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199-084
Originated: Delivered to:13-Aug-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-26 50-029-22115-00 909422974 Kuparuk River Leak Detect Log Field- Final 18-Jul-24 0 1 2 1A-26 50-029-22115-00 909422974 Kuparuk River Multi Finger Caliper Field & Processed 18-Jul-24 0 1 3 1D-12 50-029-22948-00 909422973 Kuparuk River Leak Detect Log Field- Final 15-Jul-24 0 1 4 1D-12 50-029-22948-00 909422973 Kuparuk River Multi Finger Caliper Field & Processed 15-Jul-24 0 1 5 1D-101 50-029-22988-00 909422480 Kuparuk River Patch Setting Record Field- Final 9-Jul-24 0 1 6 1F-03A 50-029-20853-01 909423152 Kuparuk River Packer Setting Record Field- Final 20-Jul-24 0 1 7 1G-01 50-029-20805-00 909469740 Kuparuk River Multi Finger Caliper Field & Processed 31-Jul-24 0 1 8 1G-01 50-029-20805-00 909469740 Kuparuk River Packer Setting Record Field- Final 30-Jul-24 0 1 9 1G-07A 50-029-20872-01 909383029 Kuparuk River Leak Detect Log Field- Final 2-Jul-24 0 1 10 1G-07A 50-029-20872-01 909383029 Kuparuk River Multi Finger Caliper Field & Processed 11-Jul-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39431 T39431 T39432 T39432 T39433 T39434 T39435 T39435 T39436 T39436 190-166 199-084 200-183 196-096 182-130 218-051 8-14-2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.14 08:29:49 -08'00' 3 1D-12 50-029-22948-00 909422973 Kuparuk River Leak Detect Log Field- Final 15-Jul-24 0 1 4 1D-12 50-029-22948-00 909422973 Kuparuk River Multi Finger Caliper Field & Processed 15-Jul-24 0 1 199-084 STATE OF ALASKA ALAIPA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ .erforate New Pool ❑ Repair Well I] Re-enter Susp Well 111Other: le` S*-te,�dJ petejeQ V 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 2 Exploratory ❑ 199-084 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-029-22948-00 7.Property Designation(Lease Number): 8.Well Name and Number KRU 1 D-12 ADL 25650 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9,250 feet Plugs measured None feet true vertical 6,688 feet Junk measured None feet Effective Depth measured 9,248 feet Packer measured 8095, 8405 feet true vertical 6,687 feet true vertical 5929, 6136 feet 1Casing Length Size MD TVD Burst Collapse CONDUCTOR 86 feet 16 " 121' MD 121 TVD 1 SURFACE 5,606 feet 9 5/8" 5,641' MD 4327 TVD PRODUCTION 8,665 feet 7 " 8,696' MD 6323 TVD LINER 706 feet 3 1/2 " 9,248'MD 6687 TVD SCEP JAW 2 5201$ Perforation depth Measured depth 8136-8138,9001-9031,9051-9065,9064-9089,9136-9138,9171-9181 feet True Vertical depth 5957-5958,6523-6543,6556-6566,6565-6582,6613-6614,6636-6643 feet Tubing(size,grade,measured and true vertical depth) 4 1/2 X 3 1/2 L-80 8,572'MD 6,243'TVD Packers and SSSV(type,measured and true vertical depth) PACKER- BAKER, 598-387 PREMIER 8,095' MD 5,929'TVD PACKER- BAKER, 4782 FHL 8,405' MD 6,136'TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A FilECEIVED Treatment descriptions including volumes used and final pressure: DEC 1 9 2017 13. Representative Daily Averag ,: tion Data Oil-Bbl Gas-Mcf Water- . ' Voiltsing Pressure Tubing Pressure Prior to well operation: SHUT-IN 0 0 0 0 Subsequent to operation: SHUT-IN 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ 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: 317-384 Contact Name:Andrew Beat Authorized Name: Andrew Beat Contact Email:Andrew.T.Beat@cop.com Authorized Title: Sr.Drillin Engineer > Contact Phone: (907)265-6341 Authorized Signature: Date: 1 2 /1 1 � �o L:Tom` J ' : l?Form 10-404 Revised 4/2017 /v / / r �v'„. � , � , .i, / . Submit Original Only nl Y • • Operations Summary (with Timelog Depths) 1D-12 Cort©ecPhiitip `: Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Tune End Time Our(hr)', Phase Op Code Activity Code Time P-T-x Operation (ftKB) End Depth(ftKB) 10/27/2017 10/27/2017 0.50 MIRU MOVE RURD P Prepare to skid rig floor to moving 0.0 0.0 11:00 11:30 position 10/27/2017 10/27/2017 0.50 MIRU MOVE RURD P Skid rig floor to moving position 0.0 0.0 11:30 12:00 10/27/2017 10/27/2017 1.25 MIRU MOVE MOB P Move rig off 1D-124 and stage on pad. 0.0 0.0 12:00 13:15 10/27/2017 10/27/2017 3.00 MIRU MOVE RURD P Pull rig mats from 1D-124 and lay 0.0 0.0 13:15 16:15 around 1D-12.Stage wellhead equipment in cellar. 10/27/2017 10/27/2017 2.50 MIRU MOVE MOB P Move the rig over well 1D-12.Center 0.0 0.0 16:15 18:45 and shim rig. 10/27/2017 10/27/2017 1.00 MIRU MOVE RURD P PJSM-Skid rig floor to drilling position. 0.0 0.0 18:45 19:45 10/27/2017 10/27/2017 2.25 MIRU MOVE RURD P Housekeeping around the rig. RU the 0.0 0.0 19:45 22:00 mud lines and steam to the rig floor. Spot the snack shack,mud shack, supply connex and cuttings tanks. Prep pits for taking on brine. Accept rig at 22:00 hrs 10-27-17 10/27/2017 10/28/2017 2.00 MIRU WELCTL RURD P Position new tree and adapter flange 0.0 0.0 22:00 00:00 in cellar.Rig up circulating lines in cellar.Take on and condition brine in pits. 10/28/2017 10/28/2017 2.25 MIRU WELCTL RURD P Continue to rig up circulation lines in 0.0 0.0 00:00 02:15 cellar.Take on and condition brine in pits. 10/28/2017 10/28/2017 0.50 MIRU WELCTL SEQP P Test circulating lines to 3500 psi.Blow 0.0 0.0 02:15 02:45 down lines. 10/28/2017 10/28/2017 1.25 MIRU WELCTL COND P Take on and condition NaCUNaBr 0.0 0.0 02:45 04:00 brine to 10.4 ppg. 10/28/2017 10/28/2017 1.50 MIRU WELCTL MPSP P Pick up lubricator and pull ISA-BPV. 0.0 0.0 04:00 05:30 Lay down lubricator in pipe shed 10/28/2017 10/28/2017 10.25 MIRU WELCTL KLWL P SIP's T/IA= 1,400/900 0.0 0.0 05:30 15:45 RU circulation lines to kill tank and connect to Tree and Casing valves. Pressure test lines to 3,500 psi. Bleed IA to 750 psi-TBG tracking. Circulate down the TBG taking returns up the annulus while maintaining IA psi of 750 psi. Pump 130 bbls TBG volume at 2.5 bpm at 1,180 ICP and 680 FCP. Continue to circulate while maintaining 680 psi for the next 170 bbls for a total of 300 bbls pumped. Had 10.4 ppg brine at choke house. Monitor well for flow -slight flow on the IA SWI for 30 minutes TBG/IA=100/160 Attempt to bleed off pressure to zero-SWI, TBG/IA=20/60 psi. Circulate another 70 bbls to kill tank. Monitor well-slight flow,SWI-TBG/IA= 60/60. Bleed off pressure-slight flow. Reverse circulate 435 bbls at 6 bpm at 2,000 psi back to rig pits -monitor well for flow-well bouncing till it finally (Bled back 12 gallons) static for 30 minutes of no flow. RD Pump lines. Page 1/33 Report Printed: 11/28/2017 • • Operations Summary (with Timelog Depths) 1D-12 CcoPhitips Asv ka , Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Cede Aatrvity Code Time P-T-X Operation (ftKB) End Depth(ftKE) 10/28/2017 10/28/2017 2.00 MIRU WHDBOP SLKL T PJSM with slick line and rig crew.RU 0.0 0.0 15:45 17:45 slick line-Rigging up.125"Wire w/ 1.875"TS-RS,6', KJ,5',KJ,LSS. Having issues getting tools to fall- trouble shoot-appears to be head catcher. 10/28/2017 10/28/2017 1.50 MIRU WHDBOP SLKL T lay down lubricator assembly and 0.0 0.0 17:45 19:15 trouble shoot head catcher and pack off assembly. 10/28/2017 10/28/2017 2.00 MIRU WHDBOP SLKL T PT lubricator at 3,500 psi and RIH w/ 0.0 0.0 19:15 21:15 4-1/2"Z-6 running tool(3 brass shear pins in top and 4 brass shear pjns in the bottom,3.812"DB-6E High pressure lock w/3"P plug body to 499 -ft,Attempt to set plug.Unable to set. POOH and redress setting tool(found Good indications on No-Go ring and shear pins were lightly worked)MU with 2 fewer shear pins and add weight to tool string. 10/28/2017 10/28/2017 1.50 MIRU WHDBOP SLKL T RIH w/4-1/2"Z-6 running tool(3 brass 0.0 0.0 21:15 22:45 shear pins in top and 2 brass sahear pjns in the bottom,3.812"DB-6E High pressure lock w/3"P plug body to 499 -ft,and set plug.Shear off and POOH w/slickline.Make up 4-1/2"GS,4-1/2" P prong(8.34-ft long)and RIH w/slickline.Set prong and POOH. 10/28/2017 10/28/2017 0.50 MIRU WHDBOP MPSP T Test plug to 300 psi/5 min's and 3500 0.0 0.0 22:45 23:15 psi/10 mins. 10/28/2017 10/29/2017 0.75 MIRU WHDBOP SLKL T PJSM,Rig down lubricator and 0.0 0.0 23:15 00:00 slickline. 10/29/2017 10/29/2017 0.50 MIRU WHDBOP SLKL T Rig down lubricator and slickline. 0.0 0.0 00:00 00:30 10/29/2017 10/29/2017 1.50 MIRU WHDBOP NUND P PJSM-Bleed pressure off hanger void. 0.0 0.0 00:30 02:00 Nipple down tree and secure in cellar out of way. 10/29/2017 10/29/2017 1.00 MIRU WHDBOP NUND P Clean and inspect hanger profile. 0.0 0.0 02:00 03:00 Screw X-O into hanger to check threads. 11 1/4 turns to make up. Threads good.Check LDS. 10/29/2017 10/29/2017 2.50 MIRU WHDBOP NUND P Nipple up 7 1/16"x 11"DSA and 0.0 0.0 03:00 05:30 BOPE. 10/29/2017 10/29/2017 1.50 MIRU WHDBOP RURD P Rig up test equipment 0.0 0.0 05:30 07:00 10/29/2017 10/29/2017 1.50 MIRU WHDBOP BOPE P Conduct initial BOPE test.All tests 0.0 0.0 07:00 08:30 250/3000 psi for 5 mins each.Test#1- 2 3/8"lower pipe rams,upper IBOP. Test#2-Annular w/2 3/8"test joint, valves 12, 13, 14,kill HCR and lower IBOP. 10/29/2017 10/29/2017 4.00 MIRU WHDBOP BOPE T Test Upper 3 1/2"x 6"VBR's with 3 0.0 0.0 08:30 12:30 1/2"test joint,valves 9, 11,20 and 4" dart valve.Could not get good test. Trouble shoot and diagnose pressure loss. No observable surface leaks. Page 2/33 Report Printed: 11/28/2017 • • Operations Summary (with Timelog Depths) 1D-12 Ccwto W Rig: DOYON 14 Job: RECOMPLETION Time Log Start Time End Time Our(hr) PhaseStart Depth Op Code Activity Code Time P-r-x Operation (ftKB) End Depth(rtKe): 10/29/2017 10/29/2017 1.75 MIRU WHDBOP BOPE T Lay down 3 1/2"test joint.Test blind 0.0 0.0 12:30 14:15 rams to 3000 psi.Observed same pressure loss.PU 2 3/8"test joint and pressure up against lower rams to check integrity of plug set in nipple at 499'MD.Observed same pressure loss.Lay down 2 3/8"test joint. 10/29/2017 10/29/2017 1.25 MIRU WHDBOP BOPE P Pick up 4 1/2"landing joint and make 0.0 0.0 14:15 15:30 up into hanger.Test#3 upper 3 1/2"x 6"VBR's w/4 1/2"landing joint,valves 9, 11,20 and 4"dart valve.Test#4- ' Manual kill valve,valves 5,8, 10 and 4"TIW valve.Test#5-Valves 4,6 and 7.Lay down landing joint. 10/29/2017 10/29/2017 3.50 MIRU WHDBOP RURD P Mobilize 4 1/2"NSCT x 4"LH Acme 0.0 0.0 15:30 19:00 blanking plug to rig floor.Make up blanking plug and 4 1/2"EUE 8rd x 4 1/2"NSCT x-o and install in hanger with 4"test joint.Test blanking plug to 3000 psi. 10/29/2017 10/29/2017 2.50 MIRU WHDBOP BOPE P Test#6-Valve 2.Test#7-Valves 1 0.0 0.0 19:00 21:30 and 3.Test#8-Choke line HCR.Test #9-Choke line manual.Test#10- Blind rams.Test#11-Upper 3 1/2"x 6"VBR's w/3 1/2"test joint.Test#12- Hydraulic choke A and manual choke B.Test gas alarms and PVT system.The states right to witness was waived by AOGCC inspector Chuck Sheve via e-mail on 10/26/17 at 17:29 hours. Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3000 psi Accumulator Pressure After Closer= 1695 psi Pressure Gain of 200 psi=48 seconds Full System=277 Seconds Average N2(6 Bottles)=2054 psi 10/29/2017 10/29/2017 0.75 MIRU WHDBOP RURD P Rig down test equipment.Blow down 0.0 0.0 21:30 22:15 choke and kill lines. 10/29/2017 10/29/2017 0.50 MIRU WHDBOP RURD P Make up blanking plug running tool 0.0 0.0 22:15 22:45 and pull blanking plug. Lay down running tool and x-o. 10/29/2017 10/29/2017 0.50 MIRU WHDBOP RURD P Make up 4 1/2"landing joint to hanger. 0.0 0.0 22:45 23:15 10/29/2017 10/30/2017 0.75 MIRU WHDBOP SLKL T PJSM-Pick up slickline lubricator and 0.0 0.0 23:15 00:00 mobilize slickline tools to rig floor. 10/30/2017 10/30/2017 1.00 MIRU WHDBOP SLKL T Continue to rig up slickline.Make up 0.0 0.0 00:00 01:00 lubricator head to top of lubricator. Pick up lubricator and make up pressure control equipment.Test lubricator to 3000 psi. 10/30/2017 10/30/2017 0.50 MIRU WHDBOP SLKL T RIH with slickline.Engage and pull P 0.0 0.0 01:00 01:30 prong.POOH and lay down prong. Page 3/33 Report Printed: 11/28/2017 �& 0 0 st., �K`ak "r°" , Operations Summary (with Timelog Depths) g, 1D-12 Cor►ocoPhillips 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 (1tKo) End Depth(ftKE) 10/30/2017 10/30/2017 1.00 MIRU WHDBOP SLKL T Make up retrieval tool.Test lubricator 0.0 0.0 01:30 02:30 to 1000 psi.RIH with slickline and engage plug.Pull lock and plug body and lay down. Blow down cement line. 10/30/2017 10/30/2017 1.00 MIRU WHDBOP SLKL T Lay down lubricator and rig down 0.0 0.0 02:30 03:30 slickline. 10/30/2017 10/30/2017 0.50 COMPZN RPCOMP RURD P Back out landing joint.Break out x-o's 0.0 8,453.0 03:30 04:00 and floor safety valve.Make up pup joint.Make up landing joint to hanger and top drive. 10/30/2017 10/30/2017 1.00 COMPZN RPCOMP PULL P BOLDS.Unseat hanger w/105K. 8,453.0 8,453.0 04:00 05:00 Attempt to pull seal assy free of PBR at 8453'MD working tubing string from 100K to 200K. 10/30/2017 10/30/2017 0.50 COMPZN RPCOMP PULL P Attempt to pull seal assy free of PBR 8,453.0 8,453.0 05:00 05:30 at 8453'MD working tubing string from 50/100K to 250/275K.Circulate at 6 bpm,810 psi while working pipe.. 10/30/2017 10/30/2017 0.75 COMPZN RPCOMP CIRC P Pick up to 275K and hold.Circulate at 8,453.0 8,453.0 05:30 06:15 8 bpm, 1450 psi. 10/30/2017 10/30/2017 4.50 COMPZN RPCOMP WAIT T Attempt to pull seal assy free of PBR 8,453.0 8,453.0 06:15 10:45 at 8453'MD working tubing string from 140K to 275K.Circulate at 8 bpm, 1470 psi while working pipe.. 10/30/2017 10/30/2017 1.25 COMPZN RPCOMP ELNE P Set slips with tubing in tension.20K 8,453.0 8,453.0 10:45 12:00 over neutral weight.Spot Pollard e- line unit and pick up e-line tools. 10/30/2017 10/30/2017 2.00 COMPZN RPCOMP ELNE P PJSM-Make up 1.562"circulating gun 8,453.0 8,453.0 12:00 14:00 and RIH with e-line to 8200'WLM. Pick up and fire shots from 8082'to 8085'WLM.6 SPF/18 holes total. POOH w/e-line. 10/30/2017 10/30/2017 2.75 COMPZN RPCOMP ELNE P Make up 2.5"RCT and RIH w/e-line. 8,453.0 8,085.0 14:00 16:45 Tag up at 8103'WLM.Correlate on depth.Fire RCT.Cut depth at 8085' WLM.POOH w/e-line. 10/30/2017 10/30/2017 0.50 COMPZN RPCOMP ELNE P Rig down RCT and set wireline aside. 8,085.0 8,085.0 16:45 17:15 10/30/2017 10/30/2017 0.25 COMPZN RPCOMP PULL P Pull hanger to rig floor.Lay down 8,085.0 8,049.0 17:15 17:30 hanger and landing joint.PU=120K 10/30/2017 10/30/2017 0.25 COMPZN RPCOMP ELNE P Rig down Pollard e-line. 8,049.0 8,049.0 17:30 17:45 10/30/2017 10/30/2017 0.25 COMPZN RPCOMP RURD P PJSM-Rig up to lay down 4 1/2" 8,049.0 8,049.0 17:45 18:00 completion. 10/30/2017 10/31/2017 6.00 COMPZN RPCOMP PULL P POOH laying down 4 1/2"12.6#L-80 8,049.0 3,344.0 18:00 00:00 IBTM completion from 8049'MD to 3344'MD. Page 4/33 Report Printed: 11/28/2017 4F • • Operations Summary (with Timelog Depths) 1D-12 ConocoPhiiiips 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(ftK(3) 10/31/2017 10/31/2017 5.00 COMPZN RPCOMP PULL P POOH laying down 4 1/2"12.6#L-80 3,344.0 0.0 00:00 05:00 IBTM completion from 3344'MD to surface. Recovered: 1--4-1/2 EUE 8rd FMC TBG hanger w/3-ft pup jt, 1---4-ft Pup jt,258 jts of 4-1/2 L-80 IBT-M TBG,5--KBG-2 GLM's, 1 --DB Nipple and cut jt of 14.62-ft. Photo's of Pollard RCT cut in well folder S:\ANC\Longterm\Drilling& Wells Ops\G K A\1 D pad\1 D-12 RWO 2017\Pictures\Cut Joint 10/31/2017 10/31/2017 0.50 COMPZN RPCOMP RURD P RD TBG Tongs and elevators and 0.0 0.0 05:00 05:30 swap over to 4"DP running equipment. 10/31/2017 10/31/2017 0.50 COMPZN RPCOMP RURD P Install 6-15/16"OD x 6-3/8"ID x.67-ft 0.0 0.0 05:30 06:00 long FMC Wear ring 10/31/2017 10/31/2017 2.25 COMPZN RPCOMP BHAH P PJSM,PU,MU and RIH w/Fishing 0.0 308.1 06:00 08:15 BHA#1 to 308.13-ft 10/31/2017 10/31/2017 7.00 COMPZN RPCOMP PULD P PU,MU and RIH w/BHA#1 from 308.1 8,093.1 08:15 15:15 308.13-ft to 8,093-ft (14.5-ft in jt#247) 10/31/2017 10/31/2017 0.25 COMPZN RPCOMP FISH P Engage and swallow over 4-1/2 TBG 8,093.1 8,099.0 15:15 15:30 stub to 8099.1-ft 10/31/2017 10/31/2017 0.50 COMPZN RPCOMP JAR P Begin jarring at 200K(50K osw of 8,099.0 8,099.0 15:30 16:00 150K)and straight pull to 225K(75K osw of 150K). Increase jarring weight to 250K and straight pull to 300K.20 jar hits. 10/31/2017 10/31/2017 0.25 COMPZN RPCOMP SFTY P Perform derrick inspection 8,099.0 8,099.0 16:00 16:15 10/31/2017 10/31/2017 0.75 COMPZN RPCOMP JAR P Jarring at 250K(100K osw of 150K) 8,099.0 8,099.0 16:15 17:00 and straight pull to 300K(150K osw of 150K).35 jar hits. 10/31/2017 10/31/2017 0.25 COMPZN RPCOMP SFTY P Perform derrick inspection 8,099.0 8,099.0 17:00 17:15 10/31/2017 10/31/2017 1.00 COMPZN RPCOMP JAR P Jarring at 250K(100K osw of 150K) 8,099.0 8,099.0 17:15 18:15 and straight pull to 300K(150K osw of 150K).6 jar hits.Jar at 250K(100K osw of 150K)and straight pull to 325K (175K osw of 150K). 15 jar hits.Jar at 250K(100K osw of 150K)and straight pull to 350K(200K osw of 150K)18 jar hits. 10/31/2017 10/31/2017 0.25 COMPZN RPCOMP SFTY P Perform derrick inspection. 8,099.0 8,099.0 18:15 18:30 10/31/2017 10/31/2017 1.25 COMPZN RPCOMP JAR P Jar at 250K(100K osw of 150K)and 8,099.0 8,099.0 18:30 19:45 straight pull to 350K(200K osw of 150K)56 jar hits. 10/31/2017 10/31/2017 0.25 COMPZN RPCOMP SFTY P Perform derrick inspection. 8,099.0 8,099.0 19:45 20:00 10/31/2017 10/31/2017 0.25 COMPZN RPCOMP JAR P Jar at 250K(100K osw of 150K)and 8,099.0 8,078.0 20:00 20:15 straight pull to 350K(200K osw of 150K)4 jar hits.Release overshot from fish. 10/31/2017 10/31/2017 0.50 COMPZN RPCOMP CIRC P CBU. 10 bpm,2060 psi. 8,078.0 8,078.0 20:15 20:45 10/31/2017 10/31/2017 0.50 COMPZN RPCOMP OWFF P Monitor well.Static.Blow down top 8,078.0 8,078.0 20:45 21:15 drive. Page 5/33 Report Printed: 11/28/2017 • Operations Summary (with Timelog Depths) 0 1D-12 conocdPhiilips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Tone End Time Dur(hr) Phase Op Code Activity Code Time P T-X Operation {ftKB) End Depth dtKB} 10/31/2017 11/1/2017 2.75 COMPZN RPCOMP TRIP P Lay down single joint DP and POOH 8,078.0 971.0 21:15 00:00 standing back drillpipe from 8078'MD to 971'MD. 11/1/2017 11/1/2017 0.25 COMPZN RPCOMP TRIP P POOH standing back drillpipe from 971.0 339.0 00:00 00:15 971'MD to 339'MD. 11/1/2017 11/1/2017 0.25 COMPZN RPCOMP OWFF P Monitor well.Static. 339.0 339.0 00:15 00:30 11/1/2017 11/1/2017 1.00 COMPZN RPCOMP BHAH P Lay down intensifier,stand back DC's. 339.0 0.0 00:30 01:30 Change out grapple in overshot.Lay down jar and bumper sub. 11/1/2017 11/1/2017 3.25 COMPZN RPCOMP TRIP P RIH from surface to 7778'MD 0.0 7,778.0 01:30 04:45 w/fishing BHA#2. 11/1/2017 11/1/2017 0.50 COMPZN RPCOMP PULD P Pick up drillpipe from pipe shed from 7,778.0 8,094.0 04:45 05:15 7778'MD.Tag TOF at 8094'MD. PU=140K SO=107K. 11/1/2017 11/1/2017 0.25 COMPZN RPCOMP FISH P Engage and swallow over 4-1/2 TBG 8,094.0 8,099.0 05:15 05:30 stub to 8099'MD.Set slips w/20K OSW. 11/1/2017 11/1/2017 3.00 COMPZN RPCOMP ELNE P Mobilize Pollard e-line equipment to 8,099.0 8,099.0 05:30 08:30 rig floor. 11/1/2017 11/1/2017 0.25 COMPZN RPCOMP ELNE P Rig down Pollard e-line 8,099.0 8,099.0 08:30 08:45 11/1/2017 11/1/2017 2.75 COMPZN RPCOMP TRIP P Release overshot.POOH from 8099' 8,099.0 0.0 08:45 11:30 MD to surface. Calc disp=46 bbls Act disp=45 bbls. 11/1/2017 11/1/2017 0.50 COMPZN RPCOMP BHAH P Lay down BHA 0.0 0.0 11:30 12:00 11/1/2017 11/1/2017 1.00 COMPZN RPCOMP RURD P PJSM-Rig up power tongs and change 0.0 0.0 12:00 13:00 out handline equipment to 2 7/8"tools. 11/1/2017 11/1/2017 1.00 COMPZN RPCOMP BHAH P Mobilize BHA equipment to rig floor. 0.0 0.0 13:00 14:00 11/1/2017 11/1/2017 1.00 COMPZN RPCOMP BHAH P PJSM-Make up 2 joints 2 7/8"PAC 0.0 78.0 14:00 15:00 DP and spear fishing assembly#3 to 78'MD. 11/1/2017 11/1/2017 2.75 COMPZN RPCOMP TRIP P PJSM-RIH with fishing BHA#3 from 78.0 8,081.0 15:00 17:45 78'MD to 8081'MD. Calc disp=46 bbls Act disp=45 bbls. 11/1/2017 11/1/2017 1.25 COMPZN RPCOMP FISH P Make up top drive PU=140K 8,081.0 8,111.0 17:45 19:00 SO=110K.RIH to 8111'MD and engage fish.Pick up 10K OP to confirm.Pick up to 165K and bleed jars.Pick up to 200K straight pull 2x. Pick up and open bumper sub. Hit fish down 4x.Pick up and fish free at 168K. PU=145K.Slack off to 8117'MD with free pipe movement. 11/1/2017 11/1/2017 0.25 COMPZN RPCOMP OWFF P Pick up to 8049'MD.Monitor well. 8,111.0 8,049.0 19:00 19:15 Static. 11/1/2017 11/1/2017 3.75 COMPZN RPCOMP TRIP P POOH from 8049'MD to 89'MD. 8,049.0 89.0 19:15 23:00 11/1/2017 11/2/2017 1.00 COMPZN RPCOMP BHAH P Lay down jars and bumper sub.Pick 89.0 0.0 23:00 00:00 up and lay down fish.Recover Weatherford ER packer,spacer jt and snap latch seal assy.OAL=13.13'. 11/2/2017 11/2/2017 0.50 COMPZN RPCOMP BHAH P Lay down ITCO spear and make up 0.0 0.0 00:00 00:30 Weatherford retrieving tool. Page 6/33 Report Printed: 11/28/2017 • 11110 ::; Operations Summary (with Timelog Depths) M 1D-12 Conacc hiirps 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(ftKD) 11/2/2017 11/2/2017 3.00 COMPZN RPCOMP TRIP P RIH with BHA#4 from surface to 8028' 0.0 8,028.0 00:30 03:30 MD.PU=135K SO=105K 11/2/2017 11/2/2017 1.50 COMPZN RPCOMP SLPC P Slip and cut 53'drilling line. 8,028.0 8,028.0 03:30 05:00 11/2/2017 11/2/2017 0.75 COMPZN RPCOMP SVRG P Inspect saver sub. 8,028.0 8,028.0 05:00 05:45 11/2/2017 11/2/2017 1.25 COMPZN RPCOMP FISH P RIH from 8028'MD to 8146'MD.Tag 8,028.0 8,150.0 05:45 07:00 and latch up on Weatherford ER packer.Pull up 40K OSW 2x,on third pull packer pulled free at 170K. Pick up to 8126'MD w/10K drag weight. Slack off to 8150'MD to confirm packer free. 11/2/2017 11/2/2017 4.50 COMPZN RPCOMP TRIP P PJSM-POOH from 8150'MD to 69' 8,150.0 69.0 07:00 11:30 MD. Calc disp=46 bbls Act disp=45 bbls. 11/2/2017 11/2/2017 0.50 COMPZN RPCOMP BHAH P Lay down BHA#4 and fish.Recover 69.0 0.0 11:30 12:00 Weatherford ER packer.OAL=3.81' 11/2/2017 11/2/2017 0.50 COMPZN RPCOMP ELNE P PJSM-Rig up Dutch Riser. 0.0 0.0 12:00 12:30 11/2/2017 11/2/2017 1.00 COMPZN RPCOMP ELNE P Rig up Pollard e-line. Make up 3 5/8" 0.0 0.0 12:30 13:30 chemical cutter. 11/2/2017 11/2/2017 1.50 COMPZN RPCOMP ELNE P RIH with e-line.Log on depth and 0.0 0.0 13:30 15:00 make chemical cut at 8383'WLM. 11/2/2017 11/2/2017 1.50 COMPZN RPCOMP ELNE P Log past cut and confirm.POOH with 0.0 0.0 15:00 16:30 e-line. 11/2/2017 11/2/2017 1.75 COMPZN RPCOMP ELNE P Lay down spent chemical cutter and 0.0 0.0 16:30 18:15 prep new chemical cutter. 11/2/2017 11/2/2017 0.50 COMPZN RPCOMP ELNE P PJSM-Pick up e-line tools and make 0.0 0.0 18:15 18:45 up 3 5/8"chemical cutter. 11/2/2017 11/2/2017 1.00 COMPZN RPCOMP ELNE P RIH with e-line.Log on depth and 0.0 0.0 18:45 19:45 make chemical cut at 8348'WLM.Log past cut and confirm. 11/2/2017 11/2/2017 1.50 COMPZN RPCOMP ELNE P POOH with e-line. 0.0 0.0 19:45 21:15 11/2/2017 11/2/2017 0.50 COMPZN RPCOMP ELNE P Lay down spent chemical cutter.Rig 0.0 0.0 21:15 21:45 down Pollard e-line. 11/2/2017 11/2/2017 0.25 COMPZN RPCOMP ELNE P Rig down Dutch Riser. 0.0 0.0 21:45 22:00 11/2/2017 11/2/2017 0.50 COMPZN RPCOMP BHAH P Make up overshot fishing BHA#5 to 0.0 308.0 22:00 22:30 308'MD. 11/2/2017 11/3/2017 1.50 COMPZN RPCOMP TRIP P RIH with BHA#5 from 308'MD to 308.0 2,203.0 22:30 00:00 2203'MD 11/3/2017 11/3/2017 2.00 COMPZN RPCOMP TRIP P RIH w/BHA#5 from 2003'MD to 2,203.0 8,015.0 00:00 02:00 8,015'MD.PU=147K SO=110K. 11/3/2017 11/3/2017 0.25 COMPZN RPCOMP FISH P Make up top drive.RIH and engage 8,015.0 8,099.0 02:00 02:15 and swallow over 4-1/2 TBG stub to 8099'MD. 11/3/2017 11/3/2017 0.50 COMPZN RPCOMP JAR P Set down 10K.Pick up to 200K and 8,099.0 8,099.0 02:15 02:45 bleed jars and then straight pull to 300K. Begin jarring at 225K and straight pull to 350K.20 jar hits. 11/3/2017 11/3/2017 0.25 COMPZN RPCOMP SFTY P Perform derrick inspection. 8,099.0 8,099.0 02:45 03:00 11/3/2017 11/3/2017 1.00 COMPZN RPCOMP JAR P Continue to jar at 225K and straight 8,099.0 8,099.0 03:00 04:00 pull to 350K.31 jar hits. 11/3/2017 11/3/2017 0.25 COMPZN RPCOMP JAR P Perform derrick inspection. 8,099.0 8,099.0 04:00 04:15 Page 7/33 Report Printed: 11/28/2017 • • y .,.,,:,,,,',444*,,, :. Operations Summary (with Timelog Depths) '‘:-40',., 1D-12 ConocoPhillips 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 (flim) End Depth MKS) 11/3/2017 11/3/2017 1.00 COMPZN RPCOMP JAR P Continue to jar at 225K and straight 8,099.0 8,099.0 04:15 05:15 pull to 350K.37 jar hits. 11/3/2017 11/3/2017 0.25 COMPZN RPCOMP SFTY P Perform derrick inspection. 8,099.0 8,099.0 05:15 05:30 11/3/2017 11/3/2017 3.00 COMPZN RPCOMP TRIP P Release overshot.POOH from 8099' 8,099.0 ' 300.0 05:30 08:30 MD to 300'MD. Calc disp-48 bbls Act disp=47 bbls. 11/3/2017 11/3/2017 1.50 COMPZN RPCOMP BHAH P Stand back DC's and inspect grapple. 300.0 333.0 08:30 10:00 Make up fishing BHA#6.Pick up rattler to 333'MD. 11/3/2017 11/3/2017 3.00 COMPZN RPCOMP TRIP P RIH from 333'MD to 8080'MD. 333.0 8,080.0 10:00 13:00 PU=147K SO=110K Calc disp=48 bbls Act disp=48 bbls. 11/3/2017 11/3/2017 0.25 COMPZN 'RPCOMP FISH P Make up top drive.RIH and engage 8,080.0 8,099.0 13:00 13:15 and swallow over 4-1/2 TBG stub to 8099'MD. 11/3/2017 11/3/2017 1.25 COMPZN RPCOMP JAR P Set down 10K.Pick up to 25K OSW 8,099.0 8,099.0 13:15 14:30 and bleed jars.Commence rattling at 2 bpm, 1250 psi.Straight pull in 25K OSW increments holding for 15 min's 3x to 300K. 11/3/2017 11/3/2017 0.75 COMPZN RPCOMP JAR P Work pipe from neutral to 300K 8,099.0 8,099.0 14:30 15:15 pumping with rattler at 2 bpm, 1250 psi. 11/3/2017 11/3/2017 2.75 COMPZN RPCOMP JAR P Increase pump rate to 2.5 bpm, 1350 8,099.0 8,099.0 15:15 18:00 psi.Jarring at 225K and straight pull to 300K. 11/3/2017 11/3/2017 2.50 COMPZN RPCOMP JAR P Vary pump rate between 2 to 3 bpm 8,099.0 8,099.0 18:00 20:30 with 980 to 1530 psi jarring at 225K and straight pull to 350K.Work jarring weight up to 250K and straight pull to 360K. 11/3/2017 11/3/2017 0.50 COMPZN RPCOMP SFTY P Release overshot.POOH from 8099' 8,099.0 7,977.0 20:30 21:00 MD to 7977'MD.Perform derrick inspection.OWFF.Blow down top drive. 11/3/2017 11/4/2017 3.00 COMPZN RPCOMP TRIP P POOH from 7977'MD to 2235'MD. 7,977.0 2,235.0 21:00 00:00 11/4/2017 11/4/2017 0.75 COMPZN RPCOMP TRIP P Continue to POOH from 2235'MD to 2,235.0 427.0 00:00 00:45 427'MD.Monitor well.Static. 11/4/2017 11/4/2017 0.75 COMPZN RPCOMP BHAH P Lay down intensifier.Stand back DC's. 427.0 0.0 00:45 01:30 Lay down jars,bumper sub and overshot. 11/4/2017 11/4/2017 0.50 COMPZN RPCOMP BHAH P Clean and clear rig floor. 0.0 0.0 01:30 02:00 11/4/2017 11/4/2017 1.00 COMPZN RPCOMP ELNE P Rig up Dutch riser. 0.0 0.0 02:00 03:00 11/4/2017 11/4/2017 2.25 COMPZN RPCOMP ELNE P Hang top sheave and RIH w/3-5/8" 0.0 0.0 03:00 05:15 Chem cutter to 8,094-ft -Unable to get into the TOF-Sheared wire line jars-attempt to work inside TOF-still unsuccessful. POOH. Check out chem cutter-showed signs on the low side of cutter-attempting to pass thru the TOF. 11/4/2017 11/4/2017 1.00 COMPZN RPCOMP ELNE P Discuss options with Town engineer- 0.0 0.0 05:15 06:15 made decision to RIH with Mechanical cutter and attempt to make cut at 8,186-ft-Mid joint on jt 3 of 8. RD Pollard E-line Page 8/33 Report Printed: 11/28/2017 • Opeatit. rations Summary (with Timelog Depths) Or'21 1D-12 ConocoPFsifhps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Tune End Time Our{hr) Phase _ Op Code Activity Code Time P-T-X Operation {ftKB} EtaDepth{ftKB) 11/4/2017 11/4/2017 1.00 COMPZN RPCOMP BHAH P Change over pipe handling 0.0 97.0 06:15 07:15 equipment,PU,MU and RIH w/3-1/8" OD Multi String Cutter with 1"knives installed,3-joints of 2-7/8"PAC DP,X- 0,X-O to 97-ft 11/4/2017 11/4/2017 3.50 COMPZN RPCOMP TRIP P RIH w/BHA#7 3.125"MSC Assembly 97.0 8,185.0 07:15 10:45 from 97-ft to 8,094-ft--Had to rotate to enter TOF and continue to RIH and locate TOF with 4.688"OD Crossover sub-PU 2-ft for making cut @ 8,185-ft UPwt=140K,DNwt=107K and ROT wt=120K at 5 rpm with 2K TQ. 11/4/2017 11/4/2017 0.50 COMPZN RPCOMP CPBO P Begin rotating at 40 rpm and come 8,185.0 8,185.0 10:45 11:15 online with pump at 4 bpm at 750 psi. TQ at 3-4K. Increase PR to 4.5 bpm at 950 psi,seen torque increase to 5K, then fell back to free torque. Good indications of cut. Blow down Top drive. 11/4/2017 11/4/2017 2.75 COMPZN RPCOMP TRIP P POOH with BHA#7 from 8,185-ft to 8,185.0 97.0 11:15 14:00 97-ft 11/4/2017 11/4/2017 0.50 COMPZN RPCOMP BHAH P POOH w/BHA#7 and lay down- 97.0 0.0 14:00 14:30 Inspect cutter knives-good signs 11/4/2017 11/4/2017 0.75 COMPZN RPCOMP BHAH P PU,MU and RIH w/BHA#8, 5.875" 0.0 333.0 14:30 15:15 OD Overshot with 4-1/2"Grapple, Install new Bowen Fishing Jars to replace used Bowen fishing jars. Continue to RIH w/Rattler assy and Drill collars to 333-ft. 11/4/2017 11/4/2017 2.50 COMPZN RPCOMP TRIP P RIH w/BHA#8 from 333-ft to 8,040-ft 333.0 8,040.0 15:15 17:45 PU=150K SO=110K. Calc disp=49 bbls Act disp=50 bbls. 11/4/2017 11/4/2017 0.25 COMPZN RPCOMP FISH P Make up top drive.RIH and engage 8,040.0 8,099.0 17:45 18:00 and swallow over 4-1/2 Tbg stub to 8099'MD. 11/4/2017 11/4/2017 0.75 COMPZN RPCOMP JAR P Commence jarring ops.Jar at 250K 8,099.0 8,099.0 18:00 18:45 with straight pull to 350K while circulating at 3 bpm,510 psi.Rattler not functioning.20 jar hits. 11/4/2017 11/4/2017 0.50 COMPZN RPCOMP CIRC P Rig up and reverse circulate through 8,099.0 8,099.0 18:45 19:15 drain sub attempting to get rattler to function.3 bpm,510 psi.Circ total of 15 bbls.Perform derrick inspection while circulating. 11/4/2017 11/4/2017 2.00 COMPZN RPCOMP JAR P Jar at 250K with straight pull to 350K 8,099.0 8,099.0 19:15 21:15 while circulating at 3 bpm,510 psi. Rattler not functioning.40 jar hits. 11/4/2017 11/4/2017 0.25 COMPZN RPCOMP SFTY P Inspect derrick. 8,099.0 8,099.0 21:15 21:30 11/4/2017 11/4/2017 0.75 COMPZN RPCOMP JAR P Pump 20 bbl hi-vis sweep.Jar at 8,099.0 8,099.0 21:30 22:15 250K with straight pull to 350K while circulating at 3 bpm,510 psi.Rattler not functioning.30 jar hits. 11/4/2017 11/4/2017 0.25 COMPZN RPCOMP SFTY P Inspect Derrick. 8,099.0 8,099.0 22:15 22:30 11/4/2017 11/4/2017 0.50 COMPZN RPCOMP JAR P Jar at 250K with straight pull to 350K 8,099.0 8,099.0 22:30 23:00 while circulating at 3 bpm,510 psi. Rattler not functioning.20 jar hits. No observable debris returned with sweep. Page 9/33 Report Printed: 11/28/2017 • Operations Summary (with Timelog Depths) 1D-12 ConocoPhillips 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(ftKB) 11/4/2017 11/4/2017 0.50 COMPZN RPCOMP TRIP P Release overshot.POOH from 8099' 8,099.0 7,977.0 23:00 23:30 MD to 7977'MD. Blow down top drive. 11/4/2017 11/5/2017 0.50 COMPZN RPCOMP SFTY P Perform post jarring derrick inspection. 7,977.0 7,977.0 23:30 00:00 OWFF.Static. 11/5/2017 11/5/2017 0.25 COMPZN RPCOMP SFTY P Continue with post jarring derrick 7,977.0 7,977.0 00:00 00:15 inspection 11/5/2017 11/5/2017 2.00 COMPZN RPCOMP TRIP P POOH w/fishing BHA#8 from 7977' 7,977.0 427.0 00:15 02:15 MD to 427-ft MD Time corrected for end of daylight saving time. 11/5/2017 11/5/2017 0.25 COMPZN RPCOMP OWFF P Monitor well for flow at BHA 427.0 427.0 02:15 02:30 11/5/2017 11/5/2017 1.25 COMPZN RPCOMP BHAH P POOH w/BHA#8 from 427-ft 427.0 0.0 02:30 03:45 11/5/2017 11/5/2017 1.25 COMPZN RPCOMP BHAH P PU,MU and RIH w/6.125"OD x 0.0 404.0 03:45 05:00 4.75"ID Rotary shoe,3 jts 5.75"OD x 5"ID,5-3/4 TSS x 3-1/2 IF Drive sub, Float sub,2-Boot baskets,LBS,Jar,9 -4-3/4"OD DC's,and X-O.to 404-ft 15K BHA UP wt. 11/5/2017 11/5/2017 3.75 COMPZN RPCOMP TRIP P RIH w/BHA#9 from 404-ft to 8,080-ft 404.0 8,080.0 05:00 08:45 while filling DP every 20 stds. 11/5/2017 11/5/2017 1.00 COMPZN RPCOMP SLPC P Slip and cut 72-ft of 1.25"Drill line. 8,080.0 8,080.0 08:45 09:45 11/5/2017 11/5/2017 0.50 COMPZN RPCOMP SVRG P Service draw works and Top Drive 8,080.0 8,080.0 09:45 10:15 11/5/2017 11/5/2017 3.00 COMPZN RPCOMP WASH P Wash down from 8,080-ft to 8,094-ft 8,080.0 8,192.0 10:15 13:15 145K UP wt, 107K DN wt and 130K ROT at 30 RPM at 3.5K free TQ. Work over top of tubing stub and begin to wash down increasing the PR to 5 bpm at 630 psi,slowing down PR to 3 bpm at 340 psi when approaching couplings. Wash down to 8,126-ft before seeing signs of fill,continue to wash down 8,192-ft. Circulated BU at 8 bpm at 1,630 psi in the middle of wash down prior to contiunuing to wash down the last 30-ft to 8,192-ft. 11/5/2017 11/5/2017 1.00 COMPZN RPCOMP CIRC P CBU at 8 bpm at 1,630 psi-returning 8,192.0 8,190.0 13:15 14:15 fine sand until cleaning up 11/5/2017 11/5/2017 0.50 COMPZN RPCOMP OWFF P Monitor well for flow while blowing 8,190.0 8,190.0 14:15 14:45 down Top Drive 11/5/2017 11/5/2017 2.00 COMPZN RPCOMP TRIP P POOH from 8,190-ft(seeing no weight 8,190.0 404.0 14:45 16:45 change-150K UP) to 404-ft 11/5/2017 11/5/2017 0.25 COMPZN RPCOMP OWFF P Monitor well for flow at BHA 404.0 404.0 16:45 17:00 11/5/2017 11/5/2017 1.00 COMPZN RPCOMP BHAH P Stand back DC's.Lay down BHA. 404.0 0.0 17:00 18:00 Clean boot baskets.Recover 11 lbs metal debris from boot baskets. 11/5/2017 11/5/2017 1.00 COMPZN RPCOMP BHAH P Clean and clear rig floor. 0.0 0.0 18:00 19:00 11/5/2017 11/5/2017 0.75 COMPZN RPCOMP BHAH P Make up overshot BHA#10 to 312' 0.0 312.0 19:00 19:45 MD. 11/5/2017 11/5/2017 3.00 COMPZN RPCOMP TRIP P RIH w/overshot BHA#10 from 312' 312.0 8,019.0 19:45 22:45 MD to 8019'MD. PU=152K SO=105K Page 10/33 Report Printed: 11/28/2017 . 0 ,y > Operations Summary (with Timelog Depths) ''z' ff 1D-12 ConocoPhitiips i. 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 MKS) End Depth MKS) 11/5/2017 11/5/2017 0.25 COMPZN RPCOMP FISH P Make up top drive.RIH and engage 8,019.0 8,099.0 22:45 23:00 and swallow over 4-1/2 tbg stub to 8099'MD. 11/5/2017 11/6/2017 1.00 COMPZN RPCOMP JAR P Commence jarring ops.Jar at 250K 8,099.0 8,099.0 23:00 00:00 with straight pull to 350K while circulating at 3 bpm,230 psi.Vary pump rate between 3 bpm,230 psi and 8 bpm, 1340 psi.50 jar hits. 11/6/2017 11/6/2017 1.00 COMPZN RPCOMP JAR P Jar at 250K with straight pull to 350K 8,099.0 8,099.0 00:00 01:00 while circulatingi.Vary pump rate between 3 bpm,230 psi and 8 bpm, 1340 psi.50 jar hits. 11/6/2017 11/6/2017 0.50 COMPZN RPCOMP TRIP P Release overshot.POOH from 8099' 8,099.0 7,977.0 01:00 01:30 MD to 7977'MD.Blow down top drive. 11/6/2017 11/6/2017 0.50 COMPZN RPCOMP SFTY P Perform post jarring derrick inspection. 7,977.0 7,977.0 01:30 02:00 Monitor well.Static. 11/6/2017 11/6/2017 2.25 COMPZN RPCOMP TRIP P POOH with overshot BHA#10 from 7,977.0 407.0 02:00 04:15 7977'MD to 407-ft 11/6/2017 11/6/2017 0.25 COMPZN RPCOMP OWFF P Monitor well for flow at BHA 407.0 407.0 04:15 04:30 11/6/2017 11/6/2017 1.50 COMPZN RPCOMP BHAH P Pooh laying down BHA#10 407.0 0.0 04:30 06:00 11/6/2017 11/6/2017 2.50 COMPZN RPCOMP BHAH P Call out more wash over pipe and load 0.0 0.0 06:00 08:30 pipe shed 11/6/2017 11/6/2017 0.50 COMPZN RPCOMP SVRG P Change out Top Drive rail guide rollers 0.0 0.0 08:30 09:00 - found bad bearing-Covered with Daily 1/2 hr service 11/6/2017 11/6/2017 0.50 COMPZN RPCOMP RGRP T Continue to Change out Top Drive rail 0.0 0.0 09:00 09:30 guide rollers- found bad bearing 11/6/2017 11/6/2017 1.75 COMPZN RPCOMP BHAH P PU/MU and RIH w/Wash over- 0.0 577.0 09:30 11:15 Dress off assembly to 577-ft BHA#11 11/6/2017 11/6/2017 3.00 COMPZN RPCOMP TRIP P RIH w/BHA#11 to 8,094-ft filling DP 577.0 .8,094.0 11:15 14:15 every 20 stands 11/6/2017 11/6/2017 4.75 COMPZN RPCOMP WASH P Slide over TOF to 8,192-ft and begin 8,094.0 8,234.0 14:15 19:00 washing down at 7 bpm at 1600 psi while rotating at 45 RPM at 4 to 4.5K over Free TQ of 4.5K.Tag fill at 8180' MD. Wash down to 8233'MD.Silty i sand observed in returns at shakers. Progress halted at tbg collar located at 8234'MD. Increase pump rate to 6 bpm, 1180 psi.Top drive torquing up and stalling out with torque limit set at 10K ft/lbs. 11/6/2017 11/6/2017 0.75 COMPZN RPCOMP CIRC P POOH from 8234'MD to 8158'MD. 8,234.0 8,158.0 19:00 19:45 CBU at 9 bpm,2120 psi.Minimal sand returns at bottoms up. 11/6/2017 11/6/2017 0.25 COMPZN RPCOMP OWFF P Pick up to 8063'MD.Monitor well. 8,158.0 8,063.0 19:45 20:00 Static.Blow down top drive. 11/6/2017 11/6/2017 2.75 COMPZN RPCOMP TRIP P POOH from 8063'MD to 673'MD.PU 8,063.0 673.0 20:00 22:45 at 170K to 7779'MD then dropping off to 150K. 11/6/2017 11/6/2017 0.25 COMPZN RPCOMP OWFF P Monitor well for flow at BHA 673.0 673.0 22:45 23:00 11/6/2017 11/7/2017 1.00 COMPZN RPCOMP BHAH P Stand back DC's.Lay down washpipe 673.0 150.0 23:00 00:00 BHA.#11. Page 11/33 Report Printed: 11/28/2017 i 0 Operations Summary (with Timelog Depths) ‘,,,, §. &WeliS':,, 1D-12 ConocoPhitiips If 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) 11/7/2017 11/7/2017 1.00 COMPZN RPCOMP BHAH P Continue to lay down washpipe BHA 150.0 0.0 00:00 01:00 #11.Clean boot baskets. Recover 20 lbs of metal debris from boot baskets. 11/7/2017 11/7/2017 1.00 COMPZN RPCOMP BHAH P Make up dress off BHA#12.to 310' 0.0 310.0 01:00 02:00 MD. 11/7/2017 11/7/2017 3.50 COMPZN RPCOMP TRIP P RIH with BHA#12 from 310'MD to 310.0 8,080.0 02:00 05:30 8080'MD. 11/7/2017 11/7/2017 1.25 COMPZN RPCOMP MILL P Obtain parameter: PU=160K,SO= 8,080.0 8,096.0 05:30 06:45 100K,rotating weigth=125K at 60 RPM with 6-7K ft-lbs torque and 3 BPM=240 psi. Tag the tubing stub at 8094'MD. PU,start rotating and dress off the tubing stub with 3-5K down and 7-9K ft-lbs torque 8096'MD. Work over the tubing stub several times. 11/7/2017 11/7/2017 1.00 COMPZN RPCOMP CIRC P Pump a hi vis sweep and circulate the 8,096.0 8,096.0 06:45 07:45 well clean. 11/7/2017 11/7/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow for 10 8,096.0 8,094.0 07:45 08:00 minutes and the well is static. 11/7/2017 11/7/2017 3.00 COMPZN RPCOMP TRIP P PJSM. TOOH with BHA#12 from 8,094.0 310.0 08:00 11:00 8094'to 310'MD. 11/7/2017 11/7/2017 1.00 COMPZN RPCOMP BHAH P Lay down BHA#12-dress off shoe 310.0 0.0 11:00 12:00 assembly. 11/7/2017 11/7/2017 1.00 COMPZN RPCOMP ELNE P PJSM. RU Pollard E-line. 0.0 0.0 12:00 13:00 11/7/2017 11/7/2017 1.25 COMPZN RPCOMP ELNE P PU,MU and RIH with chemical cutter 0.0 0.0 13:00 14:15 assembly. Cut the tubing at 8218' ELM. 11/7/2017 11/7/2017 1.25 COMPZN RPCOMP ELNE P POOH with chemical cutter assembly. 0.0 0.0 14:15 15:30 11/7/2017 11/7/2017 0.75 COMPZN RPCOMP ELNE P RD Pollard E-line. 0.0 0.0 15:30 16:15 11/7/2017 11/7/2017 0.50 COMPZN RPCOMP BHAH P PU and MU BHA#13-overshot 0.0 312.0 16:15 16:45 assembly. 11/7/2017 11/7/2017 3.00 COMPZN RPCOMP TRIP P TIH with BHA#13 312.0 8,101.0 16:45 19:45 11/7/2017 11/7/2017 0.50 COMPZN RPCOMP FISH P Obtain parameters: PUW= 162k, 8,101.0 8,082.0 19:45 20:15 SOW=102k,Circ 3 bpm at 210 psi, TIH and tag TOF w/5k WOB at 8,096' MD, PU and rotate 2 turns right,TIH, SO 10k at 8,101'MD,PUH from 8,101'MD to 8,082'MD,BD Top Drive. 11/7/2017 11/7/2017 2.25 COMPZN RPCOMP TRIP P TOOH with BHA#13 8,082.0 407.0 20:15 22:30 11/7/2017 11/7/2017 0.25 COMPZN RPCOMP OWFF P Monitor well for flow 10 minutes,well 407.0 407.0 22:30 22:45 is static. 11/7/2017 11/8/2017 1.25 COMPZN RPCOMP BHAH P Lay down BHA#13,recovered fish, 407.0 0.0 22:45 00:00 dressed off top cut= 14.65',3 full joints=90.12'(jts#260-#262)and bottom cut=15.63',clean cut,no flaring. "NOTE:2'of perfs across collar between joints#260 and#261, -8,141'to-8,143'MD. 11/8/2017 11/8/2017 0.50 COMPZN RPCOMP BHAH P Break down the jar assembly and 0.0 0.0 00:00 00:30 mobilize fishing tools to the rig floor. Page 12/33 Report Printed: 11/28/2017 S S rF Operations Summary (with Timelog Depths) % rte 1D-12 ConocaFhiilips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(h() Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ft+KB), 11/8/2017 11/8/2017 1.75 COMPZN RPCOMP BHAH P PU MU 5 3/4"wash pipe BHA#14 to 0.0 458.0 00:30 02:15 458'MD 11/8/2017 11/8/2017 3.50 COMPZN RPCOMP TRIP P TIH w/BHA#14from 458'MD to 8039' 458.0 8,039.0 02:15 05:45 MD filling the DP every 20 stands. 11/8/2017 11/8/2017 1.75 COMPZN RPCOMP SLPC P Slip and cut the drilling line. 8,039.0 8,039.0 05:45 07:30 11/8/2017 11/8/2017 2.25 COMPZN RPCOMP SVRG P PJSM. Change out the saver sub on 8,039.0 8,039.0 07:30 09:45 the top drive and grabber dies. 11/8/2017 11/8/2017 0.50 COMPZN RPCOMP TRIP P Continue to TIH from 8039'to 8218' 8,039.0 8,218.0 09:45 10:15 MD. 11/8/2017 11/8/2017 3.25 COMPZN RPCOMP WASH P Obtain parameters: PU=162K,SO= 8,218.0 8,235.0 10:15 13:30 107,rotating weight=128K at 60 RPM=4-5K ft-lbs free torque and 5 BPM=540 psi. Tag the tubing stub at 8219'MD with 5K down. PU,shut the pumps off,SO over tubing stub to tag at 8233'MD with 5K down. Start pumping at 5 BPM=540 psi,rotating at 60 RPM=5K ft-lbs and wash down to tag 8233'MD with 5K down. Begin to burning over the collar at 8234'MD at 60 RPM=5-8K torque with 5K down. Made it down to 8235'MD and progress stopped. Attempt to make more hole varying different parameters but unable to without stalling out. 11/8/2017 11/8/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow for 10 8,235.0 8,235.0 13:30 13:45 minutes and the well is static. Blow down the top drive. 11/8/2017 11/8/2017 3.00 COMPZN RPCOMP TRIP P TOOH with BHA#14 from 8235'to 8,235.0 458.0 13:45 16:45 458'MD. Monitor the well for 5 minutes and the well is static. 11/8/2017 11/8/2017 1.25 COMPZN RPCOMP BHAH P Lay down BHA#14-5-3/4"wash pipe 458.0 0.0 16:45 18:00 assembly. Inspect shoe,extensive wear.7 lbs.metal debris recovered from boot baskets. 11/8/2017 11/8/2017 0.75 COMPZN RPCOMP BHAH P Cean and clear floors,mobilze 0.0 0.0 18:00 18:45 equipment to rig floor. 11/8/2017 11/8/2017 1.00 COMPZN RPCOMP BHAH P PU MU wash pipe(3jts WP)BHA#15 0.0 401.0 18:45 19:45 to 401'MD 11/8/2017 11/8/2017 3.00 COMPZN RPCOMP TRIP P TIH with BHA#15 from 401'MD to 401.0 8,171.0 19:45 22:45 8,171'MD 11/8/2017 11/8/2017 0.50 COMPZN RPCOMP WASH P Obtain parameters PUW=160k,SOW 8,171.0 8,234.0 22:45 23:15 =105k,ROT= 125k,Circ 11 bpm at 2,220 psi,4-5k free torque,TIH and tag TOF at 8,219'MD w/5k WOB,PU and rotate over fish and continue down to 8,234'MD w/10k WOB, Increase to 50 RPM,5-8k torque, pump rate to 12 bpm at 2,640 psi. 11/8/2017 11/9/2017 0.75 COMPZN RPCOMP WASH P Pick up off collar at 8,234'MD,pump 8,234.0 8,253.0 23:15 00:00 20 bbl high vis sweep,continue washing down from 8,234'MD to 8,253'MD,4-8k torque,3-5k WOB, sand across shakers. Page 13/33 Report Printed: 11/28/2017 • ! 4 Operations Summary (with Timelog Depths) 1D-12 Coerocitiips n 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 MKS); End Depth(ftKB), 11/9/2017 11/9/2017 2.50 COMPZN RPCOMP WASH P Continue washing down from 8,253' 8,253.0 8,313.0 00:00 02:30 MD,tag and work over collar at 8,263' MD,5k WOB, 12 BPM at 2,620 psi,50 RPM,4-8k torque,continue TIH from 8,263'MD,tag next collar at 8,294' MD,reduce pump rate to 10 BPM at 1,810 psi and work over collar, increase rate back to 12 BPM at 2,520 psi,wash down and tag up at 8,313' MD with drive sub,no pump pressure increase. 11/9/2017 11/9/2017 0.50 COMPZN RPCOMP CIRC P Pump 25 BBL high vis sweep at 13 8,313.0 8,311.0 02:30 03:00 BPM=2830 psi rotating at 20 RPM= 5K ft-lbs torque and circulate the hole clean. 11/9/2017 11/9/2017 0.50 COMPZN RPCOMP OWFF P Pumps down.Monitor well for flow, 8,311.0 8,171.0 03:00 03:30 static.POOH from 8,311'MD to 8,171' MD.BD top drive. 11/9/2017 11/9/2017 2.50 COMPZN RPCOMP TRIP P POOH from 8,171'MD to 450'MD. 8,171.0 450.0 03:30 06:00 11/9/2017 11/9/2017 1.25 COMPZN RPCOMP BHAH P Stand back the drill collars. Lay down 450.0 94.0 06:00 07:15 and cleanout the boot baskets. Observed 4-1/2"tubing in the wash pipe. 11/9/2017 11/9/2017 0.25 COMPZN RPCOMP SFTY P PJSM on how to lay down the wash 94.0 94.0 07:15 07:30 pipe with 4-1/2"tubing inside. 11/9/2017 11/9/2017 1.00 COMPZN RPCOMP BHAH P Lay down the wash shoe and wash 94.0 0.0 07:30 08:30 pipe. 11/9/2017 11/9/2017 1.00 COMPZN RPCOMP PULL P Extract the section of 4-1/2"tubing 15.0 0.0 08:30 09:30 from the joint of wash pipe(length= 14.74') 11/9/2017 11/9/2017 1.00 COMPZN RPCOMP WAIT P Discuss options with Baker fishing and 0.0 0.0 09:30 10:30 town engineer for plan forward. 11/9/2017 11/9/2017 0.50 COMPZN RPCOMP BHAH P PU and MU BHA#16-6-1/8"junk mill 0.0 305.0 10:30 11:00 assembly. 11/9/2017 11/9/2017 2.75 COMPZN RPCOMP TRIP P TIH with BHA#16 to 8170'MD. 305.0 8,170.0 11:00 13:45 11/9/2017 11/9/2017 1.25 COMPZN RPCOMP MILL P Obtain parameters: PU=162K,SO= 8,170.0 8,238.0 13:45 15:00 107K,rotating weight=130K at 80 RPM=5K ft-lbs torque and 6 BPM= 970 psi. RIH to tag at 8233'MD with 5K down. Mill the tubing stub from 8233'to 8238'MD with 4-7K down and 6-9K ft-lbs torque. Turn the rotary/pumps off and dry tag the stub at 8238'MD. 11/9/2017 11/9/2017 0.75 COMPZN RPCOMP CIRC P Pump 25 bbl hi vis sweep at circulate 8,238.0 8,238.0 15:00 15:45 the well clean at 10 BPM=2800 psi. Blow down the top drive. 11/9/2017 11/9/2017 0.25 COMPZN RPCOMP OWFF P Pumps down.Monitor well for flow, 8,238.0 8,238.0 15:45 16:00 static.BD top drive. 11/9/2017 11/9/2017 2.75 COMPZN RPCOMP TRIP P TOOH with BHA#16 from 8,238'MD 8,238.0 305.0 16:00 18:45 to 305'MD,Monitor well 5 minutes, static. 11/9/2017 11/9/2017 0.50 COMPZN RPCOMP BHAH P Stand back drill collars.Lay down 305.0 0.0 18:45 19:15 BHA#16,Large piece of milled up collar in top of boot basket. 11/9/2017 11/9/2017 1.00 COMPZN RPCOMP BHAH P PU MU 5 3/4"wash pipe BHA#17(5 0.0 458.0 19:15 20:15 jts WP)to 458'MD Page 14/33 Report Printed: 11/28/2017 r • Operations Summary (with Timelog Depths) 1D-12 eo'�f�hillmps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Time End Time Our(Er) Phase Op Code Activity Code Time P-7-XStart Depth 11/9/2017 11/9/2017 3.50 COMPZN RPCOMP TRIP P 1 Operationrom4ftK4) End Depth,2 MKS) 20:15 23:45 TIH w/BHA#17 from 458'MD to 458.0 8,228.0 8,228'MD filling DP every 20 stands. 11/9/2017 11/10/2017 0.25 COMPZN RPCOMP WASH P Obtain parameters PUW= 160k,SOW 8,228.0 8,261.0 23.45 00:00 = 105k,TIH and tag TOF at 8,238'MD w/3k WOB,Pick up and rotate over fish and continue down to 8,261'MD, pump rate to 12 bpm at 2,470 psi,50 rpm with 4-5k torque. 11/10/2017 11/10/2017 1.75 COMPZN RPCOMP WASH P Continue wash down from 8,261'MD, 8,261.0 8,356.0 00.00 01.45 12 bpm at 2,410 psi,80 rpm with 4-5k torque tag collar at 8,263'MD with 4- 6k WOB,continue washing down, ease over collar at 8,293'MD with 3- 4k WOB,continue wash down to collar at 8,355'MD,ease over collar to 8,356'MD,progress stopped,suspect fish spinning with wash pipe. 11/10/2017 11/10/2017 0.75 COMPZN RPCOMP CIRC P Pump 25 BBL high vis sweep to 8,356.0 8,354.0 01:45 02.30 surface, 12 bpm at 2,410 psi. 11/10/2017 11/10/2017 0.50 COMPZN RPCOMP OWFF P Pumps down.TIH and tag collar at 8,354.0 8,228.0 02.30 03.00 8,354'MD at 3k WOB,Monitor well for flow,static. POOH from 8,354'MD to 8,228'MD.BD top drive. 11/10/2017 11/10/2017 2.50 COMPZN RPCOMP TRIP P 03:00 05:30 TOOH with wash pipe BHA#17 from 8,228.0 458.0 8,254'MD to 458'MD. 11/10/2017 11/10/2017 1.00 COMPZN RPCOMP SHAH P Stand back the drill collars. Lay down 458.0 121.0 05:30 06:30 and cleanout the boot baskets. Lay down the first joint of wash pipe and observed 4-1/2"tubing in the next joint of wash pipe. 11/10/2017 11/10/2017 0.25 COMPZN RPCOMP SFTY P PJSM on how to lay down the wash 121.0 121.0 06:30 06:45 pipe with 4-1/2"tubing inside. 11/10/2017 11/10/2017 2.00 COMPZN RPCOMP PULL P Pull the wash pipe out of the hole, 119.0 119.0 06:45 08.45 break off the dress shoe and cut the 4- 1/2"tubing. Continue to lower and cut the 4-1/2"tubing. Recovered 119.45' of 4-1/2"tuibng. 11/10/2017 11/10/2017 0.75 COMPZN RPCOMP BHAH P Lay down the remainin wash 08:45 09:30 9 pipe 121.0 0.0 and clean out the boot baskets. 11/10/2017 11/10/2017 1.50 COMPZN RPCOMP BHAH P Mobilize fishing tools to the rig floor. 0.0 314.0 09:30 11.00 PU and MU BHA#18-dress-off overshot assembly. 11/10/2017 11/10/2017 3.25 COMPZN RPCOMP TRIP P TIH with BHA#18 to 8273'MD. 11:00 14.15 314.0 8,273.0 11/10/2017 11/10/2017 1.75 COMPZN RPCOMP SLPC P Slip and cut 52'(8 wraps)of drilling 8,273.0 8,273.0 14:15 16:00 line. 11/10/2017 11/10/2017 0.50 COMPZN RPCOMP FISH P 16:00 16:30 TIH and tag TOF at 8,357'MD.Pick 8,273.0 8,363.0 up.Obtain parameters,SPR,PUW= 150k,SOW=107k,No pumps PUW= 155k,SOW=110k. ROT w/5k WOB, 60 rpm,6k torque to 8,358'MD, continue down 60 rpm,6k torque, 1-2 WOB to 8,363'MD,set down 10k. 11/10/2017 11/10/2017 0.25 COMPZN RPCOMP CIRC P Pick up to 8,337'MD with 25k 8,363.0 8,337.0 16:30 16.45 overpull.CBU 10 bpm at 1,530 psi. 11/10/2017 11/10/2017 0.25 COMPZN RPCOMP OWFF P Monitor well for flow,static. BD top 8,337.0 8,337.0 16:45 17:00 drive. PJSM Page 15/33 Report Printed: 11/28/2017 ,4140 • • Operations Summary (with Timelog Depths) 1D-12 KtY ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Time End Time Our(hr) Phase Op Code Activity Code< Time P-T-X Operation Start Depth pa (ftK6)', End Depth{ftK8}, 11/10/2017 11/10/2017 3.25 COMPZN RPCOMP TRIP P TOOH with overshot assembly from 8,337.0 314.0 17:00 20:15 8,337'MD to 314'MD.monitor well 5min,static. 11/10/2017 11/10/2017 1.25 COMPZN RPCOMP BHAH P Rack back drill collars. Lay down and 314.0 0.0 20:15 21:30 cleanout the boot baskets. Lay down 37.17'fish,7.97'stub,GLM,pup joint and 9.84'cut joint. 11/10/2017 11/10/2017 0.75 COMPZN RPCOMP BHAH P Strap fish pulled,clean and clear floor. 0.0 0.0 21:30 22:15 11/10/2017 11/10/2017 0.75 COMPZN RPCOMP BHAH P PU MU BHA#19 dress off/overshot 0.0 318.0 22:15 23:00 w/extension assembly to 318'MD. 11/10/2017 11/11/2017 1.00 COMPZN RPCOMP TRIP P TIH with BHA#19,dress off/overshot 318.0 3,161.0 23:00 00:00 w/ext.assembly to 3,161'MD as of midnight. 11/11/2017 11/11/2017 1.75 COMPZN RPCOMP TRIP P Continue TIH with BHA#19,dress 3,161.0 6,954.0 00:00 01:45 off/overshot w/ext.assembly from 3,161'MD to 6,954'MD, 11/11/2017 11/11/2017 0.75 COMPZN RPCOMP CIRC P 10.3 ppg returns, 10.3 ppg heavy 6,954.0 6,954.0 01:45 02:30 pumping,stop and circulate around, 10.3 ppg heavy in/out. 11/11/2017 11/11/2017 0.75 COMPZN RPCOMP TRIP P Continue TIH from 6,954'MD to 8,372' 6,954.0 8,372.0 02:30 03:15 MD 11/11/2017 11/11/2017 0.75 COMPZN RPCOMP FISH P Obtain parameters-PUW=161k, 8,372.0 8,403.0 03:15 04:00 SOW= 109k,circ 5 bpm at 470 psi, TIH and tag fish at 8,392'MD with 4k WOB,pick up 4',rotate 40 rpm,5-6k torque,ROT=125k,dress TOF from 8,392'MD to 8,294'MD,SO 7k at 8,403'MD,pump pressure increase to 640 psi,Pick up with minimal over pull to 8,372'MD, SO 10k,unable to TIH. Pumps down.TIH to 8,386'MD with 8k WOB,unable to get deeper. 11/11/2017 11/11/2017 0.50 COMPZN RPCOMP CIRC P Pick up from 8,386'MD to 8,372'MD, 8,403.0 8,372.0 04:00 04:30 CBU 10 bpm at 2,270 psi,pressure increasing,reduce rate to 9 bpm at 2,350 psi,getting gas to surface at bottoms up,continue to circulate around until gas out. 11/11/2017 11/11/2017 0.50 COMPZN RPCOMP OWFF P Monitor well for flow on trip tank,static 8,372.0 8,372.0 04:30 05:00 for 20 minutes. 11/11/2017 11/11/2017 4.00 COMPZN RPCOMP TRIP P Blow down the top drive. TOOH with 8,372.0 318.0 05:00 09:00 overshot assembly and fish from 8,372'to 318'MD. 11/11/2017 11/11/2017 0.50 COMPZN RPCOMP BHAH P Lay down BHA#19-dress-off 318.0 0.0 09:00 09:30 overshot with extension assembly. 11/11/2017 11/11/2017 1.75 COMPZN RPCOMP PULL P Lay down pup joint,nipple,pup joint, 84.0 0.0 09:30 11:15 joint of tubing,crossover,pup joint and seal assembly. PU overshot and extract the cut joint from the overshot and lay down. Total length recovered =83.57'. 11/11/2017 11/11/2017 0.50 COMPZN RPCOMP BHAH P PJSM. Mobilize fishing equipment to 0.0 0.0 11:15 11:45 the rig floor. 11/11/2017 11/11/2017 0.75 COMPZN RPCOMP BHAH P PU and MU BHA#20-PBR spear 0.0 311.0 11:45 12:30 assembly. 11/11/2017 11/11/2017 2.50 COMPZN RPCOMP TRIP P TIH with BHA#20 to 8,365' 311.0 8,365.0 12:30 15:00 Page 16/33 Report Printed: 11/28/2017 • • Operations Summary (with Timelog Depths) 1D-12 conocoP'hiiiir6 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 (ft106) End Depth(ftKB) 11/11/2017 -11/11/2017 1.50 COMPZN RPCOMP TRIP P Obtain parameters&SPR-PUW= 8,365.0 8,453.0 15:00 16:30 160k,SOW=110k,6 bpm at 1,330 psi,9 bpm at 2,980 psi,wash down to 8,453'MD,PUW=160k,SOW= 110k, 1-2k drag. MW=10.3+ppg, 15:00 hrs. #1 MP-30/40 SPR=420/660 psi #2 MP-30/40 SPR=420/640 psi. 11/11/2017 11/11/2017 0.25 COMPZN RPCOMP CIRC P Pump high vis sweep around,9 bpm 8,453.0 8,453.0 16:30 16:45 at 2,980 psi. 11/11/2017 11/11/2017 0.25 COMPZN RPCOMP PULL P TIH to 8,468'MD,set down 5k, 8,453.0 8,468.0 16:45 17:00 straight pull 175k,225k,250k and 260k,set do 10k,fire jars at 225k,pull free at 175k,SO 10k and PUW 175k 11/11/2017 11/11/2017 0.50 COMPZN RPCOMP CIRC P CBU from 8,424'MD 9 bpm at 3,475 8,468.0 8,424.0 17:00 17:30 psi,monitor well,BD top drive. 11/11/2017 11/11/2017 0.75 COMPZN RPCOMP TRIP P TOOH from 8,424'MD to 8,096'MD, 8,424.0 8,096.0 17:30 18:15 15k over pull,SO 15k,pull 15k over, slack off and Kelly up to top drive. 11/11/2017 11/11/2017 1.50 COMPZN RPCOMP JAR P Begin jarring operations at 250k(100k 8,096.0 8,095.0 18:15 19:45 osw 150k) straight pull to 325k(175k osw 150k)set down 25k several times,increase jarring weight to 260k, straight pull to 350k.Circulate 6.9 bpm at 2,520 psi,continue jarring 260k, straight pull 350k,moved up 1'since jarring.36 jar hits.Able to rack back 1 stand,BD top drive and pick up single 4"DP,losing fluids. 11/11/2017 11/11/2017 0.75 COMPZN RPCOMP SFTY P Perform derrick inspection,establish 8,095.0 8,095.0 19:45 20:30 lose rate of 30 bbl/hr.Fill hole 5 bbls every 30 minutes during jarring ops. 11/11/2017 11/11/2017 1.00 COMPZN RPCOMP JAR P Continue to jar at 250K and straight 8,095.0 8,095.0 20:30 21:30 pull to 350K. 35 jar hits. 11/11/2017 11/11/2017 0.50 COMPZN RPCOMP SFTY P Perform derrick inspection, 8,095.0 8,095.0 21:30 22:00 11/11/2017 11/11/2017 0.50 COMPZN RPCOMP JAR P Continue to jar at 250K and straight 8,095.0 8,095.0 22:00 22:30 pull to 350K.26 jar hits. 11/11/2017 11/11/2017 0.50 COMPZN RPCOMP SFTY P Perform derrick inspection 8,095.0 8,095.0 22:30 23:00 11/11/2017 11/11/2017 0.75 COMPZN RPCOMP JAR P Continue to jar at 250K and straight 8,095.0 8,095.0 23:00 23:45 pull to 350K.39 jar hits. 11/11/2017 11/12/2017 0.25 COMPZN RPCOMP SFTY P Perform post jarring derrick inspection 8,095.0 8,095.0 23:45 00:00 11/12/2017 11/12/2017 0.25 COMPZN RPCOMP SFTY P Finish post jarring derrick inspection. 8,095.0 8,095.0 00:00 00:15 11/12/2017 11/12/2017 0.25 COMPZN RPCOMP TRIP P Release off fish at 8,095'MD.Lay 8,095.0 8,095.0 00:15 00:30 down single joint DP,BD top drive,fill hole with displacement every 5 stands plus 5 bbls every 30 minutes while TOOH. 11/12/2017 11/12/2017 2.75 COMPZN RPCOMP TRIP P TOOH with packer spear assembly 8,095.0 311.0 00:30 03:15 from 8,095'MD to 311'MD. 11/12/2017 11/12/2017 0.75 COMPZN RPCOMP BHAH P Lay down BHA#20-PBR spear 311.0 0.0 03:15 04:00 assembly. 11/12/2017 11/12/2017 1.00 COMPZN RPCOMP BHAH P Clean and clear the rig floor. 0.0 0.0 04:00 05:00 SimOps: Monitor the well. Page 17/33 Report Printed: 11/28/2017 • arilfing Operations Summary (with Timelog Depths) rte ' I 1 D-12 'hiUfipt 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 (EKE) End Depth MKS) 11/12/2017 11/12/2017 1.00 COMPZN WHDBOP RURD P PU and MU the stack washing tool. 0.0 0.0 05:00 06:00 Function all the rams and flush the BOP stack at 9 BPM=30 psi at 80 RPM=0 ft-lbs torque. Lay down the stack washing tool and blow down the top drive. 11/12/2017 11/12/2017 3.50 COMPZN WHDBOP RURD P Pull the wear ring and install the test 0.0 0.0 06:00 09:30 plug. RU BOPE testing equipment. Fill the BOP stack and choke manifold with fresh water. Page 18/33 Report Printed: 11/28/2017 • • KA 0 Operations Summary (with Timelog Depths) 1D-12 P Co ocohitlips 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(ftKB) 11/12/2017 11/12/2017 7.00 COMPZN WHDBOP BOPE P Conduct biweekly BOPE test: test 3- 0.0 0.0 09:30 16:30 1/2"x 6"VBR's(upper pipe rams)to 250/3000 psi with 4"and 4-1/2"test joints;test 2-3/8"solid body rams (lower pipe rams)to 250/3000 psi with 2-3/8"test joint;test annular to 250/3000 with 2-3/8"and 4-1/2"test joints;conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Jeff Jones via email on 11/12/17 at 05:59 hours. Tests: 1) 2-3/8"solid body rams(lower pipe rams)with 2-3/8"test joint(Passed) 2 )Annular with 2-3/8"test joint,upper IBOP,3"Demco(valve 20),choke valves 1, 12, 13&14(Passed) 3) Lower IBOP,kill HCR,choke valves 9&11 (Passed) 4) Manual kill,4"HT-38 FOSV,choke valves 5,8&10(Passed) 5) 4"HT-38 dart valve,choke valves 4,6&7(Passed) 6) 4-1/2"EUE 8rd FOSV,choke valve 2(Passed) 7) Blind rams(Passed) 8) Manual adjustable choke(Passed) 9) Super choke(Passed) 10) 3-1/2"x 6"VBR's(lower pipe rams)with 4-1/2"test joint,choke valves 1 &3(Passed) 11) Annular with 4-1/2"test joint, choke HCR(Passed) 12) Manual choke(Passed) 13) 3-1/2"x 6"VBR's(upper pipe rams)with 4"test joint(Passed) Note: During the Koomey draw down test the 2-3/8"solid body rams(lower pipe rams)were closed on the 4"test joint. The test joint was pulled and there was no damage to the test joint. 14) Retest of the 2-3/8"solid body rams(lower pipe rams)with 2-3/8"test joint(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3000 psi Accumulator Pressure After Closer= 1700 psi Pressure Gain of 200 psi=52 seconds Full System=206 Seconds Average N2(6 Bottles)=2050 psi 11/12/2017 11/12/2017 1.50 COMPZN WHDBOP RURD P RD BOPE testing equipment. Blow 0.0 0.0 16:30 18:00 down the choke and kill lines. PUII the test plug and install the wear bushing. Blow down 2"hard line to the kill tank. 11/12/2017 '11/12/2017 2.00 COMPZN RPCOMP SVRG P Service brakes,clean up draw works 0.0 0.0 18:00 20:00 and grease crown sheaves. Page 19/33 Report Printed: 11/28/2017 xrx • • eigua z Operations Summary (with Timelog Depths) 1D-12 L onocoPhi{lips 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 (ftKO) End Depth(ftKt3) 11/12/2017 11/12/2017 1.00 COMPZN RPCOMP BHAH P PU MU Washpipe/burnover assembly 0.0 342.0 20:00 21:00 BHA#21 to 342'MD. 11/12/2017 11/13/2017 3.00 COMPZN RPCOMP TRIP P TIH from 342'MD to 7,733'MD with 342.0 7,733.0 21:00 00:00 wash pipe/burnover assembly 11/13/2017 11/13/2017 0.25 COMPZN RPCOMP TRIP P Continue to TIH from 7,733'MD to 7,733.0 8,017.0 00:00 00:15 8,017'MD with wash pipe/burnover assembly 11/13/2017 11/13/2017 0.25 COMPZN RPCOMP CIRC P CBU 10 bpm at 1,790 psi. 8,017.0 8,017.0 00:15 00:30 11/13/2017 11/13/2017 2.50 COMPZN RPCOMP WASH P Obtain parameters PUW=155k,SOW 8,017.0 8,098.0 00:30 03:00 108k, 10 bpm at 1,780 psi,TIH from 8,017'MD and tag TOF at 8,085'MD with 5k WOB.Establish Rotation 80 rpm,5-6k torque,ROT 120k,dress off TOF at 8,085'MD with 4-7k WOB, reduce pump to 6 bpm at 840 psi, dress off PBR from 8,085'MD to 8,098'MD 11/13/2017 11/13/2017 3.50 COMPZN RPCOMP MILL P Pump 25 bbl high vis sweep 5 bpm at 8,098.0 8,101.0 03:00 06:30 730 psi.Begin milling over packer 5 bpm at 750 psi from 8,098'to 8101.5' MD and the packer fell down hole, 11/13/2017 11/13/2017 0.50 COMPZN RPCOMP TRIP P Chase the packer down to 8230'MD 8,101.0 8,230.0 06:30 07:00 and set down 15K. 11/13/2017 11/13/2017 1.25 COMPZN RPCOMP MILL P Mill on the packer at 3 BPM=220 psi, 8,230.0 8,230.0 07:00 08:15 80 RPM=7-8K ft-lbs torque. Stalled out at 9K ft-lbs. Attempt to circulate at 1 BPM and pressured up to 450 psi. 11/13/2017 11/13/2017 0.25 COMPZN RPCOMP JAR T Begin to jar to free the wash pipe at 8,230.0 8,230.0 08:15 08:30 250K with straight pull to 275K. Total jar hits=5. 11/13/2017 11/13/2017 0.50 COMPZN RPCOMP SFTY T Derrick inspection. 8,230.0 8,230.0 08:30 09:00 11/13/2017 11/13/2017 0.50 COMPZN RPCOMP JAR T Continue to jar to free the wash pipe 8,230.0 8,214.0 09:00 09:30 at 250K with straight pull to 275K. After 20 hits the wash pipe pulled free (total jar hits=25). PU 30',SO and tag the top of the PBR at 8214'MD. 11/13/2017 11/13/2017 1.00 COMPZN RPCOMP CIRC P Circulate 25 bbl hi-vis sweep at 6 BPM 8,214.0 8,214.0 09:30 10:30 =660 psi and circulate the well clean at 10 BPM=1560 psi. 11/13/2017 11/13/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow and the well 8,214.0 8,214.0 10:30 10:45 is static. SimOps: PJSM. Blow down the top drive. 11/13/2017 11/13/2017 2.75 COMPZN RPCOMP TRIP P TOOH with BHA#21 from 8214'to 8,214.0 342.0 10:45 13:30 342'MD. 11/13/2017 11/13/2017 1.00 COMPZN RPCOMP BHAH P Lay down BHA#21 -wash pipe 342.0 0.0 13:30 14:30 assembly. Recovered 52 lbs of metal debris in the boot baskets. The burn shoe was in decent condition. 11/13/2017 11/13/2017 0.50 COMPZN RPCOMP BHAH P Clean and clear the floor. PJSM for 0.0 0.0 14:30 15:00 MU BHA. 11/13/2017 11/13/2017 0.50 COMPZN RPCOMP BHAH P PU and MU BHA#22-PBR spear 0.0 306.0 15:00 15:30 assembly. Page 20/33 Report Printed: 11/28/2017 • S , ei Operations Summary (with Timelog Depths) &W 1 D-12 Conor iltttps Rig: DOYON 14 Job: RECOMPLETION TimetOg Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Tune P-T-X Operation (ftKB) End Depth(ftKB), 11/13/2017 11/13/2017 3.50 COMPZN RPCOMP TRIP P TIH with BHA#22 from 306'to 8,171' 306.0 8,171.0 15:30 19:00 MD,moitor well via TT. `11/13/2017 11/13/2017 1.75 COMPZN RPCOMP SLPC P PJSM-Slip and Cut drill line,slipped 8,171.0 8,171.0 19:00 20:45 on 55'. 11/13/2017 11/13/2017 0.75 COMPZN RPCOMP FISH P TIH form 8,171'MD.Obtan 8,171.0 8,216.0 20:45 21:30 parameters PUW=145k,SOW 115k, 5 bpm at 830 psi,Set down on fish at 8,216.5'MD with 5k WOB,pressure increased to 1,080 psi, Pull 30k over, sat down 15k WOB.Pick up hole from 8,216'MD to 8,171'MD with 35-45k drag,TBIH to 8,216'MD,fish falls freely,POOH with same drag to 8,171' MD,pull 50k over,Weight dropped to 145k,pump pressure back to 830 psi, TBIH to 8,11'MD,Pick up 145k neutral weight,possible fish parted. 11/13/2017 11/13/2017 0.75 COMPZN RPCOMP CIRC P Pick up to 8,203'MD.CBU 7.6 bpm at 8,216.0 8,203.0 21:30 22:15 1,860 psi. 11/13/2017 11/13/2017 0.25 COMPZN RPCOMP OWFF P Monitor well for flow,static.POOH 8,203.0 8,171.0 22:15 22:30 from 8,203'MD to 8,171'MD.BD top drive. 11/13/2017 11/14/2017 1.50 COMPZN RPCOMP TRIP P TOOH from 8,171'MD to 4,665'MD 8,171.0 4,665.0 22:30 00:00 as of midnight. 11/14/2017 11/14/2017 1.50 COMPZN RPCOMP TRIP P Continue TOOH from 4665'MD to 4,665.0 401.0 00:00 01:30 401'MD. 11/14/2017 11/14/2017 1.00 COMPZN RPCOMP BHAH P Flow check,static.Lay down BHA#22 401.0 0.0 01:30 02:30 -PBR spear assembly. Recovered PBR(12.97')parted at lower connection.release spear from PBR, Lay down spear. 11/14/2017 11/14/2017 0.50 COMPZN RPCOMP BHAH P Mobilize next BHA to rig floor.,Clean 0.0 0.0 02:30 03:00 and clear floors. 11/14/2017 11/14/2017 0.75 COMPZN RPCOMP BHAH P PU and MU BHA#23-packer spear 0.0 308.0 03:00 03:45 assembly(2.993"nominal grapple)to 308'MD. 11/14/2017 11/14/2017 3.25 COMPZN RPCOMP TRIP P TIH with packer spear assembly from 308.0 8,173.0 03:45 07:00 308'MD to 8173'MD. 11/14/2017 11/14/2017 0.75 COMPZN RPCOMP FISH P Obtain parameter: PU=150 K,SO= 8,173.0 8,230.0 07:00 07:45 112 K and 2 BPM=530 psi. RIH to tag 8227'MD with 5K down. PU with no over pull. RIH set down at 8228', pressure increased to 1000 psi,PU with 15K over pull. Shut down the pumps,SO to 8230'MD(top of fish at 8225'MD),PU to 175K(25K over)and the fish is free. New PU=160K with 10-20K drag. Establish circulation at 1 BPM=1650 psi. SPR's at 8173'MD with 10.3+ppg brine #1 mud pump: 3 BPM=800 psi&4 BPM=1300 psi. #2 mud pump: 3 BPM=780 psi&4 BPM=1360 psi. 11/14/2017 11/14/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow and the well 8,230.0 8,230.0 07:45 08:00 is on slight losses. SimOps: Blow down the top drive. Page 21/33 Report Printed: 11/28/2017 • �r Operations Summary (with Timelog Depths) 11 1D-12 ConotoPhitltps use>: 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 (1tK6) End Depth(fKB}', 11/14/2017 11/14/2017 5.50 COMPZN RPCOMP TRIP P TOOH with BHA#23 from 8230'to 8,230.0 3,435.0 08:00 13:30 7505'MD and over pull of 15K. PU a single joint of DP,PU to 210K,SO to 105K,PU to 225K and fish is free. Continue to TOOH from 7505'to 6626' MD and the packer is swabbing. Work the pipe to wear down the elements from 6626'to 6657'MD. The well started taking fluid. Continue to TOOH from 6657'to 3435'MD and the loss rate increased. 11/14/2017 11/14/2017 0.50 COMPZN RPCOMP OWFF T Establish a static loss rate of 90 BPH. 3,435.0 3,435.0 13:30 14:00 Call out for additional fluid. 11/14/2017 11/14/2017 1.00 COMPZN RPCOMP TRIP T TIH from 3435'to tag at 4575'MD with 3,435.0 4,575.0 14:00 15:00 25K down(PU=100K and SO=84K). 11/14/2017 11/14/2017 1.00 COMPZN RPCOMP OTHR T Attempt to work the packer past 4575' 4,575.0 4,575.0 15:00 16:00 MD with a joint of DP and 15'DP pup but unable to. Install the TIW on top of the 15'DP pup and set down 12K. 11/14/2017 11/14/2017 0.50 COMPZN RPCOMP CIRC T Pump 34 bbls hi-vis pill into the IA and 4,575.0 4,575.0 16:00 16:30 fill the DP. 11/14/2017 11/14/2017 4.00 COMPZN RPCOMP WAIT T Wait for 10.1 ppg brine to arrive from 4,575.0 4,575.0 16:30 20:30 Deadhorse. Monitor the well on the trip tank. Loss rate=3 BPH. SimOps: Clean the wind walls above the rig floor. Install shaker screens on the rock washer. Continue rig inventory projects. 11/14/2017 11/15/2017 3.50 COMPZN RPCOMP COND T Take on 10.1 ppg brine and bring 4,575.0 4,575.0 20:30 00:00 viscosity up to 40 vis in the active system. SimOps: Continue to clean the wind walls above the rig floor. Continue rig inventory projects. 11/15/2017 11/15/2017 3.00 COMPZN RPCOMP COND T Continue to bring viscosity up to 40 vis 4,575.0 4,575.0 00:00 03:00 in the active system. Loss rate=3 BPH. SimOps: Continue to clean the wind walls above the rig floor. Continue rig inventory projects. 11/15/2017 11/15/2017 0.50 COMPZN RPCOMP CIRC T PJSM. RU to reverse circulate. 4,575.0 4,575.0 03:00 03:30 Attempt to reverse circulate at 0.8 bpm=2410 psi but no returns (pumped 10 bbls). 11/15/2017 11/15/2017 1.50 COMPZN RPCOMP CIRC T Line up to circulate down the IA and 4,575.0 4,572.0 03:30 05:00 tubing at the same time. PU 3'to 4572'MD and the fluid level dropped below the well head. Begin pumping down the IA at 2.5 BPM=100 psi and down the DP at 0.4 BPM=2500 psi. Getting returns on the IA. Shut down the pumps(pump 72 bbls). 11/15/2017 11/15/2017 0.50 COMPZN RPCOMP OWFF T PU an additional 5'to 4567'MD. Fill 4,572.0 4,567.0 05:00 05:30 the IA with 10 bbls and in 10 minutes the fluid level drop below the well head. Page 22/33 Report Printed: 11/28/2017 • Operations Summary (with Timelog Depths) )otfiziP ikke 1D-12 conocaehinips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Time End Time Our{hr) PhaseStart Depth Op Code Activity Code: Time P-T-X Operation (MO); :End Depth{ftK6} 11/15/2017 11/15/2017 0.50 COMPZN RPCOMP RURD T RD DP pup joints,TIW and blow down 4,567.0 4,567.0 05:30 06:00 circulating lines. 11/15/2017 11/15/2017 0.50 COMPZN RPCOMP OWFF T Monitor the well on the trip tanks and 4,567.0 4,567.0 06:00 06:30 establish a 48 BPH static loss rate. 11/15/2017 11/15/2017 4.50 COMPZN RPCOMP COND T Add 9.8 ppg brine to the 10.1 ppg 4,567.0 4,567.0 06:30 11:00 brine in the pits and water back to make 9.9 ppg brine. SimOps: General housekeeping. Continue to wash the wind walls. 11/15/2017 11/15/2017 1.00 COMPZN RPCOMP CIRC T Install the TIW on top of the DP and 4,567.0 4,567.0 11:00 12:00 close. Close the annular. Bullhead 9.9 ppg down the IA at 1 BPM, 10 bbls away=100 psi,20 bbls away=120 psi and 30 bbls away=130 psi. Pumps off. 11/15/2017 11/15/2017 1.00 COMPZN RPCOMP OWFF T Check for pressure under the annular 4,567.0 4,567.0 12:00 13:00 and pressure is 0 psi. Open the annular. Establish a loss rate of 10 BPH. SimOps: Blow down the choke and kill. PJSM. 11/15/2017 11/15/2017 3.50 COMPZN RPCOMP TRIP P TOOH with BHA#23 from 4567'to 4,567.0 308.0 13:00 16:30 308'MD. 11/15/2017 11/15/2017 0.50 COMPZN RPCOMP BHAH P Lay down BHA#23-packer spear 308.0 0.0 16:30 17:00 assembly 11/15/2017 11/15/2017 0.25 COMPZN RPCOMP PULL P RU the power tubing tongs. Break the 41.0 41.0 17:00 17:15 connection below the packer,back out the connection,PU and encountered trapped pressure. 11/15/2017 11/15/2017 1.50 COMPZN RPCOMP SFTY P Secure the well and rig floor. Monitor 41.0 41.0 17:15 18:45 the well on the trip tank. Clean the rig floor. 11/15/2017 11/15/2017 1.00 COMPZN RPCOMP PULL P Lay down the packer,nipple assembly 41.0 0.0 18:45 19:45 and poor boy overshot. 11/15/2017 11/15/2017 1.25 COMPZN RPCOMP BHAH P PU and MU BHA#24-overshot 0.0 307.0 19:45 21:00 assembly for 3-1/2"tubing. 11/15/2017 11/15/2017 0.50 COMPZN RPCOMP SVRG P TIH with 1 stand of DP to 402'MD. 307.0 402.0 21:00 21:30 Service and inspect the top drive roller assembly. 11/15/2017 11/15/2017 0.25 COMPZN RPCOMP CIRC P Line and break circulation at 4 BPM= 402.0 402.0 21:30 21:45 60 psi. Flow check and the well is still on slight losses. 11/15/2017 11/16/2017 2.25 COMPZN RPCOMP TRIP P TIH with BHA#24 from 402'to 5235' 402.0 5,235.0 21:45 00:00 MD at midnight. 11/16/2017 11/16/2017 1.25 COMPZN RPCOMP TRIP P Continue to TIH with BHA#24 from 5,235.0 8,457.0 00:00 01:15 5235'to 8457'MD. 11/16/2017 11/16/2017 0.25 COMPZN RPCOMP CIRC P Obtain SPR's with 9.9 ppg brine at 8,457.0 8,457.0 01:15 01:30 8457'MD. #1 mud pump-3 BPM=220 psi and 4 BPM=340 psi. #2 mud pump-3 BPM=240 psi and 4 BPM=340 psi. 11/16/2017 11/16/2017 0.75 COMPZN RPCOMP CIRC P Circulate and condition the well to 9.9 8,457.0 8,457.0 01:30 02:15 ppg brine at 10 BPM=1260 psi. Reduce pump rate to 6 BPM=620 psi. Mud weight in/out=9.9 ppg. 11/16/2017 11/16/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow and the well 8,457.0 8,457.0 02:15 02:30 is static. Page 23/33 Report Printed: 11/28/2017 • „‘,,,,,,,x0;,,,,,,,, e ::,..._,,,,01.,,,,,,,.. c , , 0 Operations Summary (with Timelog Depths) 1D-12 Conohiiiips • Rig: DOYON 14 Job: RECOMPLETION Time Lag • Start Depth Start Time End Time Our(hr) Phase Op Code Activity Cade Time P-T-X Operation (ftKB) End Depth(ftKB) 11/16/2017 11/16/2017 0.50 COMPZN RPCOMP FISH P Obtain parameter: PU= 155K,SO= 8,457.0 8,520.0 02:30 03:00 115K and 4 BPM=320 psi. RIH from 8457'MD to tag at 8516'MD with 5K down. PU 5',rotate 30 RPM=5-6K ft- lbs torque,SO to 8517'MD,shut off the rotary,SO to 8520'MD and set 5K down. PU with 15K over pull,set down 10K,pull 45K over,set down 15K and straight pull to 250K. 11/16/2017 11/16/2017 1.00 COMPZN RPCOMP JAR P Begin jarring at 250K with straight pull 8,520.0 8,520.0 03:00 04:00 up to 300K(66 hits). 11/16/2017 11/16/2017 0.50 COMPZN RPCOMP SFTY P Derrick inspection. 8,520.0 8,520.0 04:00 04:30 11/16/2017 11/16/2017 1.50 COMPZN RPCOMP JAR P Continue jarring at 250K with straight 8,520.0 8,520.0 04:30 06:00 pull up to 300K(63 hits). 11/16/2017 11/16/2017 0.50 COMPZN RPCOMP SFTY P Derrick inspection. 8,520.0 8,520.0 06:00 06:30 11/16/2017 11/16/2017 1.00 COMPZN RPCOMP JAR P Continue jarring at 250K with straight 8,520.0 8,520.0 06:30 07:30 pull up to 310K(47 hits. Total jar hits _). 11/16/2017 11/16/2017 0.50 COMPZN RPCOMP SFTY P Derrick inspection. 8,520.0 8,520.0 07:30 08:00 11/16/2017 11/16/2017 0.25 COMPZN RPCOMP FISH P Release the overshot from the tubing 8,520.0 8,520.0 08:00 08:15 stub. 11/16/2017 11/16/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow. Established 8,520.0 8,520.0 08:15 08:30 a loss rate of 12-14 BPH. 11/16/2017 11/16/2017 3.00 COMPZN RPCOMP TRIP P TOOH with BHA#24 from 8520'to 8,520.0 304.0 08:30 11:30 307'MD. 11/16/2017 11/16/2017 0.50 COMPZN RPCOMP BHAH P Lay down BHA#24-overshot 304.0 0.0 11:30 12:00 assembly for 3-1/2”tubing. 11/16/2017 11/16/2017 1.25 COMPZN RPCOMP BHAH P PU and MU BHA #25-wash pipe 0.0 341.0 12:00 13:15 assembly. 11/16/2017 11/16/2017 3.50 COMPZN RPCOMP TRIP P TIH with BHA#25 from 341'to 8491' 341.0 8,491.0 13:15 16:45 MD filling every 20 stands(PU=162K and SO=105K) 11/16/2017 11/16/2017 1.25 COMPZN RPCOMP SLPC P Slip and cut 47'of drilling line. 8,491.0 8,491.0 16:45 18:00 11/16/2017 11/16/2017 1.00 COMPZN RPCOMP WASH P Obtain parameter: PU=165K,SO= 8,491.0 8,543.0 18:00 19:00 115K and 3 BPM=220 psi. Wash down from 8457'MD to tag at 8522' with 5K down. PU,rotate at 50 RPM= 6-7K ft-lbs free torque and wash down to 8543'MD. PU to 8510'MD,shut off the rotary,SO and tag at 8522'MD. PU,start rotating and wash back down to 8543'MD. 11/16/2017 11/16/2017 1.00 COMPZN RPCOMP CIRC P Pump 35 bbl hi-vis sweep at 4 BPM= 8,543.0 8,543.0 19:00 20:00 430 psi and circulate out at 7 BPM= 790 psi. Pumps off. 11/16/2017 11/16/2017 0.50 COMPZN RPCOMP OWFF P PU to 8491'MD. Observe the well for 8,543.0 8,491.0 20:00 20:30 flow and the well taking fluid. SimOps: Blow down the top drive. 11/16/2017 11/16/2017 2.75 COMPZN RPCOMP TRIP P TOOH with BHA#25 from 8491'to 8,491.0 341.0 20:30 23:15 341'MD. 11/16/2017 11/17/2017 0.75 COMPZN RPCOMP BHAH P Lay down BHA #25-wash pipe 341.0 35.0 23:15 00:00 assembly. Page 24/33 Report Printed: 11/28/2017 • Operations Summary (with Timelog Depths) c'ks,t,44144.0 10-12 ConacoPhillips 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 (ftK6) End Depth MKS) 11/17/2017 11/17/2017 0.50 COMPZN RPCOMP BHAH P Continue to lay down BHA #25-wash 35.0 0.0 00:00 00:30 pipe assembly. Recovered 10 lbs of metal debris in the boot baskets. 11/17/2017 11/17/2017 1.25 COMPZN RPCOMP BHAH P PU and MU BHA#26-overshot 0.0 333.0 00:30 01:45 assembly with rattler. 11/17/2017 11/17/2017 0.25 COMPZN RPCOMP BHAH P RIH to 428'MD and MU the top drive. 333.0 428.0 01:45 02:00 Shallow test the rattler at 2 BPM= 1342 psi(good test). Blow down the top drive. 11/17/2017 11/17/2017 2.50 COMPZN RPCOMP TRIP P TIH with BHA#26 from 428'to 8482 428.0 8,482.0 02:00 04:30 11/17/2017 11/17/2017 0.75 COMPZN RPCOMP FISH P Obtain parameter: PU= 160K and 8,482.0 8,519.0 04:30 05:15 SO=110K. RIH from 8482'MD to tag at 8514'MD with 5K down. PU 5', rotate 30 RPM=5-6K ft-lbs torque, SO to 8517'MD,shut off the rotary, SO to 8519'MD and set 5K down. PU with 15K over pull,set down 10K,pull 45K over,set down 15K and straight pull to 225K. 11/17/2017 11/17/2017 2.75 COMPZN RPCOMP JAR P Break circulation at 1.5 BPM= 1590 8,519.0 8,519.0 05:15 08:00 psi,increase to 2 BPM=1620 psi and begin rattling at 3 BPM=1890 psi with straight pull up to 300K. Begin to jar and rattle at 2.5 BPM=1430 psi and jarring at 250K with straight pull up to 310K. 11/17/2017 11/17/2017 0.50 COMPZN RPCOMP SFTY P Derrick inspection. 8,519.0 8,519.0 08:00 08:30 11/17/2017 11/17/2017 0.50 COMPZN RPCOMP JAR P Continue to rattle at 3 BPM=1550 psi 8,519.0 8,519.0 08:30 09:00 with straight pull to 310K. 11/17/2017 11/17/2017 0.25 COMPZN RPCOMP FISH P Release the overshot from the tubing 8,519.0 8,482.0 09:00 09:15 stub and PU to 8482'MD. 11/17/2017 11/17/2017 0.50 COMPZN RPCOMP SFTY P Derrick inspection. 8,482.0 8,482.0 09:15 09:45 11/17/2017 11/17/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow and the well 8,482.0 8,482.0 09:45 10:00 is taking fluid. SimOps: Blow down the top drive. 11/17/2017 11/17/2017 3.00 COMPZN RPCOMP TRIP P TOOH with BHA#26 from 8482'to 8,482.0 333.0 10:00 13:00 333'MD. 11/17/2017 11/17/2017 1.00 COMPZN RPCOMP BHAH P Lay down BHA#26-overshot 333.0 0.0 13:00 14:00 assembly with rattler. 11/17/2017 11/17/2017 0.50 COMPZN RPCOMP BHAH P Clean and clear the rig floor. Mobilize 0.0 0.0 14:00 14:30 fishing tools to the rig floor. 11/17/2017 11/17/2017 0.50 COMPZN WELLPR BHAH P Break out the dress off shoe from the 0.0 0.0 14:30 15:00 triple connect sub. 11/17/2017 11/17/2017 1.50 COMPZN WELLPR WAIT P Wait for addition fishing tools to arrive 0.0 0.0 15:00 16:30 from Deadhorse. 11/17/2017 11/17/2017 0.75 COMPZN WELLPR BHAH P PU and MU BHA#27-dress off shoe 0.0 428.0 16:30 17:15 for 3-1/2"tubing. 11/17/2017 11/17/2017 0.25 COMPZN WELLPR SFTY P Kick while tripping drill(CRT=85 428.0 428.0 17:15 17:30 seconds). AAR with rig crew. 11/17/2017 11/17/2017 1.00 COMPZN WELLPR OTHR P Doyon 14 crew appreciation BBQ. 428.0 428.0 17:30 18:30 11/17/2017 11/17/2017 3.00 COMPZN WELLPR TRIP P TIH with BHA#27 from 428'to 8483' 428.0 8,483.0 18:30 21:30 MD Page 25/33 Report Printed: 11/28/2017 • Operations Summary (with Timelog Depths) 1D-12 Co€ocoPhitiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our Or) Phase Op Code Activity Code Time P-T-X ()Persil= (ftKB) End Depth(ft(B) 11/17/2017 11/17/2017 2.00 COMPZN WELLPR MILL P Obtain parameters: PU=168K SO 8,483.0 8,520.0 21:30 23:30 105K,rotating weight= 130K at 60 RPM=5K ft-lbs free torque and 5 BPM=470 psi. Wash down from 8483'MD to tag at 8514'MD with 5K down. PU 5',start rotating and mill the tubing stub from 8514'to 8519.5'MD at 60 RPM=6-8K ft-lbs torque with 4- 5K down 4-5 BPM=470-600 psi. PU to 8510',shut down the rotary,SO and tag tubing stub at 8519.5'. 11/17/2017 11/18/2017 0.50 COMPZN WELLPR CIRC P PU to 8514'. Pump 30 bbl hi-vis 8,520.0 8,514.0 23:30 00:00 sweep and circulate the well clean at 6 BPM=800 psi. 11/18/2017 11/18/2017 0.75 COMPZN WELLPR CIRC P Continue to circulate the sweep out of 8,514.0 8,514.0 00:00 00:45 the hole at 6 BPM=800 psi. 11/18/2017 11/18/2017 0.25 COMPZN WELLPR OWFF P Observe the well for flow and the well 8,514.0 8,514.0 00:45 01:00 is taking fluid. 11/18/2017 11/18/2017 0.25 COMPZN WELLPR TRIP P TOOH from 8514'to 8483'MD. Blow 8,514.0 8,483.0 01:00 01:15 down the top drive. 11/18/2017 11/18/2017 3.00 COMPZN WELLPR TRIP P TOOH with BHA#27 from 8514'to 8,483.0 333.0 01:15 04:15 333'MD. 11/18/2017 11/18/2017 1.25 COMPZN WELLPR BHAH P Lay down BHA#27-dress off shoe 333.0 0.0 04:15 05:30 for 3-1/2"tubing. Recovered 20 lbs of metal debris from the boot baskets and magnet. 11/18/2017 11/18/2017 0.50 COMPZN WELLPR BHAH P Clean off magnet and empty the boot 0.0 0.0 05:30 06:00 baskets. Recovered 20 lbs of metal debris from the boot baskets and magnet. 11/18/2017 11/18/2017 0.50 COMPZN WELLPR BHAH P Clean and clear the floor. Off load 0.0 0.0 06:00 06:30 fishing tools from the rig floor. 11/18/2017 11/18/2017 1.00 COMPZN RPCOMP RURD P PU and break out poor boy overshot 0.0 0.0 06:30 07:30 with 10'pup joint from the 2003 RWO. PU and break out the bull nose on the test packer. 11/18/2017 11/18/2017 1.50 COMPZN RPCOMP PUTB P PU and MU the poor boy overshot, 1 0.0 158.0 07:30 09:00 joint of 3-1/2"tubing,2.813"X nipple, 1 joint of 3-1/2"tubing,FHUPBR assembly,crossover,test packer and crossover 11/18/2017 11/18/2017 4.75 COMPZN RPCOMP RCST P TIH with stacked packer assembly 158.0 8,497.0 09:00 13:45 from 158'to 8497'MD(PU= 157K and SO=107K). 11/18/2017 11/18/2017 0.25 COMPZN RPCOMP RURD P RU circulating equipment. 8,497.0 8,497.0 13:45 14:00 11/18/2017 11/18/2017 0.50 COMPZN RPCOMP HOSO P Break circulation at 1 BPM=50 psi. 8,497.0 8,524.0 14:00 14:30 RIH from 8497'to tag at 8519.5'MD with 5K down. SO to no-go at 8525.5' MD and PU 1'for space out to 8524.5' MD. 11/18/2017 11/18/2017 1.50 COMPZN RPCOMP CRIH P Pump 5 bbl hi-vis spacer followed by 5 8,524.0 8,524.0 14:30 16:00 bbls of 9.9 ppg brine followed by 32 bbls of corrosion inhibited brine at 1 BPM=70 psi. Chase with 80 bbls of 9.9 ppg brine at 2 BPM=230 psi. Page 26/33 Report Printed: 11/28/2017 • Operations Summary (with Timelog Depths) At,-v <.$ 1 D-12 40.1 conocophitios Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code ACGvity Code Time P-T-X Operation ((KB) End Depth(ftKE), 11/18/2017 11/18/2017 0.50 COMPZN RPCOMP PACK P Drop the ball&rod and allow 10 8,524.0 8,394.0 16:00 16:30 minutes for it to gravitate to the RHC plug body. Pressure up to 2500 psi to set the FHL packer and hold for 10 minutes. Bleed the pressure to 2000 psi and shear out of the PBR. Bleed the pressure to 0 psi,RD the circulating equipment and blow down. 11/18/2017 11/18/2017 0.25 COMPZN RPCOMP MPSP P PU to 8379'MD,set the test packer at 8,394.0 8,379.0 16:30 16:45 8349'MD center of element(COE). 11/18/2017 11/18/2017 0.25 COMPZN RPCOMP PRTS P Pressure up on the DP to 2500 psi for 8,379.0 8,379.0 16:45 17:00 10 minutes to test the FHUball&rod combination and 7"casing from 8407' to 8349'MD(good test). Bleed the pressure to 0 psi. 11/18/2017 11/18/2017 0.25 COMPZN RPCOMP TRIP P TOOH from 8379'to 8150'MD. 8,379.0 8,150.0 17:00 17:15 11/18/2017 11/18/2017 0.25 COMPZN RPCOMP MPSP P Set the test packer at 8120'MD COE. 8,150.0 8,150.0 17:15 17:30 11/18/2017 11/18/2017 0.75 COMPZN RPCOMP PRTS P Pressure up on the DP to 2500 psi to 8,150.0 8,150.0 17:30 18:15 establish a leak rate of-100 psi/min through the accidental perforation from 8136'to 8138'MD. Bleed the pressure to 0 psi. Close the annual and pressure up on the IA to 2500 psi for 10 minutes to test the 7"casing from 8120'MD to surface(good test). Bleed the pressure to 0 psi and open the annular. 11/18/2017 11/18/2017 0.50 COMPZN RPCOMP RURD P Release the test packer. Blow down 8,150.0 8,150.0 18:15 18:45 the top drive,kill line and choke line. 11/18/2017 11/18/2017 3.00 COMPZN RPCOMP TRIP P TOOH with test packer and seal 8,150.0 40.0 18:45 21:45 assembly from 8150'to 40'MD. 11/18/2017 11/18/2017 0.25 COMPZN RPCOMP BHAH P Lay down the test packer and seal 40.0 0.0 21:45 22:00 assembly. 11/18/2017 11/18/2017 0.25 COMPZN RPCOMP SLKL P Install the Dutch riser and RILDS. 0.0 0.0 22:00 22:15 11/18/2017 11/18/2017 0.25 COMPZN RPCOMP SFTY P PJSM with rig crew and Halliburton 0.0 0.0 22:15 22:30 slickline crew. 11/18/2017 11/18/2017 0.50 COMPZN RPCOMP SLKL P Mobilize slickline tools to the rig floor. 0.0 0.0 22:30 23:00 11/18/2017 11/18/2017 0.50 COMPZN RPCOMP SLKL P RU slickline. PU and MU slickline ball 0.0 0.0 23:00 23:30 &rod overshot assembly. 11/18/2017 11/19/2017 0.50 COMPZN RPCOMP SLKL P RIH with slickline ball&rod overshot 0.0 0.0 23:30 00:00 assembly to 6800'SLM. 11/19/2017 11/19/2017 0.75 COMPZN RPCOMP SLKL P Continue to RIH with slickline ball& 0.0 0.0 00:00 00:45 rod overshot assembly from 6800' SLM to the top of the ball&rod at 8478'SLM. Engage overshot onto ball&rod. POOH from 8478'SLM to surface. Lay down ball&rod. 11/19/2017 11/19/2017 1.00 COMPZN RPCOMP SLKL P MU GR pulling tool. RIH latch into 0.0 0.0 00:45 01:45 RHC plug body at 8482'SLM,release RHC,POOH and lay down the RHC plug body. 11/19/2017 11/19/2017 1.00 COMPZN WELLPR SLKL P MU 2-1/2"bailer, RIH to 9061'SLM, 0.0 0.0 01:45 02:45 POOH and lay down bailer. 11/19/2017 11/19/2017 1.25 COMPZN WELLPR WAIT P Wait for CTD dummy whipstock. 0.0 0.0 02:45 04:00 Page 27/33 Report Printed: 11/28/2017 • • A = Operations Summary (with Timelog Depths) 1D-12 Coo hillips 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 MKS)I End Depth(ftKB) 11/19/2017 11/19/2017 0.50 COMPZN WELLPR SLKL P Mobilize the CTD dummy whipstock to 0.0 04:00 04:30 the rig floor and MU to the tool string. 11/19/2017 11/19/2017 1.00 COMPZN WELLPR SLKL P RIH with CTD dummy whipstock 0.0 0.0 04:30 05:30 (2.625"OD and L=18.5)to 8843' SLM. POOH. 11/19/2017 11/19/2017 1.00 COMPZN WELLPR SLKL P Lay down the CTD dummy whipstock. 0.0 0.0 05:30 06:30 RD HES slickline and off load tools. RD the Dutch riser. 11/19/2017 11/19/2017 2.75 COMPZN WELLPR WWWH P Pull the wear ring. PU and MU the 0.0 0.0 06:30 09:15 BOP stack washing tool and magnet. Flush the BOP stack clean. Lay down the magnet and BOP stack washing tool. Install the wear ring. 11/19/2017 11/19/2017 0.50 COMPZN WELLPR RURD P Change elevators to 2-3/8" and RU 0.0 0.0 09:15 09:45 the power tubing tongs with 2-3/8" dies. 11/19/2017 11/19/2017 0.25 COMPZN WELLPR SFTY P PJSM for running 2-3/8"Hydril 511 0.0 0.0 09:45 10:00 tubing for the cleanout assembly. 11/19/2017 11/19/2017 1.75 COMPZN WELLPR BHAH P PU and MU BHA#28-2-3/8"cleanout 0.0 1,002.0 10:00 11:45 assembly. 11/19/2017 11/19/2017 0.25 COMPZN WELLPR RURD P Change elevators to 4'DP and RD the 1,002.0 1,002.0 11:45 12:00 power tubing tongs. 11/19/2017 11/19/2017 2.75 COMPZN WELLPR TRIP P TIH with BHA#28 from 1002'to 8299' 1,002.0 8,299.0 12:00 14:45 MD. 11/19/2017 11/19/2017 1.50 COMPZN WELLPR SLPC P PJSM. Slip and cut 51'(8 wraps)of 8,299.0 8,299.0 14:45 16:15 drilling line. 11/19/2017 11/19/2017 2.00 COMPZN WELLPR WASH P Obtain parameter: PU=150K,SO= 8,299.0 9,044.0 16:15 18:15 105K,rotating weight=132K at 10 RPM=5K ft-lbs free torque, 1 BPM= 80 psi,2 BPM= 130 psi and 3 BPM= 290 psi. Wash down from 8299'to 9044'MD at 2 BPM=230 psi. 11/19/2017 11/19/2017 1.75 COMPZN WELLPR CIRC P Pump at 27 bbl hi-vis sweep at 2 BPM 9,044.0 9,044.0 18:15 20:00 =psi and circulate out of the well at 4 BPM=880 psi 11/19/2017 11/19/2017 0.25 COMPZN WELLPR OWFF P Stand back one stand to 8962'MD. 9,044.0 8,962.0 20:00 20:15 Observe the well for flow and the well is taking fluid. SimOps: Blow down the top drive. 11/19/2017 11/19/2017 3.00 COMPZN WELLPR TRIP P TOOH with BHA#28 from 8962'to 8,962.0 1,002.0 20:15 23:15 1002'MD. 11/19/2017 11/20/2017 0.75 COMPZN WELLPR BHAH P Lay down BHA#28-2-3/8"cleanout 1,002.0 699.0 23:15 00:00 assembly. 11/20/2017 11/20/2017 1.50 COMPZN WELLPR BHAH P Continue to lay down BHA#28-2-3/8" 699.0 0.0 00:00 01:30 cleanout assembly. 11/20/2017 11/20/2017 0.50 COMPZN WELLPR BHAH P Clear and clean the rig floor. 0.0 0.0 01:30 02:00 11/20/2017 11/20/2017 1.00 COMPZN WELLPR SLKL P PJSM. Install the Dutch riser and 0.0 0.0 02:00 03:00 RILDS. Mobilize slickline tools and equipment to the rig floor. RU slickline. MU CTD dummy whipstock. 11/20/2017 11/20/2017 1.25 COMPZN WELLPR SLKL P RIH with CTD dummy whipstock to 0.0 0.0 03:00 04:15 9029'SLM and POOH. Page 28/33 Report Printed: 11/28/2017 • s Operations Summary (with Timelog Depths) 1D-12 Conoce: '"hiHips �1.rks Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Time ne. End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ttK8) End Depth(ftKE) 11/20/2017 11/20/2017 0.75 COMPZN WELLPR SLKL T Pulled tight at 8475'SLM and lost the 0.0 0.0 04:15 05:00 weight of the dummy whipstock. POOH. Missing the CTD dummy whipstock drift and the GR was sheared. 11/20/2017 11/20/2017 0.50 COMPZN WELLPR SLKL T Lay down tool string,re-pin GR tool 0.0 0.0 05:00 05:30 and MU GR assembly. 11/20/2017 11/20/2017 1.50 COMPZN WELLPR SLKL T RIH with GR assembly to 8458'SLM. 0.0 0.0 05:30 07:00 Attempt to engage the dummy whipstock but unable to. POOH. GR was sheared. Lay down GR tool. 11/20/2017 11/20/2017 1.25 COMPZN WELLPR SLKL T MU GS assembly,RIH to 8456'SLM, 0.0 0.0 07:00 08:15 engage GS into the dummy whipstock and POOH. Recovered dummy whipstock. 11/20/2017 11/20/2017 0.75 COMPZN WELLPR SLKL P RD HES slickline. 0.0 0.0 08:15 09:00 11/20/2017 11/20/2017 1.00 COMPZN WELLPR ELNE P Spot SLB E-line unit and mobilize E- 0.0 0.0 09:00 10:00 line equipment to the rig floor. SimOps: General housekeeping and cleaning wind walls. 11/20/2017 11/20/2017 2.00 COMPZN WELLPR ELNE P PJSM. RU SLB E-line. 0.0 0.0 10:00 12:00 11/20/2017 11/20/2017 2.00 COMPZN WELLPR ELNE P RIH with E-line dummy whipstock to 0.0 0.0 12:00 14:00 9012'WLM and POOH. Lay down the dummy whipstock. 11/20/2017 11/20/2017 1.50 COMPZN WELLPR ELNE P RD SLB E-line. RD the Dutch riser 0.0 0.0 14:00 15:30 11/20/2017 11/20/2017 1.00 COMPZN WELLPR RURD P PJSM. RU power tubing tongs. MU 0.0 0.0 15:30 16:30 crossover onto stand#1. MU crossover to TIW. 11/20/2017 11/20/2017 0.50 COMPZN WELLPR WAIT P Wait for motor to arrive from 0.0 0.0 16:30 17:00 Deadhorse. SimOps: continue to clean the wind walls. 11/20/2017 11/20/2017 1.75 COMPZN WELLPR BHAH P PU and MU BHA#29-2.78"mill& 0.0 722.0 17:00 18:45 motor assembly. 11/20/2017 11/20/2017 4.25 COMPZN WELLPR TRIP P TIH with BHA#29 filling DP every 20 722.0 8,366.0 18:45 23:00 stands from 722'to 8366'MD(PU= 140K and SO=110K). 11/20/2017 11/20/2017 0.50 COMPZN WELLPR TRIP P Continue to TIH from 8366'to 8584' 8,366.0 8,584.0 23:00 23:30 MD. Did not see the top of the PBR or either nipple profile. 11/20/2017 11/21/2017 0.50 COMPZN WELLPR WASH P MU the top drive and wash down at 8,584.0 8,777.0 23:30 00:00 1.5 BPM=1550 psi from 8584'to 8777'MD at midnight. 11/21/2017 11/21/2017 1.00 COMPZN WELLPR WASH P Continue to wash down at 1.5 BPM= 8,777.0 9,045.0 00:00 01:00 1550 psi from 8777'to 9045'MD. 11/21/2017 11/21/2017 1.00 COMPZN WELLPR CIRC P PU to 8961'MD and drop 5/8"ball at 9,045.0 8,961.0 01:00 02:00 1.4 BPM=860 psi. Ball did not seat after 92 bbls pumps. 11/21/2017 11/21/2017 1.50 COMPZN WELLPR CIRC P Pump 30 bbls sweep at 1.4 BPM= 8,961.0 8,961.0 02:00 03:30 970 psi and circulate out of the DP (ball still did not seat). 11/21/2017 11/21/2017 0.25 COMPZN WELLPR CIRC P Bullhead 40 bbls down the IA at 5 8,961.0 8,961.0 03:30 03:45 BPM=1910 psi. Page 29/33 Report Printed: 11/28/2017 • • Operations Summary (with Timelog Depths) 1D-12 Conoccehifi ps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Siert Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB); 11/21/2017 11/21/2017 0.25 COMPZN WELLPR OWFF P Observe the well for flow and the well 8,961.0 8,961.0 03:45 04:00 is taking fluid. SimOps: Blow down the top drive and kill line. 11/21/2017 11/21/2017 0.75 COMPZN WELLPR TRIP P TOOH with BHA#29 from 8961'to 8,961.0 8,011.0 04:00 04:45 8011 11/21/2017 11/21/2017 0.25 COMPZN WELLPR CIRC P MU the top drive and attempt to 8,011.0 8,011.0 04:45 05:00 circulate but the ball is now out seat. Pressure up to 2500 psi to shear the circulation sub ball seat. Blow down the top drive. 11/21/2017 11/21/2017 2.75 COMPZN WELLPR TRIP P Continue to TOOH with BHA#29 from 8,011.0 722.0 05:00 07:45 8011'to 722'MD. 11/21/2017 11/21/2017 1.25 COMPZN WELLPR BHAH P Lay down BHA#29-2.78"mill& 722.0 0.0 07:45 09:00 motor assembly. Found a rock in the circulation sub that was initially not allowing the ball to seat. 11/21/2017 11/21/2017 1.50 COMPZN WELLPR ELNE P Install Dutch Riser and RU SLB E-Line 0.0 0.0 09:00 10:30 1-11/16"tool string to CPAI 2.78"whip stock dummy tools for drifting 3-1/2" liner for CTD whip stock setting. 11/21/2017 11/21/2017 3.00 COMPZN WELLPR ELNE P RIH with whip stock drifting assembly 0.0 0.0 10:30 13:30 to 9010.5'WLM and set down. POOH 11/21/2017 11/21/2017 3.00 COMPZN WELLPR ELNE P RIH with 1-11/16"E-line tool string 0.0 0.0 13:30 16:30 with GR/CCL to 9090'WLM. Log up showing 3-1/2"liner patch from 9043' to 9090'MD and rough perfarea from 9003'to 9031'MD(tied in with the K1 Marker). POOH and lay down the tool string. Discuss the options with CTD engineer. 11/21/2017 11/21/2017 1.50 COMPZN WELLPR ELNE P MU CTD whip stock assembly. 0.0 0.0 16:30 18:00 11/21/2017 11/21/2017 2.00 COMPZN WELLPR ELNE P RIH with CTD whip stock assembly to 0.0 0.0 18:00 20:00 tag at 9010'WLM. 11/21/2017 11/21/2017 0.50 COMPZN WELLPR ELNE P Attempt to pump E-line down at 1/2 0.0 0.0 20:00 20:30 BPM=50 and 1 BPM=100 psi but unable to get past 9010'WLM. Bullhead a total of 6.5 bbls. 11/21/2017 11/21/2017 1.50 COMPZN WELLPR ELNE P POOH from 9010'WLM to surface. 0.0 0.0 20:30 22:00 11/21/2017 11/21/2017 1.50 COMPZN WELLPR ELNE P Lay down the whip stock assembly 0.0 0.0 22:00 23:30 and tool string. RD SLB E-line. Clear the floor of E-line tools. 11/21/2017 11/22/2017 0.50 COMPZN WELLPR TRIP P PU and MU stack washing tool with 0.0 1,142.0 23:30 00:00 crossover. TIH with DP to 1142'MD at midnight. 11/22/2017 11/22/2017 2.50 COMPZN WELLPR TRIP P Continue to TIH with DP 1142'to 1,142.0 8,312.0 00:00 02:30 8312'MD. 11/22/2017 11/22/2017 6.50 COMPZN WELLPR PULD P POOH laying down DP from 8312'to 8,312.0 0.0 02:30 09:00 surface. Lay down stack washing tool and crossover. 11/22/2017 11/22/2017 2.00 COMPZN RPCOMP RURD P Pull the wear ring. Load the 3-1/2" 0.0 0.0 09:00 11:00 tubing in pipe shed. Organize completion equipment into running order in the pipe shed. PU power tubing tongs and change elevators to 3-1/2"tubing. Page 30/33 Report Printed: 11/28/2017 • Operations Summary (with Timelog Depths) h�4 t r A` , its„ 1D-12 otikj Conoco iti ps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Time End Time Dur(hi) PhaseStart Depth { Op Code Activity Code Time P-T-X Operation (RKe) End Depth(itKB) 11/22/2017 11/22/2017 0.75 COMPZN RPCOMP PUTB P PU and MU seal assembly and 8 0.0 271.0 11:00 11:45 joints of 3-1/2",9.3#,L-80,EUE 8rd Mod tubing to 271'MD. 11/22/2017 11/22/2017 0.50 COMPZN RPCOMP RURD P Change elevators to 4-1/2"tubing. RU 271.0 271.0 11:45 12:15 DDI torque turn equipment. 11/22/2017 11/22/2017 0.75 COMPZN RPCOMP PUTB P PU and MU 3.81"DB nipple assembly, 271.0 402.0 12:15 13:00 Premier packer/PBR assembly, 1 joint of 4-1/2"tubing and GLM assembly from 271'to 402'MD. 11/22/2017 11/22/2017 0.75 COMPZN RPCOMP RURD P Change out the power tubing tongs. 402.0 402.0 13:00 13:45 11/22/2017 11/23/2017 10.25 COMPZN RPCOMP PUTB P Continue to RIH with completion on 4- 402.0 5,895.0 13:45 00:00 1/2", 12.6#,L-80,TXPM tubing with MU torque=7000 ft/lbs using DDI torque turn from 402'to 5895'MD at midnight. 11/23/2017 11/23/2017 4.50 COMPZN RPCOMP PUTB P Continue to RIH with completion on 4- 5,895.0 8,391.0 00:00 04:30 1/2", 12.6#,L-80,TXPM tubing with MU torque=7000 ft/lbs using DDI torque turn from 5895'to 8391'MD (PU=120K and SO=100K). 11/23/2017 11/23/2017 1.00 COMPZN RPCOMP RURD P Mobilize bail extension to the rig floor 8,391.0 8,391.0 04:30 05:30 and RU. MU circulating equipment to joint#197. 11/23/2017 11/23/2017 0.50 COMPZN RPCOMP HOSO P Continue to RIH form 8391'MD to no- 8,391.0 8,398.0 05:30 06:00 go at 8414'MD. PU to 8398'and break circulation at 5 BPM=400 psi. Pumps off. 11/23/2017 11/23/2017 1.00 COMPZN RPCOMP CRIH P Pump 20 bbls of 9.9 ppg corrosion 8,398.0 8,398.0 06:00 07:00 inhibited brine(1%CRW-132)at 3 BPM=190 psi followed by 121 bbls of 9.9 ppg brine at 5 BPM=410 psi down the tubing taking returns up the IA. 11/23/2017 11/23/2017 1.00 COMPZN RPCOMP PACK P Drop 1-5/16"OD ball&rod,SO,no-go 8,398.0 8,099.0 07:00 08:00 at 8411'MD and PU to 8408'MD. Pressure up on the tubing to 2700 psi for 10 minutes to set the Premier packer. Bleed the tubing to 1000 psi and PU to 165K to shear out of the PBR. Bleed the tubing to 0 psi,SO and tag the top of the PBR at 8082' MD. 11/23/2017 11/23/2017 1.50 COMPZN RPCOMP HOSO P Lay down joint#197, 196 and 195. 8,099.0 8,059.0 08:00 09:30 PU and MU 7.77'and 9.85'pup joints. PU and MU joint#195. 11/23/2017 11/23/2017 0.50 COMPZN RPCOMP RURD P RU circulating equipment to the 8,059.0 8,059.0 09:30 10:00 landing joint. 11/23/2017 11/23/2017 0.75 COMPZN RPCOMP THGR P Drift the tubing hanger to 3.833". MU 8,059.0 8,080.0 10:00 10:45 the tubing hanger,MU the landing joint and SO to 8080'MD. 11/23/2017 11/23/2017 1.25 COMPZN RPCOMP CRIH P Reverse circulate 270 bbls of 9.9 ppg 8,080.0 8,080.0 10:45 12:00 corrosion inhibited brine(1%CRW- 132)at 3 BPM=190 psi slowly increasing to 5 BPM=380 psi. 11/23/2017 11/23/2017 0.50 COMPZN RPCOMP THGR P Drain the BOP stack. PU=117K and 8,080.0 8,099.0 12:00 12:30 SO=95K. Land the tubing hanger and RILDS. Page 31/33 Report Printed: 11/28/2017 41) • Operations Summary (with Timelog Depths) .,t,h z` 1D-12 ConocoPhitlips 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 MKS) End Depth(ftKS) 11/23/2017 11/23/2017 2.50 COMPZN RPCOMP PRTS P PT the tubing to 3000 psi for 30 8,099.0 8,099.0 12:30 15:00 minutes(good test). Bleed the tubing to 1500 psi. PT the IA to 2500 psi for 30 minutes(good test). Quickly bleed the pressure off the tubing to shear the SOV. Pump both ways to ensure the SOV has a good flow path at 1.5 BPM=240 psi. 11/23/2017 11/23/2017 1.00 COMPZN RPCOMP RURD P RD the circulating equipment. Lay 8,099.0 0.0 15:00 16:00 down the landing joint. Blow down the circulation equipment and suck out the BOP stack. 11/23/2017 11/23/2017 0.50 COMPZN WHDBOP MPSP P PU the dry rod and install the 4"ISA 0.0 0.0 16:00 16:30 BPV. Pressure up on the IA to 1000 psi for 10 minutes to PT the BPV from below in the direction of flow(good test). 11/23/2017 11/23/2017 1.50 COMPZN WHDBOP OTHR P Decommissioning activities: Blow 0.0 0.0 16:30 18:00 down the injection line. RU the injection line to the cement line to the choke manifold. Flush with 15 bbls of fresh water and blow down. Flush the kill line with both mud pumps with 25 bbls for fresh water and blow down the kill line. SimOps: Demobilize handling equipment from the rig floor. 11/23/2017 11/23/2017 3.50 COMPZN WHDBOP OTHR P Decommissioning activities: Clean the 0.0 0.0 18:00 21:30 casing equipment,4"TIW,4"dart valve,3-1/2"IF lift sub and 5'DP pup and demobilize from the rig floor. Flush the top drive with fresh water functioning the upper and lower IBOP. Suck out the BOP stack. Blow down the top drive,mud pumps and charge pumps. RD the fluid ends on the mud pumps. 11/23/2017 11/24/2017 2.50 COMPZN WHDBOP OTHR P Decommissioning activities: Remove 0.0 0.0 21:30 00:00 the upper pipe rams and clean. Cleanout the ram cavities and grease. Continue to RD the fluid ends on the mud pumps. Flush all the lines in the pits with hot soapy fresh water. 11/24/2017 11/24/2017 3.25 COMPZN WHDBOP OTHR P Decommissioning activities: Remove 0.0 0.0 00:00 03:15 the blind rams/lower pipe rams and clean. Cleanout the ram cavities and grease. Continue to RD the fluid ends on the mud pumps. Continue to flush all the lines in the pits with hot soapy fresh water. SimOps: Pull the riser and ND the kill line. 11/24/2017 11/24/2017 1.00 COMPZN WHDBOP NUND P Remove the turnbuckles. ND the BOP 0.0 0.0 03:15 04:15 stack,set back on the stump and secure for transport. ND the 11"x 7- 1/16"DSA. SimOps: Continue to RD the fluid ends on the mud pumps. Continue to clean the pits. Page 32/33 Report Printed: 11/28/2017 • Operations Summary (with Timelog Depths) 1D-12 CotocoPhttitps .. 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 mks) End,Depth MKS) 11/24/2017 11/24/2017 0.50 COMPZN WHDBOP NUND P Clean the top of the tubing hanger. 0.0 0.0 04:15 04:45 11/24/2017 11/24/2017 3.75 COMPZN WHDBOP NUND P NU the tubing head adapter. The 0.0 0.0 04:45 08:30 tubing head adapter was a very snug fit onto the tubing hanger seal neck. Used two bolts to pull the adapter down over the hanger seal neck. SimOps: Continue to RD the fluid ends on the mud pumps. Continue to clean the pits. 11/24/2017 11/24/2017 0.50 COMPZN WHDBOP PRTS P PT the tubing hanger void to 250/5000 0.0 0.0 08:30 09:00 psi for 10 minutes each(good test). 11/24/2017 11/24/2017 1.00 COMPZN WHDBOP NUND P NU the tree. 0.0 0.0 09:00 10:00 11/24/2017 11/24/2017 0.50 COMPZN WHDBOP MPSP P Pull the BPV and install the tree test 0.0 0.0 10:00 10:30 plug with the dry rod. 11/24/2017 11/24/2017 0.50 COMPZN WHDBOP RURD P Fill the tree with diesel and RU 0.0 0.0 10:30 11:00 pressure testing equipment. 11/24/2017 11/24/2017 1.00 COMPZN WHDBOP DHEQ P PT the tree to 250/5000 psi(good test 0.0 0.0 11:00 12:00 no visual leaks). 11/24/2017 11/24/2017 0.25 COMPZN WHDBOP MPSP P Pull the tree test plug with the dry rod. 0.0 0.0 12:00 12:15 11/24/2017 11/24/2017 0.50 COMPZN RPCOMP RURD P RU circulating equipment from the tree 0.0 0.0 12:15 12:45 to the kill tank. Blow air through the lines to ensure they are clear. RU lines to u-tube. 11/24/2017 11/24/2017 0.25 COMPZN RPCOMP SFTY P PJSM with rig crew and Little Red 0.0 0.0 12:45 13:00 Services(LRS). 11/24/2017 11/24/2017 1.50 COMPZN RPCOMP FRZP P PT lines to 2000 psi with LRS. 0.0 0.0 13:00 14:30 Reverse circulate 73 bbls of diesel down the IA taking returns out the tubing to the kill tank at 1.5 BPM(ICP =200 psi&FCP=650 psi). Bleed back 2 bbls and RD LRS. 11/24/2017 11/24/2017 1.00 COMPZN RPCOMP FRZP P Place the tubing and IA in 0.0 0.0 14:30 15:30 communication allowing the well to u- tube and equalize at 310 psi on the tubing/IA. m : blow clal toSitheOpskill tanoks. RDdown circulircuatingting lines.ines 11/24/2017 11/24/2017 1.00 COMPZN WHDBOP MPSP P RU the lubricator,install the 4"ISA 0.0 0.0 15:30 16:30 BPV and RD the lubricator. Install gauges on the tree and wellhead. 11/24/2017 11/24/2017 1.50 DEMOB MOVE RURD P Secure the wellhead and tree. Clean 0.0 0.0 16:30 18:00 and clear the cellar. Final well pressures: Tubing=310 psi, IA=310 psi and OA= 150 psi. *Release the rig at 18:00 hours.* Page 33/33 Report Printed: 11/28/2017 KUP FOD 1D-12 CQit(Kfl11lICJS Well Attributes Max Angle TD cel<15k,.11)1,; Wellbore API/UWI Field Herne Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CaracaYhriro, 500292294800 KUPARUK RIVER UNIT PROD 50.86. 6,650 07 9,250.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date DEVIATED-10-12 12/19/20179.18:08 AM SSSV:NIPPLE 50 11/23/2015 Last WO: 10/27/2017 104.30 9/20/1999 Vertical sd,amatic(acWah Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;29.7 Last Tag:SLM 9,078.0 2/23/2016 Rev Reason:PULL&REPLACE TUBING jennalt 12/18/2017 • Ca Is ng Strmgs .t EI Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread t I LI.- CONDUCTOR 16 15.062 35.0 121.0 121.0 62.58 H-40 WELDED CasingDescription OD in ID in To ftKB Set ( ) ( ) (ftKB) Depth(ftKB) Set Depth(ND)...W1/Len(I...Grade Top Thread 111D) ' SURFACE 9 5/8 8.835 34.6 5,640.9 4,327.5 40.00 L-80 BTC < m.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR;35.0- 121. 0 PRODUCTION 7 6.276 30.9 8,695.5 6,323.0 26.00 L-80 BTC-MOD Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread 11 WINDOW L2 4 2.992 9,100.0 9,110.0 6,595.7 9.30 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread GAS LIFT;2.877.8 , WINDOW L1 4 2.992 9,135.0 9,145.0 6,619.0 9.30 1.1111 1 , Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 1 1 LINER 31/2 2.992 8,542.0 9,248.3 6,687.2 9.30 L-80 EUE8RDMO GAS LIFT;4,395.4 D Liner Details • Nominal ID p Top(ftKB) Top(ND)(ftKB) Top Ino)(°I Item Des Com (in) 8,542.0 6,223.2 50.35 HANGER BAKER SLZXP LT PACKER&HANGER w/PBR 3.500 SURFACE;34.8-5,540 9-4 - 8,559.0 6,234.1 50.29 SBE SEAL BORE EXTENSION 2.992 GAS LIFT;5,674.2 _iii 11 Tubing Strings Tubing Description I String Ma...ID(in) Top(ftKB) Set Depth(ft..f Set Depth(ND))...Wt(Ib/ft) Grade Top Connection RWO 2017 Tubing Ilf 41/2 3.958 297 8.4014 6,1330 12.60 L-80 TXPM GAS LIFT;8,667.6Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inti(°) Item Des Corn (in) GAS LIFT;7,4565 29.7 29.7 0.00 HANGER Tubing Hanger,FMC TC-1A-EN,6"x 4-1/2"EUE 8rd 3.958 top/bottom with 4"IS-A BPVG 8,071.2 5,913.2 47.48 LOCATOR Locater sub,Baker,GBH-22(bottom of the locator 3.990 spaced out 3') GAS LIFT;8,008.7 SW 8,072.3 5,913.9 47.48 Seal Assy Seal Assembly,Baker,192-47(total seal assembly= 3.870 iigg 17.00) It 8,074.8 5,915.6 47.49 PBR -PBR,Baker,80-47 4.750 LOCATOR;8,071.2 Seal Assy;8972.3 I 8,094.7 5,929.1 47.53 PACKER Packer,Baker,598-387 Premier 3.890 PBR;8,074.8RIM 8,119.0 5,945.5 47.57 NIPPLE Nipple,Camco 3.81"DB Profile,SN:3654-1 3.813 PACKER;8,094.7 8,388.6 6,124.7 49.35 LOCATOR Locater sub,Baker,GBH-22(bottom of the locator 3.000 ID spaced out 3') Air NIPPLE;8,118.0 - 8,389.6 6,125.4 49.36 Seal Assy Seal Assembly,Baker,80-40(total seal assembly= 3.000 ali 11.77) it Tubing Description String Ma...ID lin) Top(ftKB) Set Depth(k..set Depth(TVD)(...Wt 11198) Grade Top Connection .. Stacker Packer RWO 3 1/2 2.9921 8,391.9 8,522.5 6,210.81 9.301 L-80 EUE 8rd Mod APERF;8,136.0-8,1380 : 2017ial Completion Details LOCATOR,8,388.8 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 5861 Assy;8,369.6 PBR;8,391.9 - 8,391.9 6,126.9 49.39 PBR PBR,Baker,80-40,20' 4.000 PACKER,8,405.3 r- 8,405.3 6,135.6 49.57 PACKER Packer,Baker,47B2 FHL(shear release=60K) 2.910 P 8,463.7 6,173.2 50.11 NIPPLE Nipple,Halliburton,2.813"X profile,SN: C3147849 2.813 8,516.2 6,206.8 50.32 Poor Boy Poor Boy Overshot,Baker(swallow=6'and spaced out 3.750 NIPPLE;8,463 7irk Overshot 1')(from 2003 RWO) Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(IbM) Grade Top Connection It Tubing Original !String 31./.212.9921 8,517.5 8,572 .51 6242/11 .71 9.301E-80 Completion Details Tubing Stub;8,517.5 Nominal ID Poor Boy Overshot;8,518.2 Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Corn (in) 8,537.8 6,220.5 50.36 NIPPLE CAMCO'D'NIPPLE NO GO PROFILE,MILLED TO 2.80" 2.800 (1.i frIINIPPLE;8,537.8 ` 8,545.0 6,225.1 50.34 LOCATOR BAKER LOCATOR 3.000 ■',.a fr 8,546.4 6,226.0 50.33 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.992 LOCATOR;8,545.0 2 i; Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SEAL ASSY;8,546.4 U'- Top(ND) Top Incl Top(ftKB) (ftKB) r) Des Corn Run Date ID(in) 8,517.5 6,207.6 50.32 Tubing Stub Original chemical cut was milled off from 8512'to 11/19/2003 2.990 i 8517.5'MD during 2017 RWO 9,043.0 6,551.1 48.53 STRADDLE 35"KB"STRADDLE ASSEMBLY SET w/NEW 7/10/2008 1.830 ASSY LATERALS 3"GS FN-15k Shear release PRODUCTION;30.98,895.5 1 Perforations&Slots APERF;9,001.0-9,031.0 1 Shot Dens Top(ND) Bim(ND) (shots) Top(ftB) Btm8(73B8).0 (ftKB) (ftKB) Zone Date k) Type Com RPERF;8.051.0-9,065.1 8,136.0 8,138.0 5,956.9 5,958.3 6/15/2008 6.0 APERF 2"HYPERJET 6SPF STRADDLEASSV;9,043.0 HSD.Shot 1000'off APERF;8,084.0-9,0 .0 - depth. 9,001.0 9,031.0 6,523.5 6,543.2 UNIT D,C-4, 4/2/2004 6.0 APERF 1D-12 9,051.0 9,065.1 6,556.4 6,565.8 C-4,1D-12 4/2/2004 6.0 RPERF COVERED BY 2 3/8" WINDOW U;9,100.0-9,110.0 STRADDLE ASSEMBLY w/SIDETRACK I LINER L1;9,133.8-10,695.0 I 9,064.0 9,089.0 6,565.0 6,581.7 C-4,C-3,1D- 11/8/1999 4.0 APERF COVERED BY 2 3/8" 12 STRADDLE ASSEMBLY APERF;9,136.08,1380 It wISIDETRACK SOZ;9,138.0 fIK6 WINDOW L7;9,135.0-9,145.0 ` 9,136.0 9,138.0 6.613.0 6,614.3 C-1,1D-12 6/17/2008 6.0 APERF Pre-CTD squeeze penis (PERF;9,171.0-9,181.0 _ 9,171 0 9,181.0 6,636.2 6,642.8 C-1,1D-12 11/5/1999 4.0 IPERF 2.5"HC,DP,180 deg-F1- 90 deg low side LINER;8,542.69.248.3 KUP OD • 1D-12 Con �Phillips � . CoriocoPhillips DEVIATED-1D-12,72119/2017 9:18:09 AM Vereral.O4iO0144{actual) :.: RANGER,29.7 :.:Iit.'; Mandrel Inserts if 5 st ati °^ Top(TVD) Valve Latch Port Size TRO Run N Top(TtKB) (01KB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com ... 1 2,677.9 2,399.8Camco KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/23/2017 CONDUCTOR;35.0-121.0 II 2 4,395.4 3,517.8 Camco KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/29/2017 3 5,6742 4,349.4 Camco KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/23/2017 GAS LIFT;2677.9 laip 4 6,667.6 4,990.6 Camco KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/23/2017 Mr MIN GAS LIFT,4,395.4 ., , 5 7,458.9 5,504.2 Camco KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/23/2017 6 8,008.7 5,871.0 Camco KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/23/2017 Notes:General&Safety SURFACE;34.6-5,640.9 End Date Annotation 7/20/2008 NOTE: L1 DRILLED 7/11/2008,L2 DRILLED 7/20/2008 GAS LIFT;5,674 2 GAS LIFT,6,667.6 l18 I GAS LIFT;7,458.9 GAS LIFT;8,008.7 It lit LOCATOR',8,071.2 Mit Seal Assy;8,072.3 PBR,8,074.8 h PACKER;8,094.7 NS NIPPLE;8119.0 1-1 APERF;8,136.0-8,138.0 ti MS LOCATOR,8,388.6 Seal Assy;8,389 6, .-. PBR;8,391.9 t • t allai PACKER;8,405.3 411 Mk a NIPPLE;8,463.7 RE AK Tubing Stub,8,517.5 Poor Boy Overshot;8,516.2 a NIPPLE;8,537.8 :-I ., LOCATOR, LOCATOR,8,545.0 'f i SEAL ASSY,8,546.4 a a PRODUCTION;30.9-8,695.5 - APERF;9,001.0-9,031.0 RPERF,9,051.0-9,065.1 STRADDLE ASSY,9,043.0-, APERF,9,064.0-9,089.0 WINDOW L2;9,100.0-9,1100 I• LINER L1,9,133.8-10,695.0 APERF;9,136.09,138.0` SO2,9,136.0 RKB • 5' WINDOW L1;9135.0-9,145.0 L IPERF;9171.0-9,181 0 LINER;8,542.0-9,248.3 �- • v t � 7co >o X >? Z r'¢ CC W w _C a, o t_ + , { N oU 0N 0 W ato . 1OA a"' M A O � _ • 0 QO C O vQ 0V 'a' > i s_QV aco c C S co*a cit ou E Q 0- m p Q r- n N. 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U , 000700D0 ( ac O N v v v v CO N 0 0 X in ca �■ E W CO 0 o O o 0 0 0 0 0 y W N w # o o O o o O o o @ w /- 1 r � 4 to d) co 0o co co co o o > w 0 0 0 0 0 0 0 0 Q c W x ^. C) I o U E co O C. 0 0 0 0 0 0U co tn O o 0 0 0 o 0 0 c Q 4 4 to 4 00 N C 4 N 00 00 M Co '1 N 0 0 m toN CO u) O) M a) a) I I I = =1 a N N N N N N 0 N N I I I I I I I I -L- 1-:::. rpp: N CO N N N 0 N N C O CL Q) 0 0 0 0 0 — O O R U O W In N N in in N � t� ar 4' 00 O CO H ( v C 0 v an E W Y E O yr — '4 E E v c( Q Q Q 'a co co 'C ~ d N •-i Q r 7 N N to to C i i y E Z +. 00 m Z o e- M r� Csi .4 E a) a a, 1~a a Q to ^ -, 2 ± a _' p _ (p to -, � O N w . - M o o z a) 6 0 O CO a Q E 3 co � - o 0 H a a r- r • PTD l l-o Loepp, Victoria T (DOA) From: Heskin, Sara E <Sara.E.Heskin@conocophillips.com> Sent: Saturday, November 18, 2017 7:28 PM To: Loepp,Victoria T(DOA) Subject: RE:ConocoPhillips RWO 1D-12 Operations Update(PTD#199-084) Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, I wanted to send a clarification on my inform from yesterday.We will be repairing 1D-12 within the scope of the original sundry.As a result, no action is necessary from your end and we are continuing to move forward with workover operations. Happy Thanksgiving! Sa ra.}f e4law Associate Wells Engineer North Slope Workover Engineering ConocoPhillips Alaska Office: 907-265-1027 sara.heskin@conocophillips.com SCANNED From: Heskin,Sara E Sent: Friday, November 17,2017 7:20 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Brian R Buck(Brian.R.Buck@conocophillips.com)<Brian.R.Buck@conocophillips.com>; Phillips, Ron L <Ron.L.Phillips@conocophillips.com>; Doyon 14 Company Man<doyon14cm@conocophillips.com> Subject:ConocoPhillips RWO 1D-12 Operations Update (PTD#199-084) Hi Victoria, I wanted to send an update on the preset workover operations for well 1D-12(PTD#199-084).The scope of the workover is to pull the entire completion down to an existing liner top packer and re-complete with a new stacked packer to isolate off-depth perforations shot in 2008.The original scope involved engaging a seal assembly into the existing seal bore in the liner top packer at 5,540' MD.We have removed the completion down to the tubing stub and seal assembly at 8,501' MD(remaining from a 2003 workover where the tubing was cut).After multiple attempts to remove the tubing stub and seals we have been unsuccessful.As a result we have decided to forgo retrieving the tubing stub and instead install a straddle packer assembly around the off-depth perforations at^'8,136' MD. Please see the attached updated completion schematic. Please contact myself or Ron Phillips(265-6312)with any questions. Sincerely, 1 • • Associate Wells Engineer North Slope Workover Engineering ConocoPhillips Alaska Office:907-265-1027 sara.heskina,conocophillips.com 2 IV 0 • ConocoPhillips 1 D-12 KRU Producer REVISED Well Details: PROPOSED API: 50-029-22948-00 COMPLETION PTD: 199-084 Wellhead: FMC Gen IV 5M Casing/Tubing Details: 16"62.5# H-40 Conductor to 121' KB 9-5/8"40# L-80 Surface to 5,641' KB — _ 7"26# L-80 Production to 8,696' KB 4-1/2" 12.6#L-80 Tubing to 8,000' KB 3-1/2" 9.3# L-80 Tbg -8,000'-8,540' KB — Camco 4-1/2" x 1" KBG-2 GLM's Misc Details: Ili Max Inclination: 51° Max Dogleg: 5.6°/100' Last Tagged Fill: 9,078' KB Total Depth: 9,248' KB Perforation Details: 9,001'-9,031' KB-C4 Sand "��4J� 9,051'-9,065' KB-C4 Sand ` 9,064'-9,089' KB–C4 Sand -. 4.5" Baker Premier Packer and PBR 9,171'-9,181 KB-C1 Sand 1;::14 4.5" x 3.31" DB Nipple w/RHC Plug Installed Off Depth Perforations jjI 4.5" x 3.5" Tubing XO 8,136'-8,138' KB , In " 3.5" Baker FHL Packer and PBR 3.5" x 2.813" X Nipple w/RHC Plug Installed Poor Boy Overshot -a ,L, Existing Baker 80-40 Seal Assembly & SBE, s' `J IL Camco D Nipple Milled to 2.80" ID, SLZXP Liner Top Packer C-Sand Perfs CTD Whipstock (Set via E-Line) KB Packer Assy 8 N Existing CTD Laterals Date: November 17,2017 I Updated By: Sara Heskin S Loepp, Victoria T (DOA) From: Heskin, Sara E <Sara.E.Heskin@conocophillips.com> Sent Friday, November 17, 2017 7:20 PM To: Loepp,Victoria T(DOA) Cc: Buck, Brian R; Phillips, Ron L; Doyon 14 Company Man Subject: ConocoPhillips RWO 1D-12 Operations Update (PTD# 199-084) Attachments: REVISED 1D-12_PropComp_Schematic.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, I wanted to send an update on the preset workover operations for well 1D-12 (PTD#199-084).The scope of the workover is to pull the entire completion down to an existing liner top packer and re-complete with a new stacked packer to isolate off-depth perforations shot in 2008.The original scope involved engaging a seal assembly into the existing seal bore in the liner top packer at 5,540' MD.We have removed the completion down to the tubing stub and seal assembly at 8,501' MD(remaining from a 2003 workover where the tubing was cut).After multiple attempts to remove the tubing stub and seals we have been unsuccessful.As a result we have decided to forgo retrieving the tubing stub and instead install a straddle packer assembly around the off-depth perforations at—8,136' MD. Please see the attached updated completion schematic. Please contact myself or Ron Phillips(265-6312)with any questions. Sincerely, Sara.}f elk- 'ij Associate Wells Engineer North Slope Workover Engineering ConocoPhillips Alaska Office: 907-265-1027 sara.heskin(a conocophiIIips.com 1 • PTD 119 -z,R • Loepp. Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Thursday, October 26, 2017 10:37 AM To: Loepp,Victoria T(DOA) Cc: Regg,James B (DOA) Subject: RE: [EXTERNAL]RE: KRU 1D-12(PTD 199-084, Sundry 317-384) BOP Configuration Question Follow Up Flag: Follow up Flag Status: Flagged Understood.Thanks for the quick response. Thanks, Andrew 303-378-8881 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday,October 26, 2017 10:29 AM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com> Cc: Regg,James B(DOA)<jim.regg@alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 1D-12(PTD 199-084,Sundry 317-384) BOP Configuration Question Andrew, Please plan on utilizing the 2-3/8" solid body rams. Thanx, SCANNED .` Victoria From: Beat,Andrew T[mailto:Andrew.T.Beat@conocophillips.com] Sent:Thursday,October 26, 2017 10:24 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Regg,James B(DOA)<jim.regg@alaska.gov>;CPA Wells Supt<n1030@conocophillips.com>; Buck, Brian R <Brian.R.Buck@conocophillips.com>; Doyon 14 Company Man<dovon14cm@conocophillips.com> Subject:RE: [EXTERNAL]RE: KRU 1D-12(PTD 199-084,Sundry 317-384) BOP Configuration Question Victoria, Thank you for the review and approval. We were able to source a string of 2-3/8"tubing that we plan to use instead of the 2-1/16" as originally premised. Doyon does have a solid body ram for 2-3/8"and we plan on changing out our lower VBR for the 2-3/8"solid body.. We can eliminate this step and maintain two sets of VBR's for the primary tubulars for the RWO if we can apply your approval to the 2-3/8" pipe as well. Can we utilize the annular along with a crossover on the floor in lieu of the 2-3/8" solid body rams on 1D-12? 1 411 Weplan to swaprams sometime overnight.We will continue with that plan if whave not received approval before then. Thank you, Andrew 303-378-8881 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday,October 26, 2017 10:10 AM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com> Cc: Regg,James B(DOA)<jim.regg@alaska.gov> Subject: [EXTERNALJRE: KRU 1D-12(PTD 199-084,Sundry 317-384) BOP Configuration Question Andrew, Your proposal meets the intent of 20 MC 25.285(c)(4)and is approved as outlined in your note below. Please include this approval with the approved Sundry application. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W. 7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From:Beat,Andrew T[mailto:Andrew.T.Beat@conocophillips.comj Sent: Monday,October 23,2017 3:53 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Regg,James B(DOA)<jim.regg@alaska.gov> Cc:Doyon 14 Company Man<dovonl4cm@conocophillips.com>;CPA Wells Supt<n1030@conocophillips.com>; Buck, Brian R<Brian.R.Buck@conocophillips.com> Subject: 1D-12 BOP Configuration Question Victoria/Jim, We would like to run about 500'of 2-1/16"tubing on the bottom of drill pipe for our cleanout run on 1D-12(next RWO on Doyon 14). Doyon does not have a set of rams that fit 2-1/16" pipe so can we plan on using the annular in combination with having a crossover joint on the rig floor in lieu of a dedicated set of rams? Let me know if you have any questions or want to discuss. I will be headed up to the slope tomorrow morning but can talk after arrival. Thank you, 2 • • Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303) 378-8881 cell (907)265-6341 office 3 • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday,October 24, 2017 1:44 PM To: 'Beat,Andrew T' Cc: Regg,James B(DOA) Subject: RE: 1D-12 (PTD 199-084, Sundry 317-384)) MPSP Change Andrew, Thanx for the notification and update. Include a copy of this change approval with the approved Sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loerpt alaska.Qov From: Beat,Andrew T[mailto:Andrew.T.Beat@conocophillips.com] Sent: Monday,October 23, 2017 2:05 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Regg,James B(DOA)<jim.regg@alaska.gov>; Doyon 14 Company Man<doyon14cm@conocophillips.com> Subject: 1D-12(PTD 199-084) MPSP Change Victoria, We had a new pressure survey taken last week on 1D-12 ahead of the upcoming workover.The pressure increased slightly and gives us a new MPSP of 2,736 psi.We will continue with the approved BOP test pressure of 3,000 psi but the value entered on the notification from the rig will not match the Sundry submitted last month. Below are the details of the new pressure survey. SBHP Survey&Date =3,233 psi(10/18/2017) Datum Depth =6,164'TVD Formation Pressure(w/8.4 ppg below gauge) =3,388 psi(6,523'ND at Top Perf) Gas Gradient(as per 20 AAC 25.005(c)(4)(A)) =0.1 psi/ft Gas Column Hydrostatic =652 psi MPWHP=Form.Press.-Gas Col. Hydrostatic =2,736 psi Let me know if you have any questions. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska 1 • • ti OF 7,4 � THE STATE Alaska Oil and Gas p fA JS Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 `T Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Andrew Beat Sr. Wells Engineer S%MINED NOV 2 1 Z017, ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1D-12 Permit to Drill Number: 199-084 Sundry Number: 317-384 Dear Mr. Beat: 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, Hollis S. French Chair DATED this ((day of September, 2017. RBDMS `./. SEP 1 5 2017 STATE OF ALASKA A U(; 0 8 ?017 ALASKA OIL AND GAS CONSERVATION COMMISSION j /d APPLICATION FOR SUNDRY APPROVALS ACG( k T 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations Li Fracture Stimulate ❑ Repair Well ❑, , Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate El Pull Tubing ID, Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: ❑ 2.Operator Name: 4.Current Well Class: f; 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development II 199-084 ' 3.Address: Stratigraphic ❑ Service 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-22948-00 • 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 1D-12 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025650 • Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY • Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9250' , 6688' , 9248' , 6687' , 2700 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 86' 16" 121' 121' Surface 5602' 9.625" 5639' 4326' Intermediate Production 8662' 7" 8693' • 6321' Liner 689' 3.5" 9247' 6686' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9001'-9031' 6523'-6543' 4.5"x 3.5" L-80 8542 9064'-9089' 6565'-6582' 9136'-9138' 6613'-6614' 9171'-9181' , 6636'-6643' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV: CAMCO DB LANDING NIPPLE 4 MD=500 TVD=499 PACKER-BAKER RETRIEVABLE PACKER • MD=8467 TVD=6175 PACKER-BAKER SLZXP LT PACKER MD=8542 TVD=6223 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Ltb Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development[la Service L 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/1/2017 OIL ❑., WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Andrew Beat Contact Name: Andrew Beat Authorized Title: Sr.AWell gineer Contact Email: Andrew.T.Beat@conocophillips.com ® Contact Phone: 265-6341 Authorized Signature: Date: bit7-/Z0/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 5 o 1-,.5t to 3000 I7 I-r$5Virc A4-6 3J DC7r15I, f}-o vcUG a r p f—C tf- `, C >n firs-I-- Post Initial Injection MIT Req'd? Yes 0 No Er. j Spacing Exception Required? Yes ❑ No ' Subsequent Form Required: D C)-- 4 0 r APPROVED BY 114 I( Approved by: COMMISSIONER THE COMMISSION Date: ?fr b 8iii fil- V7- a// // O irei ASubmn Form ane Form to-4o3 vis ai2ot� a I n valid for 12 months from the date of approval. attachments in Duplicate �C VrRBDMS i, - SEP 1 5 2017 • • ConocoPh i l l i ps RECEIVED Alaska AUG 0 8 z17 P.O. BOX 100360 0 ANCHORAGE,ALASKA 99510-0360 7 August 2017 AOGOC Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7t Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits a n Application for Sundry Approval to work over Kuparuk Producer 1D-12(PTD# 199-084). 1D-12 was drilled and completed in 1999 as a C-sand producer. In 2003 a workover was performed to upsize the tubing.In 2008 the well was identified as a CTD candidate.During pre-CTD well operations,an attempt to shoot pre-cement squeeze holes was fired off depth creating holes in the tubing and production cas�n¢above lx prod_,uction packer. The holes in the production casing were opposite the HRZ formation and within the cemented portion of the casing.A inflow test was performed with diesel and no flow was observed.CTD completed drilling two laterals and the tubing was patched post-rig. The well was brought back online after passing a tubing test. 1D-12 was shut-in in 2015 for rock production. While investigating a potential tubing leak,rocks were discovered in the tubing. Multiple attempts have been made to set various sized screens to control rock production with no success. In 2017 the latest screen became stuck while attempting to retrieve.Non-rig efforts have been exhausted and the well has moved to a workover.New CTD laterals will be drilled post-RWO to alleviate the rock production issues. The planned workover scope includes pulling the entire completion down to the liner top packer and then re- completing with a new stacked packer to isolate the off-depth perforations shot in 2008. 1 If you have any questions or require any further information,please contact me at 265-6341. Sinc- ely, Andrew I-.t Senior Wells Engineer CPAI Drilling and Wells 1D-12 Rig Workover CTD Setup (PTD#: 199-084) Current Status: Shut-in Scope of Work: Pull the existing completion down to liner top packer. Install new stacked packer completion. General Well info: Well Type: Producer MPSP: 2,700 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 3,352 psi/6,523' TVD(9.9 ppg EMW)measured on 02/23/2016 Wellhead type/pressure rating: FMC Gen IV, 5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-T PASSED— 10/22/2015 Earliest Estimated Start Date: October 1,2017 Production Engineer: Dana Glessner Workover Engineer: Andrew Beat(263-6341/Andrew.T.Beat@ConocoPhillips.com) Pre-Rig Work 1. Inspect pad and work area for hazards. Complete the PJSM. 2. PT POs and FT LDS. Workover Procedure 1. MIRU. 2. Circulate KWF throughout well. Obtain SITP&SICP,if pressure is seen at surface,calculate new KWF, weight up,and repeat circulation as necessary.Verify well is dead. 3. Set BPV,ND tree,NU BOPE and test to 250/3,000 psi. a. If the lower pipe rams are unable to be tested because of the blanking plug position,the lower pipe rams will be tested upon pulling the completion. 4. Pull BPV,screw in landing joint,BOLDS's,unland tubing hanger. 5. POOH laying down 4-1/2"tubing from PBR. 6. MU and RIH with 3-1/2"spear. Spear the PBR and jar the packer free.POOH with packer and tubing tail. 7. MU overshot and RIH.Engage tubing stub and jar free from seals.POOH with tubing stub. 8. MU cleanout assembly and cleanout to top of KB Packer Straddle assembly. 9. RIH with new 4-1/2" stacked packer completion. Space packer out to set above off-depth perforations.Pressure up to set packer.Pressure up on IA to 1,000 psi to confirm packer set. 10. Shear out of PBR. Space out and MU tubing hanger.Circulate corrosion inhibited fluid in the IA from the PBR to surface. Land the tubing hanger,RILDS. 11. PT the tubing. Hold pressure on tubing and pressure test IA and chart.Bleed tubing pressure quickly to shear the SOV. 12. Pull the landing joint,install BPV. 13. ND BOPE. 14. NU tree.Pull BPV and install tree test plug.Test tree and pull test plug. 15. Freeze protect well with diesel. 16. RDMO. Post-Rig Work 1. RU Slickline to pull SOV.Run gas lift design. 2. Reset well house(s)and flowlines of adjacent wells. 3. Turn well over to operations. 1 • - - - • ConocoPhillips 1 D-1 2 KRU Producer PROPOSED Well Details: COMPLETION API: 50-029-22948-00 PTD: 199-084 ` Wellhead: FMC Gen IV 5M \` Casing/Tubing Details: 16" 62.5# H-40 Conductor to 121' KB 9-5/8"40# L-80 Surface to 5,641' KB 7"26# L-80 Production to 8,696' KB 4-1/2" 12.6# L-80 Tubing to 8,446' KB 3-1/2" 9.3#L-80 Tbg 8,446'—8,540' KB — Camco 3-W x 1-1/2" MMG GLM's Misc Details: Max Inclination: 51° Max Dogleg: 5.6°/100' Last Tagged Fill: 9,078' KB Total Depth: 9,248' KB Perforation Details: Y 9,001'-9,031' KB—C4 Sand 9,051'-9,065' KB—C4 Sand 9,064'-9,089' KB—C4 Sand 9,171'-9,181' KB—Cl Sand ,2 4 Baker Retrievable Packer and PBR Off Depth Perforations 8,136'-8,138' KB 2.81" D Nipple Existing SLZXP Liner Top Packer and SBE Gpit � C-Sand Perfs erc KB Packer Assy t N Existing CTD Laterals Date: July 18,2017 I Drawn By: Andrew Beat XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Mildred D'aretha ~owell Date: ~;;2-/Y /si /~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: /si i Nov ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 Commissioner Dan Seamount NOV 2fl11 Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 Ala4ko Oil & Gas Cons. Commission Anchorage, AK 99501 r`;:w!'+ic14 6111- OW Commissioner Dan Seamountt 1 9 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 9/11 and, 9/12, 2011. The corrosion inhibitor /sealant was pumped 10/15, 10/16, 10/17 and, 10/18, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, *':.;' 1! C E` 1 3 2 0 f Martin Walters ConocoPhillips Well Integrity Projects Supervisor . • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/26/11 1A,1B,1C,1D, 1E & 1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement _ pumped cement date inhibitor sealant date _ ft bbls ft gal 1A -22 50029221270000 1910030 SF N/A 18" N/A 2.55 10/18/2011 WSW -01 50029205370000 1801400 20" N/A 20" N/A 2.5 10/16/2011 WSW -02 50029208120000 1821370 2'10" N/A 2'10" N/A 6 10/16/2011 WSW -03 _ 50029208170000 1821420 _ 12" 1.00 20" 09/11/2011 4.25 10/16/2011 WSW -07 50029208610000 1821880 SF N/A 19" N/A _ 1 10/17/2011 _ 1C -170 50029231540000 2030780 19'3" 1.20 10" 09/11/2011 18.74 10/15/2011 1C -174 _ 50029231400000 2030270 7' 1.00 8" 09/11/2011 14.8 10/15/2011 1C-190 50029231360000 2030030 9'4" 1.50 8" 09/11/2011 _ 15.2 10/16/2011 1 D -08 50029220266000 1770530 52" 1.20 6" 5/28/2011 _ 3.8 10/15/2011 too >. 1D-12 50029229480000 1990840 18" N/A 18" N/A 3.4 10/15/2011 1D -41 50029232880000 2051880 16" N/A 16" N/A 3.55 10/15/2011 1 D -123 50029229140000 1981700 11'5" 230 5" 09/12/2011 4.4 10/15/2011 1E-11 E -11 50029207870000 1820510 22" N/A 15" N/A _ 1.2 10/17/2011 1Y -09 50029209350000 1830520 7' 2.00 5" , 09/12/2011 _ 1.7 10/18/2011 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 29, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 1D -12 \iq_ Oc6A c-5:7 Run Date: 6/12/2011 I 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 1D -12 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 22948 -00 Production Profile Log 1 Color Log 50- 029 - 22948 -00 4py PONES) SEF 0 (i ZD ic PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: ,4UC. ) 2-011 Signed: LLB i • ~ '~ . ~.~.x. ;; STATE OF ALASKA ,;;~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~`~ ~' ! '~` t~ `~~"~ REPORT OF SUNDRY WELL OPERATIO~~.~ t. ° ~ .. 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ ~ Stimulate ^ Other` ^' , Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ~ ` Exploratory ^ 199-084 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22948-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 104' 1 D-12 8. Property Designation: 10. Field/Pool(s): ADL 25650 ' Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9250' feet true vertical 6688' ~ feet Plugs (measured) Effective Depth measured 9205' feet Junk (measured) true vertical 6659' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 5537' 9-5/8" 5641' 4328' PRODUCTION 8592' 7" 8696' 6323' LINER 706' 3-1/2" 9248' 6687' Perforation depth: Measured depth: 9001'-9031', 9051'-9089', 9136'-9138' (6/17/08), 917~~rC~~~~i ~4 ii ~ ~ ~QU~ Ut~ true vertical depth: 6523'-6543', 6556'-6582', 6636'-6643' Tubing (size, grade, and measured depth) 4.5" / 3.5", L-80, 8469' / 8568' MD. Packers & SSSV (type & measured depth) Baker FHL retr. Pkr @ 846T Camco'DB' Landing Nipple @ 500' 12. Stimulation or cement squeeze summary: Intervals treated (measured) squeeze (6/23 - 6/24/08) Treatment descriptions including volumes used and final pressure: 28 bbls + 15 bbl, final sqz. Pressure = 1000 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation not applicable Subsequent to operation not applicable - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 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: 308-204 Contact Gary Elle 263-4172 ,. Printed Name ~~ ary Elle Title Wells Engineer ` Signature Phone: 263-4172 ~~ Date Pre ared b Sharon All u -Drake 263-4612 Form 10-404 Revised 04/ f0~ ~ ~ ~ ~ ~ ~ ~ ~ L Submi~Or~~~3 ryly 1 D-12L1 & L2 CTD Sidetrack (7/24/08) 9-5/8" 40# L-80 shoe @ 5641' MD Perfs shot off depth through 3- 1/2" tubing and 7" casing, 8136' -8138' MD (6-15-08) Retrievable tubing patch 8128' - 8143' MD. Min ID = 2.25" (7/31/08) 7" 26# L-80 shoe @ 8696' MD Squeezed Perts 9001 - 9031' MD (C4) 9051 - 9089' MD (C4) 9136 - 9138' MD 9171 - 9181' MD (C1) Snap-latch assembly at 9107' MD 3-1 /2" KB Packer at 9110' MD 1.71" R-nipple at 9123' MD Muleshoe at 9128' MD IL1 KOP @ 9135' MD off of 3-1/2" monobore whipstock shoe @ 9248' MD 9043' - 9099' MD 4-1/2" Camco DB nipple @ 500' MD (3.813" min ID) 4-1/2" 12.6# L-80 IBT-Mod Tubing to surface 4-1/2" Camco KBG-2 gas lift mandrels @ 2963', 4727', 5525', 6651', 7654', 8356' MD 4-1/2" Camco DB landing nipple @ 8408' MD (3.75" min ID) 4-1/2" x 3-1/2" cross-over @ 8446' MD 3-1/2" Baker PBR @ 8453' MD 3-1/2" Baker FHL packer @ 8467' MD 3-1/2" Camco DS nipple @ 8491' MD (2.812" min ID) 1.81"' D' reducer nipple installed 7/29/08 Poor Boy Overshot @ 8502' MD 3-1/2" cut tubing @ 8502" (11/19/03) 3-1/2" Camco DS nipple @ 8538' MD (2.75" min ID) Baker 3-1/2" 80-40 seal assembly @ 8546' MD (3" ID) BAKER 7"x 3.5" SLZXP LT PACKER & Hanger w/PBR @ 8542' MD Baker SBE @ 8549' MD (1 L2KOP@9100'MD off of 3-112" snap-latch tray (removed) L2 Liner: 2-3/8", 4.6 #, L-80 ST-L liner 9108' - 10935' \\ solid liner: 9106' - 9129' L2 TD @ 10,955' MD slotted liner: 9129' - 10935' 3" borehole L1 PB1 9340' - 10,251' MD no liner L1 TD @ 10,695' MD L1 Liner: 2-3/8", 4.6 #, L-80 ST-L liner 9134' - 10695' 3" borehole solid liner: 9134' - 9271', 9334' - 9429', & 10219-10346' slotted liner: 9271' - 9334', 9429' - 10219', 10346' - 10662' • • • ~ 1 D-12, Well History Date Summary 3/23/07 PRE CTD - POT & PPPOT-T & IC PASSED, TIFL FAILED. MITOA PASS~ PT & DD ON MV & SV PASSED 3/28/07 PULLED OV AND SET NEW OV ~ 4727' RKB. PULLED GLV (SCALE ON CHECK) AND SET NEW GLV ~ 2963' RKB. 3/30/07 TIFL - PASSED 4/8/07 TAGGED ~ 9166' RKB, EST. 15' FILL. LOGGED CALIPER SURVEY FROM 9166' RKB TO SURFACE. 6/2/07 SET 2.81" C-LOCK W/ DHSIT W/ DUAL HALLIBURTON GAUGES C~ 8491' RKB, TOOL WILL CLOSE 6/7/07 Q 10:00, OPEN 6/12/07 ~ 10:00, CLOSE 6/17/07 @ i0:00, OPEN 6/22/07 C~ 10:00 6/25/07 GAUGE TUBING TO 2.95" TO "DS" NIPPLE C~ 8491' RKB, EQUALIZE DHSITC«~ SAME W/26" LONG KOBE EQUALIZING PRONG, PULL 2.81" C-LOCK, DHSIT & DUAL HALLIBURTON GAUGES FROM "DS" NIPPLE C~ 8491' RKB, SET 2.81" C-LOCK, DHSIT & DUAL HALLIBURTON GAUGES ~ 8491' RKB "`*TOOL WILL CLOSE 1 JUL 07 C~ 0900, TOOL WILL OPEN 6 JUL 07 C«~ 0900, TOOL WILL CLOSE 11 JUL 07 C~3 0900, TOOL WILL OPEN 16 JUL 07 C~? 0900"""" 7/17/07 BAILED FILL OFF EST & GAUGES C~3 8491' RKB. ATTEMPTED PULL SAME, UNABLE TO LATCH DUE TO FORMATION SAND PACKED IN F/N. FLOW WELL OVER NIGHT TO CLEAN UP. 7/19/07 PULLED EST & GAUGES C~ 8491' RKB. 7/23/07 SET 2.81 C LOCK WITH EST AND DUAL GAUGES C~ 8491' RKB. TOOL CLOSES ~ 0900, 7/28/07, OPENS C~ 0900, 8-2-07, CLOSES C~ 0900, 8-7-07 AND OPENS C~ 0900, 8-12-07. 8/14/07 PULLED HES' EST & GAUGES C~ 8491' RKB. MODERATE EROSION ON PISTON CYLINDER & MOTOR HOUSING. 8/16/07 TIFL - PASSED, T-POT - PASSED , T-PPPOT - PASSED 8/24/07 SET 2.81 C-LOCK W/KOBE, DHSIT,SHOCK ABSORBER, DUAL HES GAUGES. C~ 8491'RKB. TOOL WILL CLOSE ON 8/29 C~ 14:10, OPEN 9/3, C~? 14:10, CLOSE 9/8 C~3 14:10, OPEN 9/13 C«? 14:10. TOOL CAN BE PULLED AFTER 2ND OPENING. ( EQUALIZING PRONG NEEDS TO BE 23"-26" NO LONGER.) "'"END JOB"'` 9/14/07 ATTEMPTED BAIL FILL OFF EST, NO SUCCESS. FLOWED WELL TO CLEAN UP. PULLED EST & GAUGES C~3 8491' RKB. COMPLETE. 10/8/07 C sand Scale Squeeze. Pumped 50 bbls SW ahead of treatment. Pumped 32 bbls of Seawater pre-flush containing 100 gallons of WAW-5206. Pumped 187 bbls of Seawater containing 1030 gallons of SCW- 4004. Pumped 420 bbls SW overdisplacement. 3/27/08 T& IC POT = PASSED. FUNCTION TEXT LDS = PASSED. TIFL, MITOA = PASSED. (PRE CTD) PT & DDONMV&SV. 3/28/08 MV-DD - PASSED, MV-PT - PASSED, SV-DD - PASSED, SV-PT - PASSED 6/10/08 GAUGED TUBING TO 2.84" TO 2.812"DS NIPPLE C~3 8491' RKB TAGGED FILL ~ 9057' SLM, SET SV C~3 8491' RKB, PULLED GLV C~ 2963' RKB, REPLAGED W/ 1"DV, PULLED OV C~ 4727' RKB, LEFT OPEN FOR CIRC OUT IN AM. 6/11/08 LOADED IAlfBG W/ DIESEL. PERFORMED COMBO MIT TO 2500 PSI- PASS. SET DV C~3 4727' RKB & MIT-T 2500 PSIG- PASS. PULLED CAT SV C~3 8491' RKB. PERFORMED 30 min SBHPS C~ 9059'=3012 PSI, 157 DEG F. 15 MIN GRADIENT STOP MADE C~ 8907'=2970 PSI. RE-TAGGED X2 ~ 9057' SLM, UNABLE TO GET DEEPER (NO SAMPLE) EVEN W/ PUMP ASSIST. ~~w~; `~~~ ~AUC~ ~ a' 2009 Page 1 of 2 • 1 D-12, Well History Date Summary ~ 6/13/08 RAN 2.41" LIB TACCED Co3 9067' SLM_~IMPRESSION OF FINE SANDI. RAN 2.5" PUMP BAILER TO 9105' SLM, SMOOTH REMAINDER OF THE WAY DOWN (OBTAINED SAMPLE OF FORMATION SAND). COMPLETE. 6/14/08 MU AND RIH WITH A 2.74" CRAYOLA MILL DOWN TO 9205' CTMD. WORKED AREA WHERE SLICKLINE TAGGED C~ 9057 & 9105' SLMD. HAD SEVERAL STALLS DURING MILLING OPERATION ~ 9105' AND 9170' CTMD. WELL READY FOR SLICKLINE TO DRIFT FOR E-LINE. 6/15/08 DRIFT TBG WITH 6.75' BAR BELL ASSY (MAX OD= 2.73") 70 9166' SLM. TAG FILL WITH BAILER C~ 9167' SLM. RECOVERED SAMPLE. READY FOR E-LINE. JOB COMPLETE. ~ 6/15/08 PERFORATED FROM $1,36'-8138' WITH 2' HYPERJET 6SPF HSD GUNS. INFORMED AFTER ~~ YJ" SHOOTING THAT THE INTENDED INTERVAL WAS 9136'-9138'. ~ 6/16/08 GAUGED TBG TO 2.84" TO 8491' RKB. NO OBSTRUCTIONS. SET 2.81" CAT STANDING VLV ~ 8491" RKB. eTTEMPT GMITIA TO 2500#. ESTABLISHED LINER L EAK OF -50# IN 15 MIN INCREMENTS, 6/17/08 PULLED 2.81" CAT STANDING VLV C~ 8491' RKB. JOB COMPLETE. 6/17/08 PERFORATE INTERVAL 9136'-9138' WITH 2" HYPERJET 6SPF 60-DEG PHASED HSD CHARGES. 6/17/08 SET 2.81" CA-2 BLANKING PLUG C~ 8491' RKB. CMlT. PASSED, SET 2.72" CATCHER, OAL=88" ON TOP OF PLUG. JOB COMPLETE. 6/18/08 CMIT T& IA - FAILED. TBC DD - PASSED Well Events - Post CTD Multilateral Drilling 7/25/08 ASSISTED APC PULL BPV. PULLED DVs ~ 2963, 6651, 7654' RKB. SET GLV C~ 6651', OV C~ 7654' RKB. NOTE: DROPPED 1" GLV WHILE ATTEMPTING TO SET IN STN # 2. 7/26/08 RAN 1-1/4" JD AND 1.75" CENT TO 9032' WLM; UNABLE TO PROGRESS FURTHER DUE TO DEVIATION. LOST GLV NOT RECOVERED. SET CATCHER SUB C~ 8408' RKB. SET GLV ~ 2963' RKB. ATTEMPTED PULL DV C~ 4727' RKB. 7/27/08 PULLED DV, SET GLV ~ 4727' RKB. PULLED CATCHER SUB; SAT DOWN C~ 7440' IN TBG, CONTINUED PULL CATCHER. RECOVERED LOST GLV AND CEMENT CHUNKS. BFiUSHED TBG FOR PATCH C~ 8050' TO 8200' WLM. DRIFTED WITH 15'x3.75" DUMMY TO 8469' RKB. TAGGED DS NIPPLE C~ 8491' RKB. 7/28/08 SET 2.813 DS x 1.81 D NIPPLE REDUGER C~ 8491' RKB, FUNCTION TEST: SET & PULLED 1.81 CA2 BLANKING PLUG. READY FOR E/L SET STRADDLE PATCH. 7/29/08 SET 4.5" WEATHERFORD PACKER MID-ELEMENT AT 8143', READY FOR S/L 7/31/08 SET 3.74" WEATHERFORD ER PATCH ASSY IN LOWER ER PKR (OAL=13.75',MIN ID=225").TOP OF UPPER PKR C«~ 8128' RKB.SET 1.81" CA-2 PLUG IN NIPPLE REDUCER C«3 8491' RKB.MITT FAILEQ 8/1/08 STATE WITNESSED ( JOHN CRISP ) MIT-T ( PASSED ) 8/1/08 MITT PASSED ""PLUG STILL IN HOLE FOR STATE WITNESSED MITT"" 8/2/08 PULLED 1.81" CA-2 PLUG FROM NIPPLE REDUCER C~ 8491' RKB.PERFORMED 30 MIN BHP 3090 psi C~ 9000' RKB COMPLETE. Page 2 of 2 ~ • 'BP AMERICA Page 1 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date' From - To Hours Task Code NPT Phase Description af Operations 6/21/2008 03:30 - 04:00 0.50 MOB P PRE RD and pre to move rig off 1 D-04 04:00 - 04:30 0.50 MOB P PRE Move off well and spot rig on pad waiting for well prep 04:30 - 09:30 5.00 MOB N WAIT PRE Rig on standby waiting on well 1 D-12 Prep 09:30 - 13:30 4.00 MOB N WAIT PRE Drilling Mouse Hole with ACS. Having the same problem with 13:30 - 15:30 2.00 MOB N WAIT PRE 15:30 - 18:30 3.00 MOB N WAIT PRE 18:30 - 19:30 I 1.001 MOB I P I I PRE 19:30 - 00:00 I 4.50I RIGU I P I I PRE 6/22/2008 I00:00 - 03:30 I 3.50I RIGU I P I I PRE 03:30 - 07:00 I 3.50I BOPSUp P I I PRE 07:00 - 09:45 I 2.75I BOPSUF# P I I PRE 09:45 - 10:50 I 1.08I BOPSUFI P I I PRE 10:50 - 11:00 0.17 BOPSU~ P PRE 11:00 - 14:00 3.00 BOPSU P PRE mousehole they did on 1 D-04 Nordic worked on BOP and changed out to 4-1/16 adaptor. Pulled accumulator bottle of rack. Pulsar damper change out and working on the suction pits. Schlumberger Change brushes on power pack and installed new pack offs. Stim 3 reel stand and greased injector and guide arch. Drilling Tool House shot grade and level Pad Install herculite and rig 40ft rig mats for rig to move on. Crew change. Hold PJSM to discuss moving rig over well. 1 D Pad operator on location. Move rig over well. Accept riq at 1930 hrs on 6/21/08. Rig up for CTD operations. Berm cellar. Berm rig. RU MPD loop. Spot and RU external tanks. NU BOPs. Move choke line in cellar for MPD loop clearance. Continue to rig up MPD and BOP equipment. Install 7" lubricator to rig floor. Load pits with 1# biozan. Pressure test BOP epuipment as per Permit to Drill #207-153 and AOGCC Regulations. PT to 250/3500 psi Test witness waived by J Crisp with AOGCC. Complete test results e-mailed to AOGCC by R. Holmes. RU the MPD Loop. Install 1 valve and plugs on SSV outer flange Installed SSV rupture disc on top side of SSV Re-oriented the MPD check valve. PT the MPL. Installed the ESD system on the rig. NOTE: ESD on Drillerside is 1 D-14 (water Injection) and off driller side ESD is 1 D-01 (Producer). PT floor valves and tiger tank line to 1000 psi. PJSM on pulling BPV RU lubricator and ~ull BPV WHP at 300 psi. Closed MV and No recovery, RIH and to retrieve BPV PT lubricator to 1000 psi and RIH worked on retrieving BPV. POOH, no plug, Get new retrieving tool Pulled plua on 3rd trv. 14:00 - 14:15 0.25 BOPSU P PRE PJSM on cir IA to 2% KCL 14:15 - 14:30 0.25 BOPSU P PRE Line out to cir IA. PT the line to squeeze manifold to 2000 psi. Open well to tiger tank 14:30 - 16:45 2.25 BOPSU P PRE Circulating out IA at 3.00 / 3.00 bpm at 600 psi with 2% KCI. Density = 6.92ppg out. Taking returns to tiger tank. Circulated 85 bbl to TT and recovered in Vac truck. Sent to recycle Circulated the remainder 250 of fluid to TT. Pumped 65 bbls of 2% KCL with 1 ppb bio down tubing. SD and monitor well. 16:45 - 17:15 0.50 BOPSU P PRE Shut in IA and blow down surface line. Install IA transducer 17:15 - 17:30 0.25 PULL P DECOMP PJSM on RU Halliburton Wireline Printed: 8/27/2008 3:25:29 PM i • $P AMERICA Page 2 Qf 31 Qperations Sumrnary Repart Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/22/2008 17:30 - 18:30 1.00 PULL P DECOMP RU Halliburton Wireline w/ pressure control on rig floor. 18:30 - 00:00 5.50 PULL P DECOMP Rim #1. Retrieve catcher s~b from 8491'. Run #2. Pull prong from CA-2 blanking plug at 8491'. No I6/23/2008 I00:00 - 01:00 I 1.00 I PULL I P Run #3 Add centralizer to tool string. RIH to pull plug prong. Recover ron . WHP & IA = 210 psi after pulling plug. Run #4: En9age and pull C2 plug. DECOMP Continue to run slickline. Rig down Halliburton. 01:00 - 03:30 2.50 ZONISO P DECOMP Cut off short bad section of coil. Meg and cont test e-line. Rehead e-coil. Pull test to 35K#. 03:30 - 05:00 1.50 ZONISO P DECOMP Pressure test inner reel valve and packoffs. 05:00 - 05:30 0.50 ZONISO P DECOMP MU nozzle on stinger and Inteq blind sub. 05:30 - 06:45 1.25 ZONISO P DECOMP RIH, gas to surtace at 3000 ft, Stopped at 3,569 psi. Lined out pumping down annulus. Qp 4.5 bpm PUPa = 500 psi / 371 psi Vp 140 bbl 06:45 - 08:15 1.50 ZONISO P DECOMP RIH maintaining constant WHP / BHP Qp=1.00 to 0.5 bpm down annulus Taqped at 9,172 ft.54 Vp = 203 bbp SD SIWHP = 320 psi = 9.3 ppg 08:15 - 09:15 1.00 ZONISO P DECOMP Pump injectivity test using 140deg 2%KCL Qp = 1 bpm at 370 psi 311 psi on IA Q= 1 b m at 370 si 377 si on IA Qp = 1.76 bpm at 480 psi IA at 453 psi Vp = 120 bbl at 130 deg F 09:15 - 09:30 0.25 ZONISO P DECOMP Cement Job PJSM 09:30 - 10:22 0.87 ZONISO P DECOMP Open well to choke and returns are Qp = 1.77 / 0.52 bpm at 300 psi WHP Pumped a total 180 bbl 130 deg 2% KCL down CT, SD and pumped bio to reel and SD. isolated MP and lined out to cementers, pumped 2 bbl fresh water and PT to 4000 psi. Batch up 1 tub of cement. Set nozzle at 9,161 ft 10:22 - 10:45 0.38 ZONISO P DECOMP Pumped 3 bbl water , 1.16cf/sxs yield and 5.094 gal /sxsx water requirement. 70BC at 3:18 hr:mn Qp 1.55 / 0.5 bpm IA 344 psi Cement to density at 10:20 hrs. Pumped 5 bbl water. 10:45 - 11:22 0.62 ZONISO P DECOMP Displace Cement with Bio / KCL 1.75 bpm Pp = 3500 psi With 4.0 bbl out Qp = 1.00 bpm at 800 psi. PUH lavina in 1:1 WHP climbed to 450 and then broke back to 350 psi Reduced running speed to 67 fpm in the 4-1/2" tubing 28 bbl cement out. PUH to 7000 ft Qp = 0.6 bpm Vp = 33.8 bbl 11:22 - 13:15 1.88 ZONISO P DECOMP Walking squeeze Qp = 0.36 bpm Pi = 190 bbl Pf =183 psi Vp =2/26bb1 SD10min Pf=157psiQp=0.50bpm Pf=155psiVp=3/ 23 bbl SD 15 min Pf = 157psi Qp = 0.50 bpm Pf = 185 psi Vp = 4/ 19 bbl SD 15 min Pi = 187 psi Qp = 0.50 bpm Pf = 220 psi Vp = 3/ 16 bb112:25 hrs SD 8 min Pi = 220 psi Qp 0.50 bpm Pf = 250 psi Vp = 3/ 15 Printed: 8/27/2008 3:25:29 PM ~ i ' BP AMERICA Page 3 af 31' Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/23/2008 1122 - 13:15 3:15 - 13:50 3:50 - 14:10 14:10 - 14:30 1.88 .58 .33 0.33 ZONISO ONISO ONiSO ZONISO P P P P DECOMP ECOMP ECOMP DECOMP bbl 12:31 hrs SD 15 min Pi = 240 psi Qp = 0.40 bpm Pf = 250 psi Vp 2/ 13 bbl 12: 48 hrs SD 12 min Pi = 245 psi Qp = 0.48 bpm Pf = 275 psi Vp 3 bbl / 10 bbl 13:05 hrs SD 5 min Pi 271 si Qp = 0.50 bpm RIH cleanin out wellbore for next cement'ob Qp = 1.00 / 0.26 bpm WHP = 370 psi T 7 MD PU Cement in place at 13:00 hrs Inc Qp 2.85 bpm Rih and confirm inteqrity TaqQed hard apain at 9072 ft Cir and maintain constant BHP while WOC. SWI. RU to confirm IA communication at 8 136 ft. Circulated 50 bbl down IA at 1:1 takin returns to its. 14:30 - 21:00 6.50 ZONISO P DECOMP Circulating Qp = 0.99 / 0.90 bpm. WHP = 179 psi. Spot SLB cement bulk truck. 21:00 - 21:15 0.25 ZONISO P DECOMP Perform in'ectivit test. 460 si wh at 1.22 b m Shut in pump. WHP bled from 460 psi to 360 psi in +/- 7 minutes. 21:15 - 21:45 0.50 ZONISO P DECOMP Hold PJSM with rig and SLB crews. Discuss safe area, pump schedule, fluid handling, clean up issues. 21:45 - 23:00 1.25 ZONISO P DECOMP Prep mix water for 15 bbis Class G 15.8 ppg cement. Pump 5 bbis fresh water ahead. PT lines to 4000 psi. Mix on the fl and um 15.7 bbls cement int reel. Pump 5 bbls water behind. Displace cement in reel with 1# biozan/kcl water from pits. Maintain 170 psi WHP 2700 psi at 1.67 in/1.69 out. 23:00 - 23:30 0.50 ZONISO P DECOMP RIH to 9060' nozzle de th. Lay in cement at 1:1. Cement in place at 23:15 hrs. P 23:30 - 00:00 0.50 ZONISO P DECOMP Wait on cement for 30 min. SIWHP: 95 psi 6/24/2008 00:00 - 00:15 025 ZONISO P DECOMP Continue to wait on cement for one hr total. 00:15 - 02:00 1.75 ZONISO P DECOMP Circ down coil to squeeze cement away: 00:15 Pi: 55 psi Vp: 3.6 bbls Pf: 250 psi. After 30 min: Pf: 165 psi 00:45 Pi: 165 psi Vp: 1.0 bbls Pf: 215 psi After 30 min: Pf: 172 psi 01:15 Pi: 176 psi Vp: 1.0 bbls Pf: 295 psi After 10 min: Pf: 280 psi 01:25 Pi: 280 psi Vp: 1.0 bbis Pf: 410 psi After 20 min: Pf: 340 psi 01:45 Pi: 340 psi Vp: 1.0 bbls Pf: 695 psi After 5 min: Pf: 688 psi 01:52 Pi: 688 si Vp: 1.0 bbls Pf: 1010 psi. Held solid for 10 min. Begin circulating well with 500 psi WHP. Start 2# bio pill down coil. 02:00 - 03:30 1.50 ZONISO P DECOMP RIH. 4100 psi at 3.1 in/3.4 out. Maintain WHP at 300 psi. Wash tb to 8950'. Make up pass. Wash packers at 8467' and 8542'. Circulate down IA to verify clear of cement. Printed: 8/27/2008 3:25:29 PM • ~ 'BP /~MERICA Page 4 c~f 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To i Hours Task Code NPT Spud Date: 6/21/2008 Start: 6/21 /2008 End: 7/24/2008 Rig Release: 7/24/2008 Rig Number: Phase Description of Operations 16/24/2008 102:00 - 03:30 I 1.501 ZONISO I P DECOMP ~ Cement back to surface. Treat same and send to cuttings box. 03:30 - 06:00 2.50 ZONISO P DECOMP Continue to circulate out of hole. Wash each GLM. 06:00 - 07:00 1.00 ZONISO P DECOMP OOH, LD Nozzle BHA and PU swizzel stick. Jet stack at 4100 psi 07:00 - 07:10 0.17 ZONISO P DECOMP Stand back injector and LD swizzle stick. Make read to conduct slack management Load pits with SW abd mix in Biozan 07:10 - 07:55 0.75 ZONISO P DECOMP Rehead CTC / UQC. Wire tested goo at >2000ohm resistance and continunity of 50mohms. Install head and failed test. Set inject over well and pump slack to get enough wire to rehead. Pumped slack and heard it move in the reel house . SD 07:55 - 10:00 2.08 ZONISO N SFAL DECOMP Re-head UQC following failed test 10:00 - 10:25 0.42 ZONISO P DECOMP PJSM on MU of clean out BHA useing pressure deployment procedure. 10:25 - 12:05 1.67 ZONISO P DECOMP MU and PU clean out BHA following pressure deployment procedures. Compressive strength of cement was 1200psi ~ 04:30hrs. via UCA 12:05 - 13:05 1.00 ZONISO P DECOMP RIH maintaining 300 psi well Head Pressure. Taqed at 8496' 13:05 - 14:55 1.83 ZONISO P DECOMP PU to 8487' Free spin of 2040 C~ 1.51 bpm. Taged again at 8504' CP=3000 psi ~ 1.5 bpm free after 8502' ~~.,_....~~ ___~...--- -__._ _. ~~.," __~ .~___ _u__ :_ ~ _.__~__ 8545' CP=2700psi ~ 1.4 bpm and 4000# WOB 8564' CP=2500 psi (~ 1.75 bpm DH W06=200# ROP=6.6 fpm 8700' RIH ~ 25 fpm. After 8700' hole was clean down to 8956'. 14:55 - 15:20 0.42 ZONISO P DECOMP Log for GR tie in from 8850' to 8908' - 6 ft correction 15:20 - 15:40 0.33 ZONISO P DECOMP Continue to RIH T ~ 9 4' CP=2500 psi ~ 1.77 bpm 1400# WOB. free @ 8940' 8956' CP=3300 psi 15:40 - 18:45 3.08 ZONISO P DECOMP Hard Ta C~89 ' CP=3300 psi ~ 1.75 bpm DH WOB 1100 #'s ROP=.7 fpm 18:45 - 21:30 2.75 ZONISO P DECOMP 15-20 FPH ROP 2900 CTP ~ 1.6 BPM, - 1000 DH WOB 21:30 - 00:00 2.50 ZONISO P DECOMP 9075', stalled and got hunq up, worked pipe with ma~ circulate 20 bbls and continue milling to 9100'. Circulate a 2 ppg bio sweep and CBU 6/25/2008 00:00 - 00:30 0.50 ZONISO P DECOMP CBU. 00:30 - 01:55 1.42 ZONISO P DECOMP Pressure test cemented perfs. Printed: 8/27/2008 3:2529 PM ~ ~ BP AMERICA Page 5 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Weli Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code N'PT Phase Description of Operations 6/25/2008 00:30 - 01:55 1.42 ZONISO P DECOMP PrPSSUred un to 1000 WHP and nressure bled off to 450 in 10 m~ Pump at 2 BPM and pressured up to 900 WHP. Able to iniect Consult with town engineers and decide to continue with milling 01:55 - 06:15 4.33 ZONISO P DECOMP RIH to 9100' and continue milling 2700 CTP at 1.8 BPM, 800 DH WOB, 10-15 FPH 06:15 - 06:30 0.25 ZONISO P DECOMP Short trip to 8903' and pumped 10 bbl sweep with 2 ppg Bio Cp=2550 psi C~? 1.80 bpm 1/O =1.82/1.87 While RIH 06:30 - 08:05 1.58 ZONISO P DECOMP Continue to mill ahead. ~ 9150' CP=2650psi ~ 1.80 bpm In/Out=1.80/1.76 bpm (Annular pressure = 3496 psi / 10.35 ECD) DH WOB = 1060 #'s ROP=22 FPH 08:05 - 08:40 0.58 ZONISO P DECOMP POOH to GR tie ~ 8854' with + 3 ft correction Continue loging with GR correction for CCL tie in 08:40 - 10:05 1.42 ZONISO P DECOMP POOH maintaining 300 psi Well head pressure 10:05 - 10:15 0.17 ZONISO P DECOMP PJSM on pressure undeployment procedures while POOH 10:15 - 10:20 0.08 ZONISO P DECOMP POOH 10:20 - 11:30 1.17 ZONISO P DECOMP Prusseure undeploy BHA using MPD loop to maintain 300 psi well head pressure. 11:30 - 12:00 0.50 WHIP P WEXIT LD millinq BHA and PU whipstock assemblv. 12:00 - 12:15 0.25 WHIP P WEXIT PJSM on PU and Pressure deployment of Whipstock BHA 12:15 - 13:30 1.25 WHIP P WEXIT Pressure deploy whipstock BHA. 13:30 - 14:00 0.50 WHIP P WEXIT RIH with Whipstock BHA maintaining 300 psi WHP with EDC open. 14:00 - 15:30 1.50 WHIP N SFAL WEXIT 15:30 - 16:55 1.42 WHIP P WEXIT 16:55 - 1720 0.42 WHIP P WEXIT 17:20 - 18:00 I 0.671 WHIP I N I DPRB I WEXIT Stop ~ 1200 ft to check on SLB injector pack off condition. Decided Pack off needs replacement. discuss situation with SLB and complete a THA. Hold PJSM with SLB and Nordic hands. Repair SLB injector pack off assembiy. Continue to RIH after repairs. GR tie in from 8850' to 8898' -6 ft correction. Continue to RIH While RIH at 30 FPM, taged ~ 9017.5' w/ 5500 # WOB, PU to 9012 showing -1750# DH WOB. Stopped while Baker TT consulted with Deadhorse. Deadhorse says max up wt is 18,000 # over pull. Pulled up to -9200 #'s Down Hole WOB. Set back down and stacked down 6440 #'s DH WOB. Went Neutral and tried to rotate with orienter. - Unsuccessful. Pulled up -6500 #'s DH WOB. Sett back down = 6500 #'s DH WOB. Printetl: S/27/2008 3:25:29 PM • • BP R'MERICA Page 6 of 31 Operations Surnmary Report ' Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description af Qperations 6/25/2008 17:20 - 18:00 0.67 WHIP N DPRB WEX~T Pulled up -8200 #'s slacked off to neutral and tried to orienter again. Brought pump rate up to .60 bpm with ECD open. Discuss situation with town engineers. 18:00 - 19:30 1.50 WHIP N DPRB WEXIT Wait on Safe -lube. 19:30 - 21:00 1.50 WHIP N DPRB WEXIT Circulate 30 Bbls 2 ppg biozan with Safe-lube, squeeze two bbl down past whipstock. Work pipe, -7000 to + 16000 DH WOB. 21:00 - 22:10 1.17 WHIP N DPRB WEXIT Pressure up to set whipstock. 4400 psi to set. Top of While working pipe from -8000 to 50000, increased pump rate to 1.6 bpm, opened up to choke to attempt to clean up around setting tool. Pulled free and weight back to normal up weight at 28000. 22:10 - 00:00 1.83 WHIP N DPRB WEXIT POOH 6/26/2008 00:00 - 02:00 2.00 WHIP N DPRB WEXIT Lay down WS settinq BHA, setting tool looked normal with no 02:00 - 05:10 I 3.171 KILL I N I DPRB I WEXIT 05:10 - 06:45 1.58 KILL N DPRB WEXIT 06:45 - 07:05 0.33 KILL N DPRB WEXIT 07:05 - 08:30 I 1.421 FISH I N I DPRB I WEXIT 08:30 - 08:55 0.42 FISH N DPRB WEXIT 08:55 - 10:25 1.50 FISH N DPRB WEXIT 10:25 - 12:12 I 1.781 FISH I N I DPRB I WEXIT 12:12 - 1222 0.17 FISH N DPRB WEXIT 12:22 - 12:27 0.08 FISH N DPRB WEXIT 12:27 - 14:10 1.72 FISH N DPRB WEXIT indication of sticking mechanism. PU 2 3/8' extreme motor, 2.74 go/2.73 no-go string reamer and parabolic mill. RIH, swap well to 9.8 PPG NaCI brine with flo-vis. Slow ROP at 8480' to 20 FPM Slow to 8 FPM at 8900' Taq WS at 9012.5' Backream at 10 FPM to 8900' Ream down at 10 FPM to tag at 9012.5' CBU, POOH PJSM while POOH for LD of Clean out BHA and PU of Fishing tools Unstab injector LD clean out tools, MU fishing BHA Stop and stand by discuss new plan forward with town. LD Fishing BHA with overshoot and MU different fishing BHA with Hook retrieving system. PU BHA Stab in injector RIH to 8900' with Fishing BHA. Up WT = 29,000#'s. Continue RIH to 8975'. log from 8975' to 8995' for GR tie in. -6 ft correction. Taq fish at 9011' with 50 deg rt TF and 4000# WOB straight pull 30K - nothing set down with 35 deg RT TF, 65 RT, 80 RT, 90 RT, 20 RT, 10 RT, 0, 10 L, 25 L, 45 L, 75 L, 45 RT, 80 RT, 100 RT, 130 L, 160 L, 180, 40 RT, 55 RT, Set down with 55 RT TF and 1000 #'s DH WOB and orientate HOT from 55 deg RT TF to the left, saw orienter stops change positions. PU - nothing. Set back down with 10 RT TF and 1800 # DH WOB and orientate to the right, amped out. Try again with 750#'s DH WOB and orientat to the right saw WT and TF jump- no catch. Printed: 8/27/2008 3:25:29 PM • ~ BP AMERICA Page ~ of 31 ' C?perations Summary Repart Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Qperations 6/26/2008 12:27 - 14:10 1.72 FISH N DPRB WEXIT try again with 25 RT TF and straight pull (twice). 60 RT TF and straight pull Set dn with 10 RT, 870 #'s DH WOB and orientate to the RT. 14:10 - 15:50 I 1.671 FISH I N I DPRB I WEXIT 15:50 - 16:30 I 0.67I FISH I N I DPRB I WEXIT ~ 16:30 - 19:00 2.50 FISH N DPRB WEXIT 19:00 - 19:30 0.50 FISH N DPRB WEXIT 19:30 - 22:00 2.50 FISH N DPRB WEXIT 22:00 - 23:50 1.83 FISH N DPRB WEXIT 23:50 - 00:00 0.17 FISH N DPRB W EXIT 6/27/2008 00:00 - 00:45 0.75 FISH N DPRB W EXIT 00:45 - 02:20 1.58 FISH N DPRB WEXIT 02:20 - 03:30 1.17 FISH N DPRB WEXIT 03:30 - 08:30 5.00 FISH N DPRB WEXIT 08:30 - 08:40 0.17 FISH N DPRB WEXIT 08:40 - 09:20 0.67 FISH N DPRB WEXIT 09:20 - 11:05 1.75 FISH N DPRB WEXIT 11:05 - 11:45 I 0.671 FISH I N ~ DPRB I WEXIT 11:45 - 13:05 1.33 FISH N DPRB WEXIT 13:05 - 13:20 0.25 FISH N DPRB WEXIT 13:20 - 15:00 1.67 FISH N DPRB WEXIT unstab injector and LD fishing BHA. Shut in well using Swab and Master valves. Also shut in IA and OA casing valves. Shut down for Kuparuk field wide safety stand down. PJSM Pump Eline slack out of coil, 300' cut off. PU fishinq BHA RIH 8900' weight check, 28000 up, 7700 down tag WS at 9012', PU 20K over and jarred off. RIH to re-engage. Can't gat latched in. Continue attemptinq to fish WS, unable to engage fish after first attempt. Can not go down past fish at 9012' POOH, pumping across top of hole. 1500# weight bobble at 8538', 2.75" nipple. Lay down BHA Over shot had a broken collet (0.5" x 1.5") and bent housing, indicating that we did latch whipstock on first tag. Over shot will need to be taken to Deadhorse machine shop for repairs Waiting on fishing tools to be repaired PJSM on MU and PU of overshot fishing BHA. MU and PU overshot BHA. RIH with Overshot BHA. Up WT ~ 8900' = 29,000#'s CT WT Dn WT ~9000' 7,500#'s CT WT Taa ~ 9010' set down with 2,000#, PU with no over pull Set down with 3,500#, PU no over pull Set DN w/ 2,500 #'s pause and PU w/ no over pull Set Dn while circulating 0.25 bpm w/1600 CT WT pumps off, pause, PU w/ no over pull. SD C~3 10 fpm 1.0 bpm CT WT of 4000#'s pause. set DN w/ 2700#, pause. Pumps off, PU to 8994' no over pull. SD w/ pumps off, 2400#'s CW, pause, PU to 8997' No over pull. SD 700#'s, PU - no over pull. SD -300#'s, PU 3300#'s, DN -400#'s, PU no overpull. SD 2700#'s, PU no overpull. SD 2400#, pause, SD 2500#, no overpull. SD 2400#, pause, SD 2200#, pause, PU no overpull. POOH POOH without fish. PJSM while POOH on BHA LD and PU LD Overshot BHA. Evaluate Overshot condition and consult with town. Printed: 8/27/2008 3:25:29 PM ~ • BP AMERICA Page 8 c~f 31 aperations Summary Repart Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date Frorn - To Hours Task Code ~~-- I-` 6/27/2008 15:00 - 18:30 3.50 FISH N 18:30 - 18:45 0.25 FISH N 18:45 - 19:30 0.75 FISH N 19:30 - 21:20 1.83 FISH N 21:20 - 23:30 2.17 FISH N 23:30 - 00:00 0.50 FISH N 6/28/2008 00:00 - 02:45 2.75 FISH N 02:45 - 03:00 0.25 FISH N 03:00 - 04:00 1.00 FISH N 04:00 - 07:30 3.50 FISH N 07:30 - 09:30 I 2.001 FISH I N 09:00 - 11:00 2.00 FISH N DPRB WEXIT 11:30 - 12:45 1.25 FISH N DPRB WEXIT 12:45 - 15:00 2.25 FISH N DPRB WEXIT 15:00 - 16:20 1.33 FISH N DPRB WEXIT 16:20 - 18:30 2.17 FISH N DPRB WEXIT Spud Date: 6/21 /2008 Start: 6/21 /2008 End: 7/24/2008 Rig Release: 7/24/2008 Rig Number: ~se ' Description of Operations DPRB W EXIT Pump slack managment to be able to rehead for running Inteq tools on impression block. Cut Coil, 329'. Rehead coil. Test connection. DPRB WEXIT PJSM DPRB WEXIT PU BHA #8 with LIB. Scribe line to know orientation of LIB impression. DPRB WEXIT RIH, orient to high side. Taq WS at 9008', set down 2000 WOB. Wait - 1 min. for jars to fire. DPRB WEXIT POOH DPRB W EXIT OOH with LIB, Good marks but unsure of what they show. Three distinct. deep impressions. Defnitely part of the whipstock, but does not resemble the WS tray at the surface. Obstruction is -1" into well path. Call out SL. DPRB WEXIT Waiting on SL unit DPRB WEXIT PJSM with Halliburton SL crew DPRB WEXIT RU SL equipment DPRB WEXIT DPRB WEXIT 18:30 - 19:30 1.00 FISH N DPRB WEXIT 19:30 - 20:00 0.50 FISH N DPRB WEXIT 20:00 - 21:20 1.33 FISH N DPRB WEXIT 21:20 - 23:30 2.17 FISH N DPRB W EXIT 23:30 - 00:00 0.50 FISH N DPRB WEXIT 6/29/2008 I 00:00 - 00:30 I 0.501 FISH I N I DPRB I W EXIT 00:30 - 02:20 I 1.83I FISH I N I DPRB I W EXIT SL Run with 1.10" x 30" prong with 2.62" swedge and knuckle joint. tagout and not able to work past obstruction with prong. No conclusive marking on prong. Evaluation of prong run, decied on plan forward Wait on tools for SL. SL Run wit 2.5" x 4 ft pump bailer. No returns in basket at surface. SL Run with 2.5" x 5 ft Hydrostatic bailer. Burst disk did not shear. 2nd SL Run with Hydrostatic bailer with smaller burst disk. Burst disk fired but nothing in basket. SL run with shrouded whipstock retrieval hook on a knuckle joint and eccentric weight bar. Unable to hook into whipstock. RD SL, prep for camera run PJSM for camera run PU Inteq tool string and camera. Camera has a snorkle which allows circulation ahead of lens. Camera programed for two shots per second for two 45 second intervals 15 minutes apart. First will be taken with while pumping, second with pumps down RIH 8500', Tie in, -1' correction Tag fish at 9006' Continue circulating clean, filtered 9.5 ppg NaCI brine C~? 1.8 bbm Camera set to begin taking pictures at 00:15 Wait on camera timer First set of shots at 0015 hrs, circulating at 0.5 bpm. Second set at 0030 hrs, pump down, well static During both sets reciprocated down to tag and then PUH 2' and attempt to get back down to fish within the 45 sec. POOH Printed: 8/27/2008 325:29 PM • ! BP AMERICA Page 9 of 31 Operations Summary Repart Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Da#e From - To Hours Task` Code NPT Phase Description of Operations 6/29/2008 02:20 - 03:00 0.67 FISH N DPRB WEXIT Lay down camera BHA and view pictures 03:00 - 04:20 1.33 FISH N 04:20 - 07:00 2.67 FISH N 07:00 - 07:15 0.25 FISH N 07:15 - 07:30 0.25 FISH N Consult with town enqineer and decide to attempt to dress top _ of dama ed WS with crayola mill Missing collet from overshot is not visible in photos WS tray is standing off from low side of hole about 1" and appears to have been damaged by the nose of the inner mandrel of the overshot tool. DPRB WEXIT MU inteq TS with orienter, 0.4 deg. motor and 2.74" crayola mill DPRB WEXIT DPRB WEXIT DPRB WEXIT Log GR tie in from 8854'. No correction. Run in hole. 12k# dn, 27k# up wt. Circ min rate. 445 psi fs at 0.36 bpm in/out. Make a series of tags: TF 30R: 9007.8'. TF 212R: 9007.8' Circulate at 2480 psi fs at 1.77 bpm in/out. Tag TOW at 9007.6' and stall. PU and tag again. 70 psi mtr work at 9007.5'. Mill ahead at 0.05' increments. :;,, ~fat~ 9007.55': 2560 psi / 60 psi mtr work. 0# dhwob. TF: 33.9R. 9007.60': 2582 psi / 80 psi mtr work. Ok# dhwob: TF: 31.7R. 9007.65': 2590 psi / 90 psi mtr work. 0.01 k# dhwob: TF: 35.1 R 9007.70': 2615 psi / 115 psi mtr work: 0.02k# dhwob: TF: 29.2R. Roll TF left to 340, 297 then 180 deg opposite WS tray face, 207R. 9007.75': 2585 psi / 85 psi mtr work: 0.01 k# dhwob: TF: 207R. 9008'.0': 2622 psi then stall. PU and RIH. 07:30 - 08:30 I 1.001 FISH I N I DPRB I W EXIT 08:30 - 09:00 I 0.501 FISH I N I DPRB I WEXIT 09:00 - 10:30 1.50 FISH N DPRB WEXIT 10:30 - 11:00 0.50 FISH N DPRB WEXIT 11:00 - 11:30 0.50 BOPSU~N DPRB WEXIT 11:30 - 12:30 1.00 FISH N DPRB WEXIT 12:30 - 14:00 1.50 FISH N DPRB WEXIT 14:00 - 14:15 0.25 FISH N DPRB WEXIT 9007.75': 2593 psi / 60 psi mtr work. 0.07k# dhwob. TF: 203.8R. 9007.82'. 2593 psi / 50 psi mtr work. 0.10k# dhwob. TF: 213.3R. 9007.87' 2582 psi / 50 psi mtr work. 0.09k# dhwob. TF: 209.6R. 9007.90'. 2604 psi / 75 psi mtr work. 0.11 k# dhwob. TF: 206.5R. 9007.93'. 2615 psi / 85 psi ntr work. 0.18k# dhwob. TF: 211.5R. Stall. Decide this is enough footage. Estimate 3" to 4" "milled footage". Don't want to over do it. Pull out of hole. At surface. Get off well. LD Inteq BHA. Perform weekly BOPE function test as per AOGCC regulations. All equipment functioned properly. Hold PJSM to discuss MU and configuation of BHA. MU two drill collars w/ jars & accel with unskirted hook on Inteq tools. Scribe hook backside to high side tool face. Crew change. Run in hole. Log gr tie in from 8920'. -1' correction. Printed: 8/27/2008 3:2529 PM ~ ~ ~ !BP AMERICA Page 10 of 31' Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Descriptian of Qperations 6/29/2008 14:15 - 15:45 1.50 FISH N DPRB WEXIT RIH to WS. 10k# dn, 27.5k# up wt. Orient hook to 90 deg left of tray face (at 30 deg RHS) to try and get hook past TOW at 9007'. PU and RIH again. Stop at 1' above previous tag and orient to 20RHS. PU. No catch. Orient to 32R. RIH. Take wt at 9009'. Make 12 attempts at TF from 35 RHS incrementing by 3-5 deg up to 57RHS. No over ulls. 15:45 - 18:30 2.75 FISH N DPRB W EXIT PU and orient 180 deg opposite tray face to 240 RHS. RIH to check tag. Took wt at 9009.3'. Orient to 30RHS. PU and et 1.4k# over ull, then back to neutral wt, Orient to 26RHS. RIH. Set down at 9007.3 (TOW). PU and orient to 285RHS. RIH. Continue to take weiqht now at 9007'. Unable to pet down to Orient to 240RHS to try and get deeper again. Make to 9009.15. Orient to 15RHS. 18:30 - 19:40 I 1.171 FISH I N I DPRB I WEXIT Continue with fishing Staying below 9006' with the hook, spread allowable HOT "window" for tool face to +/- 20 deg. This means the orienter does not try to correct tool face until it goes 20 deg beyond set point. This allows hook to orient to slot without the orienter trying to correct TF. Stacked down to 2000 WOB and made 12" deeper. After three attempts at 40R, set TF at 20 R Hooked at 32R. Pulled 5k over and let iars fire. Pulled uo to 15K over and mav have moved un hole -4'. 19:40 - 22:30 2.83 FISH N DPRB WEXIT POOH, slight weight swings, <1000 #'s, coming through nipple and jewelry. 22:30 - 00:00 I 1.501 FISH I N I DPRB I WEXIT 6/30/2008 00:00 - 01:55 1.92 CLEAN N DPRB W EXIT 01:55 - 06:00 4.08 CLEAN N DPRB WEXIT 06:00 - 12:00 I 6.001 CLEAN I N I DPRB I WEXIT 12:00 - 13:45 I 1.75I CLEAN I N I DPRB I W EXIT 13:45 - 16:00 I 2.251 CLEAN I N I DPRB I W EXIT M Make up milling BHA for cleanout run. 2.80" diamond parabolic mill (D331) and 2.78" diamond string reamer. RIH with 2.80" mill and 2.78" string mill Millinq on nipple 2.75" nipple at 8538'. 1.8 BPM ~ 2600 CTP free spin, 7000 down weight, 27000 up. Two stall at 8540', time mill at 0.1' per six minutes. Continue to clean out 3.5" liner. Some stalling, at 9007' and 9013', in WS setting interval. Circ 5 bbl hi-vis sweeps to help clean hole Smooth milling untill stall at 9021' smooth aaain untill 9057' stalled aqain runninq at 0.3 fprr Continue to mill ahead. Numerous stalls. Having to mill at 1.0 or less per hour. Milled down to 9140 ft. PU to 8860 ft and log down for GR tie in at 8854 ft. +0.5 ft correction Printed: 8/27/2008 325:29 PM ~ ~ ~ V~ ~~ BP AMERIGA Page 11 of 31' Qperations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: ' Date Frorn - To Hours Task Code NPT Phase ' Description of Operations 6/30/2008 16:00 - 16:10 0.17 CLEAN N DPRB WEXIT RIH tag bottom at 9140 ft 16:10 - 18:00 1.83 CLEAN N DPRB WEXIT Mill ahead to 9150 ft. 40 motor stalis in all with milling from DS nipple to 9150 ft. 18:00 - 20:00 2.00 CLEAN N DPRB WEXIT POOH, pumped sweep off bottom and second sweep at 4.5" X 3.5" XO 20:00 - 20:40 0.67 CLEAN N DPRB W EXIT La down cleanout assembl Mill guaged 2.78 go/2.77 no-go, string reamer 2.78 go / 2.77 no-go PU dumm whi stock with 'Ls 20:40 - 22:40 2.00 WHIP N DPRB WEXIT RIH clean run til stack out at 9155' PU clean off bottom 22:40 - 00:00 1.33 WHIP N DPRB WEXIT POOH 7/1/2008 00:00 - 01:50 1.8~ WHIP N DPRB WEXIT Lay down dummy WS. PU WS and setting tools and Inteq BHA. One PIP tag installed. Test Inteq tools 01:50 - 04:30 2.67 WHIP N DPRB WEXIT RIH with EDC open, pumping at .2 BPM, 400 CTP 04:30 - 05:00 0.50 WHIP N DPRB WEXIT 8860' Tie-in, -3' correction Continue RIH 05:00 - 05:05 0.08 WHIP N DPRB WEXIT 7000 RIW, 27000 up weight. Park at 9143.7' and close EDC. Pressure up to 4400 psi. This will ut to of whi stock / To of window at 9 135 ft 05:05-0620 1.25 WHIP P WEXIT POOH 06:20 - 06:35 025 WHIP P WEXIT PJSM while POOH on LD/PU of whipstock BHA and window milling BHA 06:35 - 07:55 1.33 WHIP P WEXIT LD whipstock running BHA and PU Window milling BHA 07:55 - 09:40 1.75 STWHIP P WEXIT RIH with window milling BHA. 09:40 - 09:50 0.17 STWHIP P WEXIT Log for GR tie in at 8854 ft. Subtract 3' correction. 5~,~,~ 09:50 - 13:00 3.17 STWHIP P WEXIT Tag whipstoc at . / tti t t U f b i N ll ~S~ IZ s ge ng s a e . 2375 psi s at 1.6 pm Nout. umerous s a ' ~, d L2 Tlme mill ahead at 0.1 per six minutes. ' Milling depth: 9135.7 . 13:00 - 16:00 3.00 STWHIP P WEXIT Continue to mill ahead from 9135.7'. ~'R L.~ Stall at 9136.1'. PU and resume ti illing. v 1 2560 psi fs at 1.63 bpm in/out . 5-1.85k# dhwob Mill to 9137.6' _`~S 16:00 - 19:15 325 STWHIP P WEXIT Continue milling, .' r six minutes. 2600 ctp, 125 WOB ~ Milled to 914 ' 19:15 - 19:55 0.67 STWHIP P WEXIT Milling f ation to 9151' 19:55 - 20:35 0.67 STWHIP P WEXIT D window with 3 up down passes at < 1 fpm. rift with pump down at 5 fpm. 20:35 - 22:20 1.75 STWHIP P EXIT POOH pumping at 1.6 BPM 22:20 - 23:15 0.92 STWHIP P WEXIT Lay down milling BHA Mill and string reamer guage, 2.74" go / 2.73" no go Face of mill shows normal wear indicative of exiting the liner Prep to blow down reel 23:15 - 23:30 0. IGD P PROD1 PJSM for N2 blowdown. 23:30 - 00:00 .50 RIGD P PROD1 Blow down reel with N2 7/2/2008 00:00 - 03• 3.00 RIGD P PROD1 Bleeding down N2 from coil Remove Inteq UQC and cut off connector Tail pipe back to coil and secure Rig down reel hard line Printed: 8/27/2008 3:2529 PM • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 27, 2008 4:03 PM 70: Eller, J Gary Cc: Saltmarsh, Arthur C OA ~ Hubble, Terrie L; Allsup-Drake, Sharon K Subject: RE: KRU D-~ (199-084) --1 D-12L1 (208-104). 1 D-12L2 (208-105) Page 1 of .y- Gary, The 404 is all we will need. I now have the operations reports you mention after making a copy from one of the lateral well reports. Thanks, Tom Maunder, PE AOGCC From: Eller, J Gary [mailto:].Gary.Eller@conocophillips.com] Sen#: Monday, October 27, 2008 3:51 PM To: Maunder, Thomas E (DOA) Cc: Saltmarsh, Arthur C (DOA ; H ble, Terrie L; Allsup-Drake, Sharon K Subject: RE: KRU iD-12 (199-084 --iD-12L1 (208-104). 1D-12L2 (208-105) Tom -Just to make sure I understand what all you need regarding well 1 D-12: 1. You'd like a 10-404 to close out 308-204, which was the sundry to plug the original perfs in 1 D-12. (Not a problem - we can get you one this week.) 2. You want details of the isolation assembly at 9043' - 9099' MD. (That isolation assembly was run from the Nordic #2 rig 7/21 & 7/22/08. You should already have operations reports for those days.) Did I miss anything? -Gary From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, October 27, 2008 3:25 PM To: Eller, J Gary; Hubble, Terrie L; Allsup-Drake, Sharon K Cc: Saltmarsh, Arthur C (DOA Subject: KRU D-12 (1 - 84) -iD-12L1 (208-104). 1D-i2L2 (208-105) Alf, 1 am not sure who should get this, so everyone does. I am reviewing a 407 submitted for 1 D-12. This document was a requirement of sundry 308-204 which was approved 6/12/08. While the purpose of the work was to squeeze a thief zone in the C sand, the entire completed interval would be squeezed although the upper portion would still be available for future perforation. Gary and I exchanged an email in late May addressing the naming of the planned laterals. It was determined that both penetrations would be considered "Ls" rather than an "A" and "AL1" since the upper portion of the existing interval would be available to perforate. Unfortunately, that email did not make it to the 1 D-12 file. On the basis of our discussion, it was my error that a 407 was required to report the work of 308-204. A 404 is the correct form and I request that one be prepared and submitted. Sorry for the additional work. !t is not necessary to submit additional copies of the operations summary for the pre-rig work conducted in June or the actual operations conducted in 1 D-12 prior to milling the window for 1 D-12L1 on July 1. The post rig work summary provided beginning July 25 and ending August 2 does not appear to be complete. The provided summary details the setting of the tubing patch to isolate the off depth perforations in the tubing at 8136 - 8138. It appears from the drawing that a patch was also set in the completion interval from 9043 - 9099 since even after squeezing, the perforations still leaked off. I have not been able to find any details of that operation. Thanks in advance. Call or message with any questions. 11/16!2008 MEMORANDUM Toy Jim Regg ~~ ~~~ P.I. Supervisor (~p(~( ~g FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commis DATE: Thursday, August 07, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-12 KUPARUK RIV UNIT ID-12 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .1~~~~~-- Comm Well Name' KUPARUK RN UNIT ID-12 API Well Number 5o-oz9-229as-00-00 Inspector Name• John Crisp Insp Num• mitJCr080807071756 Permit Number: 199-084-0 Inspection Date• 8/1/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well tnaz TYPe Inj. N TVD 6175 ~ IA 6zo Ito Ito Ito p.T t99osao TypeTest SPT Test psi 1543.75 OA o zo zo zo Interval R>;QvAR P/F P `~ Tubing to7o zsao za9o zaso Notes' MIT-T for tubing integrity. 1.5 bbl's pumped for test. ,~ ~~}n p is ~,~~ii~~ti~ J~~ s. ~ LU~U Thursday, August 07, 2008 Page I of 1 • STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION ~"~ `~ ~' ~~ L `~``'` REPORT OF SUNDRY WELL OPERATIO~a ~-,, ~. Operations Performed: Abandon ^ Repair Well^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhllllps Alaska, InC. Development^ Exploratory ^ 199-084 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 ''Y 50-029-22948-00 • 7. KB Elevation (ft): 9. Well Name and Number: } RKB 104' ~ 1 D-12 ' 8. Property Designation: 10. Field/Pool(s): ``. ADL0025650 • ALK468 `Kuparuk River Field /Kuparuk Oil Pool - 11. Present Well Condition Summary: Total Depth measured 9250' ~ feet true vertical 6688' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 5537' 9-5/8" 5641' 4328' 5750 3090 PRODUCTION 8502' 7" 8696' 6323' 7240 5410 LINER 702' 3-1/2" 9248' 87' 1 6 6 0 159 10533 ~, y7 p~g ~+~ {~} y t A~ ~~ ' ~ ~y 'y t.~ ~ rJ i P s lii .. 6 „Y83 Perforation depth: Measured depth: 9001-9181' true vertical depth: 6524-6643' Tubing (size, grade, and measured depth) Tubing 4.5", L-80 0' - 8502', Tubing 3.5", L-80 8469' - 8568' Packers &SSSV (type & measured depth) Baker FHL retriev. packer Packer = 8467' SSSV= NIP SSSV= 500' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A NIA N/A N!A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 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: 308-221 Contact Perry Klein / MJ Lovelan Printed Name MJ Lovelan file Well Integrity Projects Supervisor Signature Phone 659-7043 659-7043 Date 08/01/08 ~L~~L~ Form 10-40 Revised 04/2004 U R Submit Ori 1D 12 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/27/08 PULLED DV, SET GLV @ 4727' RKB. PULLED CATCHER SUB; SAT DOWN @ 7440' IN TBG, CONTINUED PULL CATCHER. RECOVERED LOST GLV AND CEMENT CHUNKS. BRUSHED TBG FOR PATCH 8050' TO 8200' WLM. DRIFTED WITH 15'x3.75" DUMMY TO 8469' RKB. TAGGED DS NIPPLE @ 8491' RKB 07/28/08 SET 2.813 DS x 1.81 D NIP® DUCER Cam 841' RKB. FUNCTION TEST: SET & PULLED 1.81 CA2 BLANKING PLUG. READY FOR E/L SET STRADDLE PATCH. 07/29/08 SET 4.5" WEATHERFORD PACKER MID-ELEMENT AT 8143', READY FOR S/L ----_ - - 07/31/08 08/01 /08 SET 3.74" WEATHERFORD ER PATCH ASSY IN LOWER ER PKR (OAL=13.75',MIN ID=2.25").TOP OF UPPER PKR @ 8128' RKB.SET 1.81" CA-2 PLUG IN NIPPLE REDUCER @ 8491' RKB.MITT FAILED State Witnessed (John Crisp)MIT-T (passed ), T/I/0= 1070/620/0. Pressured up T with 1.5 bbls dies/, T/I/0= 2540/620/20. 15 min T/I/0= 2490/710/20. 30 min T/I/0= 2480/710/20. Bled T, final T/I/0= 780/620/0. SUMMARY Set retrievable tubing patch from 8143' - 8128' RKB, MIT-T passed. ~~ , ; i ~, $ y ~ , -~ ;~ ~.~ • • ~ f Y ~ ~ ~ { ! ,.. t ~ l ~ ~ ~~ ~ ~t , , ~°---=:A ~..~•w/ ..t {w~ ~ r ~ 1 F a.. ~ x k ~_ ~ ~ ~ { ~ Y ~ i ~ ~s t ~ ~ t ~ <.. tN~` ~ ARAH PALIN GOVERNOR _ . .._. . ._ ~__.a a ~_ ~ d. i , CO1~T5ERQATIO CODII~ii55 pl'S1T Perry HIein Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 (~ , o ~`~ 1i~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 D-12 Sundry Number: 3(--~~~ ~~~ ~ ~ ZDO$ Dear Mr. HIein: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ,~/~ Chair DATED thi~~ day of June, 2008 Encl. ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 22, 2008 ~~~ Alaska Oit & Ga,, ions, C®mmiss~n ~Ano,~o~~aga Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-403 Request for Sundry Approval to patch off depth perforations in the production tubing of well 1D-12 (PTD 1990840). A description summary of the proposal and well schematic are attached. Please call me or MJ Loveland at 659-7043 or Martin WaltersBrent Rogers at 659-7224 if you have any questions. Sincerely, ,G.__ Perry e' Well integrity Supervisor Attachments 10-403 sundry request for 1 D-12 1 D-12 Description summary of proposal 1 D-12 -well schematic ~~ STATE OF ALASKA ~;~v ~ ALASKA OIL AND GAS CONSERVATION COMMISSION aSkS ~1~ ~ GB£ ~(7f1S ~.ORird113S1®Ti APPLICATION FOR SUNDRY APPROV~ AnC~~l~~~e 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^/ J Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ ~ Exploratory ^ 199-084 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22948-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Required? YeS ^ NO^ 1 D-12 ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL0025650 - ALK 468 RKB 104' ( Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9250' ' 6688' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121' SURFACE 5537' 9-5/8" 5641' 4328' 5750 3090 PRODUCTION 8502' 7" 8696' 6323' 7240 5410 LINER 702' 3-1 /2" g24g' 6687' 10159 10533. Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9001-9181' 6524-6643' 3-1/2" L-80 8568' Packers and SSSV Type: Packers and SSSV MD (ft) Baker FHL retriev. packer Packer = 8467' SSSV= NIP SSSV= 500' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: July 12, 2008 Oil^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is tr rrect to the best of my knowledge. Contact: Perry Klein I MJ Loveland Printed N er le~ Title: Well Integrity Projects Supervisor Signature ~ ZZ. ~ Phone 659-7043 Date06/22/08 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ N1, \'~" Other: ~ ~~~' i~~~il ~~ ~ ~~dt~ Subsequent Form Required: ~~~ ~ - • APPROVED SY / ~~ Approved b ~ COMMISSIONER THE COMMISSION Date: Ct Form 10 Revised 06/20 Submit in Duplicate • 1 D-12 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska, Inc. Kuparuk Well 1 D-12 (PTD 1990840) Sundry Notice 10-403 Request 22-Jul-07 purpose: fhe purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to set a retrievable patch across the off depth perforations shot n the 4.5" production tubing at 8136-8138' MD. History: 3/15/08 1 D-12 PTD # 199-084, gas lift producer, was mistakenly perforated off iepth with 2' of 2", six shot per foot, Schlumberger Hyperjet HSD guns from 8136- 3138' MD. The intended scope of the job was to prepare the well for a coiled ubing side track, sundry # 308-204. Job design was to shoot pre cement squeeze poles at 9136-9138'. The off depth holes were shot through the tubing above the production packer, between gaslift mandrels # 5 and 6. The well has tubing by nner annulus communication through the off depth perfs. roposed Plan: • Slick line drift well to packer with dummy patch, 15' x 3.654" • Brush and flush area 50' above and below the planned patch depth at 8136' • Install nipple reducer in Camco DS nipple at 8491'. Design to accept plug that will pass Weatherford ER 4.5" packer, note minimum ID of packer assembly is 2.250" through the seal anchor. • E-line set bottom Weatherford ER packer and anchor seal assembly with seals below perfs at 8136-8138' and • Slick line set blank pipe and top Weatherford ER packer with ETD firing tool. • Set positive pressure plug in Camco DS nipple at 8491' MD and perform 30 MITT to 2500 psi. ~~.~- ~~1.~~.~,r..~~r • After a passing MITT, run gaslift design, perform MIT to check set of GLVs Pull the plug set at 8491' and place well on production. If the post patch tubing test fails an MIT, slick line will troubleshoot the failure and repair as necessary. CorwcoPhillips• TAG I 4!11/2007 NIP. 500 GAS LIFT, 2,983 OAS LIFT, 4,]2] OAS LIFT, 5,525 Surface OAS LIFT, 8,881 GAS LIFT, 7,854 OAS LIFT, 8.356 NIP, 8,408 XO, 8,148 PBR, 8.453 PACKER, 8,4fi] NIP, 8,191 Overahol, 8,502 TUBING, 8,502 NIP, 8,538 Dena Shot Zone (shot... Total Date Comment TD, 9,248 1 D-12 PTD 199-084, Off depth perf • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, June 23, 2008 8:33 AM To: 'NSK Well Integrity Proj'; Eller, J Gary Subject: RE: 1 D-12 PTD 199-084, Off depth pert and CTD sidetrack Gary and Perry, This is as we discussed. Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Saturday, June 21, 2008 3:09 PM To: Maunder, Thomas E (DOA); Eller, J Gary Subject: RE: 1D-12 PTD 199-084, Off depth pert and CTD sidetrack Tom, Per our conversation this a-mail is intended to provide a plan forward outlining well work on 1 D-12. CPAI plans to continue with the coiled tubing sidetrack. Page 1 of 3 Once the side track is complete and the CTD rig has left the well head CPAI plans to install two 4.5" Weatherford ER packers to isolate the section of tubing that was mistakenly perforated at 8136-8138'. A mechanical integrity test will be performed to ensure tubing integrity before placing the well on production. CPAI does not intend to gas lift below station # 5 @ 7654/ 5634' MD /TVD. The production casing currently supports a column of diesel with 1600 psi surface pressure. This equates to 3700 psi or 12.0 ppg EMW at the perfs. The perfs @ 8136-8138' could experience a maximum pressure of 4000 psi with a full column of water in the production casing and full gas lift pressure. However it is not our practice to bring wells online with full gaslift pressure. We unload fluid packed wells slowly in order to protect the orifice valve from damage. It is unlikely that maximum gas lift pressure would be applied to the IA with a full column of fluid. While in operation and the well lifting from station # 5 @ 7654' we estimate the pressure on the perfs to be 1598 psi. CPAI will submit a 10-403 sundry request to patch the off depth perforations in the 4.5" tubing and notes will be made in the 10-407 drilling report addressing the current condition of the tubing and plan forward. Please let me know if you have any questions Perry Klein ~~~ JUN ~ ~ 2D0~ Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, June 19, 2008 12:19 PM To: NSK Well Integrity Proj; Regg, James B (DOA) 6/23/2008 1 D-12 PTD 199-084, Off depth pert Page 2 of 3 • • Cc: Eller, J Gary; NSK Problem Well Supv Subject: RE: iD-12 PTD 199-084, Off depth perf Perry, I think Gary is due to come over in about 45 minutes. It appears that this well is intended to be gas-lifted. Is it intended to lift the well deeper than GLM #5 at 7654'? What is the calculated EMW at the oops perfs with active gas lift lifting from GLM #5? If gas lift were shut down, what is the EMW at the oops perfs? If gas lift pressure were to be blown down on the IA, what does CPA! expect might happen? Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Thursday, June 19, 2008 12:11 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Eller, J Gary; NSK Problem Well Supv Subject: iD-12 PTD 199-084, Off depth perf Tom, 1 D-12 PTD 199-084, gas lift C-sand producer, was reported on 6/17/08 for T X IA communication after squeeze perfs were mistakenly shot off depth. Diagnostics indicate that the shots have penetrated the 7" production casing. Schlumberger has provided a CADE that predicts 4" of penetration past the production casing for the 2", 6 spf big-hole Hyperjet HSD guns. The penetration is into the HRZ shale within the cemented portion of the 7" casing. The design cement top behind the 7" is 7700' MD. Full reciprocation and full returns were achieved throughout the cement job. TVD to the off-depth perforations is 5957 ft. The well does not inflow with a column of diesel. The perforated zone takes fluid at 0.5 bbl per minute with a column of diesel and 2100 psi surface pressure (estimated 4200 psi or 13.5 ppg EMW at the perfs). The well stabilizes with approximately 1600 psi surface pressure and a column of diesel (estimated 3700 psi or 12.0 ppg EMW at the perfs). Just prior to this incident, successful pressure tests had been made on the tubing, packer, 7" casing, and tubing hanger packoff. Please see the supporting test data below. 3/28/08 - TIFL -passed , T-POT -passed, T-PPPOT -passed, IC-POT -Passed, IC-PPOT -Passed, MITOA - Passed, LDS Functional, Initial T/1/O = 165/1325/800. Stung into the T-PO test port with 0 psi. Pressured up the T-PO test void to 4500 psi with hydraulic fluid 15 min reading 4500 psi, 30 min reading 4500 psi. Bled down the T-PO test void to 0 psi. Stung into IC-TP with 0 psi. Pressured up IC-TP test void to 3000 psi with hydraulic fluid 15 min reading 3000 psi. 30 min reading - 3000 psi for a total loss of 0 psi during test. Bled IC TP down to 0 psi. Shut in the WH and GL and shot the initial IA FL @ 4727' sta. # 2 OV. Stacked out the T with LG. Bled down the IA and shot the 2nd IA FL @ the same location. Final T/1/O = 165/1325/750. MITOA-passed. Initial T/I/0= 165/1330/800. Pressure up the OA to 1800 psi. with 1.5 bbls.of diesel. T/I/0= 165/1300/1800. 15 min. T/I/0= 165/1300/1790, 30 min. T/I/0= 165/1300/1790, Bled down the OA. Final T/I/0= 15/1250/500. 6/11/08 -LOADED IA/TBG W/ DIESEL. PERFORMED COMBO MIT TO 2500 PSI- PASS. SET DV @ 4727' RKB & MIT-T 2500 PSIG- PASS. PULLED CAT SV @8491' RKB. PERFORMED 30 min SBHPS @ 9059'=3012 PSI, 157 DEG F. 15 MIN GRADIENT STOP MADE @ 8907'=2970 PSI. 6!15/08 -PERFORATED FROM 8136'-8138' WITH 2" HYPERJET 6SPF HSD GUNS. INFORMED AFTER SHOOTING THAT THE INTENDED INTERVAL WAS 9136'-9138' 6/17/08 -PERFORATE INTERVAL 9136'-9138' WITH 2" HYPERJET 6SPF 60-DEG PHASED HSD CHARGES. SET 2.81" CA-2 BLANKING PLUG @ 8491' RKB, SET 2.72" CATCHER, OAL=88" ON TOP OF PLUG. 6/23/2008 1 D-12 PTD 199-084, Off depth perf Page 3 of 3 6/18/08 -ATTEMPTED CMIT, PUMPING DOWN THE TUBING, UNABLE TO PRESSURE UP TO 2500 PSI ESTABLISH LIQUID LEAK RATE OF 0.5 BBUMIN @ 2100 PSI. CMIT, START T/I/O = 1790/1920/0, 15 MIN T/I/O = 1680/1820/0, 30 MIN T/I/O = 1620/1770/0, 45 MIN T/I/O = 1605/1760/0 BLED T & IA TO 0 PSI FOR DRAW DOWN TEST - T. START T/I/O = 0/0/0. 15 MIN. READING T/1/O = 0/0/0. 30 MIN. READING T/I/O = 0/0/0. Sincerely, Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 6/23/2008 • I ~ ~ .- SARAH PAt/N, GOVERNOR CO~S~j R~MrO ^ ~ I~ 333 W 7th AVENUE, SUITE 100 '~+A~~~~.•••[[[[~iiii t..V Oi` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Gary Eller Wells Engineer ConocoPhillips Alaska Inc. ~~~N~ J U N ~. ~ 2008 PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 D-12 Sundry Number: 308-204 O ~ "! ~~~' Dear Mr. Eller: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided iri AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ,~,~ Chair DATED this l ~ day of June, 2008 Encl. ~~cEw~ • ~.~• STATE OF ALASKA ~'~~ ~~~\ ,JU~ ~ 9 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV~~a Oil & Gay G~ ml~ any) Ancharaga 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^~ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 199-084 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22948-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Yes ^ NO ^~ 1 D-12 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25650 ALK 468 RKB 104' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9250' 6688' 9205' 6659' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121' SURFACE 5537 9-5/8" 5641' 4328' PRODUCTION 8592' 7" 8696' 6323' LINER 706' 3-1 /2" 9248' 6687' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9001'-9031', 9051'-9089', 9171'-9181' 6523'-6543', 6556'-6 582', 6636'-6643' 4-1 /2" L-8~ 8502' Packers and SSSV Type: Packers and SSSV MD (ft) PKR =Baker Retrievable Packer PKR = 8467' SSSV= NIP SSSV= 500' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: June 13, 2008 Oil ^ Gas ^ Plugged ^~ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certi at the foregoing is ue and correct to the best of my knowledge. Contact: Gary Eller Printed Name Ga Eller Title: Wells Engineer Signature C Phone: 263-4172 Date Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry NyKnber: _ G~~ •W~/`~ Plug integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~S OC'7 ~S ~ ~~ °~ ~~ Subsequent Form Required: t,,,~ APPROVED BY I ~~ Approved by: COMMISSIONER THE COMMISSION Date: / Form 10-403 Revised 06/200 ~ ~ ~~~"~. Submit in Du licate • -~ • - --.~ }I~ KRU 1 D-12 1D-12 API: ' 500292294800 Well T e: PROD An le TS: 49 de 9002 ~ TUBING € SSSV Type: Nipple Orig 9/20/1999 Angle @ TD: 49 deg @ 9250 (o-ssoz, OD;4so0, Com letion: ID:3.958) r '. Annular Fluid: Last W/O: 11/18/2003 Rev Reason: TAG Reference Lo Ref Lo Date: Last U date: 4/11/2007 Last Ta : 9166 TD: 9250 ftKB Last Tag Date• 4/R/2n07 Max HnIP Angle• 51 dent n F650 Casin String -ALL ' ~: f .-~-. ~-- ~ . Descrl tlon S¢e To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58. H-40 WELDED SURFACE 9.625 0 5641 4328 40.00 L-80 BTC-MOD PRODUCTION 7.000 0 .'orb' - .26.00 L-80 BTC-MOD LINER 3.500 8546 9248 668 7 9.30 L-80 EUE 8RD . _ ~[ ~ ,.~ ~,F Tubin Strln TUBING_ [ ~ ize T D m TV Botto tti't Grade Thread - _ - ~ - 4.500 0 ~~ , - ___ -- i ~~ 'o L =,i] F_U• 'F;D ~Perforations Summa _ - ~~ Interval TVD Zone Status Ft SPF Date T e Comment 9001 - 9031 6524 - 6543 UNIT 30 6 4/2/2004 APERF 2.5" HSD PJ -a D.C-4 ~ 9051 - c 9064 - c ` i ~ 9065 - £ 9171 - 5 Gas Lift - ~ St MD 1 296 ~ 2 472 . 3 552 'RODUCTION (0-6502, OD:7.000, wrzs.oo) TUBING (8502-6546, OD:3.500) NIP (8538-8539, OD:3.500) SEAL (8546-8547, OD:6.500) ice, VJVV- VJVG l,-Y,l.r-J GY Y 11/V/ IJJJ /"Ir Llll G.J IIV, VI , IVV VGI~ •(-JV de low side 6636 - 6643 C-1 10 4 11/5/1999 IPERF 2.5" HC, DP, 180 deg +/- 90 deq Inw tide e_Is/Valves _ _ _ Man Mfr Man Type ~ V Mfr V Tppe I V OD ~ Latch ~ Port ~ TRO ~ Date Run Vlv 4 6651 4980 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 11/18/200 5 7654 5634 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 11/18/200 6 -8356 6103 CAMCO -- - ..Other 1u s, a ui ., etc KBG-2 DMY 1.0 BK-5 0.000 0 11/26/200 ..) -JEWELRY -POST WORKOVER De th TVD T e Descri lion ID 23 23 HANGER FMC TUBING HANGER 3.958 500 500 NIP CAMCO'DB' LANDING NIPPLE 3.813 8408 6137 NIP CAMCO'DB'NIPPLE 3.750 8446 6162 XO 3.000 8453 6166 PBR BAKER 80-40 3.000 8467 6175 PACKER BAKER RETRIEVABLE PACKER 3.000 8491 6191 NIP CAMCO'DS' NO_GO NIPPLE 2.812 8502 6198 Overshot POOR BOY OVERSHOT 3.750 'Other. lugs, a ui ., etc. -JEWELRY-`ORIGINAL De th TVD T e Descri lion ID 8502 6198 TUBING ORIGINAL TUBING, CHEMICALLY CUT 8502' 2.992 8538 6221 NIP CAMCO D NIPPLE 2.750 8546 6226 SEAL BAKER 80-40 SEAL ASSY 3.000 Tub----~-~Z. 3~1z\ ~~ - `3S4Sf. Mfl, loZZSr Tv fl °~ 3 eP~, ~ ~o, Eut s~~ Perf (9051-9065) Perf (9064-9089) +t ~ ~- ~~~~ ~~~, ~~~. To: GPA Wells Supervisor Date: June 3, 2008 From: Dan Venhaus 263-4372 O, 230-0188 M Gary Eller 263-4172 O, 529-1979 M Subject: 1 D-12 Pre-CTD Sidetrack Prep Wells network: 10171114 The anticipated spud date for Nordic 2 to drill a CTD horizontal sidetrack from well 1 D-12 is June 30, 2008. Objectives: Prep well for a CTD sidetrack by squeezing the C-sand perfs. The purpose is to isolate a thief zone at 9058' MD in the C4 sand. After achieving an adequate squeeze, cement will be drilled out of the 3'/2" liner to accommodate a whipstock. Pre-Rig Work Summary: 1. DHD MIT-IA and OA. (Done 3/28108) 2. DHD PPPOT-T 8~ IC. (Done 3/28/08) 3. DHD PT/DD test on Master & Swab {Done 3/28/08) 4. S Caliper log to PBTD. (Done 4/8/07) 5. S Drift and Tag 6. S Dummy GLVs. 7. S Obtain updated SBHP survey 8. C Cement squeeze perforations with 15.8 ppg cement. See detailed procedure below. 9. C Drill out cement to 9100' MD. Test cement squeeze to 1500 psi. Finish drilling out to 9170' MD. 10. S PU gauge ring for 4%2" tubing. Drift tubing to 8446' MD. 11. O Set BPV. Torque wellhead bolts to spec. 12. O Bleed gas lift and production flowlines down to zero and blind flange 13. O Install secondary swab valve and SSV on the wing or companion 14. O Remove wellhouse, drill mouse hole, level pad NOTES: ~t~J Max DLS in 1 D-12 is 5.6 deg/100ft at 930' Max deviation is 51 ° beginning at 2300' SBHP = 3043 psi @ 8491' MD, 6191' TVD (June 2007) /~ ~~'~ ~ ~1'f'~y i~f1 ~~` ~~ ~ ~ ~.'+ x-, t ~~ 1~ r`~ '' `- ,~ V•"C'~''~1~~~'tt ~ ~' ~/~f' ,(;~5 G ' C_t//~//d;l i `~ ~~_~ sr~~ ~1 D-12 Pre-CTD Procedure a Coil -Cement Squeeze Objective: Isolate thief zone at --9058' MD. Note: Historically it has been difficult to get a successful squeeze on fractured C sand producers. Aggregate is included to help seal off the fracture. In 1 D-12, there is a significant C-4 thief zone at -9058' MD. The thief appears to be associated with a fracture, and the 3'/2" liner is significantly eroded at this depth (see picture below from the caliper of 4/8/07). The remainder of the 3%2" liner is in good condition. 1. MIRU 13/" CTU. Pressure test. MU nozzle BHA: standard 2.5" balldrop nozzle w/jet swirl profile and 5' stinger to CT. Ensure center hole is large enough to prevent aggregate plugging. RIH. 2. Load well with 1.5 times wellbore volume with 140° seawater/KCL water. Maintain sufficient rate (>3 bpm) to sweep any residual gas out of tubing and liner. Limit WHP to 1500 psi (assuming 0.68 psi/ft frac gradient). Monitor annulus pressures while pumping and bleed off as necessary. Max IA & OA pressure should be 2000 psi & 1000 psi respectively. 3. SD pumping and obtain SIWHP. If it is not possible to maintain neither positive wellhead pressure nor steady 1-for-1 returns at surface load the tubing with diesel. 4. RIH and tag bottom while pumping at minimum rate. Flag pipe. Note: Last slickline tag was at 9166' MD on 4/8/07.) PUH above perfs. 5. RU cementers. Perform infectivity test. 6. Mix a pumpable, 25 bbl of 15.8 ppg Unislurry Since this is not akick-off plug, the slurry can be mixed on the fly assuming aggregate can be added consistently. Include 10-12 ppb aggregate to aid in obtaining a squeeze. If batch mixed, bring pod up to weight and shear thoroughly. QC test cement. Send sample to lab for UCA testing. Specs: 3-4 hour thickening time, 90 cc fluid loss, BHT (circulating) = 140° F, BHT (static) = 160° F. Pump the following down the coil: a) water spacer for PT (do not use friction reducer, J313 will clabber cmt) b) 5 bbl neat 15.8 ppg Unislurry 2of3 D-12 Pre-CTD Procedure c) 15 bbls of 15.8ppg Unislurry w/ 10-12 ppb Aggregate d) 5 bbl neat 15.8 ppg Unislurry e) 5 bbl of water f) 1.5# biozan gel for cement clean out 7. Position nozzle 5' above the flagged TD as cement reaches nozzle. Take retums and allow cement top in casing to rise 50' above nozzle before pulling up hole. Verify getting 1:1 returns in 40 bbl open top tank before moving nozzle. POOH laying in cement 1:1 taking returns. 8. Lay in cement 1:1 until nozzle reaches -8700' RKB. Yo-yo pipe and close choke while continuing to pump down CT until a 500 psi pressure bump over baseline injection pressure (recorded instep #5) is observed. At 500 psi over, open choke, and maintain 500 psi over while taking returns laying in cement at 1:1. Notes: 1. Volume of 3%2" liner is 0.0087 bbl/ft. Volume from 9166' to 8700' MD is 4.1 bbl. 2. If no cement is placed behind pipe, 25 bbl of cement will extend from 9166' up to 7200' MD in the 4%2" tubing (i.e. across both packers and 2 GLMs). 3. Deepest TOC is 8770' or -2 bbl above the top perf. If less than 500 psi squeeze pressure develops by this time, bullhead away remaining cement into perfs and perform second squeeze. 9. Position nozzle at cement top just as last barrel of cement reaches nozzle. Pull up hole at maximum speed to safety holding 500 psi over. Once at safety, stage up squeeze pressure to target of 1500 psi in 500 psi increments. Note: If squeeze pressure is not obtained contact town engineering before proceeding. 10. Maintain stable WHP for 30 minutes. Circulate around nozzle at minimum rate to maintain WHP. 11. Slowly bleed pressure down to 300 psi of overbalance (over SIWHP from step 3). Minimize pressure surges while bleeding down WHP and during clean out. 12. Swap to 1'/2# Biozan and launch ball. Chase ball to nozzle then RIH at 1:1 jetting at max CT pressure down to the top perf at 9001' MD. Hold 300 psi overbalance during the cleanout. 13. Swap to friction reduced water. Make 3 down passes and 2 up passes at 80% to ensure both packers (FHL at 8467' and ZXP at 8542' MD) are free of cement. 14. Jet uphole at 80% running speed and max CT pressure. Wash all GLMs, particularly any that had cement laid in across them while performing the squeeze. 15. Freeze protect top 2000' of well bore. Thoroughly wash the tree and BOP stack. Leave well with minimum 500 psi of overbalance. WOC. 16. PU 2.74" D331 diamond speed mill and straight motor. RIH. Drill out cement to 9100' MD. Pressure test C4 perfs to 1500 psi. If pressure test fails, resqueeze. If pressure test is successful, continue drilling out cement to 9170' MD to accommodate the Baker 3%2" monobore whipstock. Circulate clean. 17. Freeze protect top 2000' of well bore. RDMO CTU. 3 of 3 . . ConocJPhillips Alaska RECEIVED AUG 2 9 2007 Alaska ai' & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 SCANNED SEP 0 ß 2007 Jq q -O<ð'4-. . Dear Mr. Maunder: . Enclosed please find a spreadsheet with a list of wells trom the Kuparuk field (KRU). Eac~ of thesë wells was fóund to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCCt this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 19 & 21, 2001. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please can me at 907-659-7043, if you have any questions. ~4~~/ M.J.¿el~d ConocoPhilIips Wen Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date -- ft bbls ft Qal 10-28 204-237 18" N/A N/A N/A 10 8/19/2007 10-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 1 0-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007 10-14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 -1C-11 199-172 - SF NA NA NA .0.5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C-16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199-005 SF NA NA NA 0.5 8/21/20Q7 1 C-24 201-248 20" NA NA NA 11 8/21/2007 1 C-26 199-051 3" NA NA NA 0.85 8/21/2007 1 C-27 199-043 4" NA NA NA 1.7 8/21/2007 1 C-28 205-104 SF NA NA NA 0.5 8/21/2007 1C-117 201-121 26" NA NA NA 12.3 8/21/2007 RECE\VED 09f11 f06 SEP 1 2 2006 Schlumbergel' NO. 3955 ~ Oil & Gas Cons. Commission Anchorage Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth lCJ~ -OoLf Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ')nf\ç, ,., "\ Ç\ ,,'þJ~ 5~~~&:P StJ' :>. 0 Field: Kuparuk Well Log Description Date BL CD Color Job# 2M-35 11213795 LDL 08/16/06 1 1Y-24A 11213786 SBHP 07/25/06 1 2X-12A 11249946 PROD PROFILE W/DEFT 08/25/06 1 1 D-06 11249948 INJECTION PROFILE 08/26/06 1 1 A-1 0 11216318 INJECTION PROFILE 08/28/06 1 1J-184 11249951 PRODUCTION PROFILE 08/29/06 1 1J-127 11249953 PRODUCTION PROFILE 08/31106 1 1 J-170 11249954 PRODUCTION PROFILE 09/01/06 1 1 G-04 11216321 INJECTION PROFILE 08/31/06 1 1 D-12 11216322 PRODUCTION PROFILE 09/01/06 1 2F-06 11216320 FLOWING BHP SURVEY 08/30/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . ~ ..........., Mike Mooney Wells Group Team Leader Drilling & Wells Conoc~ ill i ps P. O. Box 100360 Anchorage. AK 99510-0360 Phone: 907-263-4574 May 13, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 10-12 (APD # 199-084) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the Kuparuk well 1 0-12. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )/t,4~ RECEIVED MAY 14 2004 Alaska Oil & Gas Cons. Commission Anchorage M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad ORIGINAL 1. Operations Performed: ~ ,-.., STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon 0 Alter Casing 0 0 RepairWell 0 Pull Tubing 0 Operat. ShutdownD Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 104' 8. Property Designation: ADL 25650, ALK 468 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: measured 9250' feet true vertical 6688' feet measured 9138' feet true vertical 6614' feet Length Size MD 121' 16" 121' 5537' 9-5/8" 5641' 8592' 7" 8696' 702' 3-1/2" 9248' Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development - 0 Stratigraphic 0 Stimulate 0 Other 0 Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 Service 0 199-084/ 6. API Number: 50-029-22948-00 9. Well Name and Number: 10-12 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 121' 4328' 6323' 6687' RECEIVED MAY 14 2004 Alaska Oil & Gas Cons. Commission Anchorage Measured depth: 9001'-9031',9051'-9089',9171'-9181' true vertical depth: 6524'-6543',6557'-6582',6636'-6643' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 8502' MD. Packers & SSSV (type & measured depth) Baker retriev. Pkr pkr @ 8467' SSSV= NIP SSSV= 500' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 13. Treatment descriptions including volumes used and final pressure: N/A Oil-Bbl 1763 1547 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Representative Daily Average Production or Injection Data Gas-Mcl Water-Bbl 2942 2508 2258 2718 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: oil0 Gas 0 WAG 0 CasinQ Pressure TubinQ Pressure 306 271 Service 0 GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundcy Number or N/A if C.O. Exempt: Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney )J(.}M~ Form 10-404 Revised 04/2004 Title Wells Group Team Leader I Phone Date &: þ:5 ó f IØK)DrL M^Y 1 4. 1~~~ PreoaredbvSharonAlIsuo-Drake263-4612 ORIGINAL Submit Original Only TUBING (0-8502, OD:4.5O0, ID:3.958) 'RODUCTION (0-8502, OD:7.000, Wt:26.00) TUBING (8502-8546. OD:3.500) NIP (8538-8539, OD:3.500) SEAL (8546-8547, OD:6.5O0) Perf (9051-9065) Perf (9064-9089) ",........., ConocbPhitlips Alaska, Inc. 11!)..12 API: 500292294800 SSSV Type: Nipple Annular Fluid: Reference Log: Last Tag: 9138 LastTa,9 Date: 4/212004 ~as}ng SíiìrtQ'~ÄI.t . '. Description CONDUCTOR SURFACE PRODUCTION LINER TubinQìString", TtJBING Size I Top 4.500 0 . I?,erforãtiöhs' SVrtuna ry Interval TVD 9001 - 9031 6524 - 6543 9051 - 9064 9064 - 9065 9065 - 9089 9171 - 9181 6557 - 6565 6565 - 6566 6566 - 6582 6636 - 6643 ~ Well Type: PROD Orig 9/20/1999 Completion: Last W/O: 11/18/2003 Ref Log Date: TD: 9250 ftKB Max Hole Angle: 51 deg @ 6650 Size Top Bottom 16.000 0 121 9.625 0 5641 7.000 0 8502 3.500 8546 9248 Bottom TVD Wt 8502 6198 9.30 KRU Angle @ TS: 49 deg @ 9002 Angle @ TO: 49 deg @ 9250 Rev Reason: PERF, tag fill Last Update: 4/4/2004 TVD Wt Grade Thread 121 62.58 H-40 WELDED 4328 40.00 L-80 BTC-MOD 6198 26.00 L-80 BTC-MOD 6687 9.30 L-80 EUE 8RD I Grade I Thread L-80 EUE 8RD Zone UNIT D,C-4 C-4 C-4 C-4,C-3 C-1 Status Ft SPF Date Type Comment 30 6 4/212004 APERF 2.5" HSD PJ 6 4/212004 RPERF 2.5" HSD PJ 10 4/212004 RPERF 2.5" HSD PJ 4 11/8/1999 APERF 2.5" HC, DP, 180 deg +/- 90 deg low side 4 11/5/1999 IPERF 2.5"HC,DP,180deg+/-90 deg low:;ide 13 1 24 10 Gas UftManörA!iísNJîlvøs . . . St MD TVD Man Man Type V Mfr V Type V OD Latch Mfr 1 2963 2586 CAMCO KBG-2 GL V 2 4727 3734 CAMCO KBG-2 GLV 3 5525 4252 CAMCO KBG-2 OV 4 6651 4980 CAMCO KBG-2 DMY 5 7654 5634 CAMCO KBG-2 DMY 6 8356 6103 CAMCO KBG-2 DMY Other (plugs. eqì.ìiP., ete;).,. JEWELRY- POST WORKOVER ~ Depth TVD Type Description 23 23 HANGER FMC TUBING HANGER 500 500 NIP CAMCO 'DB' LANDING NIPPLE 8408 6137 NIP CAMCO 'DB' NIPPLE 8446 6162 XO 8453 6166 PBR BAKER 80-40 8467 6175 PACKER BAKER RETRIEVABLE PACKER 8491 6191 NIP CAMCO 'DS' NO GO NIPPLE 8502 6198 Overshot POOR BOY OVERSHOT OttIec(pJUQfi,.equip., etc.) -JEWELRY -ORIGINAL" Depth TVD Type 8502 6198 TUBING 8538 6221 NIP 8546 6226 SEAL Description ORIGINAL TUBING, CHEMICALLY CUT @ 8502' CAMCO D NIPPLE BAKER 80-40 SEAL ASSY 1.0 1.0 1.0 1.0 1.0 1.0 BK-5 BK-5 BK-5 BK-5 BK-5 BK-5 Port TRO Date Run 0.156 1315 11/27/2003 0.250 1290 11/27/2003 0.313 0 11/27/2003 0.000 0 11/18/2003 0.000 0 11/18/2003 0.000 0 11/26/2003 1 D-12 Vlv Cmnt ID 3.958 3.813 3.750 3.000 3.000 3.000 2.812 3.750 ID 2.992 2.750 3.000 ",.........., ~ 1D-12 Well Events Summary Date Summary . 03/13/04 TAG FILL @ 9146', DRIFTED TBG W/2.741 II SWAGE-22' X 2.5" DUMMY GUNS TO 9146', NO PROBLEMS. 0 [Tag] 04/02/04 PERFORATED 44' IN THE C4INTERVAL; 9001'-9031' AND 9051'-9065'6 SPF POWERJET -- TAGGED BOTTOM AT 9138' MD.O [Perf] 11/26/03 Schlumberger NO. 3053 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD ( 3H-13A Cllo'-JQ9- PRODUCTION PROFILE 11/08/03 1 3A-09 9? \ ... \ Ct L\ PRODUCTION PROFILE 11/09/03 1 2K-24 c:¿:) 9 ... I ~ SBHP SURVEY 11/10/03 1 2K-25 qn -()f::;¿ SBHP SURVEY 11/10/03 1 1D-12 " QCf ~ 08LI ÌÞLUG SET & SBHP SURVEY 09/11/03 1 , ( -;no'... "'...... ,- ~-.. - '" ,- ~ ~"~rl>t:" Sv t-, , i. \ ~ "i_V ~ "...,_.'... SIGNE~~~\" t j';:~'~ ~^'~ DATE: DEC 2 2 200~ '- /~i~wka Oil &. bé2;) \...r0i1~. ~v' ilIi8~IOL Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Anchort.!ge ~~""- " c::.- ~t/4¡~NE['; Jð~N 2 @ 2004 ~ ~\.~I\\ \...¿~ Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 ~ Anchorage, AK 99510-0360 Cono coPh ill i pS Phone: 907-263-4574 December 16, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 10-12 (APD # 199-084) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 1 0-12. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ¡(J{. ))~ M. Mooney Wells Group Team leader CPAI Drilling and Wells MM/skad RECEIVED JAN 0 () 2004 Alaska Oil & Gas Cons. Commission Anchorage ~ÇMi\!E[:I JAN 2 @ 2004 0 R \ G \ N A L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Suspend D Operation Shutdown D Periorate D Variance D Annular Disp. D Alter Casing D Repair Well 0 Plug Perforations D Stimulate D Time Extension D Other D Change Approved Program D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 199-084/ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22948-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 104' 1 D-12 8. Property Designation: 10. Field/Pool(s): ADL 25650, ALK 468 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9250' feet true vertical 6688' feet Plugs (measured) Effective Depth measured 9130' feet Junk (measured) true vertical 6609' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 5537' 9-5/8" 5641' 4328' PRODUCTION 8592' 7" 8696' 6323' LINER 702' 3-1/2" 9248' 6687' Perioration depth: Measured depth: 9064'-9089',9171'-9181' true vertical depth: 6565'-6582',6636'-6643' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8502' MD. R E eEl VE 0 Packers & SSSV (type & measured depth) Baker retr. Pkr 8467' JAN 0 5 2004 sssv= NIP SSSV= 500' oil. . n:i 0,.. n .... 12. Stimulation or cement squeeze summary: \TIT UI. UQð \.lUll;). \.11,1111 Anchorage Intervals treated (measured) N/ A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation 1017 1070 1864 - 224 Subsequent to operation 1619 1682 2814 - 305 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD 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 Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team leader Signature JJ:i< ¡ÅmhOAA. Phone Date 1-:z./:z..ZJP3 1'1/. 1Y1"", Pr¡:¡nsred bv Sharon AI1,~un-DrAke 263-4612 ,----'" Form 10-404 Revised 2/2003. 0 RIG I N A L ~Ji18 SUBMIT IN DUPLICATE ~ 9Ft JAM 0 1 - ConocoPhilUpsAlaska, Inc. KRU 1 D-12 1D.12 PROD 9/20/1999 11/18/2003 Comment 2.5" HC, DP, 180 deg +/- 90 de low side 9171 - 9181 6636 - 6643 C-1 10 4 11/5/1999 ¡PERF 2.5" HC, DP, 180 deg +/- 90 de low side St MD TVD Man Man Type V Mfr V Type VOD Latch Port Date Vlv Mfr Run Cmnt 2963 2586 CAMCO KBG-2 GLV 1.0 BK-5 0.156 1315 11/27/2003 4727 3734 CAMCO KBG-2 GLV 1.0 BK-5 0.250 1290 11/27/2003 5525 4252 CAMCO KBG-2 OV 1.0 BK-5 0.313 0 11/27/2003 6651 4980 CAMCO KBG:.2 DMY 1.0 BK-5 0.000 0 11/18/2003 7654 5634 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 11/18/2003 8356 6103 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 11/26/2003 Descri tion ID FMC TUBING HANGER 3.958 CAMCO 'DB' LANDING NIPPLE 3.813 CAMCO 'DB' NIPPLE 3.750 2.992 BAKER 80-40 3.000 BAKER RETRIEVABLE PACKER 3.000 CAMCO 'OS' NO GO NIPPLE 2.812 POOR BOY OVERSHOT 3.750 Descri tion ID ORIGINAL TUBING CHEMICALLY CUT 8502' 2.992 CAMCO D NIPPLE 2.750 BAKER 80-40 SEAL ASSY 3.000 TUBING (8502-8546, 00:3.500) ; I Legal Well Name: 1 0-12 Common Well Name: 10-12 Spud Date: 9/6/1999 Event Name: WORKOVER/RECOMP Start: 11/17/2003 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours.. Code Sub Description of Operations Code 11/17/2003 06:00 - 11 :30 5.50 MOVE RURD MOVE Release rig. prepare for move to 1 D pad. 11 :30 - 13:00 1.50 MOVE MOVE MOVE Begin move from 1 C-1 D. Stby for aircraft. 13:00 . 22:00 9.00 MOVE RURD MOVE AOL. begin spot equip on 1 D-12. Accept rig at 22:00 hours. Pre-spud at 22:00 hours. 22:00 - 00:00 2.00 WELLS RIGUP Pull tree. Install test plug. Build Bop stack. Load pipe shed w/4 1/2". 11/18/2003 00:00 - 06:30 6.50 WELLS RIGUP Install Bop's on well head. Prep for Bop test. Load pipe shed. Drift new 41/2" pipe & install new seal rings. 06:30 - 14:00 7.50 WELCT RIGUP BOP test. Grease choke manifold. RE-due kill line to get pressure to hold. Change out needle valves. Blow all iron and hoses down for freze protect. Load pipe shed. ' 14:00 - 14:30 0.50 WELCT RIGUP Pull blanking plug. Check mud weight in pits. 9.6# 14:30 - 15:30 1.00 WELCT RIGUP Bleed gas cap off of WHP. 200# SIWHP. 15:30 - 16:00 0.50 WELCT RIGUP Pull BPV, prep to stab landing joint. 16:00 - 17:00 1.00 WELLS DECOMP Pre-spud with new crew. 17:00 - 21 :00 4.00 WELLS DECOMP Stab in landing joint for pull. Lose LDS Prep for pull. UP WT = 180,000# no movement. Continue to cycle pipe then hold in tension. Call Anchorage and discuss with Smalstig, Worthington, and Mooney. 21 :00 - 22:45 1.75 WELLS CIRC DECOMP Circulate 9.6 brine in 9.5 out. Spot e-line prep for possible string shots and cut. Continue to cycle pipe up and down with and without jogging motions. 22:45 - 23:45 1.00 WELLS DECOMP Install Schlumberger E-line equip to completion string for a string shot across seal asym. 23:45 - 00:00 0.25 WELLS DECOMP Schlumberger's packoff assym will not screw into the male thread of the pump in sub provided by Schlumberger. Deadhorse to deliver a new collar that will match the threads. 11/19/2003 00:00 - 02:00 2.00 WELLS EaRP DECOMP Stand by for Schlumberger to deliver the right collar for there new pump in sub. 02:00 - 02:20 0.33 WELLS RURD DECOMP Install new collar for Schlumberger to rig up to 3 1/2" completion string. Begin RIH. 02:20 - 03:45 1.42 LOG ELOG DECaMP Run tie in log. Shoot string shot from 8554-8566'. No downhole indication of tubing movement. POOH 03:45 - 04:15 0.50 LOG ELOG DECOMP OOH w/ E-Line prep to RBIH for String shot across chemical cut area. 04:15 - 08:00 3.75 LOG ELOG DECOMP Shoot string shot across chemical cut area of 8502-8514. POOH for chemical cutter. LD string shot tools. 08:00 - 09:00 1.00 LOG RURD DECOMP MU full bore TIW valve on landing joint for chemical cutter. Work pipe several times up to 180K#, no change, no movement. Set pipe on slips holding 15K# to 20K# over string weight. 09:00 - 12:00 3.00 LOG ELOG DECOMP PJSM. MU 2-5/8"OD chemical cutter. RIH & tie in. Cut tubing at 8512' (referenced to Completion Detail), in middle of full joint above 2.75" D-Nipple. Good indication of cut in E-line unit and on rig floor. POOH. LD chemical cutter tools, recovered all parts. 12:00 - 12:45 0.75 WELLS PULD DECOMP Pull tubing hanger to rig floor, appear to have clean cut, no overpull to pull free, 72K# PU weight. LD 3-1/2" FMC tubing hanger. LDLJ. Finish RD SWS equipment. Well static. 12:45 -16:00 3.25 WELLS CIRC DECOMP MU TIW valve with head pin and hose. Circulate once around, 3 BPM, 270 psi, 9.6 ppg brine in & out. Monitor well, slow u-tube out tubing. Mix & pump slug. Blow down lines. 16:00 - 18:00 2.00 WELLS PULD DECOMP POOH, LD 3-1/2" tubing & jewelry. Strap out. 45 joints LD @ 1800 hrs. 18:00 - 00:00 6.00 WELLS PULD DECOMP POOH, LD 3.5" tubing & jewelry. Strap all pipe. 265 joints LD @ 00:00 11/20/2003 00:00 - 00:15 0.25 CMPL TN PULD DECOMP Continue to pull 3.5" completion. Inspect chemical cut. Chemical periect. Prep to run 4.5" completion. 00:15 - 01 :15 1.00 CMPL TN PULD DECOMP OOH, Inspect chemical cut. Prep for PBOS.Strap all jewelry and rabbit. Printed: 12/15/2003 2:45:59 PM Legal Well Name: 1 0-12 Common Well Name: 10-12 Spud Date: 9/6/1999 Event Name: WORKOVER/RECOMP Start: 11/17/2003 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 38 Rig Number: 56dbe Phase Description of Operations 11/20/2003 01 :15 - 03:00 1.75 CMPL TN RUNT CMPL TN Drift 3.5" jewelry to 2.867" RIH with PBOS and Camco 2.813" D.S. Nip. 03:00 - 06:30 3.50 CMPL TN RUNT CMPL TN Shift change. Stop at GLM# 5 for shift change. 06:30 - 23:00 16.50 CMPL TN RUNT CMPL TN Run 4 1/2" completion. Displace 30 BBLS of inhibited sea water into the IA. Set Baker FHL packer @ 8,483'. Shear out of PBR. Prepare space out pups. Add a 5.23' space out pup for landing. Land completion. 23:00 - 00:00 1.00 CMPL TN SOHO CMPL TN Pt tubing to 2,500 PSI. PT IA to 2,500#. Shear out SOV. 11/21/2003 00:00 - 06:00 6.00 CMPL TN NUND CMPL TN Lay down landing joint. Empty pipe shed. Account for all joints, 21 joints sent to pipe racks, 269 in hole. Blow down all lines for freeze protect. Set BPV. Nipple dwn BOP's Prep to install tree. 06:00 - 08:00 2.00 CMPL TN NUND CMPL TN Presure test tree to 5,000#. Pressure test pack off to 5,000#. Pull BPV. Prep for Brine recovery, with freeze protect. Called Night lead DSO for clocking of tree. DSO agreed to face the flow line flange towards pipe rack. 08:00 - 13:00 5.00 CMPL TN FRZP CMPL TN Set BOP's outside. Displace well with sea water recovering Brine. Freeze protect both IA and tubing to 2,700' by U-TUBE. 13:00 - 16:00 3.00 CMPL TN NUND CMPL TN Continue to let well U- TUBE. Install BPV Blow down all rig lines. Release rig (16:00 HRS.) Printed: 12/15/2003 2:45:59 PM 03/19/03 Schlumberger NO. 2705 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 2T-27 ' C/5~' 3,~n' TEMPERATURE LOG 01/01/03 1 1B-12c~)! ~-0~ ~ INJECTION PROFILE 03~04~03 1 1C-135 / ~c~O INJECTION pROFILE 02/26/03 1 1D-12 i ~ ~" O~ PRODUCTION PROFILE " 03/05/03 1 1F-19 /~-[).~. LEAK DETECTION LOG 02/08/03 1H-07 / ~ - ~ LEAK DETECTION LOG 02/15/03 , ,, ,, , , , ,, ... , . ,,, ...... REC SIGN ~ DATE: ~,~.~ ~ 5 2005 Alas.ka Oil & Gas Cons. Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 199-084-0 KUPARUK RIV UNIT Roll #1: Start: Stop Roll #2: MD 09250 ..... TVD 0~.6__6~8~;, Completion Date: 1D-12 50- 029-22948-00 PHILLIPS ALASKA INC Start j Stop ~9 Completed Status: l-OIL_ ..... Current: ............... T Name D 9084 L'''/'/' 1-4 L DGR/CTN-MDJ'' FINAL L DGR/CTN-TVD ~'"~' FINAL L DGR/EWR4-MD ~ FINAL L DGR/EWR4-TVD ~/'~INAL L PERF/STAT BHP~-''''~' FINAL R SRVY RPT ~'"'" ,, Interval Sent Received SPERRY MPT/GR/EWR4/CNP/SLD OH 12/16/99 12/16/99 8600-9250 OH 2/5 1/11/00 1/11/00 6322-6688 OH 2/5 1/11/00 1/11/00 250-9250 OH 2/5 1/11/00 1/I1/00 290-6688 OH 2/5 1/11/00 1/11/00 8475-9214 11/5/99 CH 5 11/18/99 11/30/99 SPERRY 0-9250. OH 10/20/99 10/28/99 T/C/D wednesday, June 20, 2001 ' Page 1 of 1 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax.' (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 ,. Dear Ms. Mahan: Please find reposed below the volumes injected into surhce casing by"~¥0duction c~sing annuli during the third queer of 2000, as well as tot~ volumes injected into annuli for which injection authorization expired during the third queer of 2000. Annular Injection during the third quarter of 2000: h(1)' h(~) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 CD1-03 33505 100 0 33605 385 33990. 1D-14 33916 100 0 34016 1487.5 35503.6 CD1-25 24860 100 0 24960 8627 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 c:t."t, lc) ! Ms. Wendy Mahan AOGCC Third Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the third quarter 2000: Total "' Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD1-39 31408 100 0 31508 Open, Freeze Protected 1D-12 32791 100 0 32891 Open, Freeze Protected CD1-37 32487 100 0 32587 Open, Freeze Protected CD 1-23 33886 100 0 33986 Open, Freeze Protected CD1-01 5121 100 0 5221 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC-' Marry Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 24, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Revised Kuparuk Area Annular Injection, Fourth Quarter, 1999 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 1999, as well as total volumes injected into annuli for ~vhich injection authorization expired during the fourth quarter of 1999. Annular bijection during tile fourth quarter of 1999: h(1) ! h(2) I h(3) Total for i Previous New Well Name Volume [ Volume Volume Quarter Total Total CD1-37 15214 ~ 100 0 15314 [ 17273 32587 CD1-39 27391 [ 100 0 27491 4017 31508 1D-12 27089 ~ 100 I 0 27189 5702 32891 CDI-16 28925 100I 0 29025 ~ 0 29025 CD1-32 7449, 100 0 7549I 0 7549 CD1-03 285 ! 100 0 385 [ 0 385 CD 1-42 287 i 100 0 387 ] 0 387 I CD1-40 20 ! 0 0 20 I 32649 132669 CD1-45 274 i 100I 0 374i 0 I 374 CD1-36 293 ! 100 . 0 393 i 0 393 CD1-35 217 I 100 I 0 317 0 317 CD1-23 20 [ 0.! 0 20 . 17085 17105 CDI-13 89 I 100 t 0 189 i 0 189 CDI-01 20 I 0 [ 0 20 5201 15221 , I Total Volumes into Annuli for which bzjection Authorization Expired during the fourth quarter I Total Total h(1) Total h(2) I Total h(3) Volume Well Name Volume , Volume ] Volume Injected ] Status of Annulus 2N-315 25326 I 100 i 0 25426 Open, Freeze Protected 2L-329A 33971 i 100 0 34071 i Open. Freeze Protected 2L-325 20280 100 0 20380 Open, Freeze Protected 2L-313 12433 i 100 i 0 12533 Ms. Wendy Mahan AOGCC Fourth Quarter 1999 Annular Injection Report Page Two Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snod~ass Morrison and Winfree Sharon Allsup-Drake Well Files WELL LOG TRANSMITTAL To: t o ask January 11, 2000 ~dtlaas~a fo6fl1 an~taGas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1D-12, AK-MM-90151 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ Jim Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-12: 2"x 5"MD Resistivity & Gamma Ray Logs: 50-029-22948-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22948-00 2" x 5" MD Neutron & Density Logs: 50-029-22948-00 2" x 5" TVD Neutron & Density Logs: 50-029-22948-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia .l_Blueline 1 Folded Sepia 1Blueline 1 Folded Sepia REGEt ED Gas Cons. 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 A Halliburton Company z ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 22, 1999 1Vh'. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-12 (Permit No. 199-84) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1D-12. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Drilling Engineering Supervisor Kuparuk Drilling GCA/skad ORIGINAL RECEIVED DEC 28 1999 Anchorage '- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [] Gas [] Suspended [] Abandoned [] Service [] 2. Name of Operator i7. Permit Number ARCO Alaska, Inc. 99~84 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~ .... ~ 50-029-22948 4. Location of well at surface . !~ ~- h 9. Unit or Lease Name 224' FSL, 594' FEE, Sec. 14, T11 N, R10E, UM . At Top Producing Interval .' 10. Well Number 460' FSL, 224' FEL, Sec. 13, T11N, R10E, UM - ~~ Ii lB-12 At Total Depth .~..' . . 474' FSL, 39' FEL, Sec. 13, T11 N, R10E, UM ' ~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 105 feetI ADL 25650 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions I September 6, 1999 September 18, 1999 September 20, 1999 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 9250' MD/6688'TVD 9205' MD/6659'TVD YES [] No []I N/A feetMD 1685' 22. Type Electric or Other Logs Run GR/Res/Neu Dens 23. CASING, LINER AND CEMENTING RECORD SE-'I-FING DEPTH MD J CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 115' 20" 230 sx AS I 9.625" 40# L-80 Surface 5641' 12.25" 676 sx Class G Lead, 600 sx Class G Tail 7" 26# L-80 Surface 8696' 8.5" 210 sx Class G 3.5" 9.3# 8rd EUE 8541' 9248' 6.125" 164sx 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) 3.5" 8542' 8542' 9064'-9089' MD 6565'-6582' TVD 4 spf 9171'-9181' MD 6636'-6643'TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A ~_7. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) November 9, 1999 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 11/25/1999 12.0 Test Period > 1290 5961 0 176I 5134 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. 320 psi 0 24-Hour Rate > 2580 11921 0 23.8° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH 9002' 9185' 9250' 925O' 6524' 6645' 6688' 6688' 30. FO RMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOB, and time of each phase. RECEIVED Oil & O0n Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call William Lloyd 265-6531 Signed ,~~'-- .~ (~~ Title Drillinq Engineering Supervisor Date G. C. Alvord INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 10/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-12 WELL_ID: AK0027 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:09/06/99 START COMP: --_ RIG:POOL 6 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22948-00 08/24/99 (D1) TD/TVD: 0/0 SUPV:FRED HERBERT 08/25/99 (D2) TD/TVD: 0/0 SUPV:FRED HERBERT 08/26/99 (D3) TD/TVD: 0/0 SUPV:FRED HERBERT 08/27/99 D4) TD/TVD: 0/0 SUPV:FRED HERBERT 08/28/99 D5) TD/TVD: 0/0 SUPV:FRED HERBERT 08/29/99 D6) TD/TVD: 0/0 SUPV:FRED HERBERT 08/30/99 (D7) TD/TVD: 0/0 SUPV:FRED HERBERT MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) CONTINUE W/ RIG DOWN OPERATION FOR NON STANDARD RIG MO Prepare derrick and top drive to be layed down. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) RIGGING DOWN Skid rig into position to remove 'C' section, remove. Remove sidewalls, top drive beam off derrick and landing. Skid rig into place and lock down rig. Lower derrick. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) MOVE RIG, SET MAT'S Remove doghouses, remove derrick. Remove pipe rack. Remove drawworks, BOPE equipment. Remove pits. Remove substructure. Hold PJSM. Move rig from lC to iD pad. Sub module broke thru road approx. 300 yds off pad. Jack up rig and put cribbing under it. Work on getting sub module out of hole. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) MOVE RIG Continue with rig move f/lC to iD pad. Road wet & soft. Continue mat laying & moving. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) MOVE RIG Continue w/rig move. Work rig up on double mats. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 (0) MOVE RIG Block up under sub module. Move sub module. Move motor module. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 ( 0) MOVE RIG Continue to move both modules. RECEIVED Date: 10/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/31/99 (D8) TD/TVD: 0/0 SUPV:FRED HERBERT MW: 0.0 VISC: ( 0) MOVE RIG 0 PV/YP: 0/ 0 Continue to move both modules. APIWL: 0.0 09/01/99 (D9) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 0/0 ( 0) MAT ROAD TO iD LOCATION SUPV:FRED HERBERT, M. WINFREE Cribbing up under sub module attempting to back up after falling through mats. Backed up 100' Move rig down double matted road. 09/02/99 (D10) TD/TVD: 0/0 SUPV:FRED HERBERT MW: 0.0 VISC: 0) RIGGING UP RIG 0 PV/YP: 0/ 0 APIWL: 0.0 Move sub module to iD pad. Unload trucks. Rig up motor module. 09/03/99 (Dll) TD/TVD: 0/0 SUPV:FRED HERBERT MW: 0.0 VISC: ( 0) RIGGING UP Continue to rig up. 0 PV/YP: 0/ 0 APIWL: 0.0 09/04/99 (D12) TD/TVD: 0/0 SUPV:FRED HERBERT MW: 0.0 VISC: ( 0) RIGGING UP Continue to rig up. 0 PV/YP: 0/ 0 APIWL: 0.0 09/05/99 (D13) TD/TVD: 115/115 SUPV:FRED HERBERT MW: 0.0 VISC: ( 115) NIPPLE UP DIVERTER Continue to rig up. 0 PV/YP: 0/ 0 APIWL: 0.0 09/06/99 (D14) TD/TVD: 115/115 SUPV:FRED HERBERT MW: 8.8 VISC: 238 PV/YP: 41/55 0) DRILLING AHEAD . DEPTH 435' APIWL: 7.6 Rig accepted @ 0200 hrs. Function test diverter. Wash to 115' Drilling from 115' to 138' 09/07/99 (D15) MW: 10.2 VISC: 144 PV/YP: 44/36 APIWL: 6.6 TD/TVD: 1832/1787 (1717) DRILLING 0 1985' SUPV:R.W. SPRINGER/MOOSE CUNNINGHAM PJSM. Drill from 138' to 205' Ball mill plugged w/surface gravel. Drill from 205' to 1832' 09/08/99 (D16) MW: 10.2 VISC: 144 PV/YP: 39/41 APIWL: 5.0 TD/TVD: 3850/3162 (2018) SHORT TRIP SUPV:R.W. SPRINGER/MOOSE CUNNINGHAM PJSM. TIH. Circ & cond. mud. Drill from 1837' to 3850' RECEIVED 28 ' 999 Cons. Commission Anchorage Date: 10/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 09/09/99 (D17) MW: 10.3 VISC: 166 PV/YP: 46/38 APIWL: 4.8 TD/TVD: 3850/3162 ( 0) DRILLING SURFACE ~ 4883' SUPV:R.W. SPRINGER/MOOSE CUNNINGHAM Drilled from 3850' to 3994' Circ f/short trip. POH to HWDP, swabbing from 2200'-2020', circ out 2020-1930', POH swab ~ 1130', RIH, tight from 2000'-2100' Drilled from 3994'-4706' Penetration slow, circ hole clean f/bit trip, monitor well. POH f/bit, wet pipe, pull slowly to prevent swabbing. Change out bit. 09/10/99 (D18) MW: 10.3 VISC: 154 PV/YP: 40/44 TD/TVD: 5651/4334 (1801) RUN 9.625" SURF. CASING SUPV:R.W. SPRINGER/MOOSE CUNNINGHAM PJSM. Drill from 4706' to 5651' APIWL: 4.8 09/11/99 (D19) MW: 10.2 VISC: 62 PV/YP: 18/24 APIWL: 6.6 TD/TVD: 5651/4334 ( 0) BOPE TEST SUPV:R.W. SPRINGER/MOOSE CUNNINGHAM PSJ. Run 9-5/8" casing. PJSM. Pump cement. Clean out cement f/flowline. 09/12/99 (D20) MW: 8.5 VISC: 38 PV/YP: 9/10 APIWL: 8.8 TD/TVD: 5671/4347 ( 20) DRILLING ~ 6350' SUPV:R.W. SPRINGER/MOOSE CI/N-NINGHAM PJSM. Test BOPE to 300/3000 psi. Wash down 47', tag float collar ~ 5557' Test 9.625" casing. Drill out float equipment & cement from 5577' to shoe ~ 5637', Drill cement from 5637' to 5651'. Drill from 5651' to 5671' PJSM. Perform FIT, 14# EMW. 09/13/99 (D21) MW: 9.0 VISC: 39 PV/YP: 11/12 TD/TVD: 7700/5681 (2029) DRILLING @ 8135' SUPV:R.W. SPRINGER/MOOSE CUNNINGHAM Drilled from 5671'to 7700' APIWL: 5.8 09/14/99 (D22) MW: 9.2 VISC: 42 PV/YP: 37/24 APIWL: 5.2 TD/TVD: 8721/6338 (1021) POOH TO RUN CASING SUPV:R.W. SPRINGER/S.D. REYNOLDS Drill from 7700' to 8642'. Perform OH LOT, EMW=12.5 ppg. Drill from 8642' to 8721' 09/15/99 (D23) MW: 9.3 VISC: 43 PV/YP: 14/13 TD/TVD: 8721/6338 ( 0) PREPARING TO TEST BOPE. SUPV:R.W. SPRINGER/S.D. REYNOLDS PJSM. Run 7" casing. APIWL: 5.4 09/16/99 (D24) MW: 10.7 VISC: 47 PV/YP: 27/20 APIWL: 4.8 TD/TVD: 8721/6338 ( 0) RIH P/U DRILLPIPE. SUPV:R.W. SPRINGER/S.D. REYNOLDS Install packoff and test to 3000 psi. NU BOPE and test. R CEiYED Oil & Gas Co~s. Commission Anchorage Date: 10/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 09/17/99 (D25) MW: 10.7 VISC: 50 PV/YP: 24/20 APIWL: 4.5 TD/TVD: 8989/6516 (268) DRLG ~ 9145', MWD FAILURE SUPV:R.W. SPRINGER/S.D. REYNOLDS Drilled cement from 8583', float collar ~ 8604, cement and float shoe ~ 8690' Drilled out rathole & 20' new hole to 8741' Perform FIT to 14.0 ppg EMW. Drilled from 8741' to 8989' 09/18/99 (D26) MW: 10.9 VISC: 52 PV/YP: 27/20 APIWL: 3.8 TD/TVD: 9250/6688 (261) PREPARING TO CEMENT LINER. SUPV:R.W. SPRINGER/S.D. REYNOLDS Drilled from 8989' to 9145'. LWD tool failure, attempt to restart tool, unsuccessful. Drilled from 9145' to 9250' PJSM. Run 3.5" liner. 09/19/99 (D27) MW: 11.0 VISC: 54 PV/YP: 28/20 APIWL: 3.6 TD/TVD: 9250/6688 ( 0) SPACING OUT COMPLETION SUPV:R.W. SPRINGER/S.D. REYNOLDS Continue to RIH w/3.5" liner. PJSM. Pump cement. PJSM. Run 3.5" completion. 09/20/99 (D28) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9250/6688 ( 0) MIRU ON 1D-14 SUPV:R.W. SPRINGER/S.D. REYNOLDS Continue RIH w/3.5" tubing completion. Freeze protect well. ND BOP's. NU tree and test. Release rig @ 2200 hrs. 9/20/99. RECEIVED D £C 2 8 1,999 ARCO Alaska, Inc. KUPARUK RIVER UNIT ,k, WELL SERVICE REPORT '~ K1(1D-12(W4-6)) WELL JOB SCOPE JOB NUM'BER ' " 1 D-12 DRILLING SUPPORT-CAPITAL 1005990545.1 DATE DAILY WORK UNIT NUMBER 11/05/99 PERFORATING & SHBP 2145 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 7 YESI YES SWS-STEPHENSON SCHUDEL FIELD AFC# CC# Signed ESTIMATE 999325 230DS10DG InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann , Initial Outer Ann , Final Outer Ann 500 PSI 650 PSI 550 PSI 600 PSII 10 PSI 0 PSI DAILY SUMMARY IPERFORATED FROM 9171'-9181' WITH 2.5" HSD @ 4 SPF & 180 DEG PHASINGSBHP @ 8900' = 3465#, SBHP @ 9176'=3545#. TAG PBTD AT 9215' ELM.[Perf] TIME 07:30 07:50 09:00 09:30 09:45 10:45 11:30 12:00 12:10 13:00 13:15 LOG ENTRY DEPART FOR 1D-12 ARRIVE ON LOCATION - HOLD SAFETY MEETING - START RIG UP CALL FOR RADIO SILENCE PRESSURE TEST TO 3000# RIH WITH CCL / MPE) / SAFE / 10' 2.5" HSD @ 4 SPF & 180 DEG PHASING TAG PBTD @ 9205', NO COLLARS TO TIE INTO - POOH RIG DOWN GUN RIG UP PSP RIH WITH CCL / GR / TEMPERATURE / PRESSURE LOG JEWELRY - TAG PBTD @ 9215' LOG STATION LOG @ 9171' FOR HYDROSTATIC PRESSURE @ PERFORATION ZONE (2799 PSI & 158 DEG F) 13:20 POOH 14:00 RIG DOWN PSP 14:25 RIG UP GUN 14:40 RIH WITH 10 FOOT 2.5" HSD @ 4 SPF & 180 PHASING 15:20 LOG TIE IN PASS ACROSS JEWELRY 15:30 LOG TIE IN PASS OVER SHOOTING ZONE 15:35 LOG INTO SHOOTING POSITION & PERFORATE FROM 9171'- 9181' WITH 550 PSI UNDERBALANCE (WHP = 50 PSI). BHP FROM JEWELRY LOG RUN WAS 2800# W/0# WHP. PRESSURE INCREASED TO 100# WHP IMMEDIATELY AFTER SHOT 15:40 POOH 15:42 AT 8000' PUH. WHP AT 250#. RECEIVED TIME LOG ENTRY 16:30 RIG DOWN GUN 16:40 RELEASE RADIO SILENCE 16:45 WAIT FOR PSP TO WARM UP 17:10 LOG LUBRICATOR STOP 17:25 RIH WITH PSP 18:20 LOG TIE IN PASS- TAG PBTD @ 9214' 18:30 LOG SBHP @ 9176' - PRESSURE = 3545 PSI 18:55 LOG SBHP @ 8900'- PRESSURE = 3465 PSI 19:15 POOH 20:00 LOG SBHP IN LUBRICATOR 20:15 START RIG DOWN 21:15 COMPLETE RIG DOWN - LEAVE LOCATION 21:30 RETURN TO KCC ~Otl & -6= Cons. C~'t¢on ~chorage ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~, WELL SERVICE REPORT '' K1(1D-12(W4-6)) WELL JOB SCOPE JOB NUMBER " 1 D-12 PERFORATIONS-E-LINE 1107991818.12 DATE DAILY WORK UNIT NUMBER 11/08/99 ADPERF 9064-9089' 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES SWS-ELMORE SCHUDEL FIELD AFC# CC# Signed ESTI MATE 999325 230 DS 10 DG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 1300 PSI 1200 PSI 600 PSI 600 PSII 0 PSI 0 PSI DAILY SUMMARY I PERF 9064-9089' (25') W/1 RUN 2-1/2"HC, DP, 4 SPF, 180 DEG PH, +/- 90 FROM LOW SIDE. NO PUMP-IN REQ'D[Perf] TIME LOG ENTRY 07:00 ON LOC. TGSM, DISCUSSED RU IN HIGH WIND. 08:00 PT TO 3000# 08:15 RIH AT 12000 FPH, NO OBSTRUCTIONS, NO ICE 09:30 TIE-IN TO 11-4-99 IPERF LOG. 10:15 SHOOT 9064-9089' INTERVAL. GOOD WT INDICATION WHEN FIRED. WHP DROPPED FROM 1300 TO 1200#. PUH. 11:00 AT SURFACE 11:45 RD, MOVE TO 2F-16 IPROF. RECEIVED Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1D, Slot D-12 1D-12 Job No. AKMM90151, Surveyed: 18 September, 1999 SURVEY REPORT 20 October, 1999 Your Ref: AP1-500292294800 Surface Coordinates: 5959888.87 N, 560490.53 E (70° 18' 03.5208" N, 149° 30' 36.2434" W) Kelly Bushing: 104.30fl above Mean Sea Level RECEIVED , ()CT 2 8 1999' sper',r~-sum Survey Ref: svy8878 Sperry-Sun Drilling Services Survey Report for 1D- 12 Your Ref: API-500292294800 Job No. AKMM90151, Surveyed: 18 September, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -104.30 115.00 0.000 0.000 10.70 204.82 0.110 191.520 100.52 297.75 0.520 130.130 193.45 386.32 2.580 98.370 281.98 474.22 4.010 102.040 369.73 572.57 2.440 97.920 467.93 663.51 0.660 59.350 558.83 754.79 0.470 93.050 650.11 847.05 2.390 87.360 742.33 932.64 7.200 91.810 827.60 1024.14 9.440 89.530 918.13 1117.30 10.300 90.410 1009.91 121'3.73 12.500 90.280 1104.43 1306.42 14.970 89.940 1194.47 1399.07 16.260 86.840 1283.70 1494.39 18.940 85.730 1374.55 1589.63 22.300 86.520 1463.67 1683.05 23.950 86.250 1549.58 1779.47 27.590 86.320 1636.40 1871.73 30.980 86.580 1716.86 1967.06 35.610 87.430 1796.52 2062.15 38.400 87.530 1872.45' 2160.80 42.280 87.210 1947.62 2247.98 46.100 87.000 2010.12 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 5959888.87 N 560490.53 E 115.00 0.00 N 0.00 E 5959888.87 N 560490.53 E 204.82 0.08 S 0.02 W 5959888.79 N 560490.51 E 297.75 0.44 S 0.29 E 5959888.43 N 560490.82 E 386.28 0.99 S 2.57 E 5959887,90 N 560493.11 E 474.03 1.92 S 7.53 E 5959887.01 N 560498.08 E 572.23 2.93 S 12.97 E 5959886,05 N 560503.52 E 663.13 2.93 S 15.34 E 5959886.07 N 560505.89 E 754.41 2,68 S 16.16 E 5959886.32 N 560506.71 E 846163 2.61 S 18.46 E 5959886.41 N 560509.01 E 931.90 2.70 S 25.61 E 5959886.38 N 560516.16 E 1022.43 2.82 S 38.85 E 5959886.36 N 560529.40 E 1114.21 2.81 S 54.81 E 5959886.50 N 560545,37 E 1208.73 2.93 S 73.87 E 5959886.54 N 560564.42 E 1298.77 2.96 S 95.88 E 5959886.68 N 560586.43 E 1388.00 2.24 S 120.80 E 5959887.61 N 560611.34 E 1478.85 0.35 $ 149.55 E 5959889.73 N 560640.08 E 1567.97 1.90 N 183.01 E 5959892.24 N 560673.52 E 1653.88 4.22 N 219.63 E 5959894.85 N 560710.12 E 1740.70 6.93 N 261.45 E 5959897.90 N 560751.92 E 1821.16 9.72 N 306.49 E 5959901,06 N 560796.93 E 1900.82 12.43 N 358.73 E 5959904.19 N 560849.15 E 1976.75 14.94 N 415.91 E 5959907.16 N 560906.30 E 2051.92 17.88 N 479.69 E 5959910.61 N 560970.06 E 2114.42 20.95 N 540.36 E 5959914.17 N 561030.71 E Alaska State Plane Zone 4 Kuparuk 1D Dogleg Vertical Rate Section (°/lO0ff) (fi) Comment 0.00 0.000 0.00 0.122 -0.02 0.514 o.27 2.433 2.52 1.644 7.44 1.613 12.83 2.163 15.20 0.410 16.03 2.084 18.33 5.632 25.47 2.474 38.69 0.937 54.64 2.282 73.68 2.666 95.66 1.658 120.59 2.833 149.40 3.540 182.92 1.770 219.61 3.775 261.51 3,677 306.62 4.881 358.94 2.935 416.16 3.939 480.01 4.385 54o.77 Continued... 20 October, 1999 - 14:00 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-12 Your Ref: API-500292294800 Job No. AKMM90151, Surveyed: 18 September, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 2345.73 48.300 2438.58 49.270 2532.28 49.270 2626.85 47.750 2720.95 49.690 2811.24 49.280 2904.95 49.210 2998.49 49.420 3094.55 48.760 3193.89 49.120 3284.68 50.250 3377.30 49.510 3474.73 48.940 3569.13 49.990 3662.31 49.240 3758.11 49.410 3848.76 48.890 3942.29 49.400 4039.43 48.980 4133.77 50.100 4221.92 49.740 4314.47 49.260 4408.81 49.470 4503.65 48.720 4595.25 49.630 Azim. 87.89o 87.460 89.770 90.090 90.070 89.310 89.580 89.290 89.190 88.670 87.570 87.570 87.840 87.370 88.170' 87.370 86.690 88.110 86.900 87.570 86.530 87.060 87.490 87.630 87.88o Sub-Sea Depth (ft) 2076.54 2137.71 2198.86 2261.51 2323.58 2382.24 2443.42 2504.40 2567.3O 2632.56 2691.30 2750.98 2814.61 2875.96 2936.33 2998.77 3058.07 3119.25 3182.74 3243.96 3300.71 3360.82 3422.26 3484.36 3544.24 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 218o.84 24.14 N 612.01E 5959917.93 N 561102.33 E 2242.01 26.97 N 681.80 E 5959921.33 N 561172.09 E 2303.16 28.69 N 752.77 E 5959923.62 N 561243.05 E 2365.81 28.78 N 823.61E 5959924.28 N 561313.88 E 2427.88 28.68 N 894.32 E 5959924.75 N 561384.59 E 2486.54 29.05 N 962.96 E 5959925.67 N 561453.23 E 2547.72 29.74 N 1033.94 E 5959926.93 N 561524.20 E 2608.70 30.44 N 1104.87 E 5959928.20 N 561595.12 E 2671.60 31.40 N 1177.46 E 5959929.75 N 561667.70 E 2736.86 32.80 N 1252.35 E 5959931.75 N 561742.58 E 2795.60 35.08 N 1321.54 E 5959934.58 N 561811.74 E 2855.28 38.08 N 1392.30 E 5959938.16 N 561882.48 E 2918.91 41.03 N 1466.02 E 5959941.71 N 561956.18 E 2980.26 44.04 N 1537.70 E 5959945.28 N 562027.83 E 3040.63 46.80 N 1608.62 E 5959948.62 N 562098.73 E 3103.07 49.63 N 1681.23 E 5959952.03 N 562171.30 E 3162.37 53.18 N 1749.70 E 5959956.13 N 562239.75 E 3223.55 56.38 N 1820.37 E 5959959.91 N 562310.39 E 3287.04 59.58 N 1893.82 E 5959963.70 N 562383.81E 3348.26 63.04 N 1965.51 E 5959967.73 N 562455.47 E 3405.01 66.51 N 2032.87 E 5959971.74 N 562522.80 E 3465.12 70.45 N 2103.14 E 5959976.25 N 562593.03 E 3526.56 73.85 N 2174.65 E 5959980.22 N 562664.51 E 3588.66 76.90 N 2246.26 E 5959983.85 N 562736.10 E 3648.54 79.62 N 2315.52 E 5959987.12 N 562805.34 E Alaska State Plane Zone 4 Kuparuk 1D Dogleg Vertical Rate Section (°/100fi) (fi) Comment 2.348 612.48 1.101 682.33 1.868 753.31 1.627 824.08 2.062 894.73 0.785 963.32 0.231 1034.26 0.325 1105.16 0.692 1177.72 0.536 1252.60 1.550 1321.82 0.799 1392.65 0.622 1466.43 1.175 1538.17 1.037 1609.15 0.658 1681.80 0.807 1750.37 1.271 1821.11 1.037 1894.63 1.304 1966.40 0.991 2033.85 0.677 2104.22 0.411 2175.81 0.799 2247.49 1.015 2316.80 Contlnue~.. 20 October, 1999 - 14:00 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-12 Your Ref: API-500292294800 Job No. AKMM90151, Surveyed: 18 September, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 4692.90 48.840 88.030 3608.00 4784.48 49.950 87.680 3667.61 4878.56 49.270 85.890 3728.57 4973.25 49.570 85.980 3790.17 5068.37 48.940 85.870 3852.25 5160.86 49.030 86.750 3912.95 5257.26 50.010 86.680 3975.53 5351.47 50.300 87.780 4035.89 5446.46 49.910 87.800 4096.82 5541.93 49.290 87.700 4158.69 5598.30 49.330 87.020 4195.44 5711.19 48.850 89.290 4269.38 5803.53 49.990 87.700 4329.45 5899.03 50.120 87.190 4390.76 5992.64 49.460 86.830. 4451.20 6086.82 48.790 86.600 4512.83 6179.93 49.640 87.830 4573.65 6272.32 50.540 87.900 4632.93 6365.67 50.010 88.810 4692.59 6460.49 49.370 88.120 4753.93 6555.25 50.310 88.790 4815.04 6650.05 50.860 87.860 4875.23 6744.64 50.400 88.890 4935.24 6837.71 50.140 87.530 4994.72 6930.69 49.790 88.620 5054.54 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3712.30 82.26 N 2389.43 E 5959990.36 N 562879.22 E 3771.91 84.86 N 2458.91E 5959993.52 N 562948.68 E 3832.87 88.87 N 2530.45 E 5959998.11 N 563020.18 E 3894.47 93.97 N 2602.19 E 5960003.79 N 563091.87 E 3956.55 99.09 N 2674.07 E 5960009.49 N 563163.71 E 4017.25 103.58 N 2743.71E 5960014.54 N 563233.32 E 4079.83 107.78 N 2816.91E 5960019.33 N 563306.48 E 4140.19 111.28 N 2889.16 E 5960023.40 N 563378.70 E 4201.12 114.09 N 2961.98 E 5960026.80 N 563451.50 E 4262.99 116.94 N 3034.63 E 5960030.24 N 563524.12 E 4299.74 118.91 N 3077.33 E 5960032.55 N 563566.80 E 4373.68 121.66 N 3162.59 E 5960035.99 N 563652.04 E 4433.75 123.51 N 3232.69 E 5960038.40 N 563722.12 E 4495.06 126.78 N 3305.83 E 5960042.26 N 563795.24 E 4555.50 130.51 N 3377.22 E 5960046.56 N 563866.59 E 4617.13 134.59 N 3448.32 E 5960051.21 N 563937.65 E 4677.95 138.01 N 3518.73 E 5960055.20 N 564008.04 E 4737.23 140.65 N 3589.55 E 5960058.41 N 564078.83 E 4796.89 142.71 N 3661.32 E 5960061.05 N 564150.58 E 4858.23 144.64 N 3733.60 E 5960063.57 N 564222.84 E 4919.34 146.59 N 3805.99 E 5960066.10 N 564295.21E 4979.53 148.74 N 3879.19 E 5960068.83 N 564368.40 E 5039.54 150.81N 3952.29 E 5960071.50 N 564441.47 E 5099.02 153.05 N 4023.83 E 5960074.31 N 564512.99 E 5158.84 155.44 N 4094.97 E 5960077.27 N 564584.12 E Alaska State Plane Zone 4 Kuparuk 1D Dogleg Vertical Rate Section (°ll00ff) (fi) Comment 0.817 2390.76 1.246 2460.28 1.619 2531.93 0.325 2603.82 0.668 2675.85 0.724 2745.62 1.018 2818.94 0.948 2891.27 0.411 2964.15 0.654 3036.85 0.917 3079.59 1.578 3164.89 1.798 3235.01 0.431 3308,22 0.764 3379.71 0.735 3450.91 1.354 3521.41 0.976 3592.28 0.940 3664.06 0.874 3736.36 1.130 3808.77 0.954 3882.00 0.972 3955.11 1.158 4026.68 0.973 4097.87 Continued... 20 October, 1999 - 14:00 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-12 Your Ref: API-500292294800 Job No, AKMM90151, Surveyed: 18 September, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 7025.88 49.570 88.600 5116.13 7115.55 49.440 89.110 5174.36 7210.79 49.170 87.320 5236.46 7304.39 48.900 86.790 5297.83 7398.65 48.690 87.020 5359.92 7490.23 47.980 86.310 5420.80 7584.71 48.470 87.720 5483.74 7678.33 48.490 86.870 5545.80 7773.10 47.880 86.800 5608.99 7868.38 48.170 85.490 5672.71 7963.94 47.870 86.840 5736.63 8061.32 47.460 87.570 5802.22 8151.83 47.640 88.070 5863.31 8247.22 48.380 88.700 5927.12 8343.01 48.740 86.910 5990.52 8437.40 50.000 85.370 6051.99 8532.41 50.380 85.930 6112.82 8564.43 50.270 85.670 6133.26 8630.58 49.040 87.390 6176.08 8788.09 48.820 84.910 6279.57 8884.58 48.880 85.820 6343.07 8979.79 49.450 87.220 6405.33 9074.96 48.070 88.530 6468.06 9175.22 48.700 82.920 6534.68 9250.00 48.700 82.920 6584.03 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 5220.43 157.20 N 4167.53 E 5960079.62 N 564656.66 E 5278.66 158.56 N 4235.71 E 5960081.53 N 564724.82 E 5340.76 160.81N 4307.88 E 5960084.36 N 564796.97 E 5402.13 164.44 N 4378.46 E 5960088.55 N 564867.52 E 5464.22 168.27 N 4449.27 E 5960092.95 N 564938.30 E 5525.10 172.25 N 4517.57 E 5960097.48 N 565006.57 E 5588.04 175.91N 4587.93 E 5960101.71N 565076.90 E 5650.10 179.22 N 4657.95 E 5960105.58 N 565146.88 E 5713.29 183.12 N 4728.47 E 5960110.05 N 565217.37 E 5777.01 187.88 N 4799.14 E 5960115.38 N 565288.01 E 5840.93 192.64 N 4870.02 E 5960120.71 N 565358.84 E 5906.52 196.15 N 4941.92 E 5960124.80 N 565430.71E 5967.61 198.69 N 5008.65 E 5960127.87 N 565497.42 E 6031.42 200.69 N 5079.52 E 5960130.44 N 565568.27 E 6094.82 203.44 N 5151.27 E 5960133.77 N 565640.00 E 6156.29 208.27 N 5222.74 E 5960139.18 N 565711.42 E 6217.12 213.80 N 5295.51 E 5960145.30 N 565784.15 E 6237.56 215.61 N 5320.09 E 5960147.30 N 565808.71 E 6280.38 218.67 N 5370.41 E 5960150.76 N 565859.01 E 6383.87 226.63 N 5488.87 E 5960159.69 N 565977.40 E 6447.37 232.51 N 5561.29 E 5960166.14 N 566049.77 E 6509.63 236.87 N 5633.19 E 5960171'.09 N 566121.63 E 6572.36 239.54 N 5704.70 E 5960174.32 N 566193.12 E 6638.98 245.14 N 5779.39 E 5960180.53 N 566267.76 E 6688.33 252.06 N 5835.14 E 5960187.90 N 566323.45 E Alaska State Plane Zone 4 Kuparuk 1D Dogleg Rate (°/lOOff) Vertical Section (ft) Comment 0.232 0.456 1.453 0.516 0.289 0.968 1.228 0.680 0.646 1.066 1.096 0.696 0.454 0.918 1.450 1.821 0.604 0.713 2.717 1.195 0.713 1.263 1.782 4.229 0.000 4170.43 4238.60 4310.80 4381.48 4452.39 4520.80 4591.25 4661.34 4731.97 4802.78 4873.79 4945.78 5012.56 5083.45 5155.25 5226.86 5299.81 5324.44 5374.85 5493.54 5566.14 5638.17 5709.72 5784.59 5840.58 PROJECTED SURVEY Continued... 20 October, 1999 - 14:00 - 5- DrlllQuest Sperry-Sun Drilling Services Survey Report for 1D-12 Your Ref: API-500292294800 Job No. AKMM90151, Surveyed: 18 September, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1D AlI data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 87.527° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9250.00ft., The Bottom Hole Displacement is 5840.58ft., in the Direction of 87.527° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9250.00 6688.33 252.06 N 5835.14 E PROJECTED SURVEY 20 October, 1999 - 14:00 - 6- DrillQuest WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 16, 1999 1D-12, AK-MM-90151 1 LDWG formatted Disc with verification listing. API#: 50-029-22948-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRAN$MtZt~AL LETTEP~-T4MglI~~Og:: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchoraze_Alasl~a t~I~ Date: ,.qa~ 0il & ~aa CXna~. C,~m~ ~ Signed:. f · 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company Scklumkerger NO. 12948 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1D-12 PERFORATION RECORD & SBHP 991105 I 1 2F-16 L, Lt eL__ INJECTION PROFILE 991108 I 1 2M-15 PRODUCTION PROFILE 991110 I 1 2M-21 PRODUCTION PROFILE 991109 I 1 2.-345 PRODUCT,ON PROFILE W/PSP 991104 1 1 2N-345 DE~ W/PSP 991104 1 1 1D-,~ i~-~ ~ 99404 SCMT 991004 I I 1 ~~ ..... '/~a<~/~ ~'n~.~ '~ 0 3999 SIGNED: I i~~t~t DATE= ~~~ Please sign and r urn e copy o s ransmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 11 / 18/99 20-0ct-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-12 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 9,250.O0' MD (if applicable) RECEIVED 1999 ~ 0il & Gas 0~.P,,ommil~n Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company ARCO Alaska, Inc. ' . Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 22, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Revised Kuparuk Area Annular Injection, Third Quarter, 1999 Dear Ms. Mahan' RECEIVED OCT 2 5 1999 Alaska Oil & Gas Cons. CommissJ.on Anchorage Please find reported below the revised volumes injected into surface casing by production casing annuli during the third quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 1999. We corrected the 1D-12 volumes due to one report that was sent in late from the field office. On September 28, 1999, an additional 1297 bbls was injected into the 1D-12 annulus. Annular lnjectim~ during the third quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 1C-25 520 100 0 620 34316 34936 CD1-40 20079 100 0 20179 12171 32350 CD1-01 4905 100 0 5005 0 5005 1C-23 24865 100 0 24965 9605 34570 CD1-23 16079 100 0 16179 0 16719 CD1-37 17173 100 0 17273 0 17273 -- CD1-39 3917 100 0 4017 0 4017 1D-12 5602 100 0 5702 0 5702 Total Volumes into Am~uli for which Injection Authorization Expired during the quarter Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus ID-09 32540 100 0 32640 Open, Freeze Protected 2N-337A 30539 100 0 30639 Open, Freeze Protected 2N-313 32758 100 0 32858 Open, Freeze Protected 2N-321A 27507 100 0 27607 Open, Freeze Protected Please call me at 263-4603 should you have any questions. .~erely, Paul Mazzolir}i at> Drilling Team Leader ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re' Kuparuk Area Annular Injection, Third Quarter, 1999 Dear Ms. Mahan' Please find reported below volumes injected into surface casing by production casing annuli during the third quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 1999. Annular Iqjection during the third quarter of 1999: Well Name 1C-25 CD1-40 CDI-O1 1C-23 CD1-23 CD1-37 h(1) Volume 520 20079 4905 24865 [6079 17173 h(2) Volume 100 100 100 100 100 100 h(3) Volume Total for Quarter 620 20179 5005 24965 16179 17273 I Previous[ New Total I Total 34316 [ 34936 12171 i 32350 0 [ 5005 9605 [ 34570 0 16719 17273 4017 CD1-39 3917 ~ 100 0 4017 ' 0 1D-12 4305 ~ 100 , 0 4405 ! 0 ! 4405 Total Volumes into Amzuli for which b~jeclion Authorization Expired during the quarter Well Name 1D-09 Total h(1) Volume 32540 Total h(2) Volume 100 Total h(3) Volume Total Volume Injected 32640 Status of Annulus Open, Freeze Protected 2N-337A 30539 100 0 30639 Open, Freeze Protected I 2N-313 , ~_738 100 ~ ' ~'~ ' 0 32858 Open, Freeze Protected 2N-321A ~ 27507 100 0 27607 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader 0il & Gas Cons. Commissmn -~ncnora~ CC' Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental' Engel / Snodgrass Momson and Winfree Sharon Allsup-Drake Well Files Ms. Wendy Mahan AOGCC Third Quarter 1999 Annular Injection Report Page Two ARCO Alaska, Inc. Post Office Box 100360 Anohorage, Alnska 99510-0360 Telephone 907 276 1215 Scptcmbcr 24, 1999 Mr. Blair Wondzell State of Alaska Alaska Oil & Ga~ Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-12 Annular Injccti{m Sundry Dear Mr. Wondzell' 1'his letter is to provide additional inlbrmation you requested h~r the sundxT application for annular injection for ID- 12. The maximum volume of fluids to be pumped down thc annulus of this well will not exceed 35,000 bbl as stipulated in AOCrCC's regulation 20 AAC 25.080. The maximum anticipated injection pressurc is 1500 psi. Drilling fluids we anticipate will be in. jectcd include drilling mud, drilling cuttings, reserve pit fluids, cement-contaminated drilling mud, completion fluids and fmmation fluids associated with the act of drilling a well permitted under 20 AAC 25.005. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Drilling Team Leader A. AI Drilling PM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _X Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Injection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 35' feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 224' FSL, 594' FEL, Sec. 14, T11N, R10E, UM 1D-12 At top of productive interval 9. Permit number/approval number 460' FSL, 256' FEL, Sec. 13, T11 N, R10E, UM (proposed) 99-84 At effective depth 10. APl number 50-029-22948 At total depth 11. Field / Pool 469' FSL, 53' FEL, Sec. 13, T11 N, R10E, UM (proposed) Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured 9250' feet Plugs (measured) true vertical 6688' feet . Effective depth: measured 9250' feet Junk (measured) true vertical 6688' feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 85' 16" 230 sx ASl 120' 120' Surface 5606' 9.625" 676 sx Class G Lead 5641' 4327' 600 sx Class G Tail Production 8661' 7" 210 sx class a 8696' 6322' Liner 9213' 3.5" 164 sx c~ass a 9248' 6687' Perforation depth: truemeasured N/Avedical N/A O~/G/~4/ SEP 2. Tubing (size, grade, and measured depth 3.5", 9.3¢, EUE Mod @ 9248' AI~ 0il & Gas Packers & SSSV (type & measured depth) Baker SLZXP LT packer @ 8542', No SSSV Anchorage 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: October 1, 1999 16. If proposal was verbally approved Oil X Gas__ Suspended __ Name of approver Date approved Service__ 17. I hereby certify tha~th.¢, foregoing is true and correct to the beast of my knowledge. Questions? Ca//Wil/iam Lloyd265-6531 Signed Title: Drilling Engineering Supervisor Date · Prepared b~, Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approvah Notify Commission so representative may witness I Appr°valn~-~'"''/8~--~ Plug integrity_ BOP Test __ Location clearance__ Mechanical Integrity Test__ Subsequent form required 10- _r~.~ Appr0vec~ by order of the Commission Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE [^ Casing Detail 9. 625' Surface Casing ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL: 1 D- 12 DATE: 09/09/99 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LR = 34.60' TOPS Above RKB 9 5/8" Landing Joint 34.60 FMC GEN IV- Kuparuk 9 5/8" Csg Hgr 1.96 34.60 jts 122-146: its. 3-121 jts 1-2 9 5/8", 40#, L-80 BTC (25 its) 965.30 36.56 TAM 7 5/8" Port Collar 2.98 1001.86 4555.09 1004.84 9 5/8", 40#, L-80 BTC (119 its) Gemeco Float Collar 9 5/8", 40#, L-80 BTC (2 its) Gemeco Float Shoe Casing shoe @ T.D. @ 5651' leaving 10.00' of rathole 1.41 77.84 1.70 37 Gemeco Bow Spring CENTRALIZERS, 2 ridgid centralizers & 5 stop collars Run centralizers in center of Jts. 1, 2 over stop collars J and over casing collars on Jts. 3-34 and over stop collars of its 121 & 122 &it 144 5559.93 5561.34 5639.18 5640.88 Remarks: String Weights with Blocks: 325k Up, 160k Dn, 68k Blocks. Ran 146 joints of casing. Drifted casing with 8.679" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Pool 6 Drilling Supervisor: R, W. SPRINGER/D,J. CUNNINGHAM ARCO Alaska, Inc. Cementing Details Well Name: 1D-12 Report Date: 09/11/99 Report Number: 19 Rig Name: Pool 6 AFC No.: AK0027 Field: KRU I Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: % washout: 9-5/8 12-1/4 49 5641I 5560 Centralizers State type used, intervals covered and spacing Comments: 37 BOW SPRING, 2 RIDGID, JTS 1-35, 121,122,144 Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.2 48 18I 46 24 CIRC XTRA AWAITING Gels before: Gels after: Total Volume Circulated: ARRIVAL OF ADDITIONAL 22/82 12/16 3 CSG VOLUMES (1200 BBL) VACUMN TRUCKS. Wash 0 Type: Volume: Weight: Comments: ARCO B47 23.6 BBL 8.34 Spacer 0 Type: Volume: Weight: Comments: ARCO B45 47.4 BBL 10.5 Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: Weight: Yield: Comments: GI 70 676 10.7 4.44 Additives: th ixotrop D53(30%bwoc), antifoam D46 (.6%bwoc), extender D79(1.5%bwoc), acc S001(1.5%bwoc), extender(D124(50%bwoc), accelerator D44(9%bwoc) Tail Cement 0 Type: I Mix wtr tamp: No. of Sacks: Weight: Yield: Comments: GI 70 600 15.8 1.17 Additives: antifoam D48 (.2%bwoc), dispersant D65 (.3%bwoc), accelerator S001 (l.0%bwoc) Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 8 bpm 4 bpm 325 displaced w/rig pumps Reciprocation length: Reciprocation speed: Str. Wt. Down: bumped plug & pressured up 10' I stkJmin 130 to 500 psi over (2100 psi) & held fl5 min. Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 401.5 403.5 Calculated top of cement: CP: Bumped plug: I Floats held: cement to surface Date:9/11/99 yesI Yes Time:1840 hr Remarks:CiRC 3+ CSG VOLUMES AWAITING ARRIVAL OF VACUMN TRUCKS DUE TO FIELD SHUTDOWN/MAINTENANCE. Cement Company: DS IRig Contractor: POOL Approved By: R.W. SPRINGER CASING TEST and FORMATION INTEGRITY TEST Well Name: 1 D-12 Reason(s) for test: Date: 09/18/1999 Supervisor: S.D. REYNOLDS [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7" X 9-5/8" CASING ANNULUS Casing Setting Depth: 5,641' TMD 4,334' TVD Mud Weight: 9.3 ppg Length of Open Hole Section: Hole Depth: 7,696' TMD 5,662' TVD 2,055' EMW = Leak-off Press. + Mud Weight = 1,150 psi + 9.3 ppg 0.052 x TVD 0.052 x 5,662' EMW for open hole section = 13.2 ppg Pump output = 0.0197 bps Fluid Pumped = 5.4 bbl 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi -- 300 psi 200 psi 1 O0 psi 0 psi STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE , ................ .-. ................ ~ ................. ~ , ................. ~ ............... .~ ................. -. .... .o__9_._r9_!~- ....... 9__s__t_k__s_ ......... .o__p._sj_ .......................... .q__s_t._k.s____] ..... .o__p__s! ..... 0.5 min 25 stks 400 psi 0 min 50 stks 750 psi .... _' .......... J ................ .L ................. i____2_:_s__~!_"_ ..... ! .a. 9_ _s_ _t .k_ .s_ ..... ~9__p_s_! .... ___.3=9___m_!P_ ..... J_ _5. 9_ .s_ _t .k_ .s_ ..... _9__3_9___P_S_! .... 3.5 min 175 stks 920 psi 4.0 min 200 stks 900 psi L__.4_..5___m_!_n_ ..... _2__2__s__s__t_k__s_ ..... &o_.o_._p_s_! .... ................ ~ ................ + ................. .4 i ................ J ................ .~ ................. .~ .J .L .z i ................................................. 5.0 min 250 stks 900 psi , I SHUT IN TIME SHUT IN PRESSURE = 0.0min 0psi SHUT IN TIME SHUT IN PRESSURE, -- -- -----[__3_-O_min 0.0 rain 900 psi 2.0 min 3.0 min 4.0 min ................ .., ................ .~ ................. 5.0 rain 6.0 min i ................ J ................ .~ ................. 7.0 min i ................................. 1. ................. / 8.0 min 9.0 min 10.0 min 4.0 min 5.0 min 6.0 min '---~:-6-~i'~ ...................................... 8.0 min ................. i., ............... -i ................. -i 9.0 min 10.0 min ................. ~. ................~ .................J 15.0 min 20.0 min 25.0 min , 30.0 rain ' NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1 D-12 Date: 9~22~99 Supervisor: S.D. REYNOLDS Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7" X 9-518" CASING ANNULUS Casing Setting Depth: 5,641' TMD Hole Depth: 7,696' TMD 4,334' TVD 5,662' TVD Mud Weight: 8.3 ppg Length of Open Hole Section: 2,055' EMW = Leak-off Press. + Mud Weight 0.052 x TVD -- 1,300 psi + 8.3 ppg 0.052 x 5,662' EMW for open hole section = 12.8 ppg Pump Rate: 0.79 bpm Fluid Pumped = 7.9 bbl 1,500 1,400 1,300 1,200 1,100 1,000 9OO 800 700 6OO 500 400 300 200 100 0 psi pSI psi psi ps1 / Dsl psi ,,, ! : ONEMINUTE TICKS = LEAK-OFF TEST --a--CASINO TEST ......... ~.~,..... LOT SHUT IN TIME -~*--CASING TEST SHUT IN TIME ~ TIME LINE .... BARe, ELSc ~ LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ___.0._._5___m_Ln- ....... _o:~_b_~!?_ ....... .4__0.o._.p_.s!.._ 1.0 min 0.8 bbls 600 psi 1.5 min 1.2 bbls 800 psi 2.0 min 1.6 bbls 1,000 psi , ---'~:~'-F~B- ...... ~:if~i~i;' ...... i-,igO"~;i ................................... ? .................. .... .3__9___m_!_n- ...... _2:.4_?_!?_ ...... _t,.2..qg_?.s.~_ .................................... ,,, .............. .. 3.5 min 2.8 bbls 1,250 psi i ',.: ~ ................ -~- ................ -~ .................. 4 ~' ................ -*- ............... -~- ............... 4.0 min 3.2 bbls 1,300 psi , 5.0 min 4.0 bbls 1,300 psi 6.0 min 4.7 bbls 1,290 psi ~ ................ .+. ................ .~ .................. 6.5 min 5.1 bbls 1,290 psi 7:b"~iF,' ...... [i:ii'~iii;' ...... .z.-.s...m_!.a_...L_...~-?.~ L~. ...... ].,.z..s_.°.P_?.L_, .... .a...o...m_!_n_ ...... .~...~R!?. ...... .']_,.z_ R _o.P_.s.L_. 8.5 min 6.7 bbls 1,290 psi .... §~B--Fri~Ff --""---i":§-~iij~- ...... ~-,-~-~-~i[--, ..................................................... ! ! 10.0 rain 7.9 bbls 1,290 psi SHUT IN TIME SHUT IN PRESSURE 0.0 min : 0 psi : , '-"~.'O"r~i'r~' .................. T ................. ~ ~ .................................. + ................. -I SHUT IN TIME ' SHUT IN PRESSURE 3.0 min : ,~ ........... .- ..... I- ................ ~ ............... .---',~ ........... .- ..................... ~ ................. : 0.0m~n : i 1,290ps~ : 4.0m~n : 2.0 min : ! 1,100 psi 6.0 min i .... -~:[:)--r~[~---T ................ i---i-,~iib"~;i ....... Y;b"r~[ff .................. T .................. .... .4...o_..m.[_n_._.L ................ j.._.~.,.o..6..O__p_.s.!__! .... _8. ._ _o__ .m_ i. .n__ _ ; ............... _L .................. 5.0min i i 1,050psi 9.0min : l " ........... :' ..... " ................ '~ ............... :*-'"" ............ ,"'--I- ............... ~ ................. " 6.0 m~n : : 1,050ps~ 10.0 m~n : .... 7:~"~i,:,'"T ................ i'"i',ii~'ii'~i'-' . ................................ , ................. I .... §:b"F~iff-":' ................ !'"¥,'6§~-'~;i'" 20.0 min : ............ : ..... r ................ t ............... r--t ," ............ :' .... I ................ -f- .................. 9.0m~n : : 1,050ps~ : : 25.0m~n : : [iii! _ZgiiSCCiiiiiiiiiiiiiiiiii]iii)iai . ii _ E] [Z; EoZ. !CtiiZiiiiiiiiiiT' iiiiiZiZZii] NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' Robert Christenson,~,¢, A DATE' Chairman September 16, 1999 THRU: Blair Wondzell, ~ FILE NO: aa5kipgf, doc P. I. Supervisor '~/~-~[~? ChuckSchev,¢ SU. CT: Petroleum Inspector BOPE Test Pool 6 KRU 1D-12 PTD # 99-84 Thursday, September 16, 1999: I traveled to Arco's KRU 1D-12 well being drilled by Pool Rig 6 and witnessed the weekly BOPE test. -- As the attached AOGCC BOPE test report indicates, the test lasted 4 hours with no failures. The lower pipe rams were not tested at this time due to the length of the cross over subs from the test plug to the test joint. These rams were tested in conjunction with the casing test after the drilling assembly was run in the hole. The rig was clean and all related equipment appeared to be in good working order. The location though crowded was well organized allowing good access to the rig. Summary: I witnessed the weekly BOPE test on Pool Rig 6 drilling Arco's 1D-12 Well. Pool 6, 9116199, Test time 4 hours, no failures Attachment: aa5kipgf, xls X Unclassified -- Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: Pool Rig No. 6 PTD # ARCO Rep.: 1 D-12 Rig Rep.: 7" Set @ 8,691 Location: Sec. Weekly X Other TEST:DATA 99-84 DATE: 9/16/99 Rig Ph.# 659/7562 Ray Springer Jimmy Greco 14 T. 11N R. 10E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES ,- Standing Order Posted YES Well Sign OK Drl. Rig OK Hazard Sec. OK - BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I 250/2500 P 1 250/3500 P 1 250/3500 P 1 25O/35O0 P 2 250/3500 P 1 250/3500 P N/A FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/3500 P I 250/3500 P 1 250/3500 p 1 250/3500 P CHOKE MANIFOLD: No. Valves 15 No. Flanges 30 Manual Chokes 1 Hydraulic Chokes 2 Test Pressure P/F 250/350011 P 250/35001 ! P Functioned I P Functioned I P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 20 sec. Trip Tank OK OK System Pressure Attained 2 minutes 10 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: OK Flow Indicator OK OK Nitgn. Btl's: 6 @ 2000 Psi Meth Gas Detector OK OK · Psig. H2S Gas Detector OK OK" 2900 1600 Number of Failures: 0 ,Test Time: ~ours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 ~ Notify the Inspector and follow with ~-'~'ten or Faxed verification to ttle AOCCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Lower pipe rams not tested at this time due to length of cross over subs. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve FI-021L (Rev.12/94) aa5kipgf.xls ~$/12/95 07:1~P P,~i MEMORANDUM State of Alaska AlaSka Oil and Gas Conservation Commission TO: Robert Christenso~/,~ DATE: September 12, 1999 Chairman THRU' BlairWondzell, ~ FILE NO: aa5gilgf. DOC P. I. Supervisor ol/I.3 Lawrence M Wad~~4- Petroleum Inspector FROM' SUBJECT: BOP Test Poole 6 KRU 1 D-12 PTD 99-84 September 12,1999: I traveled to Kupurak to witness a BOP test on Poole 6 which is drilling a well on 1D pad. Nordic 3 is also on the pad but the pad is still in orderly shape. The rig looked clean and in good shape after the one week it took to move from 1C. The roads on the slope are suffering from budget restraints and the time it takes for rig moves reflects it. The BOP test went well. We had a leak on the bottom flange and the graylock clamp. SUMMARY: Witnessed the BOP test on Poole 6, 3.5 hours, 0 failures. Attachments: aa5gilgf.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Poote ~ Rig No. § PTD # 9g-84 Operator: ARCO Rep.: Well Name: 1D~12 Rig Rep.' Casing Size: 9,5/8' Set @ 5640' Location: Sec. 14 T. 1~N Test: Initial X Weekly Other Test Pressures DATE: ~/12./9g Rig Ph.# 65g-7562 Ray SpMnger Jim David$on R. 10E Meridian Umiat 300t3000 Test MISC. INSPECTIONS: Location Gen.' ok Housekeeping' ._.o../( .... (Gan) PTD On Location X Standing Order Posted Well Sign Drl, Rig Hazard Sec. FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. 1 , , 1 1 Pressure P/F 3O0/3O00 P 300/3000 P 300/3000 300/3000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves 2 Kill Line Valves Check Valve n/a Quan. Test Press, 300/2500 300/'3000 300/3000 I 300/3000 300/3000 300/300O ...... : .... ~: .~ ~...._._ 30023000 PIF P P P P CHOKE MANIFOLD: No, Valves 20 ,I No. Flanges 40 I Manual Chokes , Hydraulic Chokes 2 Test Pressure P/F 300/3000 P 300/3000 P Functioned Functioned ACCUMULATOR SYSTEM: , System Pressure 2,900 J Pressure After Closure Ir 550 ! MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 25 sec. Tdp Tank ok ok System Pressure Attained 2 minutes 30 sec. Pit Level Indicators ok' ok Blind Switch Covers: Master: X Remote: X Flow Indicator ok ok Nitgn. Btl's: 1900-2000.2000 Meth Gas Detector ok ok 2000-2000-2000 Psig. H2S Gas Detector ok ok · ----:-:-- -~-- i Number of Failures: 0 ,Test Time: 3,5 Hours, Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with wriff'en or Faxed verification to the AOGCC Commission Office at: Fax Nc;. 276-7542 Inspector North Slope Pager No, 659-3607 or 36B7 If your call i~ not returned by the inspector within 1:2 hours please contact the P. I, Supervisor at 279-1433 REMARKS: Grayiock on boEom of rams had to be tightened. Distribution: odg-Well File c - Oper.IRig c - Database c - Trip Rpt File c - Inspector FI-O21L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO ___ ' I I I I I Waived By: Witnessed By: I aaSgilgf, xls Larr~ Wade TONY KNOWLE$, E;OVEF~NOFI ALASKA OIL AND GAS CONSERVATION COHHISSION September 3. 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Graham Alvord Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Unit 1 D- 12 ARCO Alaska. Inc. Permit No: 99-084 Sur Loc: 224'FSL. 594'FEL. Sec. 14. T11N, RIOE, UM Btmhole Loc. 469'FSL. 53'FEL. Sec. 13. T11N, R10E. UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1 D-12. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site ID must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through the annular space ora single well or to use that well for disposal purposes for a period longer than one .,,'ear. Bloxvout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witncss a test of BOPE installed prior to drilling new hole. Notice ma5' be given by contacting thc Commission petroleum field inspector on the North Slope pager at 659-3607. si= = / Robert N. Ch-fi~tfinson. P.E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Consen'ation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ofwork: Drill [] Redrill [] I lb. Type ofwell. Exploratory [] Stratigraphic Test [] Development Oil [] Re-entry [] Deepen [][ Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-036( ADL 25650 ALK 468 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 224' FSL, 594' FEL, Sec. 14, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 460' FSL, 256' FEL, Sec. 13, T11N, R10E, UM 1D-12 #U-630610 At total depth 9. Approximate spud date Amount 469' FSL, 53' FEL, Sec. 13, T11N, R10E, UM September 5, 1999 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 53 @ TD feetI 1D-01 14.3' @ 275' feet 2560 9231 ' MD/6680' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 800 MD Maximum hole angle 49° Maximum surface 2562 psig At total depth (TVD) 3040 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantib/of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" 62.5# R-3 Weld 85' 35' 35' 120' 120' 230 sx ASI 12.25" 9.625" 40# L-80 BTC 5617' 35' 35' 5652' 4343' 680 sx AS III L & 610 sx Class G 8.5" 7" 26# L-80 BTC-Mod 8661' 35' 35' 8696' 6331' 230 sx Class G 6.125" 3.5" 9.3# L-80 8rd EUE-Mo~ 685' 8546' 6233' 9231' 6680' 210 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production Liner Perforation depth: measured ' ... ORIGINAL true vertical /' i'i:L'.~.: :;~ ~.'-!~ ~: ':.:i :-.': ::.- ~)~ ~';~ ' 20. Attachments Filing fee [] Properly Pl~t [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 2O AAC 25.O5O requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledg6 Questions? Call William Lloyd265-653 ~~gned.__,~- ~- ~ Title: D~,,ing Engineering Superv~or Date Commission Use Onb Permit Num(:~¢_ o(~ y APl number JSee cover letter 50-O2..¢-'- 2. .~. ~~:~" I Approvaldate ¢~"c~'"~'~ Ifor other requirements Conditions of approval Samples required [] Yes ,~ No Mud Icg required [] Yes [] No Hydrogen sulfide measures [] Yes [~ No Directional survey required [] Yes [] No Required working pressure for DOPE [] 2M; [] ('~ [] 5M; [] 10M;[] [] Other; OR'G'NAL S,GNED BY by order of Approved by Robert .N_. Christenson Commissioner the commission Da. te Form 10-401 Rev. 12/1/85 · Submit in triplicate ARCO Alaska, Drill and Case Plan for 1D- .2 Kuparuk Producer General Procedure: :[. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Hove in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 12 1/4" hole to the surface casing point at 5652' iVlD/4343' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. · Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. · TAM Port Collar will be placed in the casing string at 1000' MD to be used in the event that cement does not reach the surface in the primary one stage job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. Hake up 8 1/2" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 9. Drill 8 1/2" hole to intermediate casing point at +8,696' MD/6331' TVD · Perform a second LOT and determine an acceptable kick tolerance · If kick tolerance is acceptable, 8 1/2" hole will be drilled to TD · ~[f kick tolerance is unacceptable, 7" casing will be run to top Kuparuk 10. Run and cement 7" 26# L80 BTC-Mod (if required from step #9) Steps 11-14 are only applicable if we are required to top set the Kuparuk with 7" casing 11. Hake up 6 :[/8" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 13. Drill 6 :[/8" hole to TD at 9231' IVlD/6680' TVD · Condition hole and mud for casing 14. Run and cement 31/2'' 9.3#/ft L~80 8rd EUE-Mod Liner :[5. Hake a cleanout run with bit and scrapers if necessary · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes · Record results and fax to town 16. Run and land 3 1/2" tubing with gas lift completion :[7. Nipple down BOP's. ~lnstall production tree and pressure test same. 18. Secure well, release rig ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 1D-12 Drillinq Fluid Properties: Density PV YP Funnel Vis ]:nitial Gel 10 Hinute Gel AP]: Filtrate pH % Solids Spud to surface casing point 9.5-10.2 ppg 16-26 25-35 100 - 300* Drill out to TD 9.5- 10.8 ppg 7-21 7-22 35-50 10-20 15-40 7-15 9.5-10 +10% 2-6 4-8 <6 through Kup 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander/Desilter/Hud Cleaner Centrifuge Degasser Pit Level ]:ndicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 200-300 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (HASP) while drilling the production hole is calculated using a surface casing leak-off of :1.3.5 ppg EMW (0.70 psi/ft) and a gas gradient of O.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2,562 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. HASP = (4,343 ft)(0.70- 0.11) = 2,562 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 1D pad are expected to be ~3,400 psi (0.52 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6,505'. Target (Kuparuk C4) (3400+ 150)/(0.052'6505)= 10.5. An additional risk is associated with gas pressurization of sand stringers within the Kalubik interval. These stringers have become charged with gas due to historic gas injection in the GSA area. Identification of, and degree of charging of these sands is unpredictable and best determined by offset records. ]:n the area of 1D-12 it is anticipated that the mud weight required to balance gas in the Kalubik zone may be as high as 11.8 ppg T ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 1D-::!.2 is 1D-01. The wells are 14.3' from each other at a depth of 275' MD. Drillinq Area Risks: Drilling risks in the 1D-12 area are surface interval hydrates, lost circulation and potential borehole instability in and below the permafrost formation. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and optimum rheological properties to safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM) Annular Pumpinq Operations: ]:ncidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class ]:! disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1D-12 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. ]:f isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We anticipate that 1D-12 will be requested to be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. All necessary documentation for the permitting of this well for annular injection will be provided after the well is completed. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300- 500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. All Depths are RKB Pool Rig 6 1D-12 FMC Prudhoe Gen IV 9-5/8 x 7 9-5/8 Mandrel Hanger Base of permafrost at 1,685' MD / 1,653' TVD 12-1/4" Top of West Sak at 4,662' MD / 3,696' TVD Base of West Sak 5,346' MD / 4,143' TVD 9-5/8" 40 ppf L-80 BTC Surface Casing 5,652' MD / 4,343' TVD 8-1/2" Hole Baker 3.5" x 7" SLZXP LTP and Hanger w/PBR @ 8,546' MD Weatherford Gemoco 7" Float Collar and Float Shoe Baker 3-1/2" Landing Collar, Float Collar and Float Shoe (1 jt. spacing between each) Completion Type 2 ,' :: ;: :: :: 16" Conductor Weatherford Gemoco 9-5/8" PORT Collar Standard Grade, BTC 1,001' MD/1,000' TVD Mud Weight in Surface hole: 10.0 ppg by 1100' TVD 10.2 ppg by 1900' TVD Weatherford Gemoco 9-5/8" Float Collar and Float Shoe Mud Weight in Production hole 10.8 to 12.5 ppg iiiiiii 7" 26 L-80 BTC Mod Csg i:i:i:i 8,696' MD / 6,331' TVD 3-1/2" 9.3#/ft L-80 8rd-Mod 8/31/1999 Completed 1D-12 FMC Prudhoe Gen IV 9-5/8 x 7 x 3~ Base of permafrost at 1,685' MD / 1,653' TVD 12-1/4" Hole 81/2" Hole Weatherford Gemoco 9-5/8" PORT Collar Standard Grade, BTC 9-5/8" 40 ppf L-80 BTC-Mod Surf. Csg. 5,652' MD / 4,343' TVD 3Y2" 9.3 ppf L-80 8rd-Mod w/15' seal bore extension tied into top of liner 7" 26 ppf L-80 BTC Intermediate. Csg. 8,696' MD / 6,331' TVD Baker 3.5" x 7" SLZXP LTP and Hanger. TOL @ 8546' MD/6233' TVD 6-1/8" Hole .:.;.;.: .;-:. ..... ::::::-: :.:.: ;::;:;.: :':': 8:::: :':::: ::::::: :-:::: 2.813" CAMCO DB or Otis X nipple for SCSSV at 500' + MD Camco 3W' x 1" side pocket GLM's station# MD TVD #1 * 8487' 6195' #2 7807' 5750' #3 6735' 5050' #4 5165' 4025' #5 2983' 2600' * Station #1 = 1.5" orifice CAMCO or Otis 2.813 nipple cr~ot~ by r~,e FOE; LLOYD Dote p~oEed: 5O-A~g-lggg Plot Reference is 1Z Ve~on ~5, o Begin 1.5 Deg/lO0' Nudge 0.75 Begin 3 Deg/lO0' Nudge 400 5.00 Begin Angle Drop 3.00 End Angle Drop 800 KOP 5.00 6.00 9.00 DLS: 5.00 dog per 100 ft 12.00 15.00 18.00 21.00 24.00 27.00 Bose Permafrost 50.00 33.00 39.00 45.00 EOC 1200 1600 2000 24O0 2800 5200 5600 4000 440O 4800 5200 56OO 6OO0 6400 6800 ARCO Alaska, Inc. Siruofure: Pad 1D Well: 12 Field : Kuparuk River Unit Looafion : North Slope, Alaska East (feet) -> 0 500 1000 1500 2000 2500 $000 3500 4000 4500 5000 5500 6000 6500 I I I I I ,~1 I I [ I I I I I I I I I I I I I I I I.~ t I -eR t~- e-~ 5OO Top West Sak Bose West Sak 9 5/8 Casing Pt CBO C50 C4-0 C50 7 Casing Pt/Bose HRZ ._%.,,~ C20 Top O Shale '~,~ K-1 Target-Top C4 1D-12 Ver#5 Top C3""-~. Top C2 Top C1 Top B Sheie TD - Casing Pt i i i i i i i i i i i i i i i i i i i i i ii i i i i i i i i i 0 400 800 1200 1600 2000 2400 2800 5200 5600 4000 4400 4800 5200 5600 6000 Vertical Section (feet) -> Azimuth 87.58 with reference 0.00 N, 0.00 E from slot #12 5OO Creoted by r;xse Dote plotted: 30-Aug-1999 Plot Reference ts 12 Vere;on ~/5. Coord~notes ere ;n feet reference slot l~12. True Vert~cel Depths ore reference RKB Pool 6./ ARCO Alaska, Inc. Structure : Pad 1D Well : 12 Field: Kuparuk River Uni~ Looation : North Slope, Alaska Point Begin 1.5 Deg/lO0' N&8 Begin 3 Deg/lO0' Nud&8 Begin Angle Drop End Angle Drop KOP Base Permafrost EOC Top West Sok Bose West Sok 9 5/8 Casing Pt C80 C50 C40 C50 C20 7 Casing Pt/Bose HR&~ K-1 Top D Shale Target - Top C4 Top C5 Top C2 Top C1 Top B Shale TD - Cosinq Pt PROFIL MD 250.00 350.00 500.00 700.00 800.00 1685.08 2440.82 4661.71 5546.14 5652.58 5976.99 7552.08 7785.77 8519.68 8592.25 8696.55 8815.78 8950.62 8962.78 9014.84 9065.57 9105.18 9125.55 9250.75 Inc 0.00 1.50 6.00 0.00 0.00 26.55 49.22 49.22 49.22 49.22 49.22 49.22 49.22 49.22 49.22 49.22 49.22 49.22 49.22 49.22 49.22 49.22 49.22 49.22 E COMMENT DATA Dir TVD North East V. Sect 0.00 250.00 0.00 0.00 0.00 00.00 349.99 -0.25 1.29 1.28 00.00 499.65 - 1.93 10.95 10.86 00.00 699.26 -5.75 21.25 21.07 00.00 799.26 -5.75 21.25 21.07 87.53 1 653.00 4.94 222.51 222.51 87.53 2245.55 24.81 683.18 683.62 87.55 5696.00 97.30 2563.44 2365.44 87.53 4143.00 119.64 2881.27 2883.75 87.53 4545.00 129.64 3112.96 5115.65 87.55 4555.00 140.25 3558.55 5561.47 87.53 5440.00 184.47 4583.77 4587.65 87.53 5755.00 199.21 4725.51 4729.71 87.55 6085.00 21 6.70 5150.97 5155.54 87.55 6265.00 225.60 5537.17 5341.94 87.53 6551.00 229.00 5415.95 5420.79 87.55 6409.00 252.90 5506.51 5511.25 87.55 6484.00 256.64 5593.19 5598.19 87.55 6505.00 257.69 5617.52 5622.54 87.55 6559.00 259.59 5656.90 5661.97 87.53 6572.00 241.04 5695.13 5700.23 87.53 6598.00 242.34 5725.25 5730.58 87.55 6610.00 242.94 5739.15 5744.29 87.55 6680.00 246.44 5820.24 5825.46 Deg/lO0 0.00 ,i 3.00 3.00 0.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Creoted by Hxse Dote plotted: 50-Aug-1999 Plot Reference ~s 12 Version #5. Coord;notee ore in feet reference slot t~12. True Vert[col Depths ore reference RKB Pool ARCO Alaska, Inc. Struoture : Pod 10 Well : 12 Field : Kuparuk Rlver Unit Location : North Slope, Alaska East (feet) -> 0 ,:300 600 900 1200 1500 1800 21 O0 2400 2700 3000 5300 ,3600 3900 4200 4500 4BO0 51 OD 5400 5700 6000 6500 I I I I I I I I i I I I I I I I I I I I I I I I I I I I I I I I I I I I I [ I I I I I 600 ~oo ~ o ~ ARCO Alaska, Inc. Pad 10 12 slot #12 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 12 Version#5 Our ref: prop2077 License : Date printed : 30-Aug-1999 Date created : 19-Feb-1997 Last revised : 27-Aug-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 18 3.519,w149 30 36.226 Slot Grid coordinates are N 5959888.673, E 560491.139 Slot local coordinates are 224.00 N 594.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel lpath PMSS <291 - 5795'>,,125,Pad 10 PMSS <0.5126'>,,106,Pad 10 PMSS <D-5047'>,,124,Pad 10 PGMS <0-8930'>,,5,Pad 10 PMSS <256 - 5973'>,,1lO,Pad 10 PMSS <294 - 8250'>,,112,Pad 10 PMSS <290-6245'>,,116,Pad 10 GSS <0.175'>,,116,Pad 10 PMSS <287-6055'>,,123,Pad 10 GSS <0-173'>,,123,Pad 10 PNSS<O-7045'>,,111,Pad 10 PMSS <0 - 6270'>,,114,Pad 10 PMSS <0 - 5445'>,,122,Pad 10 PMSS <0 - 6580'>,,128,Pad 10 PMSS <467 - 5802'>,,132,Pad 10 PMSS <377 - 6224'>,,134,Pad 10 PMSS <0 - 6472'>,,131,Pad 10 PMSS <0 - 7432'>,,127,Pad 10 PMSS <0 - 6716'>,,126,Pad 10 PMSS <0-4530'>,,120,Pad 10 PGMS <0-8070'>,,3,Pad 10 PNSS <0-5142'>,,115,Pad 10 PGMS <O-7502'>,,4,Pad 10 PMSS <O-4778'>,,130,Pad 10 MSS <3311-8200'>,,7,Pad 10 PMSS <0-5015'>,,135,Pad 10 PMSS <1957-5265'>,,133,Pad 10 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 19-Aug-1998 506.0 520.0 520.0 2-Jun-1998 76.6 1433.3 1433.3 2-Jun-1998 4B3.8 760.0 760.0 13-Nov-1997 461.8 900.0 900.0 5-0ct-1998 129.1 800.0 800.0 21-Sep-1998 195.8 811.1 811.1 17-Sep-1998 289.6 644.4 644.4 8-Sep-1998 299.8 160.0 160.0 13-Sep-1998 435.0 100.0 100.0 4-Sep-1998 435.0 100.0 100.0 3-Sep-1998 169.7 920.0 920.0 2-Sep-1998 204.6 1211.1 1211.1 29-Aug-1998 419.2 566.7 566.7 17-Aug-1998 552.8 500.0 500.0 6-Aug-1998 660.0 100.0 100.0 3-Aug-1998 734.1 325.0 325.0 23-Ju1-1998 645.0 100.0 100.0 6-Ju1-1998 538.3 312.5 312.5 1-Ju1-1998 523.5 390.0 390.0 2-Jun-1998 382.9 966.7 966.7 13-Aug-1998 224.3 760.0 760.0 2-Jun-1998 244.2 800.0 800.0 4-Aug-1992 179.7 2020.0 2020.0 2-Jun-1998 627.4 611.1 611.1 6-Nov-1997 705.6 511.1 511.1 2-Jun-1998 746.0 688.9 688.9 2-Jun-1998 671.9 370.0 370.0 PMSS <0'4850'>,,109,r ' 1D PMSS <0-5205'>,,117 .... 1D PMSS <0'4515'>,,119,P~d 1D PMSS <0.4414'>,,121,Pad 1D PMSS <0 - 7340'>,,lO,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGMS <0-8365'>,,1,Pad 1D PMSS <381-6092'>,,1D5,Pad 1D PGMS <0-9783'>,,2,Pad 1D PMSS <0.4590'>,,118,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <293 - 6866'>,,113,Pad 1D 2-jun-1998 2-Jun-1998 2-Jun-1998 2-Jun-1998 28-Apr-199B 11-Jun-1999 10-Dec-1997 2-Jun-1998 4-Aug-1992 2-Jun-1998 29-Apr-1998 22-Sep-1998 PMSS <0 - 7150'>,,108,Pad 1D 28-0ct-1998 PGMS <0-8850'> 28-May-81,,MP i 17-ii-ii,Pad 1D 23-Apr-1999 PMSS <O-5462'>,,129,Pad 1D 2-Jun-1998 PGMS <0-8610'>,,6,Pad 1D 13-Nov-1997 124.7 243.7 364.0 395.5 780.0 820.2 14.3 45.2 39.8 214.8 308.8 227.6 105.7 1557.3 614.2 584.7 1200.~. 840.0 860.0 100.0 1000.0 275.0 780.0 1166.7 1580.0 1631.9 720.0 700.0 9230.7 312.5 688.9 944.4 1200.0 840.0 860.0 100.0 1000.0 720.0 780.0 1166.7 1580.0 1631.9 720.0 700.O 9230.7 312.5 688.9 ARCO Alaska, Inc. Diverter Schematic Pool #6 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline I I I 21 ¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. POOL #6 13-5/8" 5,000 PSI BOP COMPONENTS ¼ ~J r"i I I 3" 5,000 psi WP OCT rj MANUAL GATE V KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator E~ / 1 / BSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom b ] 3" 5,000 psi WP Shaffer GATE VALVE R....~p~raulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL LI'~'% w/two 3" 5M psi WP outlets I I SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams I ARCO Alaska, Inc. Post Office Box 10¢~60 Anchorage, Alaska 99510-0360 August 31, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill: KRU :1D-:12 Surface Location: 224' FSLf 594' FEL Sec :14 T:1:1N R:1OEf REVISED Target Location: 460' FSL, 256' FEL Sec, 13, TI:1N, R10E, UM REVI:SED Bottom Hole Location: 469' FSL~ 53' FEL Sec. 13, T11N~ R10E, UM Dear Commissioner Christenson, ARCO Alaska, Tnc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1D pad. The well is designated as a conventional producer using a 9 5/8" surface casing string, a 7" intermediate casing string, a 3 1/2" liner and 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) 2) 3) 4) 5) 6) 7) 8) 9) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. A copy of the proposed drilling program. ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. Robert Christenson . Application for Permit io'Drill - 1D-12 Page 2 10) Due to the large volume of regional information available, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) 2) Completion Report Technologist (20 AAC 25.070) Geologic Data and Logs (20 AAC 25.071) Sharon AIIsup-Drake, Drilling 263-4612 Bill Raatz, Geologist 263-4952 The anticipated spud date for this well is September 5, 1999. If you have any questions or require further information, please contact Bill Lloyd at (907) 263- 6531 or Chip Alvord at (907) 265-6120. CC.' Kuparuk 1D-12 Well File Chip Alvord ATO-1200 M.] Loveland NSK6 RCO Alaska, inc. ~paruk Unit Disbursement Account Box 102776 ~chorage, AK 99510-2776 CHECK NUMBER 230098596 839 Y THE DER OF: STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMI :3001 PORCUPINE DRIVE AUGUST 10, 1999 *** VOID AI~ER 90 DAYS *** 0997587 First National Bank of chic,go.oTtoEXACTLY ***********100 DOLLARS A/VD O0 CENTS $**********'100.00 Chicago, Illinois Shelby¥ille, Kentucky TRACE NUMBER: 23009859~ ,' i~ itOO clP, 5 q r=,, ~.'08 ii qo L, ~. r= 0qq ? 5P, WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION DATE COMPANY ENGINEERING APP~R ~ DATE WELL NAME ~~)-/2_ INIT CLASS ./~,~/ .,/~ ~, ~/ GEOL PROGRAM: exp __ dev ~ redrll AREA N N N N N N N N N N N N N 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected pady ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued withoul administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... L~ N 15. Surface casing protects all known USDWs ........... L~) N 16. CMT vol adequate to circulate on conductor & surf csg ..... ~ N 17. CMT vol adequate to tie-in long string to surf csg ........ Y N 18. CMT will cover all known productive horizons .......... ~ N 19. Casing designs adequate for C, T, B & permafrost ....... ~ N 20. Adequate tankage or reserve pit ................. N 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. ~ N 23. If diverter required, does it meet regulations .......... ~ N 24. Drilling fluid program schematic & equip list adequate ..... '/)L;.'~ N 25. BOPEs, do they meet regulation ................ ~.~ N 26. BOPE press rating appropriate; test to ~, ~O psig. . N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N serv __ wellbore seg ann. disposal para req UNIT# //,//'c~'/'~ ON/OFF SHORE ~ ,) GEOLOGY ANNULAR DISPOSAL 28. Work will occur without operation shutdown ........... ~) N 29. Is presence of H2S gas probable ................. Y ~) // 30. ~e'~n-~--~:-~-~b-e-is-~e-d-~,/'~-~(~"~'r~-'~,-aif~J~~~'~-'i- Y N ./-" 31. Data presented on potential overpressure zones ....... Y N//' ~. ~ 32. Seismic analysis of shallow gas zones ............. Y,,,,fq ,//~,{~-¢', 33. Seabed condition survey (if off-shore) ............. /'¢ N "' '" 34. Contact name/phone for weekly progress reports [exploratory on~ Y N ~-- 35. With proper cementing records, this plan /~r~r- ~o~¢ (~'~.~-.--~'~ -- y N~~ APPR DATE (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N : ENGINEEI~IN_G: J DH-_J-------~ UlC/Annular COMMISSION: WM~ 91119c) RDNWo.~ co co ~1~?. Comments/Instructions: c:\msoffice\wordian\diana\checklist Well HistorY.File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Dec 15 14:27:10 1999 Reel Header Service name ............. LISTPE Date ..................... 99/12/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/12/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-90151 BRETT HENNIN FRED HERBERT 1D-12 500292294800 ARCO ALASKA INC. Sperry Sun 14-DEC-99 MWD RUN 2 AK-MM-90151 GREG GRIFFIN RAY SPRINGER RECEIVED 1 6 1999 Anchorage MWD RUN 3 AK-MM-90151 PAUL SMITH RAY SPRINGER JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 4 AK-MM-90151 GREG GRIFFIN RAY SPRINGER liN t0E 224 594 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 104.30 70.80 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 16.000 120.0 12.250 9.625 5640.0 8.500 7.000 8693.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 &2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILZING GEIGER- MUELLER TUBE DETECTORS. 3. MWD RUN 3 IS DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. MWD RUN 4 IS DIRECTIONAL WITH DGR, EWR4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), STABILIZED LITHO-DENSITY (SLD). DOWNHOLE DENSITY TOOL FAILU PRECLUDES PRESENTING SLD DATA. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE EMAILL FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON 12/14/99. MWD DATA IS CONSIDERED PDC. 6. MWD RUNS 1-4 REPERSENT WELL 1D-12 WITH API%: 50-029-22948-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9250'MD, 6688'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY {SS MATRIX, FIXED HOLE SI CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 10.6 - 10.9 PPG MUD SALINITY: 650 PPM CHLORIDES FORMATION WATER SALINITY: 13000 PPM CHLORIDES LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 246.0 ROP 249 0 FET 5638 5 RPD 5638 5 RPM 5638 5 RPS 5638 RPX 5638 NCNT 8683 FCNT 8683 NPHI 8683 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 9195 5 9249 5 9202 5 9202 5 9202 5 9202 5 9202 5 9158 5 9158 5 9158 5 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 BIT RUN NO MERGE TOP MERGE BASE 100 246.0 4706.0 200 4706.0 5651.0 300 5651.0 8721.0 400 8721.0 9250.0 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT Service Order Units Size Nsam FT 4 1 MWD FT/H 4 1 MWD API 4 1 MWD OHMM 4 1 MWD OHMM 4 1 MWD OHMM 4 1 MWD OHMM 4 1 MWD HOUR 4 1 MWD PU-S 4 1 MWD CNTS 4 1 MWD CNTS 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 Name Service Unit Min Max DEPT FT 246 9249.5 ROP MWD FT/H 0 2645.51 GR MWD API 19.42 473.04 RPX MWD OHMM 0.23 27.95 RPS MWD OHMM 0.8 2000 RPM MWD OHMM 0.54 2000 RPD MWD OHMM 0.77 2000 FET MWD HOUR 0.1658 68.8183 NPHI MWD PU-S 17.79 63.4 FCNT MWD CNTS 97.87 805.38 NCNT MWD CNTS 13745.3 31360.3 Mean Nsam 4747.75 18008 191.945 17901 98.1083 17889 3.28381 7129 4.07181 7129 13.2613 7129 12.6043 7129 2.2685 7129 37.4512 952 301.235 952 20919.1 952 First Reading 246 249 246 5638.5 5638.5 5638.5 5638.5 5638.5 8683 8683 8683 Last Reading 9249 5 9249 5 9195 5 9202 5 9202 5 9202 5 9202 5 9202 5 9158 5 9158 5 9158 5 First Reading For Entire File .......... 246 Last Reading For Entire File ........... 9249.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 246.0 ROP 249.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY {OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 4666.0 4705.5 09-SEP-99 Insite 5.46 Memory 4706.0 .0 50.1 TOOL NUMBER P1352CGV8 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 12.250 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Water Based 10.20 144.0 8.5 450 5.0 .000 .000 .000 .000 .0 108.0 .0 .0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 1 FT/H 4 1 68 4 2 GR MWD 1 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 246 4705.5 2475.75 8920 ROP MWD 1 FT/H 0 2645.51 221.968 8825 GR MWD 1 API 19.42 193.25 71.1313 8841 First Reading 246 249 246 Last Reading 4705.5 4705.5 4666 First Reading For Entire File .......... 246 Last Reading For Entire File ........... 4705.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4669.0 5611.0 ROP 4706.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (PT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 5650.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ......... · ............. -999 Depth Units ....................... Datum Specification Block sub-type...0 10-SEP-99 Insite 5.46 Memory 5651.0 48.9 50.3 TOOL NUMBER P1352CGV8 12.250 Water Based 10.30 166.0 8.5 500 4.8 .000 .000 .000 .000 .0 104.6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 4669 5650.5 5159.75 1964 ROP MWD 2 FT/H 0.24 1353.52 202.547 1890 GR MWD 2 API 44.91 148.18 90.6197 1885 First Reading 4669 4706 4669 Last Reading 5650.5 5650.5 5611 First Reading For Entire File .......... 4669 Last Reading For Entire File ........... 5650.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ 5611 5 5638 5 5638 5 5638 5 5638 5 5638 5 5651 5 LOG HEADER DATA STOP DEPTH 8671 0 8663 5 8663 5 8663 5 8663 5 8663 5 8721.5 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 14-SEP-99 Insite 630.9 Memory 8721.0 47.5 50.9 TOOL NUMBER P1354CGV6 P1354CGV6 8.500 Water Based 9.00 39.0 9.5 5OO 5.8 2.400 1.440 3.000 2.000 76.0 131.0 76.0 76.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 GR MWD 3 RPX MWD 3 RPS MWD 3 RPM MWD 3 RPD MWD 3 FET MWD 3 FT/H 4 1 68 API 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 HOUR 4 1 68 4 8 12 16 20 24 28 Name Service Unit DEPT FT ROP MWD 3 FT/H GR MWD 3 API RPX MWD 3 OHMM RPS MWD 3 OHMM RPM MWD 3 OHMM RPD MWD 3 OHMM FET MWD 3 HOUR Min Max 5611.5 8721.5 0.28 2010.94 38.7 473.04 0.68 17.25 0.8 2000 0.73 13.95 0.77 2000 0.1658 60.6179 Mean Nsam 7166.5 6221 167.472 6129 136.753 6120 2.97499 6051 3.71385 6051 3.0909 6051 3.93436 6051 1.15969 6051 First Reading 5611 5 5651 5 5611 5 5638 5 5638 5 5638 5 5638 5 5638 5 Last Reading 8721.5 8721.5 8671 8663.5 8663.5 8663.5 8663.5 8663.5 First Reading For Entire File .......... 5611.5 Last Reading For Entire File ........... 8721.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH R?S 8600.0 9202.5 RPX 8600.0 9202.5 RPM 8600.0 9202.5 RPD 8600.0 FET 8600.0 GR 8671.5 NCNT 8683.0 NPHI 8683.0 FCNT 8683.0 ROP 8722.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 9202.5 9202.5 9195.5 9158.5 9158.5 9158.5 9249.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 18-SEP-99 Insite 0.41 Memory 9250.0 48.7 49.5 TOOL NUMBER P1335GRV4 P1335GRV4 P1335GRV4 P1335GRV4 6. 125 Water 10.70 50.0 9.5 650 4.5 1.900 .949 1.250 2.100 65.0 137.0 65.0 65.0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 API 4 1 68 8 3 RPX MWD 4 OHMM 4 1 68 12 4 RPS MWD 4 OHMM 4 1 68 16 5 RPM MWD 4 OHMM 4 1 68 20 6 RPD MWD 4 OHMM 4 1 68 24 7 FET MWD 4 HOUR 4 1 68 28 8 NPHI MWD 4 PU-S 4 1 68 32 9 FCNT MWD 4 CNTS 4 1 68 36 10 NCNT MWD 4 CNTS 4 1 68 40 11 Name Service Unit DEPT FT ROP MWD 4 FT/H GR MWD 4 API RPX MWD 4 OHMM RPS MWD 4 OHMM RPM MWD 4 OHMM RPD MWD 4 OHMM FET MWD 4 HOUR NPHI MWD 4 PU-S FCNT MWD 4 CNTS NCNT MWD 4 CNTS Min Max Mean Nsam 8600 9249.5 8924.75 1300 15.97 173.27 64.2087 1056 32.58 270.72 113.6 1038 0.23 27.95 4.81675 1206 1.22 529.11 5.97109 1206 0.54 2000 230.61 1206 1.49 2000 167.799 1206 0.5827 74.1747 15.0994 1206 17.79 63.4 37.4512 952 97.87 805.38 301.235 952 13745.3 31360.3 20919.1 952 First Reading 8600 8722 8671.5 8600 8600 8600 8600 8600 8683 8683 8683 Last Reading 9249 5 9249 5 9195 5 9202 5 9202 5 9202 5 9202 5 9202 5 9158 5 9158 5 9158 5 First Reading For Entire File .......... 8600 Last Reading For Entire File ........... 9249.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/12/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/12/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
