. 7/30/2017 7/30/2017 0.75 COMPZN RPCOMP FISH P Attempt to release the packer by right 6,550.0 6,550.0 03:30 04:15 hand release. Make a total of 15 right hand turns and work the turn down but unable to get the packer to release. 7/30/2017 7/30/2017 1.75 COMPZN RPCOMP FISH P Attempt to release the spear,rotate to 6,550.0 6,550.0 04:15 06:00 the right and work the DP from 190K to 90K. 7/30/2017 7/30/2017 0.50 COMPZN RPCOMP JAR P Continue to jar at 240K with straight 6,550.0 6,550.0 06:00 06:30 pull to 350K. 7/30/2017 7/30/2017 1.50 COMPZN RPCOMP FISH P PU to 175K rotate at 50 RPM=8-11K 6,550.0 6,550.0 06:30 08:00 ft-lbs torque and work the DP. 7/30/2017 7/30/2017 0.50 COMPZN RPCOMP SFTY P Post jarring derrick inspection. 6,550.0 6,550.0 08:00 08:30 7/30/2017 7/30/2017 2.00 COMPZN RPCOMP FISH P Continue to attempt to release the fish 6,550.0 6,550.0 08:30 10:30 jarring at 175K. PU to 175K.rotate at 50 RPM=10-12 ft-lbs torque,2 BPM =800-1040 psi and the spear pulled free. Total jar hits=255. 7/30/2017 7/30/2017 3.50 COMPZN RPCOMP TRIP P TOOH with BHA#6 from 6500'to 226' 6,500.0 226.0 10:30 14:00 MD. 7/30/2017 7/30/2017 1.00 COMPZN RPCOMP BHAH P Lay down BHA#6-spear assembly. 226.0 0.0 14:00 15:00 Recovered the entire BHA. Clear and clean the floor. 7/30/2017 7/30/2017 0.50 COMPZN RPCOMP SVRG P Change out the top drive dies and 0.0 0.0 15:00 15:30 inspect the saver sub. 7/30/2017 7/30/2017 1.00 COMPZN RPCOMP BHAH P Mobilize fishing tools to the rig floor. 0.0 222.0 15:30 16:30 PU and MU BHA#7-packer mill assembly. 7/30/2017 7/30/2017 3.75 COMPZN RPCOMP TRIP P TIH with BHA#7 to 6476'MD 222.0 6,476.0 16:30 20:15 7/30/2017 7/31/2017 3.75 COMPZN RPCOMP MILL P Obtain parameter: PU=140K,SO= 6,476.0 6,538.0 20:15 00:00 105K,rotating weight=120K at 60 RPM=4K ft-lbs free torque and 3 BPM=560 psi. Wash down at 1.5 BPM=420 psi to tag at 6516'MD with 10K down,SO 20K and continue to wash down to tag on the top of the packer at 6538'MD. Mill the packer;at 60-100 RPM=5-6K ft-lbs torque, 1-2 BPM=450-550 psi with 10-15K down. 7/31/2017 7/31/2017 3.00 COMPZN RPCOMP MILL P Continue to mill the packer at 60-100 6,538.0 6,539.0 00:00 03:00 RPM=5-6K ft-lbs torque, 1-2 BPM= 450-550 psi with 10-15K down. Milled to 6539'MD and stopped making progress. 7/31/2017 7/31/2017 2.50 COMPZN RPCOMP TRIP P PU to 6476'MD and blow down the 6,539.0 222.0 03:00 05:30 top drive. TOOH with BHA#7 from 6476'to 222'MD. 7/31/2017 7/31/2017 1.00 COMPZN RPCOMP BHAH P Lay down BHA#7-packer mill 222.0 0.0 05:30 06:30 assembly. The packer mill was rounded on outer edges and worn on the mill face. Clean out the boot baskets. Recovered metal in the boot baskets. 7/31/2017 7/31/2017 0.50 COMPZN RPCOMP BHAH P Break out worn packer mill and MU 0.0 0.0 06:30 07:00 new packer mill. 7/31/2017 7/31/2017 1.00 COMPZN WHDBOP WWWH P PU and MU stack washing tool. Jet 0.0 0.0 07:00 08:00 the BOP stack at 9 BPM. Page 11/20 Report Printed: 8/14/2017 • • , Operations Summary (with Timelog Depths) { 2G-15 ltlips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code, Time P-T-X Operation {ftKEB), End Depth MKS) 7/31/2017 7/31/2017 1.00 COMPZN WHDBOP MPSP P Drain the BOP stack,pull the wear 0.0 0.0 08:00 09:00 ring and install the test plug. 7/31/2017 7/31/2017 1.00 COMPZN WHDBOP RURD P Fill the BOP stack and choke manifold 0.0 0.0 09:00 10:00 with fresh water. RU BOPE testing equipment. Shell test the BOP stack to 250/4000 psi. 7/31/2017 7/31/2017 6.00 COMPZN WHDBOP BOPE P Conduct weekly BOPE test: test 2= 0.0 0.0 10:00 16:00 7/8"x 5"VBR's(upper pipe rams)to 250/4000 psi with 3-1/2"and 4"test joints;test 2-7/8"x 5"VBR's(lower pipe rams)to 250/4000 psi with 3-1/2" and 4"test joints;test annular to 250/2500 with 3-1/2"and 4"test joint; conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Brian Bixby via email on 7/30/17 at 16:21 hours. Tests: 1) Annular with 4"test joint,kill valve 20,choke valves 12, 13&14 to 250/2500 psi(Passed) 2) 2-7/8"x 5"VBR's(upper pipe rams)with 4"test joint,kill valve 20, choke valves 12, 13&14(Passed) 3) Upper IBOP,HCR kill,choke valve 9&11 (Passed) 4) Lower IBOP,manual kill,choke valves 5,8&10(Passed) 5) 4"TIW,choke valves 4,6&7 (Passed) 6) 4"dart valve,choke 2(Passed) 7) HCR choke(Passed) 8) Manual choke(Passed) 9) 2-7/8"x 5"VBR's(lower pipe rams) with 4"test joint(Passed) 10) Blind ram,choke valve 3 • (Passed) 11) Annular with 3-1/2"test joint to 250/2500(Passed) 12) Super choke and manual choke (Passed) 13) 2-7/8"x 5"VBR's(upper pipe rams)with 3-1/2"test joint(Passed) 14) 2-7/8"x 5"VBR's(lower pipe rams)with 3-1/2"test joint(Passed) 15) 3-1/2"EUE 8rd TIW(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3100 psi Accumulator Pressure After Closer= 1700 psi Pressure Gain of 200 psi=45 seconds Full System=215 Seconds Average N2(6 Bottles)=2033 psi 7/31/2017 7/31/2017 1.00 COMPZN WHDBOP RURD P RD BOPE testing equipment. Drain 0.0 0.0 16:00 17:00 the BOP stack and pull the test plug. PU and MU wear ring pulling tool. Install the wear ring but unable to release the running tool. POOH and inspect. • Page 12/20 Report Printed: 8/14/2017 • • Operations Summary (with Timelog Depths) 4, it 2G-15 ConocoPhitiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKE 7/31/2017 7/31/2017 0.50 COMPZN RPCOMP BHAH P PU packer milling assembly,break out 0.0 0.0 17:00 17:30 the bumper sub,lay down the bumper sub,MU the packer milling assembly and lay down in the pipe shed. 7/31/2017 7/31/2017 0.50 COMPZN RPCOMP RURD P Re-dress the wear ring running tool, 0.0 0.0 17:30 18:00 install the wear ring and lay down the wear ring running tool. 7/31/2017 7/31/2017 0.50 COMPZN WHDBOP RURD P Blow down the choke manifold,choke 0.0 0.0 18:00 18:30 line and kill line. 7/31/2017 7/31/2017 0.75 COMPZN RPCOMP BHAH P PU and MU BHA#8-packer mill 0.0 274.0 18:30 19:15 assembly 7/31/2017 7/31/2017 2.25 COMPZN RPCOMP TRIP P TIH with BHA#8 to 6496'MD 274.0 6,496.0 19:15 21:30 7/31/2017 7/31/2017 1.75 COMPZN RPCOMP MILL P Obtain parameter: PU= 140K,SO= 6,496.0 6,539.0 21:30 23:15 105K,rotating weight=120K at 60 RPM=3K ft-lbs free torque and 3 BPM=580 psi. Wash down at 1/2 BPM=265 psi to tag at 6539'MD with 10K down. Mill the packer at 65 RPM =3-6K ft-lbs torque, 1/2-3 BPM=260- 450 psi with 8-15K down. 7/31/2017 7/31/2017 0.50 COMPZN RPCOMP CIRC P Circulate a bottoms up at 6.5 BPM= 6,539.0 6,539.0 23:15 23:45 1560 psi with resin,sand and metal shaving coming over the shakers. 7/31/2017 8/1/2017 0.25 COMPZN RPCOMP MILL P Continue to mill on the packer 5-70 6,539.0 6,539.0 23:45 00:00 RPM=3-6K ft-lbs torque,1/2-3 BPM= 260-450 psi with 8-15K down. 8/1/2017 8/1/2017 2.00 COMPZN RPCOMP MILL P Continue to mill on the packer 5-70 6,539.0 6,539.0 00:00 02:00 RPM=3-6K ft-lbs torque,1/2-3 BPM= 260-450 psi with 8-15K down. Milled 4"and stopped making progress. 8/1/2017 8/1/2017 1.00 COMPZN RPCOMP CIRC P Circulate and condition the mud at 7 6,539.0 6,539.0 02:00 03:00 BPM=1850 psi with resin,sand and metal shaving coming over the shakers. . 8/1/2017 8/1/2017 2.75 COMPZN RPCOMP TRIP P TOOH with BHA#8 from 6539'-274' 6,539.0 274.0 03:00 05:45 MD. 8/1/2017 8/1/2017 1.00 COMPZN RPCOMP BHAH P Lay down BHA#8-packer mill 274.0 0.0 05:45 06:45 assembly-showed bluing on the face of the mill,indicating spinning and heating of the contact area 8/1/2017 8/1/2017 1.50 COMPZN RPCOMP BHAH P Build spear BHA#9(Spear assembly 0.0 221.0 06:45 08:15 with 3.95"Grapple)and RIH w/BHA to 221-ft 8/1/2017 8/1/2017 2.00 COMPZN RPCOMP TRIP P RIH w/BHA#9 from 221-ft to 6,475-ft 221.0 6,475.0 08:15 10:15 8/1/2017 8/1/2017 1.50 COMPZN RPCOMP FISH P Obtain parameters:UP wt=140K,DN 6,475.0 6,539.0 10:15 11:45 wt=105K,Wash down from 6,475-ft to 6,539-ft. Set down 5K to 20K, rotate 2 turns to the left-PU no signs of grapple over pull. work for 30 minutes with no signs or pressure increases-Blow down Top drive. 8/1/2017 8/1/2017 2.50 COMPZN RPCOMP TRIP P POOH from 6,539-ft to 221-ft 6,539.0 221.0 11:45 14:15 Page 13/20 Report Printed: 8/14/2017 • • Operations Summary (with Timelog Depths) err ' .�.. 2G-15 p iiilps . Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code:. Time P-T-X Operation (ftKB), End Depth(ftKE). 8/1/2017 8/1/2017 2.25 COMPZN RPCOMP BHAH P POOH w/BHA and recovered.25"of 221.0 0.0 14:15 16:30 the 1.583"double thread pin from the of the hydraulic slip receptacle that screws into the Packing Element mandrel and the bottom of the grapple shows wear signs of trying to enter the reduced ID of this mandrel of 3.656"±. Clean and clear floor-Call Baker shop and verify the next desired tools to run in order to place proper grapple engagement due to ID changes with in the tube body. Break down and lay down spear- Shorter spear and grapple in route. 8/1/2017 8/1/2017 1.25 COMPZN RPCOMP BHAH P Bring spear assembly to rig floor. PU, 0.0 219.0 16:30 17:45 MU and RIH w/BHA#10 Short 9487 spear assembly(3.681"grapple)to 219'MD. 8/1/2017 8/1/2017 2.50 COMPZN RPCOMP TRIP P RIH w/BHA#10 from 219-ft to 6,473- 219.0 6,473.0 17:45 20:15 ft 8/1/2017 8/1/2017 1.50 COMPZN RPCOMP SLPC P Slip and cut 52'drilling line. • 6,473.0 6,473.0 20:15 21:45 8/1/2017 8/1/2017 0.75 COMPZN RPCOMP SVRG P Inspect saver sub,service top drive. 6,473.0 6,473.0 21:45 22:30 8/1/2017 8/1/2017 1.00 COMPZN RPCOMP CIRC P Obtain parameters.PU=140K 6,473.0 6,473.0 22:30 23:30 SO=107K.CBU at 5 bpm, 1450 psi. 8/1/2017 8/2/2017 0.50 COMPZN RPCOMP FISH P Wash down from 6476'MD to 6539' 6,473.0 6,464.0 23:30 00:00 MD.Tag packer and set down 20K. Pick up 5'w/5-15K overpull.Shut down pump.RIH and push packer to 6571'MD.Set down 20K.Pick up from 6571'MD to 6464'MD w/15K overpull up to 6524'MD and 5K overpull after 6524'MD. 8/2/2017 8/2/2017 1.50 COMPZN RPCOMP CIRC P Circulate and condition mud.5 bpm, 6,464.0 6,464.0 00:00 01:30 2000 psi. 8/2/2017 8/2/2017 0.25 COMPZN RPCOMP OWFF P Monitor well.Static. 6,464.0 6,464.0 01:30 01:45 8/2/2017 8/2/2017 3.75 COMPZN RPCOMP TRIP P POOH from 6,464-ft to 219-ft 6,464.0 219.0 01:45 05:30 8/2/2017 8/2/2017 1.00 COMPZN RPCOMP BHAH P Lay down intensifier.Stand back DC's. 219.0 0.0 05:30 06:30 Lay down fish.Recover packer and tailpipe assy. 8/2/2017 8/2/2017 0.50 COMPZN RPCOMP BHAH P Clean and clear rig floor.Mobilize 0.0 0.0 06:30 07:00 clean out BHA to rig floor. 8/2/2017 8/2/2017 1.50 COMPZN WELLPR BHAH P PJSM-Make up clean out BHA#11 to 0.0 252.0 07:00 08:30 252'MD. 8/2/2017 8/2/2017 3.00 COMPZN WELLPR TRIP P RIH with BHA#11 from 252'MD to 252.0 6,317.0 08:30 11:30 6317'MD.Obtain parameters. PU=140K SO=104K Rot=120K,50 rpm,3K tq. 8/2/2017 8/2/2017 3.50 COMPZN WELLPR REAM P Wash and ream down from 6300'MD 6,317.0 6,820.0 11:30 15:00 to 6820'MD.5 bpm, 1240 psi,22% FO,50 rpm,3-5K tq,2-10K WOB. Page 14/20 Report Printed: 8/14/2017 • • Operations Summary (with Timelog Depths) u 2G-15 Ccan004phitups Rig: DOYON 14 Job: RECOMPLETION Time Log start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(5KB) 8/2/2017 8/2/2017 1.00 COMPZN WELLPR CIRC P Circulate 2x surface to surface.Rotate 6,820.0 6,820.0 15:00 16:00 and reciprocate from 6820'MD to 6790'MD.8 bpm,2490 psi,32%FO, 20 rpm,3K tq.MW in and out=13.9 PP9. 8/2/2017 8/2/2017 0.50 COMPZN WELLPR TRIP P POOH from 6820'MD to 6413'MD. 6,820.0 6,413.0 16:00 16:30 PU=150K 8/2/2017 8/2/2017 0.50 COMPZN WELLPR OWFF P Monitor well.Static.Blow down top 6,413.0 6,413.0 16:30 17:00 drive.PJSM for POOH. 8/2/2017 8/2/2017 2.50 COMPZN WELLPR TRIP P POOH from 6413'MD to 252'MD. 6,413.0 252.0 17:00 19:30 8/2/2017 8/2/2017 1.00 COMPZN WELLPR BHAH P Lay down BHA#11.Clean magnets 252.0 0.0 19:30 20:30 and boot baskets. 8/2/2017 8/2/2017 1.00 COMPZN WELLPR BHAH P Clean and clear rig floor. 0.0 0.0 20:30 21:30 8/2/2017 8/3/2017 2.50 COMPZN WELLPR TRIP P Make up Baker TST-3 test packer and 0.0 4,759.0 21:30 00:00 RIH to 4759'MD 8/3/2017 8/3/2017 1.25 COMPZN WELLPR TRIP P Continue to RIH w/Baker TST-3 R& 4,759.0 6,371.0 00:00 01:15 S test packer from 4,759-ft to 6,371-ft 8/3/2017 8/3/2017 0.25 COMPZN WELLPR MPSP P MU std#68 and RIH to 6,420-ft 6,371.0 6,420.0 01:15 01:30 (Center of Element on Test packer). 135K Up wt, 107K DN wt. Rotationally set test packer and slack off 20K 8/3/2017 8/3/2017 0.50 COMPZN WELLPR PRTS P Pressure up IA to 1,180 psi at.5 bpm- 6,420.0 6,420.0 01:30 02:00 able to pump away at 1 bpm at 1,100 psi Total stks pumped=18 (Failed test) 8/3/2017 8/3/2017 0.25 COMPZN WELLPR TRIP T POOH from 6,420-ft to 5,978-ft 6,420.0 5,978.0 02:00 02:15 8/3/2017 8/3/2017 0.25 COMPZN WELLPR MPSP T Slack off and set test packer at 5,993- 5,978.0 5,978.0 02:15 02:30 ft Center Of element on test packer 8/3/2017 8/3/2017 0.50 COMPZN WELLPR PRTS T Pressure up IA to 900 psi at.5 bpm- 5,978.0 5,978.0 02:30 03:00 able to pump away at.5 bpm at 900 psi Total stks pumped=13 (Failed test) 8/3/2017 8/3/2017 0.25 COMPZN WELLPR TRIP T PU and POOH from 5,978-ft to 5,500- 5,978.0 5,500.0 03:00 03:15 ft 8/3/2017 8/3/2017 0.25 COMPZN WELLPR MPSP T Slack off and set test packer at 5,485- 5,500.0 5,500.0 03:15 03:30 ft Center Of element on test packer 8/3/2017 8/3/2017 0.50 COMPZN WELLPR PRTS T Pressure up to 2,500 psi in 15 strokes 5,500.0 5,500.0 03:30 04:00 and hold pressure for 5 minutes(Gpod Test) -Bleed of pressure 8/3/2017 8/3/2017 0.25 COMPZN WELLPR MPSP T Release test packer and RIH from 5,500.0 5,694.0 04:00 04:15 5,500-ft to 5,694-ft Rotationally set packer w/Center of element at 5,709- ft 8/3/2017 8/3/2017 0.25 COMPZN WELLPR PRTS T Pressure up to 2,500 psi in 14 strokes 5,694.0 5,694.0 04:15 04:30 and hold pressure for 5 minutes(Good Test) -Bleed of pressure 8/3/2017 8/3/2017 0.25 COMPZN WELLPR MPSP T Release test packer and RIH from 5,694.0 5,884.0 04:30 04:45 5,694-ft to 5,884-ft Rotationally set packer w/Center of element at 5,899- ft Page 15/20 Report Printed: 8/14/2017 • • `' Operations Summary (with Timelog Depths) 0 ., 2G-15 ConoccPhillips Rig: DOYON 14 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(ftK9); 8/3/2017 8/3/2017 0.25 COMPZN WELLPR PRTS T Pressure up IA to 1,100 psi at.5 bpm- 5,884.0 5,789.0 04:45 05:00 able to pump away at.5 bpm Total stks pumped= 15 (Failed test) PU to 5,804-ft Center of element Slack off 20K and attempt to pressure test- Pumping away.5 bpm at 900 psi. PU and release packer into run position and blow down kill line,while discussing results with Town engr. - decision made was to POOH laying DP • 8/3/2017 8/3/2017 1.50 COMPZN WELLPR PULD T POOH laying down 24 jts of 4"DP 5,789.0 5,170.0 05:00 06:30 from 5,789-ft to 5,170-ft-directed to stop while discussing operational decisions-Change in scope to POOH and RIH w/Baker Model"G"bridge plug and Baker TST-3 R&S test packer in tandem 8/3/2017 8/3/2017 2.50 COMPZN WELLPR TRIP T POOH w/Baker TST-3 R&S test 5,170.0 0.0 06:30 09:00 packer from 5,170-ft to surface 8/3/2017 8/3/2017 1.00 COMPZN WELLPR BHAH T PJSM,(Drain BOP stack to observe 0.0 30.0 09:00 10:00 Tools as they run through well head), PU,MU and RIH w/Baker Model"G" bridge plug and Baker TST-3 R&S test packer in tandem to 30-ft 8/3/2017 8/3/2017 2.00 COMPZN WELLPR TRIP T Continue to RIH w/Baker Model"G" 30.0 2,777.0 10:00 12:00 bridge plug and Baker TST-3 R&S test packer in tandem on DP from 30- ft to 2777'MD.Calc disp=15 bbl Act disp=25.4 bbl 8/3/2017 8/3/2017 0.50 COMPZN WELLPR CIRC T Fill DP w/11 bbls..Circ DP volume.2 2,777.0 2,777.0 12:00 12:30 bpm,280 psi, 10%FO 8/3/2017 8/3/2017 1.00 COMPZN WELLPR TRIP T Continue to RIH w/Baker Model"G" 2,777.0 3,346.0 12:30 13:30 bridge plug and Baker TST-3 R&S test packer in tandem on DP from 2777'MD to 3346'MD.Calc disp=2.6 bbl Act disp=6.7 bbl.Fill pipe w/6 bbls. 8/3/2017 8/3/2017 2.50 COMPZN WELLPR TRIP T Continue to RIH w/Baker Model"G" 3,346.0 6,420.0 13:30 16:00 bridge plug and Baker TST-3 R&S test packer in tandem on DP from 3346'MD to 6417'MD.Fill pipe every 5 stds. Page 16/20 Report Printed: 8/14/2017 • • Operations Summary (with Timelog Depths) 2G-15 imps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time PTX Operation MKS) End Depth(ftKD)> 8/3/2017 8/3/2017 4.50 COMPZN WELLPR PRTS T Obtain parameters.PU=135K 6,420.0 6,380.0 16:00 20:30 So=105K.Set"G"bridge plug at 6420' COE.Space out and set test packer at 6400'COE.Test casing from 6400' MD to 6420'MD to 1500 psi/5 min. Charted.PU and set test packer at 6350'COE.Test casing from 6350' MD to 6420'MD to 2500 psi.Test good.PU and set test packer at 5780' COE.Test casing from 5780'MD to 6420'MD.Test failed.Test casing from surface to 5780'MD to 2500 psi. Good test.RIH and set test packer at 5800'COE.Test casing from surface to 5800'MD.Test failed.Test casing from 5800'MD to 6420'MD.Test failed.RIH and set test packer at 6300'COE.Test casing from 6300' MD to 6420'MD to 2500 psi.Good test.Release test packer and RIH to 6380'MD 8/3/2017 8/3/2017 0.50 COMPZN WELLPR CIRC T CBU.4 bpm,675 psi, 19%FO.MW in 6,380.0 6,380.0 20:30 21:00 and out=13.9 ppg 8/3/2017 8/3/2017 0.50 COMPZN WELLPR MPSP T RIH from 6380'MD to 6420'MD. 6,380.0 6,420.0 21:00 21:30 Engage and release Baker G bridge plug. 8/3/2017 8/3/2017 0.25 COMPZN WELLPR OWFF T Monitor well.Static. 6,420.0 6,420.0 21:30 21:45 8/3/2017 8/3/2017 0.25 COMPZN WELLPR RURD T Blow down top drive and kill line. 6,420.0 6,420.0 21:45 22:00 8/3/2017 8/4/2017 2.00 COMPZN WELLPR TRIP T POOH from 6420'MD to 2570'MD. 6,420.0 2,570.0 22:00 00:00 8/4/2017 8/4/2017 1.25 COMPZN WELLPR TRIP T POOH from 2570'MD to surface. 2,570.0 0.0 00:00 01:15 8/4/2017 8/4/2017 0.25 COMPZN WELLPR BHAH T Release RBP from running tool.Lay 0.0 0.0 01:15 01:30 down test packer and RBP. 8/4/2017 8/4/2017 1.00 COMPZN RPCOMP RURD P Rig up to run 3 1/2"lower completion 0.0 0.0 01:30 02:30 8/4/2017 8/4/2017 0.50 COMPZN RPCOMP PUTB P PU 3 jts 4 1/2"wearsox,3 jts 3 1/2" 0.0 301.0 02:30 03:00 9.3#L-80 EUE-m 8rd tubing,2.813" DS nipple assy and PBR/packer assy. 8/4/2017 8/4/2017 12.50 COMPZN RPCOMP PUTB P Pick up and RIH with 3 1/2"9.3#L-80 301.0 6,687.0 03:00 15:30 EUE-m 8rd tubing to 6720'MD.PU to put pipe in tension to 6687'MD. PU=93K SO=80K. 8/4/2017 8/4/2017 2.75 COMPZN RPCOMP ELOG P PJSM-Rig up Pollard a-line, 6,687.0 6,687.0 15:30 18:15 lubricator.Make up GR/CCL and RBP. 8/4/2017 8/4/2017 4.25 COMPZN RPCOMP ELOG P RIH w/e-line.Log from 6570'WLM up 6,687.0 6,687.0 18:15 22:30 to 6150'WLM.Tie in w/K-1 marker at 6461'MD.Set RBP at 6433'WLM. POOH w/wireline.Rig down wireline. Page 17/20 Report Printed: 8/14/2017 • • Operations Summary (with Timelog Depths) 2G-15 Co oco hiH i ps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Cade Time P-T-X Operation MKS); End Depth MKS), 8/4/2017 8/4/2017 0.50 COMPZN RPCOMP PACK P Rig up to set packer.Pick up 7'setting 6,687.0 6,360.0 22:30 23:00 mule shoe at 6680'MD.Pressure up to 2500 psi and hold for 3 mins.Set down 20K. Pick up to 20K overpull to verify packer set.Slack off to 95K. Pressure up to 1800 psi and shear PBR.Bleed off pressure.Pick up to clear seals from PBR to 6360'MD. RBP set in first full joint 3 1/2"tubing below packer at 6426'MD. 8/4/2017 8/4/2017 0.75 COMPZN RPCOMP CIRC P CBU.3.5 bpm,450 psi. 6,360.0 6,360.0 23:00 23:45 8/4/2017 8/5/2017 0.25 COMPZN RPCOMP OWFF P Monitor well.Static. 6,360.0 6,360.0 23:45 00:00 8/5/2017 8/5/2017 0.75 COMPZN RPCOMP PULD P Back out top drive.Lay down 5 jts 3 6,360.0 6,203.0 00:00 00:45 1/2"tubing to pipe shed from 6360' MD to 6203'MD. 8/5/2017 8/5/2017 4.25 COMPZN RPCOMP TRIP P POOH standing back 3 1/2"tubing 6,203.0 0.0 00:45 05:00 from 6203'MD to surface.Change out seal rings. 8/5/2017 8/5/2017 0.75 COMPZN RPCOMP BHAH P Clean and clear rig floor. Lay down 0.0 0.0 05:00 05:45 seal assy. 8/5/2017 8/5/2017 0.75 COMPZN RPCOMP BHAH P Moblilize and make up 2 3/8" 0.0 51.0 05:45 06:30 stinger/test packer BHA. 8/5/2017 8/5/2017 3.25 COMPZN RPCOMP TRIP P RIH with stinger/test packer from 51' 51.0 6,409.0 06:30 09:45 MD to 6414'MD.No-go at 6414'MD. Pick up to 6409'MD.Set test packer. PU=135K SO=103K. Calc disp=35 bbls Act disp=36 bbls. 8/5/2017 8/5/2017 0.75 COMPZN RPCOMP PRTS P Rig up to test FHL packer.Test packer 6,409.0 6,409.0 09:45 10:30 to 2500 psi/30 min charted 8/5/2017 8/5/2017 0.75 COMPZN RPCOMP RURD P Release test packer.Rig up to 6,409.0 6,409.0 10:30 11:15 displace well to seawater. 8/5/2017 8/5/2017 0.50 COMPZN RPCOMP SEQP P Rig up and test lines to 2700 psi. 6,409.0 6,409.0 11:15 11:45 8/5/2017 8/5/2017 1.25 COMPZN RPCOMP DISP P Perform seawater displacement. 6,409.0 6,409.0 11:45 13:00 Pump 30 bbl hi-vis 13.9 ppg mud spacer,80 bbls hi-vis 8.6 ppg seawater spacer,260 bbls 8.6 ppg seawater.5 bpm, ICP=1500 psi- FCP=600 psi.Pump total of 370 bbls with 370 bbls of returns. 8/5/2017 8/5/2017 0.50 COMPZN RPCOMP OWFF P Monitor well.Static.Sim-ops/Mix 30 6,409.0 6,409.0 13:00 13:30 bbl hi-vis seawater sweep. 8/5/2017 8/5/2017 0.50 COMPZN RPCOMP CLEN P Flush all lines with clean seawater. 6,409.0 6,409.0 13:30 14:00 Clean returns trough • 8/5/2017 8/5/2017 1.00 COMPZN RPCOMP CIRC P Pump 30 bbl hi-vis seawater sweep 6,409.0 6,409.0 14:00 15:00 followed by clean 8.6 ppg seawater surface to surface.5 bpm at 370 psi. 8/5/2017 8/5/2017 0.25 COMPZN RPCOMP OWFF P Monitor well.Static. 6,409.0 6,409.0 15:00 15:15 8/5/2017 8/5/2017 7.75 COMPZN RPCOMP PULD P PJSM-POOH laying down DP from 6,409.0 0.0 15:15 23:00 6409'MD to surface.Lay down 207 jts DP. 8/5/2017 8/5/2017 0.50 COMPZN RPCOMP RURD P Make up running tool and pull 0.0 0.0 23:00 23:30 wearring.Lay down running tool and wearring. Page 18/20 Report Printed: 8/14/2017 S f " Operations Summary (with Timelog Depths) Yg w z �F G 2G-15 ConnocoPhillips ,r:f.:3 Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (5K8) End Depth MKS)f` 8/5/2017 8/6/2017 0.50 COMPZN RPCOMP WWWH P Make up stack washer.Flush BOPE 0.0 0.0 23:30 00:00 and wellhead. 8/6/2017 8/6/2017 0.75 COMPZN RPCOMP RURD P Blow down top drive.Rig up to run 3 0.0 0.0 00:00 00:45 1/2"upper completion. 8/6/2017 8/6/2017 7.50 COMPZN RPCOMP TRIP P PJSM-RIH from derrick with 3 1/2"L- 0.0 6,380.0 00:45 08:15 80 9.3#EUE 8rd Mod upper completion as per detail.No-go at 6395'MD.Set down 5K,locating seals in PBR.Pick up to clear seals of PBR to 6380'MD. Torque to 2240 ft/lbs. No rejects, 1 remake. 8/6/2017 8/6/2017 3.25 COMPZN RPCOMP CRIH P Displace well with 8.6 ppg corrosion 6,380.0 6,380.0 08:15 11:30 inhibited seawater.2 bpm, 100 psi. Pump 290 bbls,return 290 bbls to kill tank. 8/6/2017 8/6/2017 0.50 COMPZN RPCOMP HOSO P RIH and space out seals 3'from fully 6,380.0 6,389.0 11:30 12:00 located.Pressure up tubing to 2000 psi and set upper FHL packer.Shear out PBR holding 2000 psi.Test IA to 2500 psi/5 min.Charted. 8/6/2017 8/6/2017 1.25 COMPZN RPCOMP HOSO P PJSM-Lay down joints 201,200 and 6,389.0 5,722.0 12:00 13:15 199. Make up 2 space out pup jts. (10.17'and 10.28').Pick up jt.#199. 8/6/2017 8/6/2017 1.25 COMPZN RPCOMP THGR P Make up tubing hanger and landing 5,722.0 5,760.0 13:15 14:30 joint.Land hanger. RILDS. PU=95K SO-85K 8/6/2017 8/6/2017 0.75 COMPZN RPCOMP PRTS T Test tubing to 3000 psi.w/IA open to 5,760.0 5,760.0 14:30 15:15 atmosphere.Pressure bled slowly and flow observed at annulus valve. Monitor pressure to determine if pressure would stabilize.Pressure bled to 1100 psi in 45 mins and did not stabilize. 8/6/2017 8/6/2017 0.75 COMPZN RPCOMP PRTS T Test IA to 2500 psi while holding 1100 5,760.0 5,760.0 15:15 16:00 psi on tubing for 30 mins on chart. Good test with no indication of communication with tubing.Final pressures=2650 psi on IA and 1800 psi on tubing.Bleed off IA and then tubing. 8/6/2017 8/6/2017 0.75 COMPZN RPCOMP PRTS T Pressure up on tubing to 3000 psi with 5,760.0 5,760.0 16:00 16:45 IA shut in.Pressure decreased on • tubing to 2450 psi and increased on IA to 400 psi.Bleed off IA then tubing. 8/6/2017 8/6/2017 0.50 COMPZN RPCOMP PRTS T Pressure up IA to 1200 psi and hold 5,760.0 5,760.0 16:45 17:15 for 5 mins.No pressure increase on tubing.Pressure up tubing to 3000 psi while holding 1200 psi on IA.Pressure on IA increased to 1400 psi and pressure on tubing bled to 2500 psi. Bleed off IA and then tubing. 8/6/2017 8/6/2017 0.75 COMPZN RPCOMP HOSO T BOLDS.Pull and lay down hanger. 5,760.0 5,722.0 17:15 18:00 Pick up two jts tubing and locate seals stinging into PBR while pumping at.5 bpm at 50 psi.Observed pressure increase to 80 psi and seals entered PBR.No-go at top of PBR.Lay down two joints of tubing.Redress hanger in pipeshed. Page 19/20 Report Printed: 8/14/2017 • • Operations Summary (with Timelog Depths) Rc, �rRt 2G-15 ConocaPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time s Our Phase Op Code Activity Code Time P-T-X Operation (ftKB)', End Depth(ftKS) 8/6/2017 8/6/2017 0.75 COMPZN RPCOMP HOSO T Confirm joint lengths. Make up 2.34' 5,722.0 5,724.0 18:00 18:45 space out pup 8/6/2017 8/6/2017 0.75 COMPZN RPCOMP THGR T Make up hanger and landing joint. 5,724.0 5,760.0 18:45 19:30 Land hanger.RILDS. 8/6/2017 8/6/2017 1.00 COMPZN RPCOMP PRTS T Test tubing to 3000 psi.Pressure bled 5,760.0 5,760.0 19:30 20:30 to 2425 psi in 15 mins.Bleed tubing to 1500 psi.Test IA to 2500 psi/30 mins. Good test. Consult with workover engineer. 8/6/2017 8/6/2017 0.75 COMPZN RPCOMP PRTS T Bleed off IA and then tubing.Pressure 5,760.0 5,760.0 20:30 21:15 up IA and shear SOV at 2300 psi. Perform CMIT to 2500 psi/30 mins. Good. 8/6/2017 8/6/2017 0.25 COMPZN RPCOMP RURD P Bleed off pressure.Rig down test 5,760.0 0.0 21:15 21:30 equip.Lay down landing joint. 8/6/2017 8/6/2017 0.50 COMPZN WHDBOP MPSP P Rig up and set HP BPV.Test BPV to 0.0 0.0 21:30 22:00 1000 psi/10 mins in direction of flow. 8/6/2017 8/6/2017 1.00 COMPZN WHDBOP NUND P Blow down and rig down lines in 0.0 0.0 22:00 23:00 cellar.Pull riser. 8/6/2017 8/7/2017 1.00 COMPZN WHDBOP SVRG P PJSM-Nipple down flow nipple.Install 0.0 0.0 23:00 00:00 tater masher in preparation of changing out annular preventer packing element. 8/7/2017 8/7/2017 5.25 COMPZN WHDBOP SVRG P Install Potato Masher,RU 5"drill pipe 0.0 0.0 00:00 05:15 jt. Break cap,Remove oil from housing. Remove old element. Install new element-change out seals and install cap. remove Potato masher and NU Bell nipple 8/7/2017 8/7/2017 2.25 COMPZN WHDBOP NUND P Remove mouse holes and drain stack. 0.0 0.0 05:15 07:30 ND BOPE,Remove choke and kill lines. Set back stack 8/7/2017 8/7/2017 1.50 COMPZN WHDBOP NUND P NU 3-1/8 5M x 7-1/16"5M Tree 0.0 0.0 07:30 09:00 adapter-Test extended neck seals at 250/5,000 psi for 10 minutes- witnessed by Randy Dolcater. 8/7/2017 8/7/2017 1.00 COMPZN WHDBOP NUND P NU 3-1/8"5M Tree and orient as per 0.0 0.0 09:00 10:00 picture and Pad operator 8/7/2017 8/7/2017 0.50 COMPZN WHDBOP PRTS P Pressure test tree at 250/5,000 psi- 0.0 0.0 10:00 10:30 good test 8/7/2017 8/7/2017 0.25 COMPZN WHDBOP MPSP P Pull test dart and BPV 0.0 0.0 10:30 10:45 8/7/2017 8/7/2017 1.25 COMPZN WHDBOP FRZP P RU Little Red Services and PT lines to 0.0 0.0 10:45 12:00 250-2,800 psi--Pump 72 bbls of diesel into the IA taking returns trough the SOV at 5,688-ft up the TBG to the kill tank.-200 ICP 300 FCP 8/7/2017 8/7/2017 1.00 COMPZN WHDBOP OTHR P Allow well to swap,Blow down lines 0.0 0.0 12:00 13:00 and rig down hard lines. 8/7/2017 8/7/2017 0.25 COMPZN WHDBOP MPSP P Install BPV 0.0 0.0 13:00 13:15 8/7/2017 8/7/2017 0.75 DEMOB MOVE RURD P Dress the tree. Secure well. 0.0 0.0 13:15 14:00 Release Doyon 14 at 14:00 hrs on 8-7 -17 Page 20/20 Report Printed: 8/14/2017 r.' L , KUP irD 2G-15 Conocci hillips �` Well Attribut Max Angle D TD A1)95( It1L; ' Wellbore API/UWI Field Name Wellbore Status incl(°) MD(ftKB( Act Atm(ftKB) Conocethidips'0 500292116200 KUPARUK RIVER UNIT PROD 47.88 6,000.00 6,997.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date DEVIATED-2G-15,9/520173:29:35 PM SSSV:NONE 150 11/1/2014 Last WO 7/20/2017 35.00 10/16/1984 VerScal.schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 6,835.0 8/13/2017 Rev Reason:W/O,SET WRP 8 CATCHER,GLV jennalt 9/5/2017 Hangar;32.0 --TV; C/0,PULL WRP 8 CATCHER,TAG _ Casing Strings Casing Description OD(in) ID(in) Top(MOB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 105.0 105.0 62.50 H-40 WELDED Casing DescriptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 34.0 2,726.5 2,726.1 36.00 J-55 BUTT I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.1 6,983.0 6,336.3 26.00 J-55 BUTT M CONDUCTOR;35.0-105.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection 3-1/2 Upper Gas lift 3 1/2 2.992 0.0 5,757.2 5,495.6 9.30 L-80 EUE 8rd Mod GAS LIFT;2,491.511, completion 2017 RWO Li Completion Details Nominal ID Top(ftKB( Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 32.0 32.0 0.23 Hanger Tubing Hanger,McEvoy,MSDP,7-1/16"x 3-1/2"EUE 8rd 2.992 Top x Bottom with 3"H BPVG SURFACE;34.0-2,726.5 • 5,745.1 5,487.2 46.21'Locator Locator,Baker,GBH-22(bottom of locator spaced out 3') 2.990 GAS LIFT;3,052.0 5,748.4 5,489.5 46.24 Seal Seal Assembly,Baker,80-40(total seal assembly= 2.990 Assembly 11.79') ). i Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection Straddle Completion 3 1/2 2.992 5,748.7 6,390.9 5,924.2 9.30 L-80 EUE 8rd Mod 2017 RWO GAS LIFT;4,466.9 Completion Details itili Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) I 5,748.7 5,489.8 46.24 PBR PBR,Baker,10'80-40 4.000 5,761.7 5,498.8 46.36 FHL Packer Packer,Baker,4782 FHL(shear release=60K) 2.940 GAS LIFT;60931 6,378.8 5,915.9 47.03 Locator Locator,Baker,GBH-22(bottom of locator spaced out 3') 2.990 6,381.1 5,917.5 47.02 Seal Seal Assembly,Baker,80-40(total seal assembly= 2.990 GAS UFT;5,688.3 Assembly 11.80') Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection Lower Completion 41/2 3.958 6,381.1 6,680.1 6,122.5 12.60 L-80 IBTM 2017RWO Locator,5,745.1 MB Completion Details Seal Aeeembl 5, .4 Nominal ID y N. Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) PBR 5,748748.7 6,381.1 5,917.5 47.02 PBR PBR,Baker,10'80-40 4.000 FHL Packer;5,761.7 . 6,394.1 5,926.4 46.99 FHL Packer Packer,Baker,4782 FHL(shear release=60K) 2.940 6,447.6 5,962.9 46.87 Nipple- Nipple,Camco,2.813"DS profile,SN:3651-18 2.813 2.813"DS 6,553.5 6,035.5'' 46.72 Crossover Crossover,3-1/2"EUE 8rd Mod Box x 4-1/2"IBT Pin 2.992 ° In Locator;6,378.8 ME 6,555.0 6,036.5' 46.72 Wearsox Wearsox,Northern Solutions,4-1/2",12.6#,L-80,IBTM 3.958 Box x Pin Seal Assembly;8,381.1 ', . P08.6.381 � .1 Perforations&Slots FHL Packer;6,394.1 Shot ink Dens I Top(TVD( Btm(TVD) (shots/ Top(ftKB) stem(ftKB) (ftKB) (BOO) Zone Date ft) Type Com 6,566.0 6,580.0 6,044.0 6,053.6 C-4,2G-15 2/23/2005 6.0 APERF 2.5"HSD,60 deg.ph 6,658.0 6,674.0 6,107.3 6,118.3'A-5,2G-15 9/30/1985 4.0 RPERF 2 1/8"Dresser;0 Ph g. 6,660.0 6,662.0 6,108.6 6,110.0 A-5,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Nipple-2813"DS;6,4476 - Phasing 6,666.0 6,667.0 6,112.8 6,113.5 A-5,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Phasing 6,668.0 6,669.0 6,114.2 6,114.9 A-5,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. Phasing 6,694.0 6,738.0 6,132.2 6,162.8 A-4,2G-15 9/30/1985 4.0 RPERF 2 1/8"Dresser;0 Ph 6,697.0 6,698.0 6,134.3 6,135.0 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Phasing 6,700.0 6,702.0 6,136.4 6,137.7 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Crossover,6,5536 Phasing 6,705.0 6,706.0 6,139.8 6,140.5 A-4,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. Phasing APERF;6,568.08,580.0--• 6,710.0 6,712.0 6,143.3 6,144.7 A-4,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. Phasing Weareoz;6,556.0 -es •••- 6,716.0 6,718.0 6,147.5 6,148.9 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. IPERF,6,860.0-6,662.0-•-. Phasing RPERF;6,658.06,674.0, --• = 6,724.0 6,725.0 6,153.1 6,153.8 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. IPERF;6,666.08 � ,687.0 � _ Phasing IPERF;608.08,889.0 = L 6,727.0 6,728.0 6,155.1 6,155.8 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Phasing Mandrel Inserts IPERF;6,897.O-6,698.O-.--is - - - - --- St IPERF;8,700.08,702.0- at: N Top(ND) Valve Latch Port Size TRO Run ° Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn IPERF;6,705.08,706.0-•� j 2,491.5 2,491.2 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,257.0 8/12/2017 IPERF;6,710.08,712.0-• -- 2 3,652.9 3,652.1 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,245.0 8/12/2017 RPERF;6,694.08,738.0`-• �' IPERF;6,718.08,718.0-+ •---- 3 4,466.8 4,444.6 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,244.0 8/12/2017 - IPERF;6,724.D8,7250 = 4 5,093.1 4,990.8 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,240.0 8/12/2017 5 5,688.3 5,447.8 Camco MMG 1 1/2 GAS LIFT OV RK . 0.250 0.0 8/12/2017 IPERF;8,727.0-8,728.0--0 10.... Notes:General&Safety - 1. End Date Annotation 10/2122010 NOTE:View Schematic w/Alaska Schematic9.0 1/19/20)6 NOTE:100'balanced 11#WellLock Resin plug into both the Tubing and IA-0/0 on 2017 RWO PRODUCTION,33.18,983.0 KUP WD • 2G-15 ConocoPhillips A sk&.Inc, COnocopmhps • DEVIATED-20-15,9/5/20173:29:35 PM Vertical sceema9c(wt.]) Hanger,32.0 I`I I .. ..r"„e,.e....................r. Notes:General&Safety Annotation "—" 9ISI2017Entl Date Note 1 _^..ti CONDUCTOR;35.0-105.0 GAS LIFT;2,491.5 SURFACE;34.0.2,726.5—. GAS LIFT;3,652.9 GAS LIFT;4,466.8r ___ GAS LIFT;5,083.1 ti .41..e GAS LIFT;5,688.3 ;... Locator;5,745.1 Seal Asse0•6y;5,748.4, PBR,5,748.7 FHL Packer;5,761.7 I SR Locator;6,378.8 Seal Assembly;6,381.11 ! -' P86,6,381.1 FHL Packer;6,394.1 - -' I II Nipple-2.813"25,6,447.6 ar Crossover,6,553.5 APERF;6,566 0-6,580.0 Weareox,6,5550 IPERF;6,660 0-6,662.0--. RPERF;6,658.0-6,674.0, --4 IPERF;6,666 0-6,667.0 IPERF;6,6680-6,669.0�� IPERF;6,697.0-6,698.0—.--ve -- IPERF;6,700.0-6,702.0—."—•• IPERF;6,705.0-6,706.0—.---• IPERF;6,710.0-6,712.0— RPERF;6,694.0-6,738.0, --• -" IPERF;6,716.0-6,718.0- v IPERF;6,724.08,725.0-4"6. .:-•-- IPERF;8,727.06,728.0—.'".. a.- PRODUCTION;33.1-6,983.0 1. • ti of T� 4111 THE STATE • Alaska Oil and Gas N `►. °f ®A Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 (4' 1141 A7:41.- Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Ron Phillips Senior Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 AUG 2 5 zQi . Anchorage, AK 99510 scoNED Re: Kuparuk River Field, Tabasco Oil Pool, KRU 2G-15 Permit to Drill Number: 184-131 Sundry Number: 317-365 Dear Mr. Phillips: 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, /a9)4,Av Cathy Pt Foerster Commissioner DATED this (1') day of August, 2017. RBDMS L - L,JL32017 • STATE OF ALASKA • OASKA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 1 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0, Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 - Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development 0• 184-131 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-21162-00 • 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 ❑ No 0 KRU 2G-15 , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025667 ' Kuparuk River Field/Kuparuk River Oil Pool• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft):Total Depth TVD(ft): Effective Depth MD: Effectiv 1D, D: MPSP(psi): Plugs(MD): Junk(MD): 6997' 6346' 6900' 3699 none 6990 Casing Length Size MD TVD Burst Collapse Conductor 70 16 105 105 Surface 2693 9-5/8" 2727 2726 Production 6950 7 6983 6336 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6566'-6580' 6044'-6054' 3.5" L-80 6508 6660'-6662' 6109'-6110' 6666'-6667' 6113'-6113' 6668'-6669' 6114'-6115' 6697'-6698' 6134'-6135' 6700'-6702' 6136'-6138' R EC E I V 6705'-6706' 6140'-6141' r 6710'-6712' 6143'-6145' AUG A 17 6716'-6718' 6147'-6149' '/1'S 0 i'i 1a g j 1 7 6724'-6725' 6153'-6154' A 1 6727-6728' . 6155'-6156' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV: none PACKER-BAKER FHL PACKER • MD=6436 TVD=5955 PACKER-BAKER FHL PACKER • MD=6548 TVD=6032 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 8/3/2017 OIL 0 . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Ron Phillips Contact Name: Ron Phillips Authorized Title: ,�SSeennniioorr Wells Engineer Contact Email: Ron.L.Phillips@conocophillips.com 9 V`�`. 2 P404,4Date: it J 317ot-� Contact Phone. 265-6312 Authorized Signature: !! COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness (Sundry Number: Integrity ;, 3 k--1- Le Plug 9 ty ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3 O p tr,5 4 U v Mlvierkivp Y----C. '� ZS�v f'1 Post Initial Injection MIT Req'd' Yes ❑ No RBDMS L,(=. An z 3 2017 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /r —1-0D / APPROVED BY II AFpproved b . COMM( IOf�ER THE CO�UIMISSION Date: (���ub it Form and orm in 40. ev; d at z 1:., tion is vawli onths from the da l o approval. o1(11-0/Sub ;it Form and -?/4a VY/24V I =�7/7 v�� 5/,�/1 • • ConocoPhilli ps Alaska ; - I V EDP.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AUG 0 4 2017 August 3rd,2017AOGG Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover Kuparuk Producer 2G-15 (PTD# 184-131). Well 2G-15 was drilled and completed in October of 1984 as a Kuparuk A-sand producing well. In April of 2004,a RWO was performed to replace the upper completion due to tubing leaks. The original scope of that RWO was to pull the completion from the PBR and install new seals.They were unable to pull out of the PBR, so a chem cut was performed and a stacker packer completion was ran. In 2015 a leak detect log indicated a leak at the packer at 6437' MD.In January 2016,a resin job was pumped to fix the packer leak;however,the resin did not fix the leak and a failed CMIT resulted. The workover on 2G-15 began July 20, 2017. The 3-1/2"upper completion was successfully pulled. Before pulling the deepest packer a 7" casing pressure test was performed and a leak was detected. After pulling the rest of the completion,a clean out run was performed to the bottom of perforations then a test packer was ran in hole to find the leak.The leak was found just below 5694'. The CBL dated 10/27/84 indicated Probable top of cement at 5630' MD. The purpose of this letter is to formalize the verbal approval and request a retroactive sundry to complete the workover on 2G-15 by running the 3-1/2"completion with two packers,one at the original packer setting depth 6400'MD and one at 5600'MD to straddle the casing leaks. The original scope of this producer workover did not require a sundry;thus this is the first documentation provided to the AOGCC. If you have any questions or require any further information, please call me at 907-317-5092 or email me at ron.l.phillips@conocophillips.com. Sincerely, Rip, 2. (7-1.1.4,.. Ron Phillips Senior Wells Engineer CPAI Drilling and Wells -N•-' • • ConocoPhillips 2G-15 Proposed Workover Pull & Replace Tubing, Casing Leak Repair Original PTD: #184-131 General Well Information: Well Type: Kuparuk A&C-Sand Producer MPSP: 3,699 psi from most recent SBHP w/gradient of 0.1 psi/ft to surface Reservoir Pressure/TVD: 4,368 psi at 6,700' MD/6,136'ND (4/9/2017) EMW:14.1 ppg Wellhead Type: McEvoy Gen III 3-Y8" 5M BOP Configuration: Annular/Pipe Rams/ Blind Rams/ Mud Cross/Pipe Rams MIT Results: MITOA-3/18/2017 passed, MITT-11/12/2016 passed but DDT Failed Start Date: 7/20/2017 Production Engineer: Ward Cable Workover Engineer: Ron Phillips (907) 265-6312 ron.l.phillips@cop.com Current Well Status: Doyon 14 is currently working over the KRU producer 2G-15. Scope of Work: • Pull the leaking 3-1/2" Upper Completion • Run a new 3-1/2" Completion with a stacked packer Summary of Proposed RWO Procedure: Pre-Rig Work(completed): 1. FT LDS—Good. 2. Passing MIT-OA,T-POT,T-PPPOT, IC-POT, and IC-PPPOT. 3. Removed plug and catcher from 2.813" nipple at 6,487' MD and obtain new SIBHP. 4. Set CA-2 plug with catcher in 2.75" Nipple at 6,565' MD. 5. Pulled DV from GLM #5 (6,364' MD) and verified NO circulation. 6. Pulled DV from GLM #4 (5,743' MD) and verified circulation. 7. String shot and chem cuts at 6,397' &6,338'. 8. Dummy all GLM and establish circulation through chem cuts,circulate wellbore to clean seawater. 9. Freeze protect with 2,000' diesel. • • ConocoPhillips 2G-15 Proposed Workover Pull & Replace Tubing, Casing Leak Repair Original PTD: #184-131 Proposed Rig Workover Procedure (completed): 1. MIRU RWO Rig. 2. Pull BPV. Circulate KWF.Verify well is static prior to proceeding. 3. Set BPV, ND tree, NU BOPE&test BOPE to 250/4,000 psig low/high. 4. Pull blanking plug, pull BPV, screw in landing joint, BOLDS, & unseat tubing hanger. 5. P/U on tubing& pull tubing hanger to the rig floor. a. Pull tubing from pre-rig cut at 6,338'. 6. MU and RIH with fishing BHA. a. Pull tubing stub, GLM and tubing from pre-rig cut at 6,397'. 7. MU and RIH with fishing BHA. a. Pull tubing stub and seals from PBR at 6,423'. 8. MU and RIH with fishing BHA. a. Pull upper packer,tubing and overshot from 6,503'. 9. MU and RIH with fishing BHA. a. Pull tubing stub and seals from PBR at 6,535'. 10. MU and RIH with fishing BHA. a. Pull lower packer, nipple and tubing tail from 6,576'. 11. MU and RIH with a clean out BHA down to bottom of the perforations. 12. MU and RIH with a 7" test packer and verify casing integrity. a. Found the top of the casing leaks below 5,694' MD. To Be Completed Rig Work: 13. P/U and run new 3-1/2" lower completion with packer/PBR to desired depth. 14. RU E-line with CCL/GR and log the K1 marker then set a WRP plug in tubing tail. 15. Adjust depth of lower completion based on log results. 16. Set packer and shear seal assembly from PBR. 17. MU and RIH with 3-1/2" completion. Locate and stab into PBR with seals. 18. Swap well to CI seawater. 19. Set upper packer and shear seal assembly from upper PBR,slack off to fully locate and space-out seals in PBR, mark-pipe at surface. 20. Lay-down two joints, space-out with tubing pups, M/U tubing hanger. 21. Land hanger, & RILDS. 22. Pressure-test tubing to 3,000 psi & IA to 2,500 psi. 23. Bleed the tubing while maintaining 2500 psi on IA to shear the SOV. 24. Back-out landing joint& install BPV. 25. ND BOPE, install blanking plug, NU tree, & pressure test tree. 26. Remove blanking plug and BPV. 27. Freeze protect well through SOV. 28. Set BPV. 29. RDMO RWO Rig. • • ConocoPhillips 2G-15 Proposed Workover Pull & Replace Tubing, Casing Leak Repair Original PTD: #184-131 Proposed Post-Rig Work: 1. Pull BPV. 2. Run gas lift design &swap SOV for DV. 3. Pull the tubing tail Plug. 4. Reset well house(s) & re-attach flow line(s). 5. Turn well over to operations. KUP PROD • 2G-15 Conoc Phillips ,:',.414t.!...:'7.,. Attributes Max A Alaska Inc " !wen I I Angle 8r MD TO t.' Wellbore API/UWI Field Name Wellbore Status ncl(") IMD(ftK8) Act Bim(ftKB) ,_�orogypig 500292116200 KUPARUK RIVER UNIT PROD 47.88 6,000.00 6,997.0 --- Comment 6125(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 20-15,4/11/20,76'13'12 PM SSSV:NIPPLE 150 11/1/2014 Last WO: 5/4/2004 40.98 10/16/1984 Vertical schematc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;azo -- ®+ ��� - Last Tag:SLM 6,756.0 8/30/2015 Rev Reason.GLV C/O,SET PLUG&CATCHER pproven 4/11/2017 Casing Strings - Ca g pt on OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Le (I...Grade Top Thread 1(' (l CONDUCTODesR 16 15 062 35.0 105.0 105.0 62.50 H-40 WELDED l I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WELe (I...Grade Top Thread . •SURFACEI Cooing es pt on OD(n) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND).. Wt/Len(I...Grade Top Thread UCDTION 7 6.276 33.1 6,983.0 6 336 3 26.00 J-55 BUTT AA/ . CONDUCTOR 35-01050 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection NIPPLE,51x.7 TUBING WO 3 1/2 2.992 32,0 6,508.8 6,004.8 9.30 L-80 EUE-ABM 4 Completion Details Top(ftKB) Top(ND)(ftKB) Top!noir) Item Des Com N in IID 32.0 32.0 0.23 HANGER CAMERON TUBING HANGER ( ) 3.875 GAS LIFT;2,647.3 - it _ 2 514.7 514.7 0.65 NIPPLE CAMCO DS LANDING NIPPLE 2.875 4, 6,419.6 5,943.8 46.93 LOCATOR BAKER LOCATOR 3.000 SURFACE;34.0-27255 6,422.9 5,946.1 46.92 PBR BAKER 80-40 2.980 6,436.3 5,955.2 46.89 PACKER BAKER FHL PACKER 2.990 ill GAS LIFT 4514.9 6,489.9 5,991.9 46.77 NIPPLE CAMCO D NIPPLE 2.812 6,503.1 6,000.9 46.75 OVERSHOT POOR BOY OVERHSHOT(SPACEOUT 3.0"ID @ 6501) 3.625 ' '. Tubing Description String Ma...ID(in) Top(ftKB) Sot Depth(ft..Set Depth(ND)I...Wt(Ib/fQ Grade Top Connethon GAS LIFT;4,970.0 III TUBING Original 3 1/2 2 992 6,496.9 f 6,577.2 6,051 7 EUEBRD Completion Details Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal ID GAS LIFT;5,742.7 6,534.6 6,022.5 46.73 PBR BAKER PBR (3) 3.000 ri 6,548.0 6,031.6 46.73 PACKER BAKER FHL PACKER 3.000 ii 6,565.0 6,043.3 46.72 NIPPLE CAMCO D NIPPLE 2.750 GAS LIFT;6,363.5 a 6,576.4 6,051.2 46.71 SOS BAKER SHEAR OUT SUB,ELMD TTL @ 6566'during 3.000 SWS PERF LOG on 02/23/2005 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) TUBING PUNCH;6415.0 ll Top(ND) Top net Top(ftKB) (ftKB) (°) Des Com Run Date ID ig 6,415.0 5,940.6 46.94 TUBING TUBING PUNCH 6,415'-6,417' (in) ) 10/15/2015 LOCATOR;6,419.6 PUNCH ( TUBING SPACE OUT;6.419.9 6,562.2 6,041.4 46.72 CATCHER 2.73"x 34.25"AVA CATCHER on PLUG 4/10/2017 PER;6422.9 PACKER;64353 6,565.0 6,043.3 46.72 PLUG 2.75"CA-2 PLUG 4/9/2017 .. 6,990.0 6,341.3 44.58 FISH Retainer Ring 1.5"x 4"PIECE OF SHEAR PIN 2(21/2005 0.000 • RETAINER RING left in hole Perforations&Slots NIPPLE;6,489.9 i Shot Dens Top(ND) Btm(ND) (shots4 TUBING SPACE OUT;6,500.9 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com OVERSHOT 5503.1 ( I 6,566.0 6,580.0 6,044.0 6,053.6 C-4,2G-15 2/23/2005 6.0 APERF 2,5"HSD,60 deg,ph 6,658.0- 6,674.0 6,107.3 6,118.3 A-5,20-15 9/30/1985 4.0 RPERF 2 1/8"Dresser,0 Ph 6,660.0 6,662.0 6,108.6 6,110.0 A-5,20-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. PBR;6,534.6 PACKER,6,5480 - Phasing 6,666.0 6,667.0 6,112.8 6,113.5 A-5,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. CATCHER;6,562.2 I! Phasing 6,668.0 6,669.0 6,114.2 6,114.9 A-5,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. NIPPLE;6,565.0 / - Phasing PLUG;6565.0 6,694.0 6,738.0 6,132.2 6,162.8 A-4,2G-15 9/30/1985 4.0 RPERF 2 1/8"Dresser;S Ph APERF;6,566.0-6,580.0-. 6,697.0 6,698.0 6,134.3 6,135.0 A-4,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. 505;6,5764 - Phasing 6,700.0 6,702.0 6,136.4 6,137.7 A-4,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. Phasing IPERF;fi,6600-6662.0-� �- 6,705.0 6,706.0 6,139.8 6,140.5 A-4,20-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. RPERF,6,658.0-66 L 74.O � _ Phasing 6,710.0 6,712.0 6,143.3 6,144.7 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. IPERF;6,666.0-6,6670-• = Phasing (PERF;6,668.0-6,669 0- - 6,716.0 6,718.0 6,147.5 6,148.9 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Phasing ` 6,724.0 6,725.0 6,153.1 6,153.8 A-4,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. Phasing (PERF;6,6970-6,698.0-� = 6,727.0 6,728.0 6,155.1 6,155.8 A-4,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. IPERF;5,700.0-6,702.0- Phasing Mandrel Inserts St ... ati IPERF;5705.0-6,706.0 on Top(ND) R Na Top(8K8) (ftKB) Make Model OD(in) Seal, Valve Latch Pod Size TRO Run e IPERF;67100-6712.0-- _ 1e Com 2,647.3 2,646.9 CAMCO MMG 11/2 GAS LIFT DMYRKype 0.000 (ps0.0 10/11/20i) Run 115 4:00 RPERF;6,694.0-6738.0 !PERE;5715.0-5718.0- :=-- 2 4,014.9 4,013.0 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/11/2015 11:00 IPERF;s724.G-57250- = 3 4,970.0 4,887.2 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/11/2015 5:30 IPERF;6,72].0-67280-- - 4 5,742.7 5,485.6 CAMCO MMG 11/2 GAS LIFT OPEN 4/9/2017 - c 5 6,363.5 5,905.5 CAMCO MMG 11/2 GAS LIFT OPEN 4/10/2017 - Notes:General&Safety End Date Annotation 10/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 1/19/2016 NOTE:100'balanced 114 WellLock Resin plug into both the Tubing and(A - PRODUCTION'33.1-6,983 0 FISH;6,990.5 McEvoy Gen III 2G-15 Conoco1- hi"ipss Kuparuk A & C-Sand Producer Post RWC CTD Setup Design 16" 62.5# H-40 WLD, 105' MD -lb- 3-'/" 9.3#L-80 EUE-8RD-AB MOD - 2500' MD, Camco 3-1/2"x1-1/2" MMG GLM 9-5/8" 36#J-55 BTC, 2727' MD _ op. 11' 3652' MD, Camco 3-'/2"x1-'/2" MMG GLM 4474' MD, Camco 3-1/2"x1-1/2" MMG GLM f 5106' MD, Camco 3-1/2"x1-1/2" MMG GLM 5571' MD, Camco 3-1/2"x1-1/2" MMG GLM 2000 psi IA>Tbg.SOV f, "4` 1/ 5690' MD, Baker 7"x 3-1/2" FHL Retr. Packer w/10'80/40 PBR Assembly f 6397' MD, Baker Tb'lx 3'/2" FHL Retr. Packer w/10'80/40 PBR Assembly f--a 6457' MD, Camco 3-1/2"x 2.812" DS-nipple 6557' -6683' MD,4-1/2" Wearsox BTP Kuparuk C-Sand Perforations 6566' -6580' MD ---- Kuparuk A5-Sand Perforations 6658' -6674' MD 4/10/2017 Last BHP Measurement: 4368 psi at 6700' MD, 6136'ND Kuparuk A4 Sand Perforations 6694'-6738' MD 7" 26#J-55 BTC, 6983' MD —► It - FISH, 6990' MD Date: I 03 Aug 2017 I Drawn By: I Ron Phillips Pro /81---13 Loepp, Victoria T (DOA) From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Thursday,August 03,2017 9:46 AM To: Loepp,Victoria T(DOA) Subject: FW: [EXTERNAL]Re: KRU 2G-15 (PTD 184-131)casing leak Attachments: 2G-15 - Proposed Schematic 8 3 17- DRAFT.PDF;2G-15 current WV schematic.pdf Follow Up Flag: Follow up Flag Status: Flagged Good Afternoon Victoria, This is a preemptive email to request approval for a work scope change on the KRU 2G-15 rig workover.The well is a producer with PTD 184-131. In 2004,this well had a workover that was completed by stacking a packer.The initial purpose of the current workover for 2G-15 was to repair an upper packer leak. In 2015 a leak was detected at the upper packer and a resin job was performed.The resin job did not fix the leak and failed a CMIT.Well 2G-15 was added to the RWO schedule. Before pulling the lower packer a casing pressure test was performed and a leak was noted.We pulled the lower packer with tubing tail, made a clean out run to bottom of the perforations then last night ran in the hole with a test packer and located the shallowest leak just below 5694'.The decision was made to set a packer in a competent joint of casing 'x6400' MD and stack a packer just above the shallowest casing leak at^'5690' MD. I am requesting approval to stack a packer at a 5690' MD depth to fix the casing leak. Upon approval,we anticipate to be running in the hole with the stacker packer completion today. Attached is the 2G-15 Original Pre-rig Schematic and the Proposed Stacked Packer Schematic for your review. Current operations:Testing joint of tubing where we plan to set deepest packer. Plan forward: MU completion with 2 packers to RIH. Due to the original workover scope and well type, no sundry was submitted for 2G-15. Please let me know how would like to proceed and if you need me to submit anything in addition to this notification.I await your approval for the new scope on 2G-15. If you have any questions or require other documentation please contact me: Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-1592 From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent: Friday,July 28,2017 10:01 PM To: Phillips, Ron L<Ron.L.PhillipsPconocophillips.com> Subject: [EXTERNAL]Re: KRU 2G-15(PTD 184-131)casing leak 1 • • • Ron, I'm assuming this is a non-sundry RWO on a producer.Since alteration of the casing is now in the scope,the forward work will require submission of a sundry. Approval is granted to proceed as you have outlined below followed by submission of a sundry. Thanx, Victoria Sent from my iPhone On Jul 28,2017,at 9:44 PM, Phillips, Ron L<Ron.L.Phillips@conocophillips.com>wrote: Victoria, This is a notification that today Doyon 14 performing a RWO on KRU 2G-15(PTD 184-131)found a casing leak.The plan is to make a slickline run to pull the tubing tail plug,then run in the hole on drill pipe with jars and pull the 3-1/2"x7" packer.We will then run in the hole and make a clean out run to the perforations.The next run will be to run in the hole with a test packer and locate the leak in the 7" casing. If the leak is deep enough we plan to set a production packer above the leak.We will let you know the outcome of the test packer run. If you need more information please call. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-1592 2 McEvoy Gen III • 2G-15 ConocoPh i l l i ps Kuparuk A & C-Sand Producer Post RWO CTD Setup Design 16" 62.5#H-40 WLD, 105' MD —►4 - 3 1/2" 9.3#L-80 EUE-8RD-AB MOD 41 I 2500'MD, Camco 3-1/2"x1-1/2" MMG GLM 9-518"36#J-55 BTC, 2727' MD—► ,f y 3652' MD, Camco 3'1/2"x1=1/2' MMG GLM -40 4474' MD, Camco 3-1/2"x1-1/2" MMG GLM 5106' MD, Camco 31/2"x1 1/2' MMG GLM 5571'MD, Camco 3-1/2"x1-1/2" MMG GLM 2000 psi IA>Tbg. SOV 5690'MD, Baker 7"x 3-%" FHL Retr. Packer w/10'80/40 PBR Assembly 6408' MD, Baker 7"x 3'/z" FHL Retr. Packer 6457' MD,Camco 3-1/2"x 2.812" DS-nipple CA-2 plug pre-installed 6563' -6683' MD,4-h/2"Wearsox BTP Kuparuk C-Sand Perforations 6566'-6580'MD Kuparuk A5-Sand Perforations 6658'-6674'MD 4/10/2017 Last BHP Measurement: 4368 psi at 6700' MD, 6136'TVD Kuparuk A4 Sand Perforations 6694'-6738'MD - 7"26#J-55 BTC,6983'MD —► *ri FISH, 6990' MD Date: I 03 Aug 2017 I Drawn By: I Ron Phillips KUP PROD • 2G-15 ♦ `- ØConocoPhillips o � Well Attributes Max Angle&MD TDUW Alaska,Inc. 4111 'Wellbore APUI Field Name Wellbore Status Incl('I MD(ftKB) Act Bain(ftKB) 0-,...,,z,nujp, 500292116200 KUPARUK RIVER UNIT PROD 47.88 6,000.00 6,997.0 , -"" �~ Comment 62S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2G-15,4/11/20176:13'12 PM SSSV:NIPPLE 150 11/1/2014 Last WO: 5/4/2004 40.98 10/16/1984 Vencoel schema50 tactual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;32.0 14-1 j Last Tag:SLM 6,756.0 8/30/2015 Rev Reason:GLV C/O,SET PLUG&CATCHER pproven 4/11/2017 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Sat Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 105.0 105.0 62.5011-40 WELDED Casing Description OD(in) ID(in) Top OMB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thenad .I„a,.,.u ,SURFACE 95/8 8.921 34.0 2,726.5 2,726.1 36.00 J-55 BUTT .j.„. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)...WOLen(I...Grade Top Thread j PRODUCTION 7 6.276 33.1 6,983.0 6,336.3 26.00 J-55 BUTT J'A.ZCONDUCTOR;35.0-105.0 �...Tubing Strings �.4ln ins Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...MOWN) Grade Top Connection NIPPLE;514.7 1 TUBING WO 3 1/2 2.992 32.0 6,508.8 6,004.8, 9.30 L-80 EUE-ABM ICompletion Details Nominal ID Top MB) Top(TVD)(ftKB) Top InU)) Item Des Corn (in) 1 32.0 32.0 023 HANGER CAMERON TUBING HANGER 3.500 GAS LIFT;2,647.3 514.7 514.7 0.65 NIPPLE CAMCO DS LANDING NIPPLE 2.875' 6,419.6 5,943.8 46.93 LOCATOR BAKER LOCATOR 3.000 6,4229 5,946.1 46.92 PBR BAKER 80-40 2.980 SURFACE;34.0-2,726.5-41 I,. 6,436.3 5,955.2 46.89 PACKER BAKER FHL PACKER 2.990 GAS LIFT;4,014.9 6,489.9_ 5,991.9 46.77 NIPPLE CAMCO D NIPPLE 2.812 6,503.1 6,000.9 46.75 OVERSHOT POOR BOY OVERHSHOT(SPACEOUT 3.0"ID @ 6501') 3.625 Tubing Description String Ma...113(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection GAS LIFT;4,970,0 TUBING Original 31/2 2.992 6,496.9 6,577.2 6,051.7 EUE8RD Completion Details Nominal ID I Top(ftKB) Top(TVD)(ftKB) Top net(") Item Des Com (in) GAS LIFT;5,742.7-" 6,534.6 6,022.5 46.73 PBR BAKER PBR 3.000 _ 6,548.0 6,031.6 46.73 PACKER BAKER FHL PACKER 3.000 6,565.0 6,043.3 46.72'NIPPLE 'CAMCO D NIPPLE 2.750 GAS LIFT;6,363.5- 6,576.4 6,051.2 46.71'SOS BAKER SHEAR OUT SUB,ELMD TTL @ 6566'during 3.000 SWS PERF LOG on 02/23/2005 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Ind TUBING PUNCH;6,415.0 !)i Top(ftKB) (ftKB) (") Dae Corn Run Date ID(in) 6,415.0 5,940.6 46.94 TUBING TUBING PUNCH(6,415'-6,417') 10/15/2015 LOCATOR;1,1106 PUNCH TUBING SPACE OUT;6,419.0 6,562.2 6,041.4 46.72 CATCHER 2.73"x 34.25"AVA CATCHER on PLUG 4/10/2017 PBR'6'422'9 6,565.0 6,043.3 46.72 PLUG 2.75"CA-2 PLUG 4/9/2017 PACKER;6,4363 6,990.0 6,341.3 44.58 FISH Retainer Ring 1.5"x 4"PIECE OF SHEAR PIN 2/21/2005 0.000 RETAINER RING left in hole Perforations&Slots NIPPLE;6.489.9111 Shot Dena TOP(IVU) atm(TVD) (shots/( TOP(ftKB) Mho(kKB) (ftKB) OMB) Zone Dab t) Type Can TUBING SPACE OUT;6,500.9 6,566.0 6,580.0 6,044.0 6,053.6 G-4,2G-15 2/23/2005 6.0 APERF 2.5"NSD,60 deg.ph OVERSHOT;6,503.1 6,658.0 6,674.0 6,107.3 6,118.3 A-5,2G-15 9/30/1985 ' 4.0 RPERF 2 1/8"Dresser,0 Ph 6,660.0 6,662.0 6,108.6 6,110.0 A-5,20-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. P8R;6,534.6 r r Phasing PACKER;6,548.0 6,666.0 6,667.0 6,112.8 6,113.5 A5,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. Phasing CATCHER;6,5622 }j� 6,668.0 6,669.0 6,114.2 6,114.9 A-5,20-15 11/8/1984 1.0 IPERF 4"DAJJ;90 deg. NIPPLE;6,565.0 S%&IIp Phasing PLUG;6,565.0 , ' 6,694.0 6,738.0 6,132.2 6,162.8 A-4,2G-15 9/30/1985 4.0 RPERF 21/8"Dresser,0 Ph APERF;6,566.0-6,580.0- I I6,697.0 6,698.0 6,734.3 6,135.0 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. SOS;6,576.4I Phasing 6,700.0 6,702.0 6,136.4 6,1377 A-4,20-15 11/8/1984 1.0 (PERF 4'DAJJ;90 deg. ---. Phasing 6,705.0 6,706.0 6,739.8 6,140.5 A.4,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. IPERF;6,660.0-6,662.0--....... Phasing RPERF;6,658.0-6,674.01"_ 6,710.0 6,712.0 6,143.3 6,144.7 A-4.20-75 11/8/1984 1.0 IPERF 4'DAJJ;90deg. IPERF;6,666.0-6,667.0�.j -v Phasing IPERF;6,886.0-6,669.0-� 6,716.0 6718.0 6,147.5 6.148.9 A-4.20-15 11/8/1989 1.0 IPERF '4"DAJJ;90 deg. Phasing 6,724.0 6,725.0 6,153.7 6,753.8 A-4,20-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. - Phasing IPERF;6,69764,696.0- 6,727.0 6,7280 6,155.1 6,155.8 A-4,2G-15 11/8/1984 1.0 IPERF 4"DAJJ;90 deg. - Phasing IPERF;6,700.04,702.0 - Mandrel Inserts st au IPERF;0,706.0-6,7060- on Top(TVD) Valve Latch Port Size TRO Run ' N Top(ftKB) (ft(B) Make Model OD(in) Son Type Type (in) (psi) Run Date Corn IPERF;6,71D.0-6,712.8-- 1' 2,647.3 2,646.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/11/2015'4:00 RPERF;6,694.04,736.0 2 4,014.9 4,013.0 CAMCO MMG 11/2 GAS LIFT 'DMY RK 0.000 0.0 10/11/2015 11:00 IPERF;8,7186-0,718.0 -4 ERF;6,724.0$725.0-i-"• IP3' 4,970.0 4,887.2 CAMCO 'MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/11/2015'5:30 s IPERF;6,727.0-8,726A • 4 5,742.7 5,485.6 CAMCO MMG ' 1 1/2 GAS LIFT OPEN 4/9/2017 5 6,363.5 5,905.5 CAMCO MMG 1 1/2 GAS LIFT OPEN 4/10/2017 Notes:General&Safety End Data Annotation 10/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 1/19/2016 NOTE:100'balanced 11#WeIlLock Resin plug into both the Tubing and IA PRODUCTION;33.1-6,983.0 FISH;6,990.011 a) � r ^ T !O O r x- so a) n V 0 O N 0 ,L CO t+- "O CO O u 4 .Y 0 in o u t E > a' ) a r no c 1^-' v o 0 LA ro N @ .i -0 G+ _ Has o ° T co Q YL p N 0 -' w r r r r r N- N a O Oa u m Q -+ L E a„' r ..a Q In r .- 0 .:, < < < < < Q , c L to toW- O) O o M 4 (o t� CO co - C til Z Q . r' NNN N V 'D (0 0 +, 0 a) -a 0 V C i a) s- 14) a O 0 p -I 0 0 0 C p o W W W W W W W n a) 'C H LL LL LL LL LL LL LL a) < J J J J J J J a _o > '('' Q Q Q Q Q Q Q a) N C 4 . 5 ' b< Z Z z Z Z z Z N L N 0 N LL LL LL LL LL LL LL CC --- -0 t > g2 :Z"2.: -..L. u a) C (o a.+ > a) a e.:y y+.+_, a) co C ru E a) V ® ZO C O w co C a LI a) Y U c O v C ruo Q O O S. Q a c a wp U V J a) „0 4 0 a a J a) -J a (o G Q U V V O .y W tJ j W0 q x (d p a.. J J J J J J J M 'il W 3 3 3 ' a '- "� 4,fit en w 1,.°.n cexcereccrect W W W W W W W - w > > > > > > > L z Y Y Y Y Y Y Y p > GU Ar 0 a' Maa' Wa' W a) w Q 4 0 0 0 Q Q > Li a a. a. a. a. a. a. z °. 3333333 , (0 o u 0 o N N v 0 m X n ro ar 0 0 0 0 0 0 0 E 0 0 0 0 0 0 0 0 cc v cc ono oro aro 0 0 0 oro m W f� N n'.$k` f6 fi! u w ( $ 0 0 0 0 0 0 0 0 0 0 0 0 0 oa Kr N oo co o r o F- '1 E _l 4 co a0 N r L o;, I R�7 at C M M (O N M 1n u N y N N N N e- N N N i _L c. < 01 M M Of M T OI d -i ER N 0 O N 0 N N 'L .� O1 O O e- O O 3 ...r 0 0 0 0 0 0 0a.+ O a), T.. 4 c (n N 0 0 1n to in Q u C, C� of ,� 'ar co a) lin SE uci, u GMW Q J — c ci iv E z 4, QJ l,4,, z N N N e- N r o N E `1 1- % % = cl v1 E .� _. C> Y Y Ch F o E Z a) cao, c nom O. Q Q N W N N N N N of y ,y: '@) L ^ C C CO tnCD CO; OCA � � aLk i- a ii. Bl • 2-134( 2_ WELL LOG TRANSMITTAL# DATA LOGGED 1 /5/201(0 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. June 10, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 28 201u C RE: Leak Detect Log with ACX: 2G-15C Run Date: 7/10/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2G-15 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-21162-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-029-21162-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari SCANNED DEC 0 92016 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ��✓a&��aeh,�v ( yE;�k: y aitTE OF ALASKA KRU 2G-15 .. AKA OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations IT Fracture Stimulate IT Pull Tubing IT Operations Shutdown IT Performed: Suspend IT Perforate IT Other Stimulate IT Alter Casing I-.-` Change Approved Program r Plug for Redrill r Perforate New Pool IT Repair Well F Re-enter Susp Well r Other: Resin Packer Repair F' 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r 184-131 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-21162-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25667 KRU 2G-15 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 6997 feet Plugs(measured) 6490 true vertical 6346 feet Junk(measured) 6990 Effective Depth measured 6900 feet Packer(measured) 6436,6548 true vertical 6277 feet (true vertical) 5955, 6032 Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 16 105 105 SURFACE 2693 12 2727 2727 PRODUCTION 6950 7 6983 6336 RECEIVED Perforation depth: Measured depth: 6566-6580,6658-6674, 6694-6728 JUN 13 2016 True Vertical Depth: 6044-6054,6107-6118, 6132-6156 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80,6509 Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 6436 MD and 5955 TVD PACKER-BAKER FHL PACKER @ 6548 MD and 6032 ND NIPPLE-CAMCO DS LANDING NIPPLE @ 515 MD and 515 ND 12.Stimulation or cement squeeze summary: p� MAI (} Intervals treated(measured): N/A SCANNED MA`t 0 4 2 U 1( Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NuT- 11‘) 1 Subsequent to operation GI{UT- IA) 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: y`�;' Daily Report of Well Operations F Exploratory r Development F Service r Stratigraphic r Copies of Logs and Surveys Run IT 16.Well Status after work: Oil F Gas IT WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR IT WINJ IT WAG IT GINJ IT 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: 315-612 Contact Tyson Wiese a 263-4250 Email Tyson.M.Wieseaconocophillips.com Printed Name T son Wiese Title Sr. Wells Engineer Signature /(� -r Phone:263-4250 Date (:) / /// F►7 L t (U( (` on i 5` 3/l Jo Form 10-404 'evised 5/2015 VT b l Submit Original Only A/0l0 %4 RBDMS I-L Jidoi 1 4 2016 • 2G-15 • DTTMS.JOBTYP SUMMARYOPS 3/25/16 ANNCOMM SLB CTU #11: CUT 400' OF COIL AND PERFORM WEEKLY BOP TEST ON BACK DECK. PREPARE FOR MILLING JOB IN THE MORNING. 3/26/16 ANNCOMM SLB CTU#11: MILL WELL LOCK RESIN STRINGERS AND SCALE WITH BAKER 2.83" FIVE BLADE JUNK MILL FROM 1800' TO 6300'. CONTINUE MILLING HARD RESIN FROM 6300'-6446'AND THROUGH COMPOSITE BRIDGE PLUG BOTTOM. DRIFT TO 6460'. WELL LEFT SHUT IN AND FREEZE PROTECTED. WILL RETURN TO UNDERREAM RESIN IN THE MORNING. 3/27/16 ANNCOMM SLB CTU#11: MILL RESIN STRINGERS WITH BAKER 2.86" UNDERREAMER OVER AREAS OF INTEREST FROM DAY PRIOR BETWEEN 1800'AND 6450'. NO MOTOR WORK OBSERVED. DRIFT THROUGH TUBING TAIL WITH UNDERREAMER CLOSED. READY FOR POST-RESIN DIAGNOSTICS WITH DIGITAL SLICKLINE. 5/3/16 ANNCOMM BRUSH n' FLUSH &GAUGE UP TO 2.84" (RECOVERING CHUNKS OF RESIN)TO 5490' RKB; SET 2.81" CA-2 PLUG &AVA CATCHER @ 6590' RKB (ATTEMPT TO MIT&SHOWS COMMUNICATION TO IA); ATTEMPT TO CMIT(FAIL). CDDT TO 1000 PSI (PASS). READY FOR E-LINE. 5/12/16 ANNCOMM WELL S/I ON ARRIVAL. RU/PT SLB ELINE. RIH WITH CEMENT EVALUATION TOOL. OAL=47' OAW=300# MAXOD=2.5". TAG PLUG AT 6490'. LOG INTERVAL 6490'TO 5934'AT 30 FPM. LOG TIED INTO HAL CALIPER LOG DATED 02-SEP- 2016. WELL S/I ON DEPARTURE. JOB COMPLETE. �,e KUP OD 2G-15 ConocoPhiflip5 Mt Well Attrib Max Angle MD TD Ala k1 1111.. Wellbore API/UWI Field Name Wellbore Status ncl('t MD(ftKB) Act Btm(ftKB) ,„,i,i,, 500292116200 KUPARUK RIVER UNIT PROD 47.88 6,000.00 6,997.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2c-15,6!13/20163:25:49 PM SSSV:NIPPLE 150 11/1/2014 Last WO: 5/4/2004 40.98 10/16/1984 Vemral schematic(actual) Annotation Depth(ft613) End Date Annotation Last Mai By End Date HANGER:320 I 1 joi,. �.- Last Tag:SLM 6,756.0 8/30/2015 Rev Reason:SET PLUG AND CATCHER pproven 5/6/2016 Z acing Strings V Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(kKB) Set Depth(TVD)... Wt/Len(I Grade Top Thread CONDUCTOR 16 15.062 35.0 105.0 105.0 62.50 H-40 WELDED + I o, umvau or S Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND).. Wt/Len(I_Grade Top Thread • wu.SURFACE 9 5/8 8.921 34.0 2,726.5 2,726.1 36.00 J-55 BUTT / Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread i!:' ,. PRODUCTION 7 6.276 33.1 6,983.0 6,336.3 26.00 J-55 BUTT -.n CONDUCTOR;35.0-105.0 i ' Tubing Strings Tubing Description String Ma...ID(in) Top(kKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection NIPPLE;514.7 TUBING WO 31/2 2.992 32.0 6,508.8 6,004.8 9.30 L-80 EUE-ABM Completion Details Nominal ID ( Top(ftKB) Top(TVD)(ftKB) Top Inc!1') Item Des Com (in) 32.0 32.0 0.23 HANGER CAMERON TUBING HANGER 3.500 GAS LIFT:2,647.3 514.7 514.7 0.65 NIPPLE CAMCO DS LANDING NIPPLE 2.875 s6,419.6 5,943.8 46.93 LOCATOR BAKER LOCATOR 3.000 SURFACE;34.0-2,726.5-- i . • 6,422.9 5,946.1 46.92 PBR BAKER 80-40 2.980 6,436.3 5,955.2. 46.89 PACKER BAKER FHL PACKER 2.990 GAS LIFT;4,014.9 6,489.9 5,991.9 46.77 NIPPLE CAMCO D NIPPLE 2.812 6,503.1 6,000.9 46.75 OVERSHOT POOR BOY OVERHSHOT(SPACEOUT 3.0"ID @ 6501') 3.625 r Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ibift) Grade Top Connection GAS LIFT;070.0------ TUBING Original 3 1/2 2.992 6,496.9 6,577.2 6,051.7 EUE8RD Completion Details Nominal ID Top(kKB) Top(ND)(ftKB) Top Incl I') Item Des Corn (in) GAS LIFT;5,742.7 6,534.6 6,022.5 46.73 PBR 'BAKER PBR 3.000 6,548.0 6,031.6 46.73 PACKER BAKER FHL PACKER 3.000 6,565.0 6,043.3 46.72 NIPPLE 'CAMCO D NIPPLE 2.750 GAS LIFT,6363.5 i 6,576.4 6,051.2 46.71 SOS BAKER SHEAR OUT SUB,ELMD TTL @ 6566'during 3.000 SWS PERF LOG on 02/23/2005 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) TUBING PUNCH;6,415.0 /4i, Top(ND) Top Inc! - Top(ftKB) (ftKB) I') Des Com Run Date ID(in) LOCATOR;6,418.6 6,415.0 5,940.6 46.94 TUBING TUBING PUNCH(6,415'-6,417') 10/15/2015 PUNCH TUBING SPACE OUT,6,419.9 PBR;6,422.9 - 6,487.5 5,990.2 46.78 CATCHER 2.78"AVA CATCHER(OAL=30") '5/3/2016 PACKER;6,436.3 6,490.0 5,991.9 46.77 PLUG CA-2 PLUG OAL 58' 5/3/2016 6,990.0 6,341.3 44.58 FISH Retainer Ring 1.5"0 4"PIECE OF SHEAR PIN 2/21/2005 0.000 RETAINER RING left in hole CATCHER;6,487.5 'jj, Perforations&Slots ' Shot NIPPLE;6,489.9 .111//10: Ir Dens PLUG;6,490.0 �j Top(ND) Btm(ND) (shoal Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 6,566.0 6,580.0 6,044.0 6,053.6 C-4,2G-15 2/23/2005 6.0 APERF 2.5"HSD,60 deg.ph TUBING SPACE OUT;8,500.9 6,658.0 6,674.0 6,107.3 6,118.3 A-5,2G-15 9/30/1985 4.0 RPERF 2 1/8"Dresser;0 Ph OVERSHOT;6,503.1 •1 ( - 6,660.0 6,662.0 6,108.6 6,110.0 A-5,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. Phasing 6,666.0 6,667.0 6,112.8 6,113.5 A-5,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. PBR;6,534.6 Phasing PACKER;6,548.0 . - 6,668.0 6,669.0 6,114.2 6,114.9 A-5,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. :'`�'' - Phasing NIPPLE;6,565.0 -''w'` 6,694.0 6,738.0 6,132.2 6,162.8 A-4,2G-15 9/30/1985 4.0 RPERF 2 1/8"Dresser;0 Ph APERF;8,566.0-6,500.0 -•'' 6,697.0 6,698.0 6,134.3 6,135.0 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. SOS;6,5764 4 Phasing 6,700.0 6,702.0 6,136.4 6,137.7 A-4,2G-15 11/8/1984 1.0 IPERF 4"DAJJ;90 deg. Phasing IPERF;6,660.06,662.0 ' 1[ 6,705.0 6,706.0 6,139.8 6,140.5 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Phasing RPERF;8,858.08,874.0`_.,T IPERF;6,666.06,667.0-.1 I 6,710.0 6,712.0 6,143.3 6,144.7 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Phasing IPERF;6.668.06,669.0---- .1 6,716.0 6,718.0 6,147.5 6,148.9 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. 4 Phasing 6,724.0 6,725.0 6,153.1 6,153.8 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Phasing IPERF;689706,698.0-- 6,727.0 6,728.0 6,155.1 6,155.8 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. IPERF;6,700.06,702.0 Phasing Mandrel Inserts St IPERF;6,705.06,706.0-. ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com IPERF;8,710.06,712.0 1 2,647.3 2,646.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/11/2015 4:00 RPERF;8,694 0-6,738.0 IPERF;6,716.06,718.0 2 4,014.9 4,013.0 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/11/2015 11:00 IPERF;6,726.06,725.0 3 4,970.0 4,887.2 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/11/2015 5:30 IPERF;6.727.06.726.0- - 4 5,742.7 5,485.6 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/11/2015 5:30 5 6,363.5 5,905.5 CAMCO MMG 1 1/2 GAS LIFT DMY IRK 0.000 0.0 10/11/2015 4:00 I Notes:General&Safety End Date Annotation PRODUCTION;33.16,983.0 10/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 FISH;6,990.0-.--* 1/19/2016 NOTE:100'balanced 11#WelILock Resin plug into both the Tubing and IA • • c ° cr a) r r n wow O r r r r r CU V N wo (l O ZO U ro GJ JO.�m X coU CU a 3 r G YY Y3 a) O ;.-A Z r r r r r r r tio O v o _,e ll, > '-y 00 o 0.no c p o 6 a _o o p ta O . ' c 0 m Q -) l7 iD cD cD c0 a0 cD CD L O �QJ E _E m�' O R A m �o R N p@ — n C-- V) n N r r -0 > Z Q N oo ao N r e- r C (O9 aJQ a) Z a a p V ID E o >. D' CC ii H (1) > a) H III0 0 0 0 0 0 0 aVJ ...0 6 W Y W w w w w w w oo c ro O ..a H LL LL LL LL LL LL L.L. 71 CU E - v) O Q J J J J J J J Q O C N to F Q Q Q Q Q Q Q C [O Z Z Z Z Z Z Z u 03 w O u LL LL LL LL LL LL LL aJ _C ,, a) op ` ,w CO ` r > y V Q) O E ai a O 0 o Z c O_o v a O �-» aJ aJ 1--, � � 0 . ua) aJ .0 u > U 7:1? HJfl ! 1.1 o 41 -'4 6 5 1 al x 71 0 h z W aG W >, C0 :LJ G J J ti J O J \ 3 2 a W � � � �41.-. 11-p1102,_,Prf ' cuil4VI� SI I ZZZZZZ Z a`, W a ECCCCLW CCCL La 2 w w w w w w w a > > > > > > > E 12, Y Y Y Y Y Y Y r Lu > > > 0 > > > E u. d' d' Q' d' w Q' ct �.. en Y 0 > > > > > > > c > L WN N cq (0 O N N. 00 0 CO0 N 0 0 X LI a 1111 sa 'O 0 O0 0 f0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 as •Z U *t d O acs, N ch O aE �) > v 2 v 2 N 2 vaJ IMO ...IW 0 0 0 0 0 0 0 a LLIcn x V) as Ca a'� O 0 0 0 0 0 0 c..)tD 0 0 0 cD 0 0 0 C Inn N (0 T r O N N 00E CC m - O N M r cD .N O N r M N N ON N N d N N N N N N N L N < 0) O) O) O) O) M O) O _0 N N N N N 0 N c- 0 �, Q1 0 0 0 O O r O al r- 0 0 0 0 0 0 0 c- c() N cn in c() c[) N 4... O ) Cm co C O. U O in a m E aJ > rem Zg W — L C QJ kj vi 5 aJ d Q Z r O N r M N !_' E ` H « = y L ^ (, R' N U' Y f° a 1 d Q N .J r N J M E Z a) ro rC w N , y �. a a Q uo 4`42-I WELL LOG TRANSMITTAL#902760582 DATA LOGGED .V 3/201$ ..i.K.BENDER To: Alaska Oil and Gas Conservation Comm. October 30, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED NOV 0 3 1015 RE: Leak Detect Log with ACX: 2G-15 AOG CC Run Date: 20-21 SEP 2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2G-15 Digital Data in LAS format, Digital Log file 1 CD Rom 50-029-21162-00 SCANNED Leak Detect Log with ACX (Processed Log) 1 Color Log 50-029-21162-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / / ✓a ,ov —eiteat \-644--‘31 • • 2.6355 WELL LOG TRANSMITTAL#902577131 To: Alaska Oil and Gas Conservation Comm. October 9, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100K.BENDER K.BENDEDE R Anchorage, Alaska 99501 'RECEIVED OCT 14 2015 RE: Multi Finger Caliper(MFC): 2G-15 AOGCC Run Date: 9/2/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2G-15 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21162-00 CANKt s '. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ' vagcM tz.. Alk / . ;/ ti OF 77 • 4.>w��\\ 1/7. s, 9 THE STATE Alaska Oil and Gas , ofA LAsKA Conservation Commission ux == 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0 - Q. Main: 907.279.1433 ALA�J� a l Fax: 907.276.7542 tti VaC4 j? www.aogcc.alaska.gov Tyson Wiese �3I Sr. Wells Engineer ConocoPhillips Alaska, Inc. \� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-15 Sundry Number: 315-612 Dear Mr. Wiese: 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 S. Foerster Chair DATED this� day of October, 2015 Encl. RBDMS J DCS'©I 1015 STATE OF KA OIL AND GAS CONSERVATION COMOSION APPLICATION FOR SUNDRY APPROVALS OCT 0 1 2015 20AAC25.280 fl7s lo( S / /s 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r V Pull Tubing r '413 w n r Suspend r Perforate r Other Stimulate r Alter Casing rr Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well Re-enter Susp Well r Other:Resin Packer Repair fW ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc., Exploratory r' Development FL 184-131 _ 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-21162-00 . 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r / KRU 2G-15 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25667 , 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): - 6997 - 6346 - 6900' •6277' 6464' 6990' Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 16 105' 105' SURFACE 2693 9-5/8" 2727' 2726' PRODUCTION 6950 7 6983' 6336' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6566-6580,6658-6674,6694-6738 6044-6054,6107-6118,6132-6162 3.5 L-80 6508 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL PACKER MD=6436 TVD=5955 ' PACKER-BAKER FHL PACKER MD=6548 TVD=6032 . NIPPLE-CAMCO DS LANDING NIPPLE MD=515 TVD=515 • 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development p ' Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/14/2015 OIL ' . WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true d correct to the best of my knowledge. Contact: Tyson Wiese @ 263-4250 l Email: Tyson.M.Wiese(cr�conocophillips.com Printed Name Tyson Wiese( Title: Sr. Wells Engineer Signature Phone:263-4250 Date 1-30— -015 Commission Use Only Sundry Number: 31 5.(t*2 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: gb— 4-6 4— APPROVED BY C/ Approved by: % if COMMISSIONER THE COMMISSION Date: /0-.S'/J v,rt_ `r®Z2147, -- pproved application is valid to 1 o ti s t o the date oof�approval. s mit Form and Form 10-403 Revise2015 la z'/� R �� r yy / B �[ynbts in Mt 6 2015 • 2G-15 Resin Packer Repair Permit to Drill #: 184-131 The objective of the proposed 2G-15 Resin Packer Repair is to restore Tubing and IA integrity and allow the well to be put back on production. An acoustic leak detect log has confirmed leaks at the top packer, both on the tubing side and the backside. If this non-rig repair is a success the incremental production expected from this well is estimated to be 110 BOPD. J Resin Packer Repair Summary: Digital Slick Line / Little Red: (Prepare Well for Resin Plug) 1. Dummy off current gas lift design, and pull RBP @ 6,464' KB. 2. Run Pre-Resin CBL from 6,436' —6,000' as a baseline to help identify post-job top of resin. 3. Set Composite Bridge Plug @ 6,446' KB. Dump bail 3' of cement on top of bridge plug. 4. Shoot Tubing Punches from 6,415 —6,417' KB to create circ. point for balanced resin plug. 5. Confirm circulation rate through tubing punches to ensure adequate for resin placement. RDMO. Coiled Tubing: (Place Balanced Resin Plug) 1. Ensure that the 10-403 Sundry has been approved by the AOGCC. 2. RIH pumping warm diesel to prep the wellbore for the resin treatment. 3. Place the 100' balanced resin plug in the Tubing and IA, with a planned top of resin @ 6,336' KB. 4. Lay in 9.8# brine and diesel FP to balance the wellbore. RDMO. Slickline / DHD: (Locate Resin Top and Pressure Test) 1. After 7 days of cure time, RIH and tag top of resin @ approx. 6,336' KB with a sample bailer. 2. Perform MIT-T to 3,000 psi, MIT-IA to 2,000 psi, T-DDT, and IA-DDT. Record Results. 3. With passing pressure and drawdown tests, RDMO. Coiled Tubing: (Mill out 107' Resin, 3' Cement Cap, and 4' CBP) 1. RIH with milling BHA and mill through approx. 107' of resin, 3' of cement cap, and the CBP. 2. Once through the CBP @ 6,446' KB, Push any remains of the CBP down into the rathole. RDMO. Digital Slick Line/ Little Red: (Pressure Test Resin Plug, Prep for Production) 1. Drift tubing with GR to D-nipple @ 6,490" KB. B&F if needed to clean up residual resin in the area. 2. Set lock/plug in the 2.812" D-nipple @ 6,490' KB. / 3. Perform MIT-T to 3,000 psi, MIT-IA to 2,000 psi, T-DDT, and IA-DDT. Record Results. 4. RIH with CBL and log from 6,436' —6,000' to identify top of resin in the IA. 5. Install updated gas lift design. Pull catcher/lock/plug. RDMO. Turn well over to Operations. TW • e 2G-15 PTD : 184-131 Resin Packer Repair Current Completion Proposed Resin Packer Repair WI, i 6.. te•82.500 H-40 Casing a 10:5'KB 217.5"DS Nppie a 515'KB g 643'3131$J-55 Casng a 3,726'KB Ali , ,, _ i, .,-, .11 ' Top ot 6.8#Brine I6. 4 2.000r KB GLM's - I. .,,,.., DM'a 2,647 103 VW summary: DM e a 4,0 1-5KB WV a 4,070 KB • DMY off GLD DMY a 5,74Z KB ° 'i Civt`r`a 6,363'KB , pip • Set CBP • Dump Bail 3'Ceirnent Cap • Shoot Tubing Punchers ‘PTA • Confirm Ciro.Path for Resin "Orb • Warm up well with diesel r ' • Place 100 balanced resin WI i - plug wl CT. • Allow 7 days to cure .. Pressure Test Plug I MIT' Top of Resin a i DDT) 6,336"KB • Mill out Resiin and C BP 1111. from Tubing. • Set nipple plug and test resin integrity. 100' / • Install new GLD i Eake-F1-1._7-"ac•-•(...e,;:i;6,436 F.B niig, ,-, 1 T.--:ng and 5xth LE-ahs) Le.:. mu P.BP g a 464'KB Composite Bridge Plug 6,446"KE 'ff• it i If !Y - ' ( 1 Baker-FHL g 6 543'KB 10 0 2.7E*D Npple a 6,585'KB 35'0.3#L-80 Tubing a 6,577 KB C-Sand Pests from 5.566'-8,580'KB 44/1 - A-Sand Perfs g 6,858'-6.72Er KB —... T 2tV.1-55 Casing g 7,1116'KB AU . TW • c]1, KUP PROD 0 2G-15 ConocoPhillips P- ' Well Attributes Max Angle&MD TD Alaska,inc. Wellbore APIIUWI Field Name Wellbore Status Ind(°) MD(kKB) Act Blot(ftKB) t yn,c mp,4 500292116200 KUPARUK RIVER UNIT PROD 47.88 6,000.00 6,997.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 25-15,9/2220159:20:17 AM SSSV:NIPPLE 150 11/1/2014 Last WO: 5/4/2004 40.98 10/16/1984 Vertical schematic(actual) Annotation Depth(kKB) End Date Annotation Last Mod By End Date -------------- -•---- HANGER;3z.0 �. ( Last Tag:SLM 6,756.0 8/30/2015 Rev Reason:PULL PLUG,PULURESET PLUG hipshkf 9/22/2015 1 Casing Strings ) ii Cas ng Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 105.0 105.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread � SURFACE 9 5/8 8.921 34.0 2,726.5 2,726.1 36.00 J-55 BUTT 17/6/17 Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)... WtlLen(I...Grade Top Thread - PRODUCTION 7 6.276 33.1 6,983.0 6,336.3 26.00 J-55 BUTT Tubing Strings ✓VAI CONDUCTOR;35.0.105.0^ TubingDescription StringMa...ID TopkKB Set Depth(ft..Set Depth ND Wt Iblft Grade TopConnection P (in) (kKB) P P (TVD)( ( ) NIPPLE;514.7 *A TUBING WO 312 2.992 32.0 6,508.8 6,004.8 9-30 L-80 EUE-ABM Completion Details Nominal 10 Top(kKB) Top(ND)(ftKB) Top Incl(°) Item Des Cons (in) 320 32.0 0.23 HANGER CAMERON TUBING HANGER 3.500 GAS LIFT;2,647.3 1 4 514.7 514.7 0.65 NIPPLE CAMCO DS LANDING NIPPLE 2.875 6,419.6 5,943.8 46.93 LOCATOR BAKER LOCATOR 3.000 6,422.9 5,946.1 46.92 PBR BAKER 80-40 2.980 SURFACE;34.0-2.726.5--.J " 6,436.3 5,955.2 46.89 PACKER BAKER FHL PACKER 2.990 6,489.9 5,991.9 46.77 NIPPLE CAMCO D NIPPLE 2.812 GAS LIFT;4,014.9 16,503.1 6,000.9 46.75 OVERSHOT POOR BOY OVERHSHOT(SPACEOUT 3.0"ID @ 6501') 3.625 Tubing Description String Ma...ID 6e) Top(kKB) Set Depth(ft..Set Depth(ND)(...Wt(IWft) Grade Top Connection g TUBING Original 3 1/2 2.992 6,496.9 6,577.2 6,051.7 EUE8RD GAS LIFT;4,970.0, Completion Details Nominal ID Top(kKB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) 6,534.6 6,022.5 46.73 PBR BAKER PBR 3.000 GAS LIFT;5,742.7 6,548.0 6,031.6 46.73 PACKER BAKER FHL PACKER 3.000 F--' 6,043.3 46.72 NIPPLE CAMCO D NIPPLE 2.750 6,576.4 6,051.2 46.71 SOS BAKER SHEAR OUT SUB,ELMD TTL @ 6566'during 3.000 GAS LIFT;6,363.5 SWS PERF LOG on 02/23/2005 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(kKB) (kKB) (°) Des Com Run Date 15(in) LOCATOR;6.419.6 6,464.0' 5,974.1 46.83 PLUG STATEWIDE 3-1/2"PARAGON RBP(SN:CPP- 9/14/2015 TUBING SPACE OUT;6,419.9 35005)W FILL SUB PBR;6,422.9 6,990.0' 6,341.3 44.58 FISH Retainer Ring 1.5"x 4"PIECE OF SHEAR PIN 2/21/2005 0.000 PACKER;6436.3 RETAINER RING left in hole Perforations&Slots PLUG;6,464.0 *4 Shot Dens Top(ND) Otto(ND) (shots/f Top(ftKB) Btm(ftKB) (kKB) ,, (kKB) Zone Date t) Type Com NIPPLE;6.469.9 6,566.0 6,580.0' 6,044.0 6,053.6 C-4,2G-15 2/23/2005 • 60 APERF 2.5"HSD,60 deg.ph 6,658.0' 6,6740 6,107.3 6,118.3 A-5,2G-15 9/30/1985 4.0 RPERF 2 1/8"Dresser;0 Ph • 6,660.0 6,662.0 6,108.6 6,110.0 A-5,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. TUBING SPACE OUT;6,500.9 ,@{ ..„--. Phasing OVERSHOT;6,500.1 1fy 6,666.0 6,667.0 6,112.8 6,113.5 A-5,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Phasing PBR;6,534.6 6,668.0 6,669.0 6,114.2 6,114.9 A-5,2G-15 '11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Phasing PACKER;6548.0 6,694.0 6,738.0 6,132.2 6,162.8 A-4,2G-15 9/30/1985 4.0 RPERF 2 1/8"Dresser;0 Ph NIPPLE;6.565.0 6,697.0- 6,698.0' 6,134.3 6,135.0 A-4,20-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. - Phasing APERF;6,566.0-6,580.0- - 6,700.0 6,702.0 6,136.4 6,137.7 A-4,2G-15 '11/8/1984 1.0 IPERF 4"DA JJ;90 deg. SOS;6576.4 Phasing 6,705.0 6,706.0' 6,139.8 6,140.5 A-4,2G-15 '11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Phasing (PERF;6,600.0.6,662.0- .--., 6,710.0 6,712.0 6, 143.3 6,144.7 A-4,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. ' Phasing RPERF;6,658.0.6674.0L - E 6,716.0 6,718.0 6,147.5 6,148.9 A-4,2G-15 11/8/1984 1.0 (PERF 4"DA JJ;90 deg. IPERF;6,666.0.6,667.0 . .-- Phasing (PERF;6,668.0-6,669.0- L 6,724.0 6,725.0 6,153.1 6,153.8 A-4,2G-15 :11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Phasing 6,727.0 6,728.0 6,155.1 6,155.8 A-4,20-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. - -- Phasing IPERF;6,697.0.6,696.0-�_ " Mandrel Inserts - St IPERF;6,700.0.6,702.0 = ati _ _ on Top(ND) Valve Latch Port Size TRO Run NTop(kKB) (kKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1c 1'_ 2,647.3 2,646.9'CAMCO MMG 11/2 GAS LIFT 'GLV RK 0.125 1,238.0 2/14/2009 4:00 IPERF;6,705.06.706.0 -� .- 2 4,014.9 4,013.0 CAMCO MMG 11/2 GAS LIFT GLV RK 0.125 1,239.0 2/14/2009 11:00 IPERF;6,710.46712.0 . •- 3 4,970.0 4,887.2'CAMCO MMG 1 1/2 GAS LIFT 'GLV RK 0.188 1,261.0 2/16/2009 5:30 - r= 4- 5,742.7 5,485.6 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,252.0 2/13/2009 5:30 RPERF;6,694.0-5,738.04, __ _ 5 6,363.5 5,905.5 CAMCO MMG 11/2 GAS LIFT OPEN RK 9/6/2015 4:00 IPERF;6,716.0-6,718.0--- - _ Notes:General&Safety IPERF;6,724.0-6,725.0 End Date Annotation 10/21/2010 NOTE:View Schematic wl Alaska Schematic9.0 IPERF;6,727.46,726.0_ PRODUCTION;33.1-6,983.0 FISH;6.990.04 2`11Z_ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 13, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Static Bottom Hole Pressure Survey : 2G-15 Run Date: 7/10/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2G-15 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21162-00 Bottom Hole Pressure Survey Log 1 Color Log 50-029-21162-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Klinton Wood SCANNED i 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 9/6 /I2 Signed: �'G�,a- i / !ma~t-'roject* Well History 'Pile ~Jove~age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. /~_¢- / _~./ Well History Fil~ldentifier Orga. nizing RESCAN DIGITAL DATA OVERSIZED (Scannable) _ Color items: Grayscale items: Poor Quality Originals: Other: NOTES: BY: BEVERLY [] Diskettes, No. [] Other, No/Type BREN VINCEt~~ARIA LOWELL Project Proofing BY: BEVERLY BREN VINCE~ARIA LOWELL Scanning Preparation BY: BEVERLY BREN MINC~MARIA LOWELL [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other ./ Production Scanning ~/q ~ Stage f PAGE COUNT FROM SCANNED FILE: -~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: _/7?ES NO ~ IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ _ YES . _.~ NO Stage 2 BY: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ General Notes or Comments about this file:, Quality Checked • Pr') 1841310 Regg, James B (DOA) From: NSK Prod Engr Specialist [n1139 ©conocophillips.com] Sent: Monday, November 07, 2011 7:28 AM To: Regg, James B (DOA); Grimaldi, Louis R (DOA) Cc: NSK Prod Engr & Optimization Supv; NSK Fieldwide Operations Supt; CPF1 &2 Ops Supt Subject: RE: Wellhead /Flowline observations Jim /Lou The items you mentioned below for these wells were investigated and here are the responses you requested. 1 R -25 — A pipe support has been installed inside well shelter on the S -Riser and engineering has confirmed the adequacy of the support. /2G -15 - -The flowline /riser was recently upgraded, the well line and riser are all level and plumb. Our engineering group has evaluated that the 'set' of the wellhead does not pose integrity concerns. The wellhead was evaluated by CPAI's Well Integrity group and was determined to have integrity based on the tests and actions listed below. 4/2/09 - MITOA passed 2/21/09 - TIFL passed 04/29/04 - 05/03/04 - Rig workover to replace tubing and ICPOs, MITT and MITIA to 2500 passed 4/19/04 - Pre workover TxIA CMIT passed 10/19/84 - OA cement shoe pumped. Tested to 1000 psi Regards, Darrell Humphrey / Bob Christensen tkr.. t) i � f z YlL ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659 -7535 NSK -69 Pager (907) 659 -7000 (924) From: Regg, James B (DOA) [mailto:jim.reggPalaska.gov] Sent: Friday, November 04, 2011 3:49 PM To: NSK Prod Engr Specialist Cc: DOA AOGCC Prudhoe Bay Subject: RE: Wellhead /Flowline observations have these issues been addressed? please confirm. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Grimaldi, Louis R (DOA) Sent: Wednesday, October 19, 2011 10:23 AM To: NSK Prod Engr Specialist Cc: DOA AOGCC Prudhoe Bay Subject: Wellhead /Flowline observations 1 Bob, • • In the testing with Buddy the other day I made note of the following wells conditions that will be in my report. 1R-25 S -Riser (downcomer ?) appeared to be in a substantial bind possibly due to inadequate support, 2G -15 Wellhead appeared to be leaning in the direction of the flowline fairly severe. I would appreciate someone checking on these and reply to follow. Thank you, Lou From: NSK Prod Engr Specialist [ mailto :n1139 @conocophillips.com] Sent: Monday, October 10, 2011 8:55 AM To: Grimaldi, Louis R (DOA) Cc: NSK Fieldwide Operations Supt; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; NSK Prod Engr & Optimization Supv Subject: 3I -04 Wellhead Tree Lou — here is the email response you requested regarding the wellhead tree on 31 -04. The wellhead is being affected by subsidence of the flowline supports behind the well house. The repair and long term mitigation is a several part process that includes modifying the riser, adding a mid span adjustable support and adding a thermosyphon and adjustable support behind the wellhouse. Work is expected to start next week and be completed by the end of the year. This repair is part of a larger campaign to address several wells around the field. Darrell Humphrey / Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659 -7535 NSK -69 Pager (907) 659 -7000 (924) 2 • 0 Regg, James B (DOA) From: Herrera, Matt F (DOA) . --) Sent: Sunday, November 06, 2011 4:11 PM ,‘I' To: Regg, James B (DOA) Subject: RE: Wellhead /Flowline observations Jim, while SVS testing in Kuparuk today I stopped and looked at the wellheads in question and although nothing has been done to correct them as of yet I was assured by Darrell that their engineering group was looking in to it. I also had one well head with the same issue on KRU1Y -30, it was noted and reported to operator. Matt H From: Regg, James B (DOA) Sent: Fri 11/4/2011 3:49 PM To: 'NSK Prod Engr Specialist' Cc: DOA AOGCC Prudhoe Bay Subject: RE: Wellhead /Flowline observations have these issues been addressed? please confirm. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Grimaldi, Louis R (DOA) Sent: Wednesday, October 19, 2011 10:23 AM To: NSK Prod Engr Specialist Cc: DOA AOGCC Prudhoe Bay Subject: Wellhead /Flowline observations Bob, In the testing with Buddy the other day I made note of e following wells conditions that will be in my report. 1 R -25 S -Riser (downcomer ?) appeared to be in a s •stantial bind possibly due to inadequate support, 2G -15 Wellhead appeared to be leaning in the dire tion of the flowline fairly severe. I would appreciate someone checking on thes- and reply to follow. Thank you, Lou From: NSK Prod Engr Specialist [ mail 'o:n1139@conocophillips.com] Sent: Monday, October 10, 2011 8: 5 AM To: Grimaldi, Louis R (DOA) Cc: NSK Fieldwide Operations Su t; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; NSK Prod Engr & Optimization Supv Subject: 3I -04 Wellhead Tree, Lou — here is the email resp se you requested regarding the wellhead tree on 31 -04. The wellhead is being affected by subsidence of the flowline supports behind the well house. The repair and long term mitigation is a several part process that includes modifying the riser, adding a mid span adjustable support and adding a 1 • • Regg, James B (DOA) From: Grimaldi, Louis R (DOA) ,.--? Sent: Friday, November 04, 2011 4:17 PM h� To: Regg, James B (DOA) ` Subject: RE: Wellhead /Flowline observations Attachments: 1R -25 Downcomer 10 -21 -11 LG.JPG; 2G -15 Wellhead 10 -21 -11 LG.JPG forgot, I took some pix. The 2G wellhead speaks for itself The 1 R -25 downcomer, look at the horizontal section right by the "Tee ", I swear it is bent there or its one of the best optical illusions. I was thinking of getting a small torpedo level with the adjustable vial and start seeing how far off plumb these things are. I think the wellhead is far enough out of whack that it would make unseating the hanger difficult. I think after awhile you look at so many of these they don't scream at you anymore but they are still screwed up. Lou Grimaldi Petroleum Inspector N.S. Pager 659 -3607 Home 776 -5402 Cell 252 -3409 From: Regg, James B (DOA) Sent: Fri 11/4/2011 16:07 To: Grimaldi, Louis R (DOA) Subject: RE: Wellhead /Flowline observations my pleasure Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Grimaldi, Louis R (DOA) Sent: Friday, November 04, 2011 4:04 PM To: Regg, James B (DOA) Subject: RE: Wellhead /Flowline observations I wonder if they will tell you the same thing they told me; Thanx for applying some heat. Lou Grimaldi Petroleum Inspector N.S. Pager 659 -3607 Home 776 -5402 Cell 252 -3409 1 • • From: Regg, James B (DOA) Sent: Fri 11/4/2011 15:49 To: 'NSK Prod Engr Specialist' Cc: DOA AOGCC Prudhoe Bay Subject: RE: Wellhead /Flowline observations have these issues been addressed? please confirm. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Grimaldi, Louis R (DOA) Sent: Wednesday, October 19, 2011 10:23 AM To: NSK Prod Engr Specialist Cc: DOA AOGCC Prudhoe Bay Subject: Wellhead /Flowline observations Bob, In the testing with Buddy the other day I made note of the following wells conditions that will be in my report. 1R-25 S -Riser (downcomer ?) appeared to be in a substantial bind possibly due to inadequate support, 2G -15 Wellhead appeared to be leaning in the direction of the flowline fairly severe. I would appreciate someone checking on these and reply to follow. Thank you, Lou From: NSK Prod Engr Specialist [ mailto :n1139Caconocophillips.com] Sent: Monday, October 10, 2011 8:55 AM To: Grimaldi, Louis R (DOA) Cc: NSK Fieldwide Operations Supt; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; NSK Prod Engr & Optimization Supv Subject: 3I -04 Wellhead Tree Lou — here is the email response you requested regarding the wellhead tree on 31 -04. The wellhead is being affected by subsidence of the flowline supports behind the well house. The repair and long term mitigation is a several part process that includes modifying the riser, adding a mid span adjustable support and adding a thermosyphon and adjustable support behind the wellhouse. Work is expected to start next week and be completed by the end of the year. This repair is part of a larger campaign to address several wells around the field. Darrell Humphrey / Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659 -7535 NSK -69 Pager (907) 659 -7000 (924) 2 Wellhead Observations — KRU . Photos by AOGCC Inspector L. Grimaldi . 10/21/2011 al ., to iir s it -- i lli III Wit7" '- ' - - 'P '' s'- ..., , ' ' . 4611MIPP' 4 ' '' ' '' t ' :: '''''''' ' . ' 'lir 4110 . ' " ; ir . .. • 1 z r w[ 1 1 ,. .. -.._ . 7� _ 4 ". , • 7 . . _ , , , .... , ,, ... , 4 , „ , . , r'S ' - - , i''. : ‘ ' - - .41 - d"• 14 il ti KRU 1R- 25(PTD 1910470) downcomer in S- KRU 2G- 15(PTD 1841310) wellhead appears Riser appears bent bent ,' e _ C~~~~ ~E: ~ ~$~~ ~ 03/18/09 ~~r~~~~~ '; v 9 , g v+~~ - N0.5138 ~ ~~,~t ~~~s. `,, 1L s.i.r..m~- fj Schlumberger -DCS ~ f' ' 2525 Gambell S#reet, Suite 400 '~ f Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~ j ~ ~~ Attn: Christine Mahnken ATTN: Beth I , a 1 1 ~ 333 West 7th Ave, Suite 100 _ \ ; ~,,' -- ~ \~ ~ ~ Anchorage, AK 99501 i ') "t ~~ ,~ `~7 Field: Kuparuk Well Job # Log Description Date BL Color CD 2A-26 B04C-00011 OH EDIT (PEX,SSCANNER & CHFR) -p9c./ [ ~~f 02/14/09 6 1 1 E-170 ANHY-00057 PRODUCTION PROFILE ab "- ~- 03!06/09 1 1 1A-11 ANHY-00058 LDL ~ C{ 03/08/09 1 1 3G-04 ANHY-00060 PRODUCTION PROFILE Q_ 03/10/09 1 1 3B-15 ANHY-00061 INJECTION PROFILE J "~ "Zj 03/11/09 1 1 i R-10 ANHY-00063 INJECTION PROFILE C 03/13/09 1 1 2M-16 ANHY-00064 INJECTION PROFILE / _ 03/14/09 1 1 2G-15 ANHY-00065 PRODUCTION PROFILE I'~C f- l 03/15/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ._ 2G-15 (PTD 1841310) Report of failed TIFL Page 1 of 1 • • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, January 23, 2009 11:42 AM 2 I ~Z~~ZC'i)~1 ~ ~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 2G-15 (PTD 1841310) Report of failed TIFL Attachments: 2G-15 90 day TIO plot.jpg; 2G-15 schematic.pdf Tom, Jim Kuparuk gas lifted producer 2G-15 (PTD 1841310) failed a diagnostic TIFL on 01/22/09. The TIO prior to shut in for the test was 150/900/680. A leaking GLV is suspected. Slickline will troubleshoot the leak and repair if possible. Attached is a wellbore schematic and a 90 day TIO plot. «2G-15 90 day TIO plot.jpg» «2G-15 schematic.pdf» Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ,~n ~,-, , R ` ConocoPhillips Alaska, Inc. ~ (~ ' ~ ~~ , Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~o ~~t P ., ~' Z`Zo j no}~~cc~ ~w~-,.~ d~ -~U- C~.7 ~~'i4 . c~ 1 /28/2009 KRU 2G-15 PTD 184-131 1 /23/2009 --~,~. ,~ ~ ~'~u-F • _ _ - ,g,. KUP ~CN'iCKl7p~'ll~~ip5 ~ ~ ,WellAttributes _ - -- - _ - WellboreAPINWI _ Fieltl Name Well Status ''°' 500292116200 KUPARUK RIVER UNIT PROD Comment H25 (ppm) Dets Annotation End I - wen carp: - zG-u nz4/zooe lo:a t io HM --' NIPPLE 200 7/1!2008 Last WO: _ n unc ncwat A Cation Dspth (HKB) E d Deb A notation Last Taq 6 766 0 7!2/2008 Rev Reason TAG FILL ~ ~ ~ CasingStrin~s _ CONDUCTOR, pp ~ Set Depth 105 _.-1 CasingD cenptlon OD( ) ID (In) Top (NKB) (ftKB) CONDUCTOR 16 15.062 0.0 105.0 sssv sls p { ~ ~ SURFACE 95/8 8.765 0.0 2,726.0 . ~ ~ i 6 PRODUCTION 7 6.151 0.0 6,983.0 2G-15 I roeiioo 1°1 mta+ Ddhu, taKaj 47 88 6,983.0 lepth (ND) Wt (ftKB) (Ibs/ft) Oreda 7/24/2008 fop Thraad -~- Tubing Strin~s- - --- -- 2 647 -^~ Se1Depth , 9 Tubing Description OD (in) ID (in) Top ((tK6) (NKa) Set Depth (ND) (ftKB) Wt (Ibs/fl) Gt SURFACE 8M TUBING 31/2 2.992 0.0 6,504.0 6,001.5 9.30 L-F , z?zs ~ TUBING 3 1/2 2.992 6,504.0 6.577.0 6,051.6 9.30 J-° cAS uFT, '.T Other In Hol> a A Retnevable, Fish, etc~ ll Jewel : Tu b ing Run & 4,015 - ' -~ Top (ftKB) Deacnpl ion _ _ __ __ _. _ _ Commont 515.0 SSSV NIPPLE CAMCO DS LANDING NIPPLE set 5/4/04 GAS LIFT, ~ __: 2,647.0 GAS LIFT CAMCO/MMG/1.5/GLV/RK/.188/1268/ Comment: STA 1 4.976 ~ _ -_ 4,015.0 GAS LIFT CAMCO/MMG/1.5/GLV/RK/.188/1268/Comment: STA2 4,970.0 GAS LIFT CAMCO/MMG/1.5lGLV/RK1.188/1261/Comment: ST GAS LIFT, r '-" ' ~ 5,743.0 GAS LIFT CAMCO/MMG/1.5/OV/RK/.25//Comment: STA4 s,743 ~_ ~~ - 6,364.0 GAS LIFT CAMCO/MMG/1.5/DMY/RKP/// CommenC STA 5 6,423.0 PBR BAKER 80-40 PBR set 5/4/2004 cAS uPr, 8 364 -='-' 6,438.0 PACKER BAKER FHL PACKER, set 5/4/2004 , ~- 6,490.0 NIPPLE CAMCO DS NIPPLE set 5/4/2004 [ ~ 6,504.0 Overshot POOR BOY OVERSHOT, TOP OD 4.5", ID 3", BOTTI PBR, 6,423 (NO SEALS IN OVERSHOT) set 5!4/2004 ' ~ ~ 6,535.0 PBR Baker PBR (original completion) r 6,548.0 PACKER Baker'FHL' PACKER (original completion) PACKER, 6,438 6,565.0 NIPPLE Camco'D' Nipple NO GO (original completion) ' ~ 6,576.0 SOS Baker (original completon) NIPPLE, 6,490 ~f 6,577.0 TTL (original completion) 6,990.0 Fish Retainer Ring 1.5" x 4" PIECE OF SHEAR PIN RETAI ~ 2121 Y2005 over:nm, 6so4 ; -' Pertorat ions s ;J ToP ( -- snot ND) Btm (ND) Dena PBR, 6,535 . - 6,566.0 6,580.0 6,044.0 6,053.6 APERF C-0, 2G-15 6.0 2Y23/2005 2.5" HSD, 60 deg. "` ~ ~ 6,658.0 6,674.0 6,107.4 6,118.4 RPERF A-5, 2G-15 4.0 9/30/1985 21/8"Dresser, 0 P - ~',. 6,660.0 6,662.0 6,108.7 6,110.1 IPERF A-5, 2G-15 1.0 11/8/1984 4" DA JJ; 90 deg. PACKER, 6,646 _ _ 6,666.0 6,666.0 6,112.9 6,112.9 IPERF A-5, 2G-15 1.0 11/8/1984 4" DA JJ; 90 deg. 6,668.0 6,668.0 6,114.2 6,114.2 IPERF A-5, 2G-15 1.0 11/8/1984 4" DA JJ; 90 deg. NIPPLE 566 8 6,694.0 6,738.0 6,132.2 6,162.9 RPERF A-0, 2G15 4.0 9130/1985 2 1/S"Dresser; 0 P , . 6,697.0 6,697.0 6,134.3 6,134.3 IPERF A-4, 2G-15 1.0 11/8/1984 4" DA JJ; 90 deg. APERF, _ 6,5663,560 ~ 6,700.0 6,702.0 6,136.4 6,137.7 IPERF A-0, 2G-15 1.0 11/8/1984 4" DA JJ;90 deg. F SOS, 6,5]6 6,705.0 6.705.0 6,139.8 6,139.8 1PERF A-0,2G15 1.0 11/8/1984 4"DA JJ; 90 deg. - TTL 6 577 ~ ~. 6,710.0 6,712.0 6,143.3 6,144.7 IPERF A-0, 2G-15 1.0 11/8/1984 4" DA JJ; 90 deg. , , 6,716.0 6.718.0 6.147.5 6,145.9 IPERF A-0, 2G-15 1.0 11/8/1984 4" DA JJ; 90 deg. 6,724.0 6,724.0 6,153.1 6,153.1 IPERF A-0, 2G-15 1.0 11/8/1984 Top (ftKB) BM (NKB) (ftKB) (HKB) Type Zone (shot.. F ~! 4" DA JJ; 90 deg. IPERF, 6,6603,662 IPERF, 6,666 RPERF, ~,. _ 6.656-6.674 IPERF, 6,668 IPERF, 6,697 - IPERF._ _ 6,700.6,702 - IPERF. 6,705 - - IPERF, 6,7103,712 RPERF, 6,6943,736-~---- ~- - IPERF, - 6.716-6,716 IPERF, 6,724 -- ~ _ IPERF, fi,727 - PRODUCTION. 6 963 TD, 6,963 Fisn, 6,990 -------_ ~{ _--_-.._ Date -, ID (Inl 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 AUn: 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 10/28105 1 1 A-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-01 A 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 1 J-154 11022931 USIT 10/12/05 1 2F-03 11015763 INJECTION PROFILE 10/31/05 1 SIGNED: U eJJJ DATE: (Ó Ið t) v- ~Ö'~~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. l~t.. ~ f 1 ') ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 March 3, 2005 RECEIVED, MAR 1 5 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage Subject: Report of Sundry Well Operations for 2G-15 (APD # 184-131) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the Kuparuk well 2G-15. If you have any questions regarding this matter, please contact me at 263-4574. . ~I:-t'i ;0 Sincerely, !A t J1 tJ?J~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad SCANNED lVV~R 2 4 20D5 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 140' 8. Property Designation: ADL 25667, ALK 2588 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: ) ) STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TlòMA 1 5 2005 Repair Well D Pull Tubing D Operat. ShutdownD Stimula~IUa Oil & Gas CØbns. Commsion Waiver rr Afm~éFågesion D Re-enter Suspended Well D 5. Permit to Drill Number: 184-131 6. API Number: 50-029-21162-00 Plug Perforations D Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Exploratory D Service D 9. Well Name and Number: 2G-15 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 6997' feet true vertical 6346' feet measured 6820' feet true vertical 6221' feet Length Size MD 105' 16" 105' 2586' 9-5/8" 2726' 6843' 7" 6983' Plugs (measured) Junk (measured) 6990' TVD Burst Collapse 105' 2726' 6336' Measured depth: 6566'-6580',6658'-6674',6694'-6738' true vertical depth: 6044'-6054',6107'-6118',6132'-6163' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 6577' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' PACKERS set at 6438',6548' Cameo DS Landing Nipple 515' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A i{BDMS BFL MAR 1 (; 7005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casinç¡ Pressure Tubinç¡ Pressure Prior to well operation 196 1156 521 145 Subsequent to operation 221 1236 977 147 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJ D WDSPLD 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: Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney 4J 4~ Title Phone Wells Group Team Leader ~ J 907-263-4574 Date 317~5 Prepared bv Sha:t fJ¡S/,Jp-Drake 263-4612 " f'-" \ h i ¡r\ L t ~:J ~ r~'~ . Submit Original Only Form 10-404 Revised 04/2004 ') 2G-15 Well Events Summary ) Date Summary 02/23/05 PERFORATE THE INTERVAL 6566'-6580' USING 2.5" HSD GUN LOADED WITH 2506 POWERJET HMX CHARGES AT 6 SPF, 60 DEG PHASING. API DATA: 25.2" PENETRATION, 0.32" ENTRANCE HOLE. ALL SHOTS FIRED. WELL LEFT SHUT IN, TAGGED TD AT 6820'. [Perf] ) ConocoPhilllps Alaska,lnc.. 2G-15 TUBING (0.ß504, OD:3.50Q, ID:2.992) Gas Lift MandrelNalve 1 (2647-2648, Overshot (6504-6512, OD:6.000) TUBING (6504-6577, 00:3.50CJ, 10:2.992) NIp-./' (6565.ß566, 00:3.500) Perf (6566.ß58<J) 50S (6576-6577, 00:3.500) Perf (6660-6662) Perf (6658-6674) Perf (6697-6697) Perf (6700.ß702) I ¡J.., 1 " L~ -- III .i , ¡I'~' - ~ ,I. , ~: API: 500292116200 SSSV Type: NIPPLE Annular Fluid: Reference Log. Last Tag: 6820 La::.t Tag Date: 2/23/2005 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SUR. CASING 9.625 PROD. CASING 7.000 tEùþinb String - TUBING Size Top 3.500 0 3.500 6504 Perforations Summary Interval TVD 6566 - 6580 6044 - 6054 6658 - 6660 6107 - 6109 6660-6662 6109-6110 6662-6666 6110-6113 6666-6666 6113-6113 6666-6668 6113-6114 6668-6668 6114-6114 6668-6674 6114-6118 6694-6697 6132-6134 6697-6697 6134-6134 6697 - 6700 6134 - 6136 6700 - 6702 6136 - 6138 6702 - 6705 6138 - 6140 6705 - 6705 6140 - 6140 6705-6710 6140-6143 6710-6712 6143-6145 6712-6716 6145-6148 6716-6718 6148-6149 6718-6724 6149-6153 6724 - 6724 6153 - 6153 6724-6727 6153-6155 6727-6727 6155-6155 6727 - 6738 6155 - 6163 ßâ$>Lift.··..Mãt1ørels~âlvès St MD TVD Man Mfr Man Type Zone C-4 A-5 A-5 A-5 A-5 A-5 A-5 A-5 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 KRU Well Type: PROD Orig Completion: 10/16/1984 Last w/o: 5/4/2004 2G-15 Angle @ TS: 47 deç¡ @ 6566 Anç¡le @ TD: 45 deg @ 6997 Rev Reason: PERFS, Tag, pull NIP Reducer Last Update. 2/24/2005 Ref Log Date: TD: 6997 ftKB Max Hole Angle. 48 deg @ 6000 Top Bottom TVD Wt Grade Thread 0 105 105 62.50 H-40 0 2726 2726 36.00 J-55 0 6983 6336 26.00 J-55 TVD Wt Grade Thread 6002 9.30 L-80 EUE 8RD 6052 9.30 J-55 ABM-EUE Status Ft SPF Date Type Comment 14 6 2/23/2005 APERF 2.5" HSD, 60 deç¡. ph 2 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 2 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 4 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 0 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 2 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 0 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 6 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 3 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 0 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 3 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 2 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 3 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 0 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 5 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 2 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 4 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 2 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 6 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 0 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 3 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 0 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 11 4 Ph Bottom 6504 6577 V Mfr V Type VOD Latch Port TRO Vlv Cmnt 0.188 1268 0.188 1268 0.188 1261 0.250 0 0 1 2647 2647 CAMCO MMG 2 4015 4013 CAMCO MMG 3 4970 4887 CAMCO MMG 4 5743 5486 CAMCO MMG 5 6364 5906 CAMCO MMG 0thêr··(pIÙgS,..êqÙi.p:, ··.etC:;).. ......JEVVEl.SFRY Depth TVD Type 515 515 NIP 6423 5946 PBR 6438 5956 PACKER 6490 5992 NIP 6504 6002 Overshot Description CAMCO DS LANDING NIPPLE set 5/4/04 BAKER 80-40 PBR set 5/4/2004 BAKER FHL PACKER, set 5/4/2004 CAMCO DS NIPPLE set 5/4/2004 POOR BOY OVERSHOT, TOP OD 4.5", ID 3", BOTTOM OD 6", ID 3.625" (NO SEALS IN OVERSHOT) set 5/4/2004 Chemical Cut TUBING CHEMICAL CUT 5/4/2004 PBR Baker PBR (original completion) PKR Baker 'FHL' PACKER (original completion) NIP Cameo 'D' Nipple NO GO (original completion) SOS Baker (original completion) TTL (original completion) 6512 6007 6535 6023 6548 6032 6565 6043 6576 6051 6577 6052 Fish - FISH Depth I Description 6990 Retainer Ring ID 2.875 2.980 2.990 2.812 3.625 2.992 3.000 3.000 2.750 2.992 2.992 I CommeM 1.5" x 4" PIECE OF SHEAR PIN RETAINER RING left in hole 2/21/2005 ,-....., ,-....., Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage. AK 99510-0360 Phone: 907-263-4574 Conoc~iIIi pS May 25, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2G-15 (APD # 184-131) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 2G-15. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ~'i!o~ Wells Group Team leader CPAI Drilling and Wells MM/skad RECEIVED MAY 2 5 2004 Alaska Oil & Gas Cons. Commission Anchorage ORIG\NAL ~ ,-....., STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): AKB 140' 1. Operations Performed: 8. Property Designation: ADL 25667, ALK 2588 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING CSG WINDOW Perforation depth: RepairWell 0 Pull Tubing 0 Operat. ShutdownD Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development - 0 Stratigraphic 0 measured 6997' feet true vertical 6346' feet measured 6726' feet true vertical 6154' feet Length Size MD 105' 16" 105' 2586' 9-5/8" 2726' 6843' 7" 6983' Measured depth: 6658'-6674',6694'-6738' true vertical depth: 6107'-6118', 6132'-6163' Tubing (size, grade, and measured depth) 3-1/2" , L-80 / J-55, 6577' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' PACKER pkr= 6438', 6548' SSSV= Cameo Landing nipple SSSV= 515' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl ~ ~ ffi 273 1091 1296 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: oil0 Gas 0 WAG 0 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Mike Mooney @ 265-4374 Mike Mooney JIr=I. Jf~ Signature Form 10-404 Revised 04/2004 Title Phone úR\G\NAL Stimulate 0 Other 0 Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 184-131 / 6. API Number: 50-029-21162-00 Exploratory 0 Service 0 9. Well Name and Number: 2G-15 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Collapse Burst 105' 2726' 6336' RECEIVED MAY 25 2004 Alaska Oil & Gas Cons. Commission Anchorage CasinQ Pressure TubinQ Pressure 159 Service 0 GINJD WDSPLD WINJD I Sundry Number or N/A if C.O. Exempt: Wells Group Team leader ¡ j ~:~red b:i!-ro!tuS~~:ke 263-4612 lW~a200' Submit Original Only ABDMS Sf L "TUBING (0-6504. 00:3.500. 10:2.992) Gas Lift 3ndreUOummy Valve 1 (2647-2648, 00:5.968) Overshot (6504-6512, 00:6.000) ,-....., ConocoPhillips Alaska, Inc,. ;2(3':'15" . API: 500292116200 SSSV Type: NIPPLE Annular Fluid: "TUSING 6512 6007 Chemical (6504-6577, 00:3.500, Cut 10:2.992) 6535 6023 PBR 6548 6032 PKR 6565 6043 PLUG 6565 6043 NIP 6565 6043 Nipple Reducer 6576 6051 SOS 6577 6052 TTL sos (6576-6577, 00:3.500) Perf (6660-6662) Perf (6697-6697) -- ~ KRU 2G-15 Well Type: PROD Ori9 10/16/1984 Completion: Last W/O: 5/4/2004 Angle @ TS: 47 deg @ 6566 Angle @ TD: 45 deg @ 6997 Rev Reason: WORKOVER, GLV design, pull balVrod Last Update: 5/9/2004 Ref Log Date: TD: 6997 ftKB M~~;.H~le A~917: 48 d~~L~,6000 " .... Top Bottom 0 105 0 2726 0 6983 TVD 6002 6052 Size 16.000 9.625 7.000 TVD 105 2726 6336 Wt 62.50 36.00 Grade H-40 J-55 J-55 Reference Log: Last Tag: 6726 LastTag Date: 12/28/2002 t ij$lng;StiiÔÖ'¡¡oJ\C\:'$;"ERIJilGS ,. Description CONDUCTOR SUR. CASING PROD. CASING TûlSlrnJiStrlnøJ::'Tt:lBING" Size I Top 3.500 0 3.500 6504 Peffõiâtlöñs';SiiiiiñíáIY' ;: Interval TVD 6658 - 6660 6107 - 6109 6660 - 6662 6109 - 6110 6662-6666 6110-6113 6666 - 6666 6113 - 6113 6666-6668 6113-6114 6668 - 6668 6114 - 6114 6668 - 6674 6114 - 6118 6694 - 6697 6132 - 6134 6697 - 6697 6134 - 6134 6697 - 6700 6134 - 6136 6700 - 6702 6136 - 6138 6702 - 6705 6138 - 6140 6705 - 6705 6140 - 6140 6705 - 6710 6140 - 6143 6710 - 6712 6143 - 6145 6712 - 6716 6145 - 6148 6716 - 6718 6148 - 6149 6718 - 6724 6149 - 6153 6724 - 6724 6153.6153 6724 - 6727 6153 - 6155 6727 - 6727 6155 - 6155 6727 - 6738 6155 - 6163 'Gš'.rClft:1Måiîi:li'êlš'Mlvjs St MD TVD Man Man Type Mfr 1 2647 2647 CAMCO MMG 2 4015 4013 CAMCO MMG 3 4970 4887 CAMCO MMG 4 5743 5486 CAMCO MMG 5 6364 5906 CAMCO MMG 'Othêf(ÞIúfj¡¡¡;êQuiP.;etc,l :-JEWELRY Depth TVD Type 515 515 NIP 6423 5946 PBR 6438 5956 PACKER 6490 5992 NIP 6504 6002 Overshot Bottom 6504 6577 9~~ I G~_~~e I 9.30 J-55 n... . .. .' .. ...n' Thread EUE 8RD Zone A-5 A-5 A-5 A-5 A-5 A-5 A-5 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-4 Status Ft SPF Date Type Comment 2 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 2 5 9/30/1985 RPERF 21/8"Dresser; 0 Ph 4 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 0 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 2 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 0 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 6 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 3 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 0 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 3 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 2 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 3 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 0 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 5 4 9/30/1985 RPERF 21/8"Dresser; 0 Ph 2 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 4 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 2 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 6 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 0 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 3 4 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 0 5 9/30/1985 RPERF 2 1/8"Dresser; 0 Ph 11 4. 9/30/1985 ~~,ERF 21/8"[)resser;~rh Date Run S/9/2004 S/9/20O4 5/9/2004 5/9/2004 5/9/2004 .. VMfr V Type VOD Latch Port TRO DMY 1.S RK 0.000 0 DMY 1.5 RK 0.000 - 0 DMY 1.5 RK 0.000 0 DMY 1.5 RK 0.000 0 DMY 1.5 RKP 0.000 0 ..,. ,. Description CAMCO DS LANDING NIPPLE set S/4/04 BAKER 80-40 PBR set 5/4/2004 BAKER FHL PACKER, set 5/4/2004 CAMCO DS NIPPLE set S/4/20O4 POOR BOY OVERSHOT, TOP OD 4.5", ID 3", BOTTOM OD 6",ID 3.62S" (NO SEALS IN OVERSHOT) set 5/4/2004 TUBING CHEMICAL CUT S/4/2004 Baker PBR (original completion) Baker 'FHL' PACKER (original completion) 2.25" A-2 PLUG SET 4/20/2003 (original completion) NOTE: THERE IS APPROX 1300# DIFFERENTIAL BELOW PLUG Camco 'D' Nipple NO GO (original completion) Nipple Reducer 2.7S" x 2.2S" w/2.2S" D Profile (original completion) Baker (original completion) (original completion) Thread Vlv Cmnt . .." ID 2.875 2.980 2.990 2.812 3.625 2.992 3.000 3.000 0.000 2.750 2.250 2.992 2.992 ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2G-15 2G-15 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S Start: 5/2/2004 Rig Release: Rig Number: Spud Date: 10/10/1984 End: Group: 4/29/2004 00:00 - 04:15 4.25 MOVE DMOB DEMOB 04:15 - 06:00 1.75 MOVE MOVE MOVE 06:00 - 08:00 2.00 MOVE MOVE MOVE 08:00 - 10:00 2.00 MOVE MOVE MOVE 10:00 - 13:00 3.00 MOVE POSN MOVE 13:00 - 17:00 4.00 MOVE RURD RIGUP 17:00 - 22:15 5.25 MOVE RGRP RIGUP 22:15 - 00:00 1.75 MOVE RURD RIGUP 4/30/2004 1.00 WELCTL NUND WRKOVR 00:00 - 01 :00 01 :00 - 03:00 2.00 WELLSF KILL DECOMP 03:00 - 03:30 0.50 WELCTL NUND WRKOVR 03:30 - 06:00 2.50 WELCTL NUND WRKOVR 06:00 - 09:30 3.50 WELCTL NUND WRKOVR 09:30 - 14:00 14:00 - 16:15 4.50 WELCTL BOPE WRKOVR 2.25 WELCTL BOPE WRKOVR 16:15 - 17:30 1.25 WELCTL SFTY WRKOVR 17:30 - 18:30 1.00 WELCTL BOPE WRKOVR 18:30-19:30 1.00 WELCTL SFTY WRKOVR 19:30 - 21 :00 1.50 CMPL TN RURD DECOMP 21 :00 - 21 :30 0.50 CMPL TN PULL DECOMP Rigging down rig and seperating from structures. Finnish wash up and begin raising ladders. Lower derrick and mpve away from well. Contact pad operator to close in casing valve on adjacent well. Rig leaving pad. Two crew members left behind to pick up around well. More than likely that the rig will have to pull over at the Y for field change out. Rig staged @ Y for field change out Rig arrived on pad and started setting up. Camp arrived on Pad. Backed Carrier sub over well and mated up the pits and the pipe shed. Spotted the camp and turned on electricity. Worked on getting communications established. Set up kill tank and layed hardline to circulate to. Raised the derrick and continued rigging up rig. Network communications established. Welder traveled over from deadhorse. Weld up hole in suction to charge pump. Release vac truck with brine on due to delay on pits. Welders finished with repairs. Begin loading pits. Continue to load pipe in pipe shed for strapping. Recalled vac truck w/brine. Will have to pre-fab new piping for pump #3. Now isolated from pump until pre-fab finnished. Still have pump 1&2. Accepted rig at 00:01 hours. Loading pits with second truck of 9.6PPG brine. Double check all hardline top tank farm for kitty pools, and knocked up unions. Have pre-spud meeting with night shit. Discussed hazzards and operations of 2G-15. Importance of target o. Begin 9.6# Brine circulation. ISIAP = 50#, ISIWHP= 0#, ISOAP = 0#. Begin pumping at 1 BPM 135# ramp up to 3 BPM @ 300#. 100% fluid to tanks. Pump 250 BBLS. Leaves aprox 200 BBLS in the pits. Install two way check in tree. Have grease crew service choke manifold. Modify T-Bar, had a broken shear screw, cut and weld. Send MI, and Cooper Industries rep to bed. Begin nipple down tree and picking up BOPE. Have pre-tower safety meeting, with discussion of lessons leamed. Stressed the importance of target O. Called AOGCC and talked to John Crisp. He waived the witnessing test due to Nordic being test ready. Finished NU BOPS and Function tested the same. Clear gravel in cellar and installed mousehole. Strapped 220 jts of new tubing in pipe shed. Testing BOPS, Test Cap leaked on last test. Continued testing BOPS. Safety Valve connection on Test Jt. Pulled out and re-tested. Drifting Jts #181 thru #219 w/2.91" rabbit. Found Jt #220 would not drift pulled out of the pipe shed. Left 219 Jts in pipe shed. Drifting Jts #1 thru #181 wI 2.867" rabbit. Completed BOP Test. Held pre-workover operation I safety meeting with Day Rig Crew, Toolpusher, Halliburton Rep, Cameron Rep, Co-man, Workover Eng, Prod. Eng, & CPAI Safet Rep. Knocked Ice build up off of derrick. Drained stack. Checked pressure on IA and pulled 2 way check. Have pre-spud meeting with new crew that arrived today for night shift. Prepare to unlock lock down screws. Begin to unlock lock down screws. New crwe performed a safety walk through on rig. Knocked more ice off of derrick due to heavy freezing ice. Begin pulling existing completion out of well. Weight broke free at 75K. Pulled 10 cycles to 115K. Aprox pipe stretch of 5.5'. Hold 115K# up wt for 20 min and monitor. Printed: 5/24/2004 1:53'24 PM ".........., ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2G-15 2G-15 WORKOVERIRECOMP Nabors Alaska Drilling Nabors 3S Start: 5/2/2004 Rig Release: Rig Number: Spud Date: 10/10/1984 End: Group: 4/30/2004 21:30 - 23:00 1.50 CMPL TN PULL DECOMP 23:00 - 00:00 1.00 WELLSR OTHR DECOMP 5/1/2004 00:00 - 01 :45 1.75 FISH CPBO DECOMP 01 :45 - 03:00 1.25 FISH CPBO DECOMP 03:00 - 03:15 0.25 WELCTL CIRC DECOMP 03:15 - 06:00 2.75 WELCTL CIRC DECOMP 06:00 - 06:30 0.50 WELCTL OBSV DECOMP 06:30 - 10:30 4.00 FISH RURD DECOMP 10:30-11:00 0.50 FISH SFTY DECOMP 11 :00 - 11 :30 0.50 FISH RURD DECOMP 11:30 -13:45 2.25 FISH CPBO DECOMP 13:45 - 14:15 14:15 - 15:15 0.50 FISH RURD DECOMP 1.00 CMPL TN TRIP DECOMP 15:15 - 16:45 1.50 CMPLTN TRIP DECOMP 16:45 - 17:30 0.75 CMPLTNTRIP DECOMP 17:30 - 18:00 0.50 CMPLTNTRIP DECOMP 18:00.20:00 2.00 WELLSR PULD DECOMP 20:00 - 21 :30 1.50 WELLSR NUND DECOMP 21 :30 . 00:00 2.50 WELLSR NUND DECOMP 5/2/2004 00:00 - 01 :30 1.50 CMPL TN NUND DECOMP 01 :30.02:30 1.00 WELCTL BOPE DECOMP Yard on pipe to no avail. Discuss other pulling options. Pulled as high as 122K held for 30 min. No movement. Begin chemical cut deliberations and rig up. Begin rigging up E-Line for chemical cut proceedures. Pick up three pup joints for friendly operation on the rig floor. Tubing joint is too high. Continue to rig up Conductor line. Hold PJSM on rig floor with all hands. Pick up three pup joints to keep working area near rig floor. Hanging wt = 62,000# aprox 10K over string wt. E-line running in hole with string shot. Rig crew continuing rig wash and performing 0 tolerance awareness. String shot to be placed in the middle of the first joint above PBR. Set off string shot from 6502' thru 6514'. After firing off string shot 6502' - 6514' ELMD and POOH with E-line noticed fluid returns on tubing side. Fluid began to escalate in pressure. Prepare for circulation kill. Shut in Haliburton valve and prep for circulation kill. Begin pumping 9.6# brine @ 1 bpm work our way to 3 bpm @ 230 PSI. ISIDPP = 20#. Circulated 15,000 Strokes (260 BBLS surface to surface plus some). Shut down and monitor well while crews change out. Shut TIW valve and pulled out Schlumbergers strip gun. Shut valve and prepared to install 31' joint of 3.5" tubing for chemical cut. E/line prepped chemical cutter. They had some problems with their stripper head, but were able to repair. PU Eline equipment and set up to go in hole. Held pre-job safety meeting with the rig crew and e/line crew. Continued RU E/line equipment. RIH wI E/line and 2-1/4" Chemical Cutter. Chemical cut Tubing in the 1 st full joint of tbg above the PBR. Made Chemical cut @ 6512' Based on old pipe tally true depth is 6504' Surface indications showed that Chemical Cutter fired. POOH wI E/line. Rigged E/line unit equipment out of the way. Latched up to Tubing and pulled up to 100K, came free, hanging weight 57K. Monitored well closely, appears everything is static. Start tripping out slowly. Pulled Hanger to the floor with no problems. Finished rigging down E/line equipment. Continued tripping pipe. 30 Joints laid down in the pipe shed. Pipe looks to be in good shape. Hole fill is looking good, SSSV @ surface control line stayed intact all the way to the SSSV. Recovered all 34 stainless steel bands. Pipe in good shape to SSSV. Racked Back 1st GLM between joint #61 and joint #62. No apparent problems seen. This GLM has the patch in it. Will break apart later. Racked Back another double Jt #63 & Jt#64 in preperation for setting Storm Packer. Layed down Halliburton spooling equipment. Pick up Baker Storm Packer and make up same. Pressure test against blinds to 1,000#. Passed. Nipple dwn BOP stack and prep to replace 7" packoffs. Monitor OA & IA open valve for flow at all times. Change out packoff. Replace casing spool. Pressure new packoffs to 3,000#. Install BOP. Continue to nipple up BOP and prepare to pressure test. Begin loading BOPE with Brine for pressure test after installing test plug. Pressure test BOP to 3,500#. Prep to pull test joint and plug for removal of test plug. Printed: 5/24/2004 1:53.24 PM ,-....., t"'"""\ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2G-15 2G-15 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S Start: 5/2/2004 Rig Release: Rig Number: Spud Date: 10/10/1984 End: Group: 5/2/2004 02:30 - 03:30 1.00 CMPLTNTRIP DECOMP 03:30 - 05:15 1.75 CMPL TN TRIP DECOMP 05:15 - 06:10 0.92 WELCTL CIRC DECOMP 06:10 - 08:00 1.83 CMPLTN TRIP DECOMP 08:00 - 09:00 1.00 WELCTL CIRC DECOMP 09:00 - 10:00 1.00 CMPLTNTRIP DECOMP 10:00 -11:45 1.75 CMPLTNTRIP DECOMP 11 :45 - 13:00 1.25 CMPLTNTRIP DECOMP 13:00 - 15:00 2.00 CMPL TN PULL DECOMP 15:00 - 15:45 0.75 CMPLTN 8FTY CMPLTN 15:45 - 17:30 1.75 CMPL TN RUNT CMPL TN 17:30 - 21:55 4.42 CMPL TN RUNT CMPL TN 21 :55 - 22:20 0.42 CMPL TN RUNT CMPL TN 22:20 - 23:30 1.17 CMPLTN RUNT CMPLTN 23:30 - 00:00 0.50 CMPL TN RUNT CMPL TN 5/3/2004 00:00 - 01 :00 1.00 CMPL TN RUNT CMPL TN 01:00 - 03:10 2.17 CMPLTN RUNT CMPL TN 03:10 - 04:00 0.83 CMPL TN RUNT CMPL TN 04:00 - 06:00 2.00 CMPL TN PCKR CMPL TN Slowly pull Baker Storm Packer to surface for removal. Lay down Baker Packer and prep to pull orginal completion to surface. Pull completion string to surface. up wt = 54K. Hole conditions are stable. All collars are extremely tight!! Circulate Bottoms up to clean out gassy fluid. Aprox 9,000 strokes 155 BBLs. Continued tripping out of the hole. Tripping out of hole. Continued to trip out of hole. Tubing has a lot of scale on the inside of it but loooks good on the outside. Decided to circulate again. Circulated btms up 158 bbsl @ 3 BPM. Decided to pull a little slower and see if that will eliminate the need for circulating. Continued tripping out of the hole. Layed down. GLM #3. Layed down GLM#4. Pulling slower was the ticket. Tubing still in same condition scale on the inside and looks good (no corrosion) on the outside. On surface with Joint #210 stub. Chemicall Cut looks very good fairly even with no swelling. Layed down GLM #5 (which showed signs of heavy corrosion). Also Jt #210 stub showed signs of heavy corrosion. Finished up strapping old tubing and jewelry. Strap shows to be about 8' different (short) from the old tubing tally dated 11-7-84. Broke out GLM #1 that we had racked back. The inner patch unscrewed in the middle and allowed us to lay tubing and GLM down seperately. Nothing of note on either GLM or top and btm Jts of tbg. Prepped the rig floor and pipe shed for completion run. Insured all jewelery drifted to 2.867". Wrapped up new pipe tally. Held pre-job mtg on the rig floor. Started running the completion 3-1/2" 9.3# EUE L-80 Tbg, Using Jet Lube Run-n-Seal Dope. Make up torque 2400#. Run Poor Boy OS 3.625" ID, 2.812" Camco DS nipple with RHC installed, Baker FHL packer, Baker 80-40 PBR (6 pins), Camco MMG GLM's a DCK in the lower most one. Made up GLM#2 and continued running completion. Change out crews and continue program. Due to brine flowing back through tubing decide to circulate two bottoms up and pump a dry job. Dry job wt = 9.1 PPG @ 10 bbls worth. Circulation pressure never went above 200# Continue to run completion program as per described. Bottom pup joint on gas lift mandrel number 5 has issues. Threads galled, Changed out with new pup. Difference of .02' noted. Hole conditions stable after pumping the dry job. Send out rig move notification @ 23:30. Continue to run new completion. Hole conditions normal. Full pipe displacement. Mud wt = 9.6# Continue to run new completion as per program. Install GLM # 5. No worries. Hole condition normal. Talked about skate power isolation to driller while people are moving jewelry to the skate. Continue to run new completion. Hole conditions friendly. Down wt = 50K, up wt = 55K Rig up floor valve and 1502 fitting on joint number 203 for pressure confirmation by pressure increase of swallowing the chemical cut stub. Dwn wt = 53K UP wt = 58K. Pump rate 1 BPM @ 10 PSI. Witnessed a 200# pressure increase while tagging up on no-go shoulder. 30K overpull to pick off stub first time, did not repeat. PUH for 1.5' spaceout of PBO8. Drop Ball and Rod 1-3/8" fishing neck, Printed: 5/24/2004 1:53-24 PM .,-....., r"\ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2G-15 2G-15 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S Start: 5/2/2004 Rig Release: Rig Number: Spud Date: 10/10/1984 End: Group: 513/2004 04:00 - 06:00 06:00 - 06:30 06:30 - 08:45 08:45 - 09:20 09:20 -10:05 10:05 - 10:30 2.00 CMPL TN PCKR CMPL TN 0.50 CMPL TN SFTY CMPL TN 2.25 CMPL TN SOHO CMPL TN 0.58 CMPL TN DEQT CMPL TN 0.75 CMPLTN DEQT CMPLTN 0.42 CMPL TN DEQT CMPL TN 10:30 -11:00 0.50 CMPL TN NUND CMPL TN 11 :00 - 15:00 4.00 CMPL TN NUND CMPL TN 15:00 -19:00 4.00 MOVE DMOB CMPL TN 19:00 - 00:00 5.00 MOVE DMOB CMPL TN 6.75' total length , stby for 15 min. Begin pumping at min rate. Instant pressure response. Take pressure to 1,450# feel and see pressure set of PKR. Allow pressure to sit for 30 min. Bleed off pressure and set 10K on PKR to ensure set. Shear out PBR with 1,000# internal pressure on production tubing. PBR Sheared at 30K over string weight Pressure test LA. to 1,000# prior to pulling out. Pressure test passed, prep to pull out of PBR and begin spaceout. Stby for crew changeout. Do not want to start spacing out and then have a crew change. Spaced out PBR 3' off full insertion. Used a 6' pup then Jt#201 was final then Hanger Pup and Hanger. Drained the stack and landed the Hanger (Use original RKB from Doyon 9 rig of 32'). RILDS. Prepeare for pressure test. Pressure up on the Tubing to 2500 psi. Left IA valve open to the atomsphere to monitor returns. Tubing pressure tested good. No returns from IA during the test. Bled the tubing pressure back to 1500 psi. Hooked pump up to IA. Pressure up on the IA to 2500 psi. The Tubing pressure came up to 2100 psi. Monitored and charted for 15 mins. Looks OK, but decided to bleed the tubing back down to 1500 psi and pressure IA back up for at least a 500 psi DP. Begin pressure test again with 2600 psi on the IA and 1700 psi on the tubing. Monitored and charted for 15 minutes. Good Test, Held ROCK solid. Bleed tubing back slowly, IA holding 2600 psi. Shear Out Valve sheared as tubing pressure reached 575 psi wI 2600 psi on IA (nominal 2000 psi DP). Shut in and both tubing and IA balanced out @ 2000 psi. Bleed bothe the tubing and IA to 0 psi. Removed landing joint from the hanger and installed BPV. Begin nippling down the BOPE. Tree installed Pressure tested Hanger to 5000 psi (good test). Pressure tested Body to 5000 psi (good test). Unloaded and thoroughly washed Pits. Begin breaking apart the BOPE for transport set on shipping boards. Pull away pits to install new Pump head for 4" conversion. Prepare pipe sed for move. Prepare to lower derrick. Clean cellar area. Release rig AT 24:00 HRS. Printed: 5/24/2004 1 :53:24 PM n ARGO Alaska, In Post Offic{:: ..,ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 ORIGIN August 22, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchofage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Report of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. Well Action 2G-13 2G-15 2G-O8 3H-O4 1 A,-1 1 1 A-16a 1A-O4 1F-08 1F-15 Refracture Refracture Refracture Acidize Tbg.Leak Packer Leak Acidize WAG Conversion WAG Conversion If you have any questions, please call me at 265-6840. Sincerely, þß J~~ ~~ ) G. B. ~OOd Senior Operations Engineer RECEIVED A002:3 jæ9 Alaska OU & Gas Cons. Gommission Anchorage GBS:Rjr cc: J. Gruber J. R. Brandstetter L. L. Perini KOE1.4-9 ATO 1478 ATO 1120 ATO1130 w/o attachments ARGO Alaska. Inc. is a Subsidiary of AtianticRichfieldCompany ~~ ~ 1"\ ~ œ STATE OFALASKA 0 I{ IN A ALASKA OIL AND GAS CONSERVATION COMMI~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Stimulate X Plugging Perforate __ Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 183' FNL, 88' FEL, Sec. 6, T10N, R9E, UM At top of productive interval 1174' FNL, 1094' FEL, Sec. 6, T10N, R9E, UM At effective depth 1292' FNL, 1251' FEL, Sec.6, T10N, R9E, UM At total depth 1398' FNL, 1307' FEL, Sec. 6, T10N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 6997' 6346' 6900' 6277' feet feet feet feet Plugs (measured) Junk (measured) None 6. Datum elevation (DF or KB) RKB 140' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2G-1 5 '~ '/~'c ~-- 9. Permit numbe/r 84-131 / 10. APl numar so-029-211 6200 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Structural Conductor 1 0 5' S u rface 2 7 2 6' Intermediate Production 6 8 9 3' Liner Perforation depth: measured 6658'-6674, true vertical 6107'-6118', Tubing (size, grade, and measured depth 3 1/2", J-55 6577' Packers and SSSV (type and measured depth) Size 16" 9 5/8" 7" Cemented Measured depth True vertical depth 202 Sx COLD SET II 105' 735 Sx Permafrost E 2726' 370 Sx Permafrost C 340 Sx Class G 6893' 6694'-6738, MD 6132'-6163' TVD 105' 2726' 6272' RECEIVED AI 2 1989 A aska Oil & Gas Cons, Gom Ssio. i, Anchorage 13. Stimulation or cement squeeze summary Hydraulically fractured well with 36500# of 16/20 Carbolite and 1062 bbls gelled water. Job screened out. Intervals treated (measured) 6658-6674', 6694-6738' Treatment description including volumes used and final pressure 36500# Carbolite, 1062 bbls gelled water, ~2 bbls Diesel last WHIP 6300 psi 14. R~gresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 1262 2000 0 700 140 1817 4079 0 600 353 16. Status of well classification as: Oil .~. Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ./~'~,~ /~ ~ ,,'1/~ .~?~~'~ Ti,eSR. OPERATIONS ENGINEER Form 10-404 i~'ev 06/15/88 SUBMIT IN DUPLICATE WELL ARCO Alaska, Subsidiary of Atlantic Richfield Com~ , WELL SERVICE REPORT '~TRACTOR..~ / /// Z 7-'? ,¢ ! / , z~ ~ ,- i 0 ~ .-- REMARKS PBDT IOPERATION A-T REPOR~TIME~ -- -- ' " 0 70~ !,.5-oo ..... / 7.5-,9 I'-'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA ~ :., AI_~K~ OIL ,NqD C~S CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing_ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 183' FNL, 88' FEL, Sec. 6, T10N, R9E, UM At top of productive interval 1174' FNL, 1094' FEL, Sec. 6, T10N, R9E, UM At effective depth 1292' FNL, 1251' FEL, Sec.6, T10N, R9E, UM At total depth 1398' FNL, 1307' FEL, Sec. 6, T10N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 6997' 6346' 6900' 6277' feet feet feet feet Plugs (measured) Junk (measured) None 6. Datum elevation (DF or KB) RKB 140' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2G-1 5 · 9. Permit number 84-131 10. APl number ~0-029-21 1 6200 11, Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Structural Conductor 1 0 5' Surface 2 7 2 6' Intermediate Production 6 8 9 3' Liner Perforation depth: measured 6658'-6674, true vertical 6107'-6118', Tubing (size, grade, and measured depth 3 1/2", J-55 6577' Packers and SSSV (type and measured depth) Size 16" 9 5/8" 7" Cemented Measured depth True vertical depth 202 Sx COLD SET II 105' 735 Sx Permafrost E 2726' 370 Sx Permafrost C 340 Sx Class G 6893' 6694'-6738, MD 6132'-6163' TVD 105' 2726' 13. Attachments Description summary of proposal_ Detailed operation program _ BOP sketch _ Fracture stimulate the A Sand with 121000# 16/20 Carbolite 14. 15. 16. Estimated date for commencing operation June 10, 1989 If proposal was verbally approved Name of approver j['l. Date approved Status of well classification as: Oil ..)p.. Gas~ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned /"~")~_-,~. ~ ~ ,~4-'~x:,¢~-.~,..-,-¢~? Title Sr. Operations Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission IApproval No, Approved Copy Retur. n~d Commissioner Date Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Messrs Lyden and Wad~. June 7, 1989 Page 3 Kuparuk Well 2G-15 'A' Sand Re-Fracture Procedure Charge Code: K80330 1. Obtain a 24 hour well test. . . MIRU Slickline unit. RIH with tubing end Iocator and tag fill. Pull GLV's at 1952', 3864', 5503', 6653' and 7424' and run DVs. RIH with Standing Valve and set in Camco 'D' nipple. Pressure test tubing to 4500 psi to ensure DVs are set. RIH and pull SV. 4. RDMO Slickline. If less than 50 feet of rathole is discovered during the pre-frac wireline operations, a CTU cleanout may be required. Consult with Operations Engineering to determine if the CTU is necessary. If a cleanout is performed, at least 150 feet of rathole is desired. 5. MIRU fracture equipment. Install "Tree Saver". . , Carry out all quality control procedures (Onsite Operations Engineering). The specific procedures will depend on the vendor selected. Check Carbo-Lite for fines due to excessive handling. Obtain a sample of the Carbo-Lite and the gelled water with breaker and from the pad and slurry stages. Record the proppant weight before and after the treatment. Pump fracture treatment per the attached schedule. Record the 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: WHTPE = 3250 psig Fracture Gradient = 0.70 psi/ft Tubing Friction = 300 psi/1000 ft (6000' TVD) (8434' MD) @25 BPM * If treating pressure during the job exceeds 6000 psi, reduce rate to a minimum of 15 BPM. If pressure exceeds 6500 psi, shut down job and confer with Engineering. 8. Rig down frac equipment. Follow attached flowback schedule. . After well has completed flowback, obtain 24 hour well test. Contact Operations Engineering for a new gas lift design when necessary. t ARCO Alaska, Inc. Post Office I~ )360 Anchorage, AlasKa 99510-0360 Telephone 907 276 1215 October 9, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field' Well Action Date Performed on the 2C-2 Perforate 9/28/85 2G-13 Reperforate 9/28/85 2G-14 Reperforate 9/28/85 2G-15 Reperforate 9/30/85 2G-16 Reperforate 9/30/85 If you have any questions, please call me at 263-4212. T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ OTHER [] 2. N"~%°'f'~per~t'°r~ S KA,r~r~t.,~j ~L_~ INC. 7. Permit No. 8q-131 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21162 4. Location of Well SURFACE LOCATION. 183' FNL, 88' FEL, SEC. 6, T10N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 1 40' (RKB) 12. I 6 . Lease Designation and Serial No. ADL 25667 ALK 2588 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2G-15 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On September 30, 1985, the "A" sands of Kuparuk well 2G-15 were reperforated for production. After testing the lubricator to 3500 psi, the well was shot with a wireline conveyed gun. Interval (MD). 6658'-6674' (4 SPF) 6694'-6738' Alask:a 0il & Gas Cons. ~nch0ra.ge 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ /'~~ ~-~~ Title KUPARUK The space below for Commission use OPERAT i ONS COORD i NATOR Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date 10/9/85 Date Form 10-403 I~ 7-1 -ROI Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska; Post Office Box 100360 Anchorage, Alaek~ 99510-0360 Telephone 907 276 1215 September 23, 1985 Mr. C. V. Chatterton, Chairm~' Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive · Anchorage, AK 99501 Dear Mr. Chatterton: Attached is our notice of intention to perforate Kuparuk field wells 2G-13, 2G-14, 2G-15 and 2G-16. If you have any questions, please call:~e at 263-4212. T. Mark Drumm Kuparuk Operations Coordinator TMD:ps:File Attachment (In Triplicate) RECEIVED SEP2 Alasl(a, Oil & 6as Cons. Commission Anohorage ARCO Alalka, In;. Ii e/Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COw, MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLX~ OTHER [] 2' Name ~fR%'P0eraA~r a S k a, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 183' FNL, 88' FEL, Sec. 6, TION, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 140', PAD 104' 12. 7. Permit No. 84-131 8. APl Number 50- 029-21162 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2G-15 11. Field and Pool Kuparuk River Field Kuparuk River Oil I6. Lease Designation and Serial No. ADL 25667 ALK 2588 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' Pool (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 2G-15 be perforated for production. Procedures call for the well to be perforated with a wi reline conveyed gun under a lubricator. Proposed Intervals (MD)' 6658-6674' (4 SPF) 6694-6738' ANTICIPATED STATE DATE' 9/25/85 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~/.~ ~~ Tit,e Kuparuk Operations C00rdinat0r~a,e The space below for Commission use 9/23/85 Conditions of Approval, if any: Approved by ~ppro¥od Co~¥ Returned . ~.., ~:h~.~-~-~'~'''' . ~ By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate Rev. 7-1-80 ARCO Alaska, Inc, Post Offic; Anchorage, ka 99510-0360 Telephone 907 276 1215 May 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservatio Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports 2D-15 2V-8A 1E-24 2X-14 2G-14 DS 6-5 2G-15 for t~~ ~O1 lowing wells: If you have any questions, Sincerely, Gruber Associate Engineer JG/tw GRUg/L01 Enclosures please Call me at 263-4944. RECEIVED MA Y2 8 1985 Alaska Oil & Gas Cons. Commission Anchorage · ARCO Alaska, Inc. la a Subsidiary of AtlantlcRIchfleldCOmpany ~' ~, STATE OF ALASKA ...... - '~ ' ALASKA ~ AND GAS CONSERVATION C,, MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-131 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21162 - 4. Location of well at surface 9. Unit or Lease Name 183' FNL, 88' FEL, Sec. G, T10N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1174' FNL, 1094' FEL, Sec,6, T10N, RgE, UN 26-15 At Total Depth 11. Field and Pool 1398' FNL, 1307' FEL, Sec.6, T10N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 140' RKBI ADL 25667 ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/10/84 10/14/84 11/08/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 6997'MD,6346'TVD 6900'MD,G277'TVD YES [] NO []I 1882 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal, SHDT, Gyro, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 105' 24" 202 sx Cold Set II 9-5/8" :36.0# J-55 Surf 2726' 12-1/4" 735 sx Permafrost E & ~70 sx Permafrost C 7" 26.0# J-55 Surf 6982' 8-1/2" 340 sx Class G & 250 s~ Permafrost C , 24. Perforations open to Production (MD+TVD of ToP and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6727' 6668' 3-1/2" 6577 ' 6548 ' 6724 ' 6666' 6718' - 6716' 6662' - 6660' w/1 spf, 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6712' - 6710' 90° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6705' See attached Addel~dum~ dated 4/12/85. 6702' - 6700' 6697 ' 27. N/A PRODUCTION TEST Date First Production i Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c~rr) .... Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 GRUG/WC:~S Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand · GEOLOGIC MARKERS MEAS. DEPTH 6564' 6580' 6640' 6820' TRUE VERT. DEPTH 6042' 6053' 6094' 6220' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addend.m 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~T ~~_~..~.,L~A,_.,' Title Associate Engineer Date ,~- / ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in. item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-. jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" ADDENDUM WELL: 10/22/84 10/29/84 3/22/85 3/25/85 3/26/85 2G-15 Arctic Pak w/42 bbls PF "C", followed by 56.4 bbls Arctic Pak. Rn Temp/CCL log f/6464'-5900'. RU SOS & rn CBL & gyro. Frac well in 7 stages w/total of 256 bbls of gelled diesel, 500# of 100 mesh & 11,400# of 20/40 mesh, leaving 4900# of 20/40 in csg. RU CTU & N . CO to 6750' w/total of 640 bbls of diesel & 81.2 mcf o~ N2. RIH w/wt bar & CCL. Tag fill @ 6807' (80' rathole). Turn well over to Production. Drillin~Superintendent ARCO Alaska, In Post Office aox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 D¢i '1" E: 05 ... 0 ?" 85 TI::~(;NS'HIT'f'AI_ NO:D1 78 R i""' T [J R N l'O:A R C O A L A,S' K A, Z N C, A T T N: R F..: C 0 R D 3 g L E I:(1( A'f' 0- t 1 t 5 B I::',0, BOX t00360 ¢,NCI-IORAGE, Al< ~795t O ~~~ TRANS'HITTE~) HEREWITH ¢~I:(IE '¥1..IIE I::Oi...I..OW]JN[; ]:TE~5', i::'L. EF~5'IE ¢~CI(NOWL. ED6E RECEIF'T AND I:<EETURN ONEE 5'IGNED COF'Y OF' TI-.IIS' 'FRANS'MIT?AL, F:' I N ¢, L F:' R ]: N'T',:'; CBL' N / 3 CI"IL. U H B E L:;~[; E:F;: t Iii:-1 5"~,- t (')-30-84 RLIN :,",:.t 2 C- t 3 ~ ' ''~ "':" ' ':"': ....... (.~ ,:.. - u ~ '- ~:] 5 I:;~ tJ N .,,. ...... ,...~ .:) .) (';' u -' ?~ ''~ ,5 ,.'::' 2C-" t 4 ~ O ,",.....n,:. ,.,,.,"" _. o,:..~,., .., R U i",l '""~.,,- ,,-. 3800-6030 2C--t 5 ~""'"~' "":' F-:,"" o~ ':""::" 2 u ,:. '- ',: o -- o .,' I:;; i.J N :',',: t :~ C-' t 6 ~ 0 n-' O 8-'£:~ 5.,-..RUN ::::t ';;1 '"'::',' ..; "" 6'~"~ ~';.. ,:l 0 ,...(.,,-t 5'''~''~ ' I 0-2'7-84 RtJN :',"t 4'7~70-6~S':2 2 G - t ,5 ~ t 0- -.."~"",' - ~'~:t "~, R tJ N:-": t :~!t.l"'t 5 ~'"'~/ 02-t 0-85 RtJN 'II:1 6400-698D 2W'-9 ""'" 01-01-85 I::~t.JN -.-"4't '5~;, 0~'- ..... ? ~c!6"" 2W-t t~/' '01 '-02-8.'5 I:;:tJN '4l:t ,:.....o6-66''~ 2. W - t,..':-~'"~' O t -' G ,...') - ,9.._,":; R U iH'Il'- · t ,,..."~ 640 - 7 "? '7 2W-'t &'"'"" ¢)2-0t -85 RUN ',,.t 2X-t 4,,,'''~ I t -t '7-.¢54 RUN :','.'t RECEIF'T ACi<NOWL. EI)(;ED: ............. ii':i: :i: i;i' i;i :i: ]! i!i i:i":' ............ B I-'-'A [.i: * I)F;,' I 1 I.. I H (; .... B 1... W, I::' A.? 1' I E R B, CURRI~"'I::: 1_, JOHNSTON lii:XXON' C H [" V R [) N H (] B ;I I F' I'-I I L. I... I 1::'3 01 L D & M * N 5' 1< '.:; L I'": R I< --- B I .... !, R A T 1"1~'1 Ii" L L ARCO Alaska, Ir,. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Hay 2, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservat'ion Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells- 2G-11 2G-15 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L79 Enclosures RECEIVED Alaska Oil & G~s Cons. Co~irrlJssJor~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' STATE Of ALASKA ..... ALASKa. .L AND GAS CONSERVATION £ .MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-131 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21162 4. Location of well at surface 9. Unit or Lease Name 183' FNL, 88' FEL, Sec.6, T10N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1174' FNL, 1094' FEL, Sec.6, T10N, R9E, UM 26-15 At Total Depth 11. Field and Pool 1398' FNL, 1307' FEL, Sec.6, T10N, RgE, UM Kuparuk River Field. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 140' RKB ADL 25667 ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 10/10/84 10/14/84 11/08/84 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6997'MD,6346'TVD 6900'MD,6277'TVD YES [~X NO [] 1882 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal, SHDT, Gyro, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE iTOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 105' 24" 202 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2726' 12-1/4" 735 sx Permafrost E & ~70 sx Permafrost C 7" 26.0# J-55 Surf 6983' 8-1/2" 340 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6727 ' 6668' 3-1/2" 6577' 6548' ... 6724' 6666' 6718' - 6716' 6662' - 6660' w/1 spf, 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 6712' - 6710' 90° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6705' See attached Adde ~dum~ dated 4/2/85. 6702' - 6700' 6697 ' 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs'OILRATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED ~I~ 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 chi~.s. None Form 10-407 GRU6/WC25 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOi' O~lC MA~i<ERS MEAS. DEPTH TRUE VERT. DEPTH 30., 6564' 6580' 6640' 6820' 6042' 6053' 6094' 6220' F'ORMATION TESTS Include interval tested, pressure data, all fluids recove, ed and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _ .~,~ ~"~ _~..L ~'.~__ Title Associate Engineer Date 4 ---~(--) - ~-¢~'' 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 ADDENDUM WELL: 10/22/84 10/29/84 3/22/85 2G-15 Arctic Pak w/42 bbls PF "C", followed by 56.4 bbls Arctic Pak. Rn Temp/CCL log f/6464'-5900'. RU SOS & rn CBL & gyro. Frac well in 7 stages w/total of 256 bbls of gelled diesel, 500# of 100 mesh & 11,400# of 20/40 mesh, leaving 4900# of 20/40 in csg. Drillin~Superint endent ARCO'Alaska, Inc Post Offi J× 360 Anchorage, .-,laska 99510 Telephone 907 277 5637 Date' Transmitt'al No: 4842 P~E TIrRN TO: ARCO ALASka, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted here~-ith are the follo~%ng items. Please acknowledge receipt and return one signed copy of this transmittal. PL FIEI ,DS Dresser >/2d-lB Col~a_r Log 11/0S/Sa Run 1 ?350- 7746 7'ZO-15'~ " ' ...."4 Perf' 11/06/84 " 6550 - 6750 ~-8 " " "JB/G Ring/Set Packer" 10/30/84 Run 1 6844 - 7221 Otis W'2V-6 Spinner Leg 8/31/8~_ Run 1 5900 -- 6~00 8chl~oer~er ~ 2X-5 Duml Spa~3ing %mnerm~l NeuZren Decgy ~1/o2/84 ~n 1 821o- 86s8 ]A~I Temperature "Prefrac" I! Te~np "Spinner Log" "HP/FD" ...... "Fluid Density" 11/09/84 Run 1 8130 - 8500 11/09/8/i Rim 1 7160 - 7450 11/06/84 Run 1 3620- 6620 11/08/84 Run 1 6800- 7080 /cat Receipt Acknowledged' B. Currier BPAE Chevron DISTRiBUYION Drilling W. Pasher Geology Mobil G. Phillips Phillips Oil State of AK Sohio Union D & H NSK Ops. J. Rathmell Well Files ARCO Alaska, Ir,-' Post Offic, ~x 360 Anchor3ge, Alaska 99510 Telephone 907 277 5637 Date: 1/31/85 Transmittal No: 5014 RETURN TO: PAGE 1 of 3 ARCO ALASKA, INC. ATTN: Records Clerk ATO-11t5B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH FINALS Schlumberger 0~ensity Neutron "Poro" 10/16/84 Run 1 10/16/84 " 7100- 7733 2"/5" 7100- 7733 2"/5" ,, DiLisFL/GR 10/16/84 " 3276- 7758' 2"/5" " BHCS/GR 10/16/84 " 7100 - 7759 2"/5" " CPL Cyberlook 10/16/84 " 7100 - 7700 'CPL Cyberlook " Density Neutron "Poro" 10/03/84 Run 1 - 10103184 " 6400 - 7050 6400 - 7048 2"/5" !1 II · " "Raw" 10/03/84 " 6400~,- 7048 2"/5" ,, DiL_SFL/GR 10/03/84 " 2805- 7074 2"/5" CPL Cyberlook Density Neutron "Poro" 10/07/84 10/07/84 Run 1 7200 - 7710 " 7200 - 7878 2"/5" Il II " "Raw" 10/07/84 " 7200- 7878 2"/5" ,, DiL_SFL/GR /cat Receipt Acknowledged: B. Currier BPAE Chevron 10/08/84 ;' DISTRIBUTION Drilling W. Pasher ~Oeology~ ' G. Phillips Mobil Phillips Oil 3624 - 7910 2"/5" ,, I :\~, .~ AlasKa Oil & Gas Cons, Commissior: State of Sohio Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. is I subsidiary of AtlanlicRich*fielg3Cornpany ARCO Alaska, Post Offi. ~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/31/85 Transmittal No: 5014 RETURN TO: PAGE 2 of 3 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ¢~ 1L-1 CPL Cyberlook 10/08/84 Run 1 --- _ ---- '" 2"/5" DIL-SFL/GR 10/08/84 " 2359 - 7470 " 2"/5" Density Neutron "Poro" 10/08/84 " 2359 - 7447 " 2"/5" " " "Raw" 10/08/84 " 2359- 7447 " 2"/5" BHCS/OR 10/08/84 " 6750- 7473 2W-6 CPL Cyberlook " 11/06/84 Run 1 3198 - 7286 " 2"/5" DIL-SFL/GR 11/06/84 " 3198 - 7286 2"/5" Density Neutron "Poro" 11/06/84 " 6600 - 7261 " 2"/5" " " "Raw" 11/06/84 " 5600 - 7261 " RFT "DIL-SFL/GR, FDC-CNL/GR" .. :'" 2"/5" Density Neutron "Poro" ,, ,./ 2."/5" " " "Raw" / " 2"/5" DIL-SFL/GR /cat -- Receipt Acknowledged: 11/07/84 " 10/31/84 Run i 7350 -'.8050 10/31/84 " 3757- 8080 10/31/84 " 3557- 8050 10/31/84 " 3757 - 8080 B. Currier Drilling DISTRIBUTION W. Pasher BPAE ~Geology ~~ G. Phillips Chevron Mobil Phillips Oil Ah~ska Oil & (},'-~,S Cof~s, Commissior; State of ~!"~4~/,~ Sohio Union D & M NSK Ops. J. Rathmell Well Files ARCO Alaska, Inc. Post Offit . 360 Anchorage, ,-,,aska 99510 Telephone 907 277 5637 Date: 1/31/85 Transmittal No: 5014 RE TIYRN TO: PAGE 3 of 3 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~~, CPL Cyberlook 10/01/84 Run 2 " 2"/5" DIL-SFL/GR 10/01/84 " 6050 - 6520 3200 - 6626 " 2"/5" Density Neutron "Raw" 10/01/84 " 6050 - 6600 " 2"/5" " " "Poro" 10/01/84 " 6050 - 6600 2G-15 CPL Cyberlook 2"/5" FDC-CNL/GR "Poro" 2"/5" " "Raw" "2"/5" DIL-SFL/GR Stratigraphi¢ Dipmeter SHDT" 10/15/84 Run 1 6350 - 6894 10/15/84 " 6350 - 6894 10/15/84 " 6350 - 6894 10/15/84 " 2728 - 6934 10/15/84 " 6350 - 6940 /cat Receipt Acknowledged: B. Currier BPAE Chevron D&M DISTRIBUTION .. Drilling Geology'~~ Mobil NSK Ops. W. Pasher G. Phillips Phillips Oil J. Rathmell State of AK ~ Sohio Union Well Files ARCO Alaska, Inc. iS a subsidiary of Allanl~cRichfieldComoanv ARCO Alaska, In Post Office Sox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 18, 1984 b Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2G-15 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the portion of the 2G-15 Well History covering the completion details. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, ~. Gruber Associate Engineer JG/tw GRU3/LIO Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ STATE OF ALASKA ALASF'. ,. AND GAS CONSERVATION MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I-~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ..... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-131 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21162 ,, 4. Location of well at surface 9. Unit or Lease Name 183' FNL, 88' FEL, Sec.6, T10N, R9E, UM- ,.'~LC?,r'ATIONSi Kuparuk River Unit At Top Producing Intervalii VEriFiED ' lO. Well Number 1174' FNL, 1094' FEL, Sec.6, T10N, RgE, UM l~ 2G-15 Surf. ~ , t ,-; 11. Field and Pool At Total Depth 1398' FNL, 1307' FEL, Sec.6, T10N, RgE, UN f ' i Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 140' RKBI ADL 25667 ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/10/84 10/14/84 11/08/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 6997'MD,6346'TVD 6900'MD,6277'TVD YES [] NO [] 1882 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal, SHDT, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 105' 24" 202 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2726' 12-1/4" 735 sx Permafrost E & 2i70 sx Permafrost C 7" 26.0# J-55 Surf 6983' 8-1/2" 340 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6727' 6668' 3-1/2" 6577' 6548' 6724' 6666 ' 6718' - 6716' 6662' - 6660' w/1 spf, 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 671 2' - 6710' 90° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6705' N/A 6702' - 6700' 6697 ' . ,, 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-oIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)" Press. 24-HOUR RATE 28. CORE DATA Brief description of lithotogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 GRU3/WC08 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIc MARKERs MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS 6564' 6580' 6640' 6820' 6042' 6053' 6094' 6220' nclude interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS W~ll Hi.~nry~ Cyrn.~npin..qurv~.y (? copi~.s) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completi°n), 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 AtlanticRichfieldCompany '~' Daily Well History-Initial Report Inatrucflonl: Prepare and submit ~lhe "lltitill RII~I" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. North Slope Borough State Alaska District I County or Parish Alaska Field [ Lease or Unit Kuparuk River J ADL 25667 Auth. or W,O, no, [Title AFE 901105 { Drilling Doyen #9 API 50-029-21162 Well no. 2G-15 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded IDate IHour 10/10/84 Date and depth as of 8:00 a.m. 10/11/84 10/12/84 10/13/84 thru 10/15/84 complete record for each day reported 1200 hrs A.R.Co's W,I. IPrlor status f a W.O. 56.24% 16" @ 105' 2742', (2637'), TOH to rn 9-5/8" Wt. 9.4, PV 19, YP 29, PH 8, WL 12.4, Sol 9 Accept ri~ @ 0930 hrs, 10/10/84. NU 20" diverter sys. Spud well @ 1200 hrs, 10/10/84. Drl 12¼" hole to 2742', CBU, TOH. 2691', 2°, N59.5E, 2690 TVD, -22.54 VS, 11.79N, 20.00E 9-5/8" @ 2726' 3600', (858'), TOH Wt. 9.0, PV 6, YP 4, PH 8.5, WL 8.2, Sol 4 RU & rn 68 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 2726', FC @ 2643'. Cmt w/735 sx PF "E", followed by 370 sx PF "C". D±spl using rig pmp, bump plug. CIP @ 1245 hrs, 10/11/84. ND diverter sys. NU &tst BOPE to 3000 psi. TIH w/BHA to 2644', est csg to 1500 psi. DO FC @ 2644', FS @ 2726' + 8' new hole. Conduct formation tst to 12.5 ppg EMW. Drl 8½" hole to 3600', TOH. 9-5/8" @ 2726' 6997', (3400'), TOH to log Wt. 10.2, PV 17, YP 10, PH 9.5, WL 5.2, Sol 13 Drl & surv 8½" hole to 6997', CBU, C&C f/logs, POH. 3522', 1°, N39-1/2°E, 3521TVD, -44.25 VS, 25.91N, 36.54E 4032', 7.2°, S62.5W, 4031TVD, -50.16 VS, 39.32N, 31.31E 4465', 22.9°, S43.9W, 4446 TVD, +69.99 VS, 40.56S, 58.21W 5213', 35.7°, S42.9W, 5095 TVD, 438 VS, 317S, 303W 6053', 47.4°, S44.7W, 5708 TVD, 1010 VS, 710S, 718W 6620', 46.1°, S47.2W, 6096 TVD, 1423 VS, 997S, 1015W 6997', 42.7°, S41.4W, 6367 TVD, 1685 VS, 1186S, 1197W The above is correct Signature For form preparation an~ disiributiol[ see Procedures Manual, Section Drilling, Pages 86 and 87. IDate I Title 10/24/84 Drilling Superintendent AR3B-459-1-B INumber all daily well history forms consecutively Pag~ no. as they are prepared for each well. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "FI.al Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided The "Final Report" form may be used for reporting the entire operation jf space is available. District Alaska. County or Parish Field Lease or Unit Kuparuk River Auth. or W.O. no. T t e AFE 901105 Doyon #9 North Slope Borough JAccounting cost center code state Alaska ADL 25667 Drilling Well no. 2G-15 API 50-029-21162 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded A.R.Co. W.I. 56.24% Date 10/10/84 Iotalnumber of wells (active or inactive) on this ost center prior to plugging and J bandonment of this well our 1200 hrs Prior status if a W.O. Date and depth Complete record for each day reported as of 8:00 a.m. 10/16/84 10/17/84 9-5/8" @ 2726' 6997' TD, (0'), TOH, LD DP Wt. 10.2, PV 17, YP 9, PH 9.0, WL 6.0, Sol 13 TOH. RU Schl, log DIL/SFL/GR/SP/FDC/CNL/CAL f/6934'-2728', rn SHDT f/6940'-6350', RD Schl. TIH w/BHA, rm 6686'-6997', C&C, TOH. 7" @ 6983' 6997' TD, 6900' PBTD, RR 10.2 ppg Brine RU & rn 175 jts+ 1 mkr jt, 7", 26#, J-55 ERW csg w/FS @ 6983' FC @ 6900'. Cmt w/340 sx C1 "G" w/l% CFR-2, 5% KCl & .3% Halad-24. Displ w/10.2 brine, bump plug. CIP @ 1600 hrs, 10/16/84. ND BOPE, NU tbg spool, tst pack-off to 3000 psi. @ 2300 hrs, 10/16/84. RR Old TD New TD PB Depth 6997' 6900' PBTD Released rig Date Kind of rig 2300 hrs 10/16/84 Rotary Classifications (oil, gas, etc.) J Type comple on (single, dual, sic.) Oil JJ Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature J Date J Title /.,,,j.~_/")~~.~ ~0/2 4/~4 For form preparation and distr~ution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. Page;o. Olvllion of AllanllcRIchflsldCompany $ UB-$ URFA CE DIRECTIONAL SURVEY ~-~ UIDANCE F~ONTINUOUS r~OOL Company ,, Well Name Field/Location ATLANTIC RICHFIELD COMPANY 2G-15 (183' FNL, 88' FEL, S6, TION, RgE, UM) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 69692 Logged By: PEPPEL Date NOV-26-1984 Computed By: STEVENS 45 DI:,G 43 ~IN ~E~T ~.e v idf iOtl ~ !"~ (J T F? I J H E A 8 [t i~ F': i~ v !;i h T .[ r7 A ! [') [i P't 1--I PAGE 1 DATE bF $ORVF,~''- 2~-i.JC:I'-U4 KELbY I~I, iSHINC, Ei.,EVATIUN; 140,00 FT F k; E T l) 1 $ T, DEPARTUAg AZIMUTH DEB MIN O.UO 0.32 1,33 2,49 3,25 ~,17 5.20 5,95 ~,b8 7,30 0.00 N 0 0 E U.J7 N bO 17 g 1,62 N 55 12 g 2,97 N 56 54 g 4,03 N 53 55 g 5,00 N 56 3b g 6.20 m 56 5~ ~ 7,07 N 57 ~7 E 7,o3 N 59 35 g t.76 d,19 10,32 11,58 11,97 1~.2~ ~,~0 8,73 9,34 9,97 lO,bO 11,04 11,59 12,U~ 12,44 IBSq.t~l Ii 2U ~. ~b :~7 F: -7.41 l,Z6 2,25 2nbq.~l z 3 .v .i'J .3 e' -13.23 U.Uq 1.21 21bq. Tb 2 h ~' 4~ .17 F' -16.gh 0.11 3.b() Z,lbg.ht I 4~ 5, Lb F -2~,.()Z U.43 1U.19 z~bc-1%~ 1 b~ {.,a,) ~, k -j~ ~'1 I ol 12.u2 Zbbg.~!l I '.~h ~. (~') ~ ;" -3].tu 0.20 13,3h Z'lbq. ~1 I 4~, ~' 71 17. ?' -36.2b 0,31 12,o] 17.31 2u,04 22,76 75,23 3(,.J5 33.~9 30.~5 12.83 $ 79 53 g 14.55 8 85 22 g 17,35 N 86 0 g 20,36 N 79 49 E 23.b7 n 74 59 E 2b,~6 ~ 71 48 g 29.48 t'~ 69 47 t 32,b4 N 68 23 k 30,U6 N ~$ 14 E 39.~0 ~ 68 25 g 39.3] a2.Ul 44.38 b0,77 57,~7 5Z.99 5d. Z9 ~,25 4Z,Z3 a 68 37 k 45,15 ~ 68 30 E 47,76 a 68 19 g 52.9g a b7 33 g 55.19 , 06 55 E 57.39 a b6 b E 5~,~H i~ b4 57 E 5~.79 h b2 47 E 5~.81 l, 58 ~ E KIIpAHllr, i~A['P.:: 21-P~,iV-H4 b, bH ,~.42 '~. 25 1,93 3,b9 3,90 3,U3 2.01 1,U3 2.14 2.27 2.2] !,97 1.80 2.31 2.12 l,bq RFCTa PAGE 2 l)A'r'P; bF ,~URv'El': 2B-OCT-B4 KE, I.,LY H. USnIi,~G EbEVATluN: 140,00 FT ~] N G I r.~ I~: E H; P E P P ~ l., 2'1 ! H 42 t:, 9 1 '17 .44 N 37.53 F 4~,49 N 53 49 E ,13 N 20,34 F 2'1,92 N 46 45 L ,()u N U.53 E 3,73 N 8 10 g ,2~ S 20,7] W 27.b4 ~ 48 35 w ,54 S 44,26 W 61.39 5 46 8 ~ ,Oh $ 'tl.~b W 09,~6 $ 46 8 ~ .1l $ 99.00 W 141,9J ~ 44 34 W .38 8 120.59 w 187,b5 S 42 27 w .4L~ S 150.85 W 23b,~2 $ 41 28 h .UT $ 191,73 w 28B,12 S 41 42 w 251.~q S 22~.b3 W 339.96 $ 42 14 W 2H~.3'1S 267.58 W 394.12 8 42 45 , 32~.b"1S J09,21 W 451,19 fi 43 15 ~ 369.74 S 353.10 w b11,27 5 43 40 ~ · :tbT,~l S 44b0~] W b39,71 6 44 lb w 5(.,3,Sb S q(iO.b8 w 70'7,50 & 44 35 W 551,47 $ b4~,73 ~ 777,96 6 44 51 ~ bOu,~8 S ~01,47 W ~5U,19 S 45 1 ~ b51,29 S ~54.~5 W 9~$,44 & 45 8 W u.82 .I02,b2 5 7()u,48 " 997,!4 $ 45 14 W u,13 153.bu $ 761.93 W 1071,,72 6 45 18 . u.40 bOb,U3 S ~lb.20 w 1145,70 & 45 21 ~ u,32 ~5o.15 S b6~,12 w 1219,2'1 6 45 23 W U.35 ~01.21 S 920,o5 w 1292.53 S 45 25 W U.35 ~h~.24 S 972.~0 ~ 136b.49 ~ ~5 25 , 1.26 ]u6u.83 $ lO7b,bl w 1510.73 S 45 2J , l.ub 1112.u5 S 112~.97 w 1582.~b & 45 1U W u. UO li6~.4h S 1172.b6 W lb52.53 ~ 45 11 , 0997.0;., f, J4t:.J'2 oPv6.,."k ,4,~ 3% F 42 z,q ~' 1721,,,4t. t).uO ]zl~i,oB S lZ!o,b5 w 1720,56 b 45 b ~ ('(~iiPu'lfiT.if]r.~ [)A'itCi ~ g C 'r i t -38. -46. 339. 497. '120. I)ATk; iii-' $oRVE~[; 2u-UCT-U4 KELLY F'.t3St-~!N(; F:L~[-:VA'i'IUNI 140,00 Fl' hi, [:; t) G 1~ ['.': t,I°, F"C T A N G U L, A ,-{ C()UI~ T I:,LG/1 L~O F'Lt'~:T F'EE OINA'rEt~ HtJRIZ, DEPARTURE /WESt" DIS'f A Z, I i,! U'I'H 1' Ii'~ET DEG ~IN ('~u u. O0 4 t, 0,39 4, I 6 47 .1 , 26 2.25 cj(., 0,59 15,39 02 5.5R 27.44 ]3 2.14 251.o9 7 t., O. e 2 702.52 4(, 0,00 1214,0R DLP]'H 240.01 34(1. O y 440,03 540.03 640.04 740, o 4 ~40.04 DEPTH i)EG bl[h i)CL~ ~iN V 1~ P 'i.' I C A o f': C q" 1 21 -t.;OV-H4 PAGE 4 DATE UF' SURYEI: 28-0C"t-84 KEI.LY BUSHING EbEvATIUNI 140,00 FI' ()(i [';rtS~jT ()H' SuF'.-SgA I)LP]t! i [) 0 G 1., E d S E V I= R 1 T ~; aK(;/I O0 (}, ()(; (), 00 -0. -3.41 -4.34 -r4.37 -6 , 4. t: -7.14 -7.h9 - f4 . i:~ I -fl.77 -7.N9 -7,47 -'1.3 '/ -7.q2 -11 - 1 4 . t,, h -21 -.{4 t.<F:CTANGLILA H gOuRL~I NAI'E~ ~(')R Ttt/5{lUl'H EAST/W~;ST F t:: E '.r FIE F: 1' ,O~IZ, DEPARTURE DIST, AZIMUTH FEEt DEG MIN O.uO O,uO 0,1q 0.31 0.24 0,34 u,31 U,U7 U.14 O,O() N 0,00 u,O¢) M 0,00 U,48 N 0,75 1,18 N 1,77 1,99 N 2,~3 2,52 N 3,b0 2,9'1N 4,01 3,t, 1 N b,b3 3,~ N b,20 3.~4 N 0,86 0,00 N 0 0 E O,O0 N 90 U E 0,~9 N 57 16 g 2,12 N 56 19 E 3,46 N 54 49 g 4,39 N 54 50 g 5,48 N 57 14 E 6.01 N 56 50 E 't,31 a 58 6 E 7'86 ~ 60 44 E 0.17 3.97 ~ 7,59 0,~4 4,Z2 N 7,'70 u.35 3.9.3 N 'I.~6 0.17 3.33 ~ 8,44 O,()q 2,74 N 9.17 O,ll 2,20 N 9,97 U,35 1,72 N lO,b~ U.I6 u.68 N 11,24 0,30 ~,'!6 $ 11,76 0,3P t,'!2 B J2,1l 8,56 N 62 24 E 8,78 ii bl 15 g 8,79 a 63 25 E 9,07 N 68 29 E 9,58 h 73 21 g !0,20 ~ 77 33 E 10,'12 u 80 45 E 11,26 ~ 86 33 E 11.78 5 86 1~ E 12,23 5 81 55 E U . ,~ 7 I.V. 3 U. I 3 O. 0.2.6 t),0q O. 2t U , l 9 2.12 S 12.37 2.tU 5 13.11 I/,21 .5 lb,b4 Zolo 1'; 1 b,40 q,b9 ", 21,t4 '/.uJ rq 23,78 9.U9 ~ 2b, 2('> 12.55 8 ~0 15 E 13,28 $ 80 53 E 15.o4 $ 89 13 E 18,53 a 83 19 E 21,04 N 77 44 g 24,~0 u 73 32 E 2'1,74 N 70 52 E 3U,75 h 69 9 k 34,U2 N b8 15 E 37.41 u ~8 18 E 43,51 N 68 3~ g 40,21 n bR 25 E 48.79 N b8 14 k 51.51 N 67 57 E 53,90 ~ b? 17 E 50,11 N b6 39 E 5~.0] ~ ~5 41E 5~.03 ~ 04 17 g 2C-1 b i !'+ C , P 'i: H u lq P T ,~-:, r) l:'. P 'l ]O4] 4~42 41q4 42q E q]b4 479P, 4915 bl5? 540% 5~22 5070 o119 b2b7 o41 b % b ~70 -3q. 32 5,, u5 7q, '12 -17,4~ ,~, ~3 13.13 11..3b 3.3fl o,q~ q5.'15 1.9o 31.43 l~q.O% J.b7 9i.39 I/9,fib 2,Oh 132,i4 235.49 3,.34 17o.9i) 295,'2b 0.93 22U,0! 3')6,7'1 1.bfl ZP.J,o8 423.42 2.05 496,73 1,74 36u.uO 5"77,3~ 1.,93 ~lb,2b 665.4(~ l.~O ~7b,,i4 "l *'., 1 ,~3 1,b~ 540,57 8r, f~, 25 O.b] ol i,gb !~5.3~ 0,27 t~39.53 C(,IORuI~A'I'E& HOIzlZ, DEPART[ii~E LAST/WEST DIST, AZINUTH t" c; E: T F" EtJT DEG MIN' 44.58 ~.: 53,63 ~1£l, U 2 E 39.bl ll,b2 E 17,b3 9.00 W 11,57 33,25 ~ 45,75 ~i,00 W ~4.b'3 q1,97 W' 129,b5 1'22,11 ~ 179.93 ~5b,42 ~ 23b 14 197,24 ~ 295~97 241.u0 W 35'1,~7 2~9,26 34Z,"15 W 497,07 401,46 W 57'1,59 ~65,'78 W 665,b8 530.95 W 761,92 o13.19 bS2.56 w 975,73 772,18 h lU85,93 ~bu.Sl W 1195,35 9la.bi S 92u,20 9~9.30 $ 1004.20 106.3,'!6 S 1o/8,~9 lt3'/,bO S 1147,97 1210,31 $ 1214,b4 1303.07 1a09.06 151~,84 1.01b,16 1714.O3 1'120,56 N 51 15 g a 41 31 g 8 56 4 ~ $ 46 37 ~ S 46 Ii w S 45 low S 42 44 w ~ 41 28 ~ 5 41 47 W 5 42 24 ,943 ,5 43 35 a 44 ,.'.'.S 44 24 5 44 4~ W ;545 $ 45 13 W ,5 45 19 ~ ;5 45 23 W a 45 25 w ,5 45 25 w S 45 2~ W 5 45 15 W 645 u W 545 b w PAG~ 6 DATL UF 5URV[:[: 2B'UCT-B4 K~LL¥ [;u$i~lmG EbEVATIUN: 14U,OO FT ~.~r)42.].'~ 59(')2.34 991,0o S 1005,97 ~053.2'? 5913.27 999,29 ~ 1014,26 b(.)94.49 5~54.q9 1030.0o 5 1045,1~ b21~.~9 6079,99 1123,0j ~ 1134,60 t:,276,04 613b.94 1104,40 S 1172,56 ~346, ()2 62()t~, 02 1214,68 ~ 1218,55 SU T v i) t(f<C TA 5902,34 9'9 591.3,27 99 6U79,Yg 112 ~11b,94 lib 620b,{)2 121 1.06 ~ 1005,97 q.29 5 1014,2b 0,00 S 1045,16 3.03 5 I134,60 4,46 S 1172,5b 4.68 S 1218.59 t:.it:f,i, LCI{'/'~ i'[lii',I t~,'1 '11~: 'u E' ~< T I (7 A I, V t,, R '.£ l C A L 20-1S NORTH SLOPE, ALASKA OCTOBER 28, ]984 TVN PLOT FROM OCT DATA JOB REFERENCE GgG92 WELL' 2G-15 - SURFACE LOCATION' .,~3' FNL, 88' FEL, S6, TION, R9E, ~M VERTICAL PROJECTION NE -2000 -!SO0 - lO00 -SOO 0 0 SOO ~co0 ISO0 r 1 ............... 2000 PROJECTION ON vERTiCAL PLANE OF AZIMUTH 226 SCALED IN 'VERTICAL DEPTHS ;'~0R:Z SCALE = ;/S00 I;J/FT WELL: 2G-15 SURFACE LOCATION' _.~3' FNL, 88' FEL, S6, TION, R9E, HORIZONTAL PROJECTION NORTH SOO 9'E¢ 89692 SCALE : I/S00 IN/FT -SOO -~SO0 -2000 -2S00 -9000 SOUTH -9SO0 -BSO0 WEST - 3000 -2500 -2000 - 1 SOO -; CO0 -SO0 0 SO0 EAST Suggest~ fora to be inserted in each "Active" well folder to d]eck for timely ccmpliance with our regulations. Reports and Materials to be received by: /%t:~- Required Date Received Remarks, i , · Ccmpletion Report Yes / ~ .~ ~. _~ ./r~/ :~' --. Well History Yes / · . ~u~, ~'~ .-'Ix: .... i> i ..... :" - d::~-.:~ , . . Core Chips :. · ....-, · Core Description /./~/." ,i Registered Survey Plat yC~ :"~ Inclination Survey ..... /, · LDirectional Survey /T~"'~:'!/ ."? Drill Stun Test Reports ./~,.,'.~.:.. /~,~.. ,. , II . .. ARCO Alaska Post Office Box 100360 · Anchorage, Alaska 99510 Telephone 907 276 1215 November 21, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation.'f Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Monthly Reports Dear Mr. Chatterton: Enclosed are the Monthly State 2G-14 1L-1 2D-3 2G-15 1L-16 2D-2 2G-16 1L-15 2D-1 2E-16 ·2W-5 Reports for~,,t,he following 2X-16 WSP #2 2X-15 2X-14 wells: Si ncerely, A~~~ E~~n~iieer JBK/SH/tw. HILL/05 Enclosures RECEIVED Alaska 0il & G~s Co~s. Cornn~l$$1o~ Anchorage ARCO Alaska, Inc. Is a Subsidiary of AllantlcRIchfieldCompany STATE OF ALASKA · ALASK, _)ILAND GAS CONSERVATION £ ,vlMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well []X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc, 84-131 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21162 UN 4. Location of Well at surface 183' FNL, 88' FEL, Sec. 6, TION, R9E, 6. Lease Designation and Serial No. ADL 25667 ALK 2588 5. Elevationinfeet(indicateKB, DF, etc.) 140' RKB, PAD 104' 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2G-15 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of October , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1200 hfs, 10/10/84. Drld 12-1/4" hole to 2742'. 9-5/8" csg. Drld 8-1/2" hole t~-~ 6997'TD as of 10/14/84. Ran logs. csg. Secured well + RR ~ 2300 hfs, 10/16/84, Ran, cmted & tested Ran, cmtd & tstd 7" 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8" 36#, J-55 BTC csg w/shoe ~ 2726' Cmtd w/735 sxs PF "E" + 370 sxs PF "C" , · · 7" 26# J-55 HF-ERW BTC csg w/shoe @ 6983' Cmtd w/340 sxs Class "G" 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR/SP/FDC/CNL/Cal SHDT f/6940' - 6350' f/6934' - 2728' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE-RepCt' ~o~t~/m i;required for each calendar month, regardless of the status of operations, and must be¢iled~n duplicate with the Alaska Oil and G/a~ ConservatiOn Commission by the 15th of the succeeding month, unless otherwise directed. F~rm ~n-ana H I LL/NR2~ Submit in duplicate ARCO'Alaska, Inc '~ Post Off'~ x 360 Anchora~ .... ,aska 99510 Telephone 907 277 5637 Date: 11/14/84 Transmittal No: 4849 RETURN TO: -. ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS TAPES/Schlumberger ~---~39730 2D-16- 11/08/84 Run 1 3266.5 - 7855.5 ..C~q~39713 2W-5 .' 10/31/84 " 3729 - 8112 / ~39639 1L-16 , 10/17/84 " 4000 - 7837.5 f~39678 2D-l- 10/27/84 Run 2 2638 - 6787 2717.5 - 6970 76.5 - 68O3 /~39712' 2E-16' 10/30/84 Run 1 3391 -- 7693.5 /~39667 2X-15 ' 10/23/84 " 3638 - 8396.5 .. ' ~ : .. ,' .~,'' ~ ~ Receipt Acknowledged: Daue: DISTRIBUTION B. Currier Drilling W. Pasher BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathmell Well Files MEMORA TO: NDUM THRU: Lonnie C. Smith Commi s s ioner Edgar W. Sippie, Jr .~~ FROM: Petroleum Inspector State of Alaska ALASKA OIL AND GAS CONSERVATION CObR~ISSION C.V. On DATE: October 15, 1984 ~' .,~' FiLE NO: D. 5I. 78 TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO' s Kuparuk 2G- 15, Sec. 6, T10N,R9E,UM, Permit No. 84-131, Doyon Rig 9. Thursda~ October 11, 1984: I traveled this date £'rom Sohio's ball va~-~ te~~~c~ ~ther report, to ARCO's Kuparuk 2G-15, Doyon Rig 9, to witness a BOPE test. The drilling contractor was in the process of nippling up. The BOPE test commenced at 6:00 pm and was concluded at 7:15 pm. There were no failures. I filled out the AOGCC BOPE inspection report which is attached to this report. In su_n~nary, I witnessed the BOPE test on ARCO's Kuparuk 2G-15, Doyon Rig 9. Attachment 02-00IA(Rev. 10/79) oas t£4 '5/84 ._. STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Location: Sec ~ Drilling Contractor Location, .General Well Signo~ Date Well Representative ~ Permit # Casing Set Representative ACCUMULATOR SYSTEM .l. General Housekeeping ~q Rig Reserve Pit ~ g<~ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack An, ~j~a~event er Blind Rams hoke ~L ine~Va lve s H.e.l . Kill Line V~l~es Test Pressure Full Charge Pressure ~~O psig__ Pressure After Closure Pump incr. clos. pres. 200 psig Full~ Charge~ ~Pressur~"~Attained :~ ~D N21~o/ ~ ZL~I~S~ 2o.~o Controls: Master ~, ~,~C~ Remote :~-?.~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly ~/Test Pressure ~ooo Lower Kelly O~ est Pressure oo~o Ball Type ~ ~Test Pressure ~ooo Inside BOP ~ ~est Pressure ~,:o~_: psig. ~P min 2~sec. ~ min~l~ sec, psig. Choke Manifold No. Valves No. flanges~ Adjustable Chokes .,"-:~ o ~- Hydrauically operated choke Test Results: Failures ------ 0 -----~' Test Time I / hrs. Repair or Replacement of failed equipment to be made within /~/~ Commission office notified. Remarks: [//~'k,Q ~~ .?t~-{'-" days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector _~.~.~ //f.,C July 31, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2G- 15 ARCO Alaska, Inc. Pe~it No. 84-131 Sur. Loc. 183'F5~, 88'FEL Sec. 6, TION, R9E, Btmhole Loc. 1478'FNL, 1416'FEL, Sec. 6, T10N, R9E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill th. above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have be~n classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thermumder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters ~f the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended.. Prior to cgmmencing operatio~ you may be contacted by a representative of the Department of En~i~onmen~aI Conservation] To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout preventt, on Mr. Jeffrey B. K~wtn Kupa~ River Unit 2G-15 -2- July 31, 1984 equipment so that a representative of the Commission may be present to %fitness testing of the equipment before the surface casing shoe is drilled. Where a dtverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatter~on Chairman of Alaska Oil and Gas Conservation Commission BY O~ER OF ~E COMMISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. ~ Post Office E ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 18, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2G-15 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2G-15, a $100 application fee o Diagrams showing the proposed horizontal projections of the wellbore o A proximity plat o A diagram and description of the surface hole system o A diagram and description Since we estimate spudding this earliest approval will be If you have any questions, Sincerely, Area Drilling Engineer JBK/JG:tw GRU8/L57 Attachments along with and vertical diverter of the BOP equipment well on September 4, appreciated. please call me at 263-4970. 1984, your JUL2 51 It Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA U~L AND GAS CONSERVATION CO,vIMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work. DRILL E~x REDRILL [] DEEPEN [] lb. Type of wel EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC i~i_] SINGLEZONE ~ ~1~, MULTIPLE Z O N E'~l]l~ ~ _ Kuparuk_Ri_ver Unit ~ '~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 183' FNL, 88' FEL, Sec.6, T10N, RgE, UH At top of proposed producing interval 1261' FNL, 1193' FEL, Sec.6, T10N, RgE, UN At total depth 1478' FNL, 1416' FEL, Sec.6, T10N, RgE, UN 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 140', PAD 104' ADL 25667 ALK 2588 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 183 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7048' MD, 6361' TVD feet 2501 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 3715 feet. MAXIMUM HOLE ANGLE 45 o/ (see 20 AAC 25.035 (c) (2) 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 15. Distance to nearest drilling or completed 2G-14well60' ~ surface feet 18. Approximate spud date 09/04/84 2765 psig@___80°F Surface 317~psig@: 6220~ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE SETTING DEPTH QUANTITY OF CEMENT Hole 24" 12-1/4" 8-1/2" 7" 22. Describe proposed Casing 16" 9-5/8" Weight 62.5# 36.0# 26.0# program: CASING AND LINER Grade Coupling H- O/ J-55 HF[ERW BTC J-55 HF~RW BTC~ Length MD TOP TVD 80 36' I 36' 2675 35' I 35' 7015 I 33' 33' I I MD BOTTOM TVD 11~i 116' 27101 2710' 7048~ 6361' I I (include stage data) ± 200 cf 730 sx Permafrost E & 370 sx Permafrost C 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7048' MD (6361' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. it will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2765 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2G-15 will be 60' away from 2G-14 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping 'them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. The well will be completed by the workover rig using 3-½" 23. I hereby certify that the foregoing is true and correct to the best of my knowledge ~/3~, ¢ /¢~.~~Zf/~_,J, ~¢ ' Area Drilling Engineer SIGN ED ~,%._TIT LE The space below for C~mmission use/' /~ ~- CONDITIONS OF APPROVAL DATE Samples required Mud Icg required Directional Survey required APl number []YES [~O ~IYES J~NO [~YES I--INO 50- 0 '~-¥ - ~'/I G 't.- SEE COVER LETTER FOR OTHER REQUIREMENTS Permit number APPROVED B~ipl~_5~ Form 10-401 Approval date ,COMMISSIONER DATE 3uly 31, 1984 by order of the Commission Submit in triplicate Permit to Dril 1 2G-15 9.2#/ft~J-55~BTC tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED JUL 2 5 I~ Alaska Oil & Gas Cons. commission Anchorage : '::: t:=AD :;.0;: I,/!-:.I_L: :l~Oi: 1':S: :'F~ Op..B$|-:D: :.::: :':: .: .':/l xx,... "t :!<UPAf. UK-'F [-ELD~':flOR'-FH-.I~_,-OPE-i-! ALA~I(_A :..' '.z4. ' J~'~ .. I - · ~-- ~ . _ J ,,, . .... i ..... . ,, L _ ~ - [ .... , --_~ : ..... [.:: ..... , : - :- i-_. 1 : I - - , 4---- - -F ................ .i · .~ .......... ~nnn I . . j . ::::.'TOP W'.SA','S~D !)='2 I = ~ : : ;. . i OSG~PT 2T1 i , ', . c: i ': rvD-. ,." :-~ '. i · , i , __,~__. .m ~nnn~ r ~ ' ~ ~ ,-g: ~: 1~: .o,l' ~-v.D.:~:,~t~.:~7,~.,~.o . !~ . ' ' ' ~, ' ! ,' DEP=~62 ~nnn _. ;s~ ,,.. ' , · 'i :' ' ! ':"~: :" ::, :: :-A!V, ER~GE,-/,NGL£ : ' { ............... 5':' ..... --,~-::~x:--:-4 :¢ ~!:-:~~ ,--:-~':-:-: ....... :--~ ....................... -~ ............................ i ...... ~nnn i: .... ~ ..... ' TO!' UP. Pa. SND~, .TVD=605C TtID=~6607 DE:P=1j544 ~- ......... rn.~-t CNTll TVi~=B13,'i Tt~D,,8727 DEP-~I62g ..... ~.~ ' ' . ~ .. :--~.e~~.+t.e--e-~-~--..~ '~-'-v'"'v "l" rVD-6~6i 'TieD-7041~ -DEP-1~'JS: ....... ' '-:'-:-- ' ' i ' ''~%;' J B~KUP. ?~NDS ! TYD~s220..~FI'ID-6: 14.8' D.I~P"' 171 4 ...... : ' - ' ' ' ' ~ ~..,~ I :,i. I,.~1'~1..I ~..~.~' ,I LUI~ .... -~ - : ....................... ? ............................................... .............................. ~---~ .................... : ..t JUL25].984 '" J . . ' ' ' . ]lll.n~..l....~ FI; ~. /'~-- ,~,. ....... ", ... ,':: :: ................. ~ . ~ . . Anch(~rage ~77' ~ AN ULAR m PIP~ ~ BLIND ' ~ I LL.I: 2 DIAGRAM ~1 I3-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco s:ar:ing head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x i3-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 pSi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke ana kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams g. I3-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1SO0 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 NA. DC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/B" BOP STACK TEST 1. FILL BOP STACK AND MA. NIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEN~. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR-PREVENTER AND VAL¥~S Ul)S~ OF C[-~I<~S. DON~T TEST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO B. 'PR SSbl DOWNSq REAM OF CI-IO ISOLATION ~/IJ_~.VES~ TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. g. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BO1TOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND P, AMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. RECEIVED JUL 2 5 1(184 Alaska Oil & Gas Cons. Commission Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/lO" side outlets. 5. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. ?. 20" bell nipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify ~hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECEIVED JUL 2 5 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office u.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2G Pad Wel 1 s 5-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU8/L26 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ 49th D~V~O & .5 .6 .? ,,8 D~ 2G Y-5944195.0~ ~T- 70-I~-31,5000 236 ~L 607 ~L Y-59~4t35,~l ~T- 70-15-~0.9t ~5 ~- ~08929,90 LON~t49-55-40,16~ 236 ~L 547 ~L ~-5944075.12 ~T- 70-15-30.3204 I- 50S930.00 LO~149-55-40,{~ 236 ~L 4~7~L X- 50)929.94 LON~ 149-55-40.1 ~ 23~L 427~L LOCA~ IX SE~IO~ 5,TIIW,~gE, U.~ Y-~94346~.24 ~T- 70-1~-24.32l~ 273 ~L 123 ~ 272 ~L 183 ~ Y-5943345.24 ~T- ~- 508969.92 LON~9-55-39.028 ~72 ~L 243 ~ 272 ~L 303 ~ ~~ED I~ SECTIO~ Y-59~52~5.18 ~T- 70-t5-22,55~2 X- 508609.92 ~N~149-55-49,50~ 88 ~ 3O3 ~ 88 ~ 243 ~ Y-5945405.25 ~T- X- 50S609.95 ~N~I4~55-49.499 Y-594~465.22 ~T- 70-15-24,3252 2- 508609.93 LON~149-55-49.49~ 87~ 123 ~ AR60 Alaska, Inc. Kup~ruk Proj~I North Slope DriH~, D.[ 2.0 CONDUCTORS 5' 16 AS- BUILT der,' 6.Z.6~ ~ ~,**' None I HEREBY CERTIFY THAT I AM PROPERLY EEO I STERF~D AND LICENSED TO PRACTICE LA~D SURVEYING IN THE STATE OF- ALASKA AND TI-IAT THIS PLAT REPRESENTS A SURVEY. MADE UNDER MY DIRECT SUPERVISION AI~D TI-IAT ALL DETAILS ARE CORRECT AS OF:_ '=~-'~'_~.=_.. 1 ~nch~¥~,,~ CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE YES NO REMARKS (1) Fee (2) Loc (2" thru (8),_, (3) Admin ~: j'. "' "; !' ' (9'thru 11) (10 and 11) (12 thru 20) (5) BOPE (21 thru 24) (6) Add: le me 3. 4. 5. 6. 7. 8. Is the permit fee attached eeeeeeeeeeeeeeeeeeeeeeeee'eeeeeee'eeeeeeee~im:,~ Is well to be-located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore plat included ............... Is operator the only affected party ..................................... ',~%: Can permit be approved before ten-day wait ........................... ........ 9. Does operator have a bond in force .................................. 10 Is a conservation order needed · e · e e e e e e e e e e e e · e e e e e e e · e · e e · · · · · · e · · · · 11 Is administrative approval needed '~"~ · e · e e e e e e e e e · e · e e e · · e · e e e · e · · · · · · · · · 12. 13. 14. 15. 16. '17. 18. 19. 20. 21. 22. 23. 24. 25. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ...................... Will all casing give adequate safety in collapse, tensio~ and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional r&quirements ............................................. Geolo Engi~n~ering: WVA ,,:':_ JKT ~_~HJH, .~> ~'~. ~ rev: 12/08/83 6. CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA! NO. SHORE 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 inl'ormation, information, of this nature is accumulated at the end of the file under APPENDIXl No special 'effort has been made to chronologically organize this category of information. .o 2 .... -3 5.7 .. ..
