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CID d Y h c N to O Q to a) a F aJ ~ Z O N N N 4-, 05 `, I- = Z yp N J m' Q w C Z05 a �a = o w T c C m t- v 3 Co a, (o i STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMOION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations r Fracture Stimulate r Pull Tubing F Operations Shutdown r Performed: Suspend E Perforate E Other Stimulate E Alter Casing F Change Approved Program E Plug for Red rill E Perforate New Pool E Repair Well F Re-enter Susp Well E Other: Stack Packer F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r 200-036 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-22027-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25660 KRU 1L-20A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10934 feet Plugs(measured) None true vertical 6325 feet Junk(measured) 10800 Effective Depth measured 10580 feet Packer(measured) 8621, 10322 true vertical 5993 feet (true vertical) 4735, 5759 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115 SURFACE 5965 12 6000 3682 PRODUCTION 6465 7 6500 3902 PRODUCTION 4444 8 10491 5911 LINER A 612 5 10934 6324 RECEIVED JUN 30 2016 Perforation depth: Measured depth: 10574-10604, 10695-10705, 10742-10762 True Vertical Depth: 5988-6016,6101-6110,6145-6164 OGCC Tubing(size,grade,MD,and TVD) 3 1/2 x 4, L-80, 10340 MD, 5775 ND Packers&SSSV(type,MD,and ND) PACKER-PACKER, BAKER FAB-1 PERMANENT PACKER @ 8621 MD and 4735 ND PACKER-BAKER SABL-3 PACKER w/TIEBACK EXTENSION @ 10322 MD and 5760 tvd SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE Treatment descriptions includingvolumes used and finalpressure: sati4�6EI JAN 7 23�7 P 6 2 v 1.L.., 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation Shut-In 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development F Service r Stratigraphic r Copies of Logs and Surveys Run E 16.Well Status after work: Oil F Gas E WDSPL r Printed and Electronic Fracture Stimulation Data E GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG E 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-336 Contact Sara Heskin @ 265-1027 Email Sara.Heskin a conocophillips.com Printed Name ara Hes . Title Associate Wells Engineer Signature Ma, Phone:265-1027 Date 6.7/c2,7 po i 0 Form 10-404 Revised 5/2015 V71_ '11211 RBDMS c,v JUN 3 0 2016 Submit Original Only . S/0� • • Operations Summary (with Timelog Depths) 4st 1L-20 Ccxt000Phillips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS), End Depth MKS) 6/4/2016 6/5/2016 15.00 MIRU MOVE MOB P Release rig f/3K-27 Move to 1L-20 0.0 0.0 09:00 00:00 Move Derrick Shop pipe shed and rock washer.Lay mats on road to oliktock Y, Move components to Y and shuffle mats around rig and lay on the road to 1L pad. 6/5/2016 6/5/2016 3.00 DEMOB MOVE MOB P Continue prepare rig for move. 0.0 0.0 00:00 03:00 Disconnect Interconnects,and prep rig floor for skidding.Peak Trucks on location at 0900 HRS.Lower and Pin Suspensions. Held PJSM with PEAK drivers. Move and stage rockwasher. Move and stage Mootr complex. 6/5/2016 6/5/2016 12.00 MIRU MOVE MOB P Move and stage Pit system.Install tow 0.0 0.0 03:00 15:00 hitch on sub base.PJSM,Skid rig floor to move position.Lift and secure Stompers. Move Sub base off of the well.DSO and Co.man witness. Begin rig move off of the 3K pad at 1430 HRS.Arrive and stage complexes at CPF3.Waiting on change out and traffic. Inspect moving system and generators. Depart CPF3 at 1800 HRS.Arriving at Oliktok Y at 1930 HRS.Stage complexes.Wait on matting board swap and prepare 1 L- 20 Location. 6/5/2016 6/5/2016 12.00 MIRU MOVE MOB P Continue moving mats around rig lay 0.0 0.0 00:00 12:00 mats on road in front of rig,Move Complexes from Y to 1L pad stage pits pump room and generator shed on 1F while spotting Sub.Sub blew road out tool house repair and mat road. 6/5/2016 6/6/2016 12.00 MIRU MOVE MOB P Spot Sub over well move remainig 0.0 0.0 12:00 00:00 complexes to 1L spot in place,Peak moving remaing equipment from 3k pad,Spot pipshed and rock washer, Work on hooking up interconnects, Work on rig acceptance checklist. 6/6/2016 6/6/2016 2.50 MIRU MOVE RURD P Continue spot Motor and Pipe Shed 0.0 0.0 00:00 02:30 complexes. 6/6/2016 6/6/2016 3.50 MIRU MOVE RURD P Hook up all interconnects,water, 0.0 0.0 02:30 06:00 steam,Hydraulic and air lines.Work on rig acceptance checklist. Rig crew change. 6/6/2016 6/6/2016 1.50 MIRU MOVE RURD P Continue work on rig acceptance 0.0 0.0 06:00 07:30 checklist.Spot and RU hardline to the bleed tank for well kill. 6/6/2016 6/6/2016 1.50 MIRU MOVE RURD P Take on first load of 8.9 ppg brine, 0.0 0.0 07:30 09:00 Work on choke line and Take on water and fuel. 6/6/2016 6/6/2016 1.50 MIRU MOVE RURD P Rig up hard lines to kill well 0.0 0.0 09:00 10:30 6/6/2016 6/6/2016 0.50 MIRU MOVE RURD P Rig up handi berm around cellar Instal 0.0 0.0 10:30 11:00 beaver slide,Spot cuttings tank and handi berm,Rig accepted @ 1100 hrs 6/6/2016 6/6/2016 2.25 MIRU MOVE SFTY P Pre Spud meeting with crew and 0.0 0.0 11:00 13:15 hazard hunt group discussion/review findings Page 1/14 Report Printed: 6/28/2016 • Operations Summary (with Timelog Depths) � t 1 L-20 10'. Conoco Rig: DOYON 142 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) 6/6/2016 6/6/2016 2.25 MIRU WELCTL MPSP P R/U Lubricator and test t/2000 psi, 0.0 0.0 13:15 15:30 Pull BPV, LID Lubricator 6/6/2016 6/6/2016 1.00 MIRU WELCTL SEQP P Fill Lines and pressure test surface 0.0 0.0 15:30 16:30 equipment to 2500 psi,TBG 1600 psi IA 900 psi OA 725 psi. 6/6/2016 6/6/2016 1.00 MIRU WELCTL KLWL P Bleed gas cap on tubing f/1600 psi t/ 0.0 0.0 16:30 17:30 700 fliud back,Bleed IA f/720 psi t/ 420 psi 6/6/2016 6/6/2016 2.75 MIRU WELCTL KLWL P Reverse circulate 8.9 ppg brine ICP 0.0 0.0 17:30 20:15 1.5 bpm 550 psi FCP @ 2 bpm 110 psi 391 bbls pumped 312 bbls returned loss of 79 bbls 6/6/2016 6/6/2016 0.50 MIRU WELCTL KLWL P B/D Lines line up to circ on active 0.0 0.0 20:15 20:45 system 6/6/2016 6/6/2016 0.50 MIRU WELCTL KLWL P Reverse Circ 50 bbls @ 2 bpm 90 psi 0.0 0.0 20:45 21:15 slow pumps t/1 bpm 30 psi losses 50 %Loss 23 bbls during circulation 6/6/2016 6/6/2016 1.00 MIRU WELCTL OWFF P Monitor Well on trip tank slight flow 0.0 0.0 21:15 22:15 shut in well monitor psi tubing 90 psi ann 75 psi after 30 min 6/6/2016 6/7/2016 1.75 MIRU WELCTL KLWL P Bleed off pressure to tiger tank,line up 0.0 0.0 22:15 00:00 and reverse circulate @ 2 bpm 75% losses 148 bbls pumped 110 bbls lost 6/7/2016 6/7/2016 1.25 MIRU WELCTL CIRC P Continue to reverse circulating 8.9 ppg 0.0 0.0 00:00 01:15 brine at 3 BPM=190 psi(270 bbls pumped 178 bbls lost). 6/7/2016 6/7/2016 0.75 MIRU WELCTL OWFF P Observe the well for flow and the well 0.0 0.0 01:15 02:00 on a slight vac. SimOps: RD circulating equipment. 6/7/2016 6/7/2016 0.50 MIRU WHDBOP MPSP P Rig up to set BPV and test in direction 0.0 0.0 02:00 02:30 of flow.Unable to test in direction of flow discuss options with town engineer. 6/7/2016 6/7/2016 3.50 MIRU WHDBOP WAIT T Mobilize HES slickline at 02:30 hours 0.0 0.0 02:30 06:00 to set 1.81"CA-2 plug in nipple at 10308'ORKB. SimOps: Hold pre-spud meeting with rig crew. General housekeeping, maintenance,and painting around the rig. 6/7/2016 6/7/2016 4.25 MIRU WHDBOP SLKL T Bring slickline tool to the rig floor and 0.0 0.0 06:00 10:15 RU HES slickline. PT slickline lubricator to 1000 psi(good test). 6/7/2016 6/7/2016 2.50 MIRU WHDBOP SLKL T RIH and set 1.81"CA-2 plug in nipple 0.0 0.0 10:15 12:45 reducer set in DS nipple at 10308' ORKB. PT CA-2 plug to 1000 psi (good test),bleed off the pressure, and shear running tool from the plug. PT the plug to 500 psi to confirm the plug is still set(good test). 6/7/2016 6/7/2016 2.25 MIRU WHDBOP SLKL T POOH with setting tools,drain the 0.0 0.0 12:45 15:00 lubricator,and RD HES slickline. Page 2/14 Report Printed: 6/28/2016 S 0 Operations Summary (with Timelog Depths) 0 O 1 L-20 +Ccx�oco`Philgps " tikak:s Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code; Time P-T-X Operation tftK€t), End Depth(ftKD)';', 6/7/2016 6/7/2016 1.50 MIRU WHDBOP MPSP T Set 3"HP BPV with dry rod. Pressure 0.0 0.0 15:00 16:30 up on the IA to 1000 psi for 10 minutes to test the BPV from below in the direction of flow(good test). 6/7/2016 6/7/2016 1.50 MIRU WHDBOP NUND P PJSM. ND the tree and ND the tubing 0.0 0.0 16:30 18:00 head adaptor. Inspect the lift threads (threads are good)and install the HP blanking plug into the BPV. 6/7/2016 6/8/2016 6.00 MIRU WHDBOP NUND P NU the DSA,spacer spool,and the 0.0 0.0 18:00 00:00 BOP stack. NU the choke and kill lines to the BOP stack. NU the Dutch riser nipple and flow riser. 6/8/2016 6/8/2016 1.00 MIRU WHDBOP NUND P Continue to NU the choke hose 0.0 0.0 00:00 01:00 removing the extension pup on the HCR choke. 6/8/2016 6/8/2016 1.00 MIRU WHDBOP 'RURD P MU TIW and dart valve. RU BOPE 0.0 0.0 01:00 02:00 testing equipment. Flush and fill the BOPE with fresh water. 6/8/2016 6/8/2016 4.50 MIRU WHDBOP BOPE P Conduct initial BOPE test to 250/3000 0.0 0.0 02:00 06:30 psi: test 3-1/2"x 6"VBR's(upper pipe rams and lower pipe rams)with 3-1/2" test joint;test annular to 250/2500 with 3-1/2"test joint;conducted Koomey drawdown test(all tested passed). The test was witnessed by AOGCC inspector Guy Cook. Tests: 1) Annular with 3-1/2"test joint (passed) 2) Upper pipe rams with 3-1/2"test joint,upper IBOP,4"Demco on the mud line,chokes 1,12, 13&14 (passed) 3) Lower IBOP,4"Demco mezzanine kill line,chokes 9&11 (passed) 4) HCR kill,3-1/2"EUE TIW,chokes 5,8,&10(passed) 5) Manual kill,3-1/2"PH-6 dart valve, chokes 4,6,&7(passed) 6) 3-1/2"PH-6 TIW,choke 2(passed) 7) NCR choke(passed) 8) Manual choke(passed) 9) Lower pipe rams with 3-1/2"test joint(passed) 10)Blind rams,choke 3(passed) 11)Super choke(passed) 12)Manual choke(passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3000 psi Accumulator Pressure After Closer= 1775 psi Pressure Gain of 200 psi=5 seconds Full System=43 Seconds Average N2(6 Bottles)=2400 psi 6/8/2016 6/8/2016 0.75 MIRU WHDBOP RURD P Blow down and RD BOPE testing 0.0 0.0 06:30 07:15 equipment. Page 3/14 Report Printed: 6/28/2016 0 • -.. -- r Operations Summary (with Timelog Depths) 1 L-20 hilllips ,`: r�d.rk.3 Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKE), 6/8/2016 6/8/2016 0.75 COMPZN RPCOMP RURD P Bring Weatherford equipment to the 0.0 0.0 07:15 08:00 rig floor and RU the power tubing tongs. 6/8/2016 6/8/2016 1.50 COMPZN RPCOMP MPSP P Suck out the BOP stack. Pull the HP 0.0 0.0 08:00 09:30 blanking plug and BPV with the dry rod. 6/8/2016 6/8/2016 0.50 COMPZN RPCOMP RURD P MU the landing joint to the tubing 0.0 0.0 09:30 10:00 hanger,MU the crossover,and MU the top drive. 6/8/2016 6/8/2016 1.00 COMPZN RPCOMP PULL P BOLDS and unseat the tubing hanger 0.0 10,326.0 10:00 11:00 but unable to pull the seal assembly free from the PBR pulling up to 210K. 6/8/2016 6/8/2016 5.00 COMPZN RPCOMP WAIT T Wait for SLB E-line. Continue to work 10,326.0 10,326.0 11:00 16:00 the tubing pulling up to 210K. 6/8/2016 6/8/2016 0.75 COMPZN RPCOMP ELNE P Set the tubing string in the slips with 10,326.0 0.0 16:00 16:45 160K. RD pup joints and crossover. MU crossovers for E-line. Change elevators and hang E-line sheave in the elevators. 6/8/2016 6/8/2016 2.25 COMPZN RPCOMP ELNE T SLB E-line unit got stuck in the soft 0.0 0.0 16:45 19:00 gravel in front of the beaver slide while spotting their unit. Called roads and pads for a grader and pulled the unit out. Set rig mats in front of the beaver slide and spotted the SLB E-line unit. 6/8/2016 6/8/2016 2.00 COMPZN RPCOMP ELNE P Re-head E-line. MU string shot,CCL 0.0 0.0 19:00 21:00 and weight bars. 6/8/2016 6/8/2016 1.75 COMPZN RPCOMP ELNE P RU SLB on the rig floor. MU pack-off 0.0 0.0 21:00 22:45 and head catcher. 6/8/2016 6/9/2016 1.25 COMPZN RPCOMP ELNE P PU and RIH with string shot assembly. 0.0 0.0 22:45 00:00 6/9/2016 6/9/2016 3.00 COMPZN RPCOMP ELNE P Continue to RIH with string shot 0.0 0.0 00:00 03:00 assembly. Fire the string shot from 10282'-10292'ORKB. POOH with string shot assembly. 6/9/2016 6/9/2016 1.00 COMPZN RPCOMP ELNE P Lay down string shot assembly and 0.0 0.0 03:00 04:00 MU 2-1/8"chemical cutter assembly with CCL,weight bars,and centralizers. 6/9/2016 6/9/2016 1.50 COMPZN RPCOMP ELNE P RIH with centralized chemical cutter 0.0 0.0 04:00 05:30 assembly with CCL to top of the patch at 8695'ORKB at 100'/minute but unable to get through the patch. 6/9/2016 6/9/2016 0.50 COMPZN RPCOMP ELNE T Attempt to work through the tubing 0.0 0.0 05:30 06:00 patch with running speed up to 200'/minute but unable to get through the tubing patch. Call town engineer and discuss options. 6/9/2016 6/9/2016 1.00 COMPZN RPCOMP ELNE T Work centralized chemical cutter 0.0 0.0 06:00 07:00 assembly through the tubing patch with a running speed of 300'/minute. 6/9/2016 6/9/2016 0.50 COMPZN RPCOMP ELNE P Continue to RIH with centralized 0.0 0.0 07:00 07:30 chemical cutter assembly from 8708' to 10290'ORKB. Set the anchor and cut the tubing with 2-1/8"chemical cutter at 10290'ORKB. 6/9/2016 6/9/2016 0.50 COMPZN RPCOMP ELNE P POOH with cutter assembly but 0.0 0.0 07:30 08:00 unable to get through the bottom of the patch at 8708'ORKB. Page 4/14 Report Printed: 6/28/2016 • • 414 p .; Operations Summary (with Timelog Depths) 1 L-20 ConocoPhillips 13sska Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 6/9/2016 6/9/2016 4.50 COMPZN RPCOMP ELNE T Attempt to work through the tubing 0.0 0.0 08:00 12:30 patch but unable to. Call town engineer and discuss options. Pressure up on the tubing to 1000 psi, hold for 3 minutes,and bleed to 0 psi. Attempt to pull through the tubing patch unsuccessful. Pressure up on the tubing to 2000 psi,hold for 3 minutes,and bleed to 0 psi. Attempt to pull through the tubing patch unsuccessful. 6/9/2016 6/9/2016 1.25 COMPZN RPCOMP ELNE T RIH to the CA-2 plug at 10308'ORKB 0.0 0.0 12:30 13:45 and release the tool string with the electronic controlled release device. 6/9/2016 6/9/2016 1.00 COMPZN RPCOMP ELNE P POOH with E-line 0.0 0.0 13:45 14:45 6/9/2016 6/9/2016 0.50 COMPZN RPCOMP ELNE P RD E-line off to the side, RD TIW,and 0.0 0.0 14:45 15:15 change elevators. 6/9/2016 6/9/2016 0.25 COMPZN RPCOMP PULL T Attempt to pull the tubing hanger to 0.0 10,290.0 15:15 15:30 the rig floor but the tubing is not free (pulled to max pull of 210K). 6/9/2016 6/9/2016 0.25 COMPZN RPCOMP RURD T MU 6'pup joint,crossover,and top 10,290.0 10,290.0 15:30 15:45 drive. 6/9/2016 6/9/2016 1.00 COMPZN RPCOMP PULL T Continue to work the tubing pulling up 10,290.0 10,290.0 15:45 16:45 to 210K. SimOps: SLB E-line re-heading and obtaining additional chemical cutters. 6/9/2016 6/9/2016 2.50 COMPZN RPCOMP PULL T Establish circulation at 3 BPM=345 10,290.0 10,260.0 16:45 19:15 psi and continue to work the tubing pulling up to 210K. Bring the pumps up to 5 BPM=865 psi continuing to work the tubing pulling up to 210K and the tubing started to slow move upwards with heavy drag. Continue working the tubing with pumps on and pumps off and the pipe moved freely (PU=135K and SO=80K). SimOps: SLB E-line re-heading and obtaining additional chemical cutters. 6/9/2016 6/9/2016 1.00 COMPZN RPCOMP CIRC P Circulate 346 bbls at 6 BPM=1080 10,260.0 10,260.0 19:15 20:15 psi while working the tubing. At bottoms up fine sand recovered over the shakers. After the circulation PU= 112K and SO=80K. SimOps: RD SLB E-line. 6/9/2016 6/9/2016 0.25 COMPZN RPCOMP OWFF P Observe the well for flow and the well 10,260.0 10,260.0 20:15 20:30 is static. 6/9/2016 6/9/2016 0.50 COMPZN RPCOMP PULL P Pull the tubing hanger to the rig floor. 10,260.0 10,224.0 20:30 21:00 Break out the top drive,break out the tubing hanger,lay down the tubing hanger,lay down the landing joint,and break out crossover. Blow down the top drive. 6/9/2016 6/10/2016 3.00 COMPZN RPCOMP PULL P PJSM. POOH laying down 3-1/2" 10,224.0 7,578.0 21:00 00:00 EUE 8rd tubing from 10224'to 7578' RKB at midnight(PU=89K and SO= 74K). Page 5/14 Report Printed: 6/28/2016 • 4W • Operations Summary (with Timelog Depths) 1 L-20 ConocoPhiigps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Tame End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (RKB) End Depth(itKB) 6/10/2016 6/10/2016 3.50 COMPZN RPCOMP PULL P Continue POOH laying down 3-1/2" 7,578.0 4,490.0 00:00 03:30 EUE 8rd tubing from 7578'to 4490' RKB(PU=68K and SO-65K). 6/10/2016 6/10/2016 0.25 COMPZN RPCOMP RURD P MU 3-1/2"EUE 8rd x 3-1/2"IBT 4,490.0 4,490.0 03:30 03:45 crossover onto the bottom of the 3- 1/2"EUE8rdTIW. 6/10/2016 6/10/2016 5.75 COMPZN RPCOMP PULL P Continue POOH laying down 3-1/2" 4,490.0 0.0 03:45 09:30 IBTM tubing from 4490'to surface. Recovered 2.875"DS Nipple,5 GLMs, 323 joints of tubing,and cut joint (length=15.06'). 6/10/2016 6/10/2016 0.25 COMPZN RPCOMP RURD P PU the landing joint and break out 6' 0.0 0.0 09:30 09:45 pup joint. 6/10/2016 6/10/2016 1.00 COMPZN RPCOMP SLKL T RU the Dutch riser for slickline 0.0 0.0 09:45 10:45 operations. 6/10/2016 6/10/2016 2.25 COMPZN RPCOMP SLKL T PJSM. RU HES slickline with 0.0 0.0 10:45 13:00 lubricator. 6/10/2016 6/10/2016 1.00 COMPZN RPCOMP SLKL T Slickline kinked,cut,and re-head. MU 0.0 0.0 13:00 14:00 slickline fishing tool string. PT the lubricator and Dutch riser to 1000 psi. 6/10/2016 6/10/2016 1.00 COMPZN RPCOMP SLKL T RIH with slickline fish tool string to the 0.0 0.0 14:00 15:00 liner top packer at 6047'ORKB but unable to get from the 7"casing into the 5-1/2"casing. POOH with slickline fishing tool string. 6/10/2016 6/10/2016 0.75 COMPZN RPCOMP SLKL T Tool string covered in sand. Change 0.0 0.0 15:00 15:45 slickline tool configuration to include bell guide. PT the lubricator to 1000 psi. 6/10/2016 6/10/2016 1.00 COMPZN RPCOMP SLKL T RIH with slickline bell guide fishing 0.0 0.0 15:45 16:45 tool string to 10267'ORKB. 6/10/2016 6/10/2016 1.75 COMPZN RPCOMP SLKL T Engage E-line fish and attempt to jar 0.0 0.0 16:45 18:30 free without success(sheared GS spear). 6/10/2016 6/10/2016 1.00 COMPZN RPCOMP SLKL T POOH with slickline bell guide fishing 0.0 0.0 18:30 19:30 tool string. 6/10/2016 6/10/2016 1.50 COMPZN RPCOMP SLKL T RD HES slickline and RD the Dutch 0.0 0.0 19:30 21:00 riser. 6/10/2016 6/10/2016 2.00 COMPZN RPCOMP RURD T Load,strap,and tally 3-1/2"PH-6 work 0.0 0.0 21:00 23:00 string. SimOps: Install the wear ring,RU Weatherford powe tubing tongs,and prep rig floor for RIH with fishing BHA. 6/10/2016 6/11/2016 1.00 COMPZN RPCOMP RURD T Bring Baker fishing tools to the rig 0.0 0.0 23:00 00:00 floor. 6/11/2016 6/11/2016 0.50 COMPZN RPCOMP BHAH T PU and MU BHA#1 -3"GS spear 0.0 27.0 00:00 00:30 assembly. 6/11/2016 6/11/2016 11.25 COMPZN RPCOMP PULD T RIH with BHA#1 on 3-1/2"PH-6 work 27.0 10,234.0 00:30 11:45 string to tagged earlier than expected at 10234'RKB (PU= 141K and SO= 80K). 6/11/2016 6/11/2016 1.75 COMPZN RPCOMP JAR T Engage GS spear into bait sub,PU to 10,234.0 10,234.0 11:45 13:30 160K,and no movement. MU a crossover and MU the top drive. Bring the pumps on and pressured up to 500 psi. Begin jarring on the E-line fish at 180K and after 19 jar hits the E- line fish came free. Page 6/14 Report Printed: 6/28/2016 • - ' F Operations Summary (with Timelog Depths) ' 4111AMAN 1 L-20 Con000wnitlips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Cede Time P-T-X Operation (RKB) End Depth MKS)'i 6/11/2016 6/11/2016 2.00 COMPZN RPCOMP CIRC T Drop 7/8"ball for pump out sub and 10,234.0 10,234.0 13:30 15:30 wait 30 minutes for the ball to fall to the ball seat. Pressure the work string to 2000 psi but the pump out sub would not open. Stage up the pump pressure to 4100 psi and the pump out sub still would not open. 6/11/2016 6/11/2016 6.50 COMPZN RPCOMP TRIP T TOOH standing back 3-1/2"PH-6 10,234.0 121.0 15:30 22:00 work string from 10234'to 121'RKB (string pulled wet). 6/11/2016 6/11/2016 0.25 COMPZN RPCOMP SFTY T PJSM for handling E-line fish. 121.0 121.0 22:00 22:15 6/11/2016 6/11/2016 0.25 COMPZN RPCOMP PULD T Lay down 2 joints of 3-1/2"PH-6 work 121.0 51.0 22:15 22:30 string. 6/11/2016 6/11/2016 0.75 COMPZN RPCOMP BHAH T Pull BHA#1 to surface and recovered 51.0 51.0 22:30 23:15 the E-line fish. Lay down the E-line chemical cutter fish. Fish was missing the upper bow spring centralizer springs. 6/11/2016 6/12/2016 0.75 COMPZN RPCOMP BHAH T Break down BHA#1 -3"GS spear 51.0 0.0 23:15 00:00 assembly. The entire BHA was packed of with scale from the 3-1/2" PH-6 work string. The 7/8"ball was recovered in the 2-3/8"IF x Reg crossover above the pump out sub. 6/12/2016 6/12/2016 0.75 COMPZN RPCOMP BHAH T Clean scale from the 3-1/2"PH-6 work 0.0 0.0 00:00 00:45 string out of crossovers,pump out sub,oil jar,and bumper sub. 6/12/2016 6/12/2016 0.25 COMPZN RPCOMP BHAH T Clean the rig floor. Off load fishing 0.0 0.0 00:45 01:00 tools from GS spear run off the rig floor and bring fishing tools for the cleanout run to the rig floor. 6/12/2016 6/12/2016 0.75 COMPZN RPCOMP BHAH T PU and MU BHA#2- cleanout 0.0 57.0 01:00 01:45 assembly using 1 joint of 3-1/2"PH-6 work string. 6/12/2016 6/12/2016 0.25 COMPZN RPCOMP PULD T PU and MU two joint of 3-1/2"PH-6 57.0 145.0 01:45 02:00 work string. 6/12/2016 6/12/2016 5.75 COMPZN RPCOMP TRIP T TIH with BHA#2 to 10185'RKB(PU= 145.0 10,185.0 02:00 07:45 154K and SO=82K). 6/12/2016 6/12/2016 0.25 COMPZN RPCOMP PULD T PU 2 joints of 3-1/2"PH-6 work string 10,185.0 10,185.0 07:45 08:00 for the pipe shed,MU crossover,and MU the top drive. 6/12/2016 6/12/2016 1.50 COMPZN RPCOMP REAM T Obtain parameters: PU=154K,SO= 10,185.0 10,291.0 08:00 09:30 82K,3 BPM=665 psi,and rotating weight= 111K at 40 RPM=6K ft-lbs. Wash down from 10185'to tag at 10275'RKB with 7K down at 3 BPM= 665 psi. Wash down from 10275'to tag at 10291'RKB with 3K down at 5 BPM=1650 psi,40 RPM=6K ft-lbs. 6/12/2016 6/12/2016 1.50 COMPZN RPCOMP CIRC T Pump 56 bbls hi-vis sweeps at 6 BPM 10,291.0 10,291.0 09:30 11:00 =2470 psi with rotating at 40 RMP and circulate the well clean. Recovered fine sand over the shakers. 6/12/2016 6/12/2016 0.25 COMPZN RPCOMP PULD T Lay down 1 joint of 3-1/2"PH-6 work 10,291.0 10,275.0 11:00 11:15 string and break out the crossover. Page 7/14 Report Printed: 6/28/2016 • • Operations Summary (with Timelog Depths) 1L-20 ConocoPhitlip Rig: DOYON 142 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(RKB) 6/12/2016 6/12/2016 0.25 COMPZN RPCOMP OWFF T Observe the well for flow for 10 10,275.0 10,275.0 11:15 11:30 minutes and the well is static. SimOps: Blow down the top drive. 6/12/2016 6/12/2016 3.75 COMPZN RPCOMP TRIP T TOOH standing back the 3-1/2"PH-6 10,275.0 57.0 11:30 15:15 work string from 10275'to 57'RKB. 6/12/2016 6/12/2016 0.75 COMPZN RPCOMP BHAH T Lay down BHA#2- cleanout 57.0 0.0 15:15 16:00 assembly. 6/12/2016 6/12/2016 1.50 COMPZN RPCOMP BHAH T PU and MU BHA#3-overshot 0.0 285.0 16:00 17:30 assembly for 3-1/2"tubing to fish the seal assembly. 6/12/2016 6/13/2016 6.50 COMPZN RPCOMP TRIP T TIH with BHA#3 to 9685'RKB at 285.0 9,685.0 17:30 00:00 midnight 6/13/2016 6/13/2016 0.25 COMPZN RPCOMP TRIP T Continue to TIH with BHA#3- 9,685.0 10,233.0 00:00 00:15 overshot assembly for 3-1/2"tubing from 9685'to 10233'RKB. 6/13/2016 6/13/2016 0.25 COMPZN RPCOMP PULD T PU 2 joints of 3-1/2"PH-6 work string 10,233.0 10,254.0 00:15 00:30 for the pipe shed with crossover and MU the top drive. 6/13/2016 6/13/2016 0.75 COMPZN RPCOMP FISH T Obtain parameters: PU=160K,SO= 10,254.0 10,277.0 00:30 01:15 83K, 1 BPM=150 psi, 15 RPM=6K ft -lbs. Wash down at 1 BPM=150 psi to tag at 10275'RKB with 10K down (did not see pressure increase)and PU with no fish. Attempted three time with and without pumps. PU 15', rotate at 15 RPM=6K ft-lbs, 1 BPM= 150,SO,and at 10275'torque increased and pump pressure increased 340 psi. Shut down the pumps/rotary and SO to 10277'with 10K down. Straight pull 140K over with no movement. 6/13/2016 6/13/2016 0.50 COMPZN RPCOMP JAR T Jar at 40K over three time with straight 10,277.0 10,270.0 01:15 01:45 pull 140K over then jar at 60K over 4 times with straight pull 140K over and on the 5th jar at 60K over the seals pulled free100K over. Observed the seals dragging out of the PBR and the fluid level dropped. SO and tag 5' high. 6/13/2016 6/13/2016 0.75 COMPZN RPCOMP CIRC T Drop the 7/8"ball for the pump out 10,270.0 10,270.0 01:45 02:30 sub,circulate at 1-2 BPM=900 psi to seat the ball,and the pump out sub sheared at 1100 psi. Circulate at 2 BPM=350 psi 6/13/2016 6/13/2016 0.50 COMPZN RPCOMP OWFF T Observe the well for flow and the well 10,270.0 10,270.0 02:30 03:00 is on a vac. Established an estimated 25 bbls/hour loss rate. 6/13/2016 6/13/2016 0.25 COMPZN RPCOMP PULD T Lay down 2 joint of 3-1/2"PH-6 work 10,270.0 10,233.0 03:00 03:15 string and blow down the top drive. 6/13/2016 6/13/2016 4.25 COMPZN RPCOMP TRIP T TOOH with BHA#3 from 10233'to 10,233.0 285.0 03:15 07:30 285'RKB. 6/13/2016 6/13/2016 1.25 COMPZN RPCOMP BHAH T Lay down 3-1/8"drill collars. 285.0 23.0 07:30 08:45 6/13/2016 6/13/2016 0.50 COMPZN RPCOMP PULL T Recovered cut joint,2.813"D nipple 23.0 23.0 08:45 09:15 with CA-2/nipple reducer installed,and seal assembly. Lay down fish and cleanout sands from the fish. Page 8/14 Report Printed: 6/28/2016 • Operations Summary (with Timelog Depths) 1L-20 Conooc Philiips Rig: DOYON 142 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 MKS} 6/13/2016 6/13/2016 0.75 COMPZN RPCOMP BHAH T Finish laying down BHA#3-overshot 23.0 0.0 09:15 10:00 assembly. Off load fishing tools from the rig floor. 6/13/2016 6/13/2016 1.00 COMPZN WELLPR BHAH T Strap mule shoe and crossover. PU 0.0 12.0 10:00 11:00 and MU BHA#4-mule shoe cleanout assembly. 6/13/2016 6/13/2016 4.75 COMPZN WELLPR TRIP T TIH with BHA#4 to 10289'RKB(PU= 12.0 10,289.0 11:00 15:45 155K and SO 85K), 6/13/2016 6/13/2016 0.25 COMPZN WELLPR WASH T Establish circulation and wash down 10,289.0 10,289.0 15:45 16:00 from 10289'into the PBR at 10303'to 10313'RKB at 2 BPM=165 psi. PU out of the PBR,increase the pump rate to 5 BPM=1070 psi and cleanout the PBR to 10313'RKB. PU out of the PBR and shut down the pumps. 6/13/2016 6/13/2016 0.25 COMPZN WELLPR OWFF T Observe the well for flow and the well 10,289.0 10,289.0 16:00 16:15 is on a vac. 6/13/2016 6/14/2016 . 7.75 COMPZN WELLPR PULD T POOH with BHA#4 laying down the 3- 10,289.0 1,300.0 16:15 00:00 1/2"PH-6 work string from 10289'to 1300'RKB at midnight. 6/14/2016 6/14/2016 1.75 COMPZN WELLPR PULD T Continue POOH with BHA#4laying 1,300.0 12.0 00:00 01:45 down the 3-1/2"PH-6 work string from 1300'to 10'RKB. 6/14/2016 6/14/2016 0.25 COMPZN WELLPR BHAH T Lay down mule shoe joint and break 12.0 0.0 01:45 02:00 out crossover. 6/14/2016 6/14/2016 1.00 COMPZN RPCOMP RURD T MU wear ring retrieving tool onto a 0.0 0.0 02:00 03:00 joint of DP,BOLDS,pull the wear ring, lay down the wear ring retrieving tool, and lay down joint of DP. Clean the rig floor. 6/14/2016 6/14/2016 0.25 COMPZN RPCOMP RURD P Break out 3-1/2"PH-6 crossover from 0.0 0.0 03:00 03:15 TIW and MU IBT crossover to the TIW for running completion. 6/14/2016 6/14/2016 11.75 COMPZN RPCOMP PUTB P PJSM. PU and MU seal assembly, 0.0 10,298.0 03:15 15:00 crossover, 1 joint of 3-1/2"IBTM tubing,nipple assembly, 1 joint of 3- 1/2"IBTM tubing,GLM#1,and RIH with 3-1/2"IBTM tubing per tally to 10298'RKB(PU=111K and SO= 80K). 6/14/2016 6/14/2016 1.50 COMPZN RPCOMP HOSO P MU the top drive,pump at 2 BPM=90 10,298.0 10,265.0 15:00 16:30 psi,engage the seal assembly into existing PBR,observed pressure increase to 120 psi,shut the pumps off,locate out with 5K down,and mark the pipe for space out. Lay down 3 joints of tubing, MU 4.34'pup,and MU joint of 3-1/2"tubing. 6/14/2016 6/14/2016 0.25 COMPZN RPCOMP THGR P MU the tubing hanger and landing 10,265.0 10,270.0 16:30 16:45 joint with circulating equipment. 6/14/2016 6/14/2016 1.75 COMPZN RPCOMP CRIH P PJSM. Reverse circulate 248 bbls of 10,270.0 10,270.0 16:45 18:30 8.9 ppg corrosion inhibited brine at 3.5 BPM=300 psi down the IA taking returns out the tubing. 6/14/2016 6/14/2016 0.25 COMPZN RPCOMP RURD P Drain the BOP stack. 10,270.0 10,270.0 18:30 18:45 6/14/2016 6/14/2016 0.75 COMPZN RPCOMP THGR P Land the tubing hanger and RILDS. 10,270.0 10,315.0 18:45 19:30 Page 9/14 Report Printed: 6/28/2016 •• Operations Summary (with Timelog Depths) ►fit,.� -¢ r } 1 L-20 ConocoPriiiiips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKEi) End Depth MKS) 6/14/2016 6/14/2016 2.50 COMPZN RPCOMP PRTS X Drop the ball&rod with rollers and 0.0 0.0 19:30 22:00 allow 15 minutes to fall to seat. Attempt to PT the tubing to 3000 psi but the tubing and IA pressures tracked stopped at 1500 psi and the tubing/IA dropped to 1000 psi in 13 minutes. Double check surface line up and secondary kill hose from the IA. Pressure back up to 1500 psi with the same result. Notified the town engineer. Pressure up on the IA to 2500 psi(the tubing pressure tracked the IA),triple block both sides,and the tubing/IA dropped to 1000 psi in 15 minutes. Reverse circulate 5 bbls down the IA taking returns up the tubing at 1 BPM=300 psi.getting 1 for 1 returns. 6/14/2016 6/14/2016 1.00 COMPZN RPCOMP WAIT X Discuss all options with town engineer 0.0 0.0 22:00 23:00 and decided to POOH with the completion due to the suspected failed SOV and suspected 5-1/2"casing leak. 6/14/2016 6/15/2016 1.00 COMPZN RPCOMP RURD X Blow down and RD 0.0 0.0 23:00 00:00 circulating/pressure testing equipment. SimOps: BOLDS. 6/15/2016 6/15/2016 0.50 COMPZN RPCOMP RURD X Prep the rig floor for TOOH standing 0.0 0.0 00:00 00:30 back the 3-1/2"tubing. 6/15/2016 6/15/2016 1.50 COMPZN RPCOMP SLPC X Cut and slip 102'of drilling line. 0.0 0.0 00:30 02:00 6/15/2016 6/15/2016 •0.25 COMPZN RPCOMP PULL X Pull the tubing hanger to the rig floor, 10,315.0 10,276.0 02:00 02:15 lay down the tubing hanger,and lay down the landing joint. 6/15/2016 6/15/2016 1.75 COMPZN RPCOMP PULL X TOOH standing back the 3-1/2"tubing 10,276.0 6,858.0 02:15 04:00 from 10276'to 6858'RKB. 6/15/2016 6/15/2016 0.50 COMPZN RPCOMP PRTS T RU head pin and pressure testing 6,858.0 6,858.0 04:00 04:30 equipment to GLM#1 with DV. Attempt to PT the tubing but just established circulation at 2 BPM= 1000 psi. RD pressure testing equipment and head pin. 6/15/2016 6/15/2016 1.50 COMPZN RPCOMP PULL X Continue to TOOH standing back the 6,858.0 4,068.0 04:30 06:00 3-1/2"tubing from 6858'to 4068'RKB. 6/15/2016 6/15/2016 0.50 COMPZN RPCOMP PRTS T RU head pin and pressure testing 4,068.0 4,068.0 06:00 06:30 equipment to GLM#2 with SOV. Attempt to PT the tubing and observed flow through the SOV. RD pressure testing equipment and head pin. 6/15/2016 6/15/2016 0.50 COMPZN RPCOMP PULL X Lay down GLM#2 with SOV and send 4,068.0 4,042.0 06:30 07:00 outside. Wire line shop pulled the sheared SOV and installed a new 2500 psi(casing to tubing)SOV. Page 10/14 Report Printed: 6/28/2016 • • • Operations Summary (with Timelog Depths) 1 L-20 ConocoPhillips Rig: DOYON 142 Job: RECOMPLETION Time Log Startdepth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (RKB) End',Depth(ft KB 6/15/2016 6/15/2016 0.50 COMPZN RPCOMP PRTS T RU head pin and pressure testing 4,042.0 4,042.0 07:00 07:30 equipment to the tubing. PT the tubing against the ball&rod on seat in the RHC plug body to 1000 psi for 10 minutes(good test). RD pressure testing equipment and head pin. 6/15/2016 6/15/2016 4.50 COMPZN RPCOMP PULL X Continue to TOOH standing back the 4,042.0 12.0 07:30 12:00 3-1/2"tubing from 4068'to surface laying down GLM's. 6/15/2016 6/15/2016 0.75 COMPZN RPCOMP PULL X Lay down and inspect seal assembly. 12.0 0.0 12:00 12:45 6/15/2016 6/15/2016 0.50 COMPZN WELLPR SVRG X Service Top Drive 0.0 0.0 12:45 13:15 6/15/2016 6/15/2016 1.00 COMPZN WELLPR BHAH X PU and MU BHA#5-5-1/2"test 0.0 44.0 13:15 14:15 packer with 5-1/2"casing scraper and set off to the side. 6/15/2016 6/15/2016 0.75 COMPZN WELLPR RURD X MU wear ring running tool,install the 0.0 0.0 14:15 15:00 wear ring,and lay down the wear ring running tool. 6/15/2016 6/15/2016 6.75 COMPZN WELLPR PULD X RIH with BHA#5 on 3-1/2"PH-6 work 0.0 6,139.0 15:00 21:45 string to 6139'RKB(-50'down inside the 5-1/2"liner). 6/15/2016 6/15/2016 0.25 COMPZN WELLPR MPSP X MU the crossover to the 3-1/2"PH-6 6,139.0 6,139.0 21:45 22:00 work string and MU the top drive. Set the 5-1/2"test packer at 6099.48'RKB (center of element). 6/15/2016 6/15/2016 0.75 COMPZN WELLPR PRTS X Purge the kill line,close annular,and 6,139.0 6,139.0 22:00 22:45 PT the IA(5-1/2"liner top packer and 7"casing to surface)to 2500 psi for 10 minutes(good test). Bleed the pressure to 0 psi and open annular. 6/15/2016 6/15/2016 0.25 COMPZN WELLPR MPSP X Release the test packer and 6,139.0 6,139.0 22:45 23:00 manipulate back into the running mode. Break out the top drive and break out the crossover. 6/15/2016 6/16/2016 1.00 COMPZN WELLPR PULD X Continue to RIH with BHA#5 on 3- 6,139.0 7,145.0 23:00 00:00 1/2"PH-6 work string from 6139'to 7145'RKB at midnight 6/16/2016 6/16/2016 4.00 COMPZN WELLPR PULD X Continue to RIH with BHA#5-5-1/2" 7,145.0 10,335.0 00:00 04:00 test packer with 5-1/2"casing scraper on 3-1/2"PH-6 work string from 7145' to 10335'RKB 6/16/2016 6/16/2016 1.50 COMPZN WELLPR CIRC X MU the top drive and break circulation 10,335.0 10,335.0 04:00 05:30 at 2 BPM=100 psi. Pump 30 bbl hi- vis sweep and circulate out of the hole at 2.5 BPM=350 psi but losses are at 60%. Shut down the pumps 6/16/2016 6/16/2016 8.00 COMPZN WELLPR PRTS X Set the test packer at 10287.23'RKB 10,335.0 8,666.0 05:30 13:30 (center of element). Begin 2500 psi test sequence as follows: 10287'-fail, 10193'-fail, 10098'-fail, 10004'fail, 9909'-fail,9802'-fail,8973'-fail, 8504'—pass,8785'-fail,8693'-fail, 8634'-pass, 8666'—pass. Leak between 8693'-8666'RKB. 6/16/2016 6/16/2016 4.00 COMPZN WELLPR TRIP X TOOH with BHA#5-5-1/2"test 8,666.0 43.0 13:30 17:30 packer with 5-1/2"casing scraper standing back 3-1/2"PH-6 work string from 8666'to 43'RKB Page 11/14 Report Printed: 6/28/2016 ` Operations Summary (with Timelog Depths) 1L-20 ConocaPhillips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftKE) 6/16/2016 6/16/2016 0.50 COMPZN WELLPR BHAH X Lay down 5-1/2"test packer and 5- 43.0 0.0 17:30 18:00 1/2"casing scraper 6/16/2016 6/16/2016 4.00 COMPZN RPCOMP PUTB X PU and MU seal assembly, 1 joint of 3 0.0 1,728.0 18:00 22:00 -1/2"IBTM tubing,nipple assembly,50 joints of 3-1/2"IBTM tubing from the derrick,and FAB-1 packer assembly with B-2 hydraulic setting tool. 6/16/2016 6/17/2016 2.00 COMPZN RPCOMP RCST X RIH with stacked packer assembly on 1,728.0 5,478.0 22:00 00:00 3-1/2"PH-6 work string from 1728'to 5478'RKB. 6/17/2016 6/17/2016 4.00 COMPZN RPCOMP RCST X Continue to TIH with stacked packer 5,478.0 10,302.0 00:00 04:00 assembly on 3-1/2"PH-6 work string from 5478'to 10271'RKB. PU and MU two joints of 3-1/2"PH-6 work string,MU the top drive,roll the pumps at 2 BPM=90 psi,engage the seal assembly(observed pressure increase to 130 psi)into existing PBR, shut down the pumps,locate out, mark the pipe,and PU to just above the PBR to 10302'RKB to circulate corrosion inhibited brine. 6/17/2016 6/17/2016 1.75 COMPZN RPCOMP CRIH X PJSM. Pump 30 bbls of 8.9 ppg 10,302.0 10,302.0 04:00 05:45 corrosion inhibited brine and chase with 180 bbls of clean 8.9 ppg brine at 3.5 BPM=415 psi. Shut down the pumps. 6/17/2016 6/17/2016 1.00 COMPZN RPCOMP PACK X Drop the setting ball,engage the seal 10,302.0 10,315.0 05:45 06:45 assembly,place the packer on depth, and pump ball to seat. Pressure up to 2000 psi to set the FAB-1 packer, PU 35K over,bleed pressure to 0 psi,and SO 35K down. Pressure up to 2000 psi to, PU 50K over,bleed pressure to 0 psi,and SO 45K down. 6/17/2016 6/17/2016 0.50 COMPZN RPCOMP PRTS X Pressure up on the IA to 2500 to test 10,315.0 10,315.0 06:45 07:15 the FAB-1 packer for 15 minutes (good test). 6/17/2016 6/17/2016 0.50 COMPZN RPCOMP PACK X Rotate 15 turn to the right to release 10,315.0 8,605.0 07:15 07:45 the B-2 hydraulic setting tool(top of the packer at 8608'RKB). Pressure up to 3220 psi to shear the ball seat and confirmed a good shear by establishing circulation. 6/17/2016 6/17/2016 '5.75 COMPZN RPCOMP PULD X POOH laying down 3-1/2"PH-6 work 8,605.0 2,945.0 07:45 13:30 string from 8605'to 2945'RKB. 6/17/2016 6/17/2016 0.50 COMPZN RPCOMP TRIP X TIH with 3-1/2"PH-6 work string out of 2,945.0 4,634.0 13:30 14:00 derrick from 2945'to 4634'RKB. 6/17/2016 6/17/2016 4.50 COMPZN RPCOMP PULD X POOH laying down 3-1/2"PH-6 work 4,634.0 23.0 14:00 18:30 string from 4634'to 23'RKB. 6/17/2016 6/17/2016 1.00 COMPZN RPCOMP BHAH X Breakdown B-2 hydraulic setting tool 23.0 0.0 18:30 19:30 and bumper sub. Clear and clean rig floor, 6/17/2016 6/17/2016 0.50 COMPZN RPCOMP RURD X MU wear ring retrieving tool,pull the 0.0 0.0 19:30 20:00 wear ring,and lay down the wear ring retrieving tool. Page 12/14 Report Printed: 6/28/2016 • M Operations Summary (with Timelog Depths) 1 L-20 ConocoPhillips >„xk Rig: DOYON 142 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(RKB) 6/17/2016 6/17/2016 0.25 COMPZN RPCOMP SFTY P Held PJSM with rig crew,Baker 0.0 0.0 20:00 20:15 completion hand,and Weatherford power tong operators on PU,MU and RIH with 3-1/2"upper completion. 6/17/2016 6/18/2016 3.75 COMPZN RPCOMP PUTB P PU and MU anchor/PBR assembly, 1 0.0 3,514.0 20:15 00:00 joint of 3-1/2"tubing, GLM with DV, and TIH with 3-1/2"tubing from the derrick installing GLM's per tally to 3514'RKB at midnight(PU=68K and SO=66K). 6/18/2016 6/18/2016 4.50 COMPZN RPCOMP PUTB P Continue to TIH with 3-1/2"tubing 3,514.0 8,589.0 00:00 04:30 from the derrick installing GLM's per tally from 3514'to 8589'RKB. 6/18/2016 6/18/2016 1.50 COMPZN RPCOMP CRIH P Pump 46 bbls of 8.9 ppg corrosion 8,589.0 8,589.0 04:30 06:00 inhibited brine and chase with 144 bbls of clean brine at 3.5 BPM=498 psi. 6/18/2016 6/18/2016 0.50 COMPZN RPCOMP HOSO P Latch KBH-22 anchor into the FAB-1 8,589.0 8,608.0 06:00 06:30 packer,set 10K down,and PU 10K to confirm it is anchored into the packer. Drop the ball&rod with rollers. Pressure up to 2000 psi and PU 10K over to shear the seal assembly from the PBR(top of the PBR at 8589' RKB). 6/18/2016 6/18/2016 0.75 COMPZN RPCOMP HOSO P Locate out and mark the pipe for 8,589.0 8,552.0 06:30 07:15 space out. Lay down 2 joints of tubing. MU pups 10.3'10.29',and 4.34'. MU 1 joint of 3-1/2"tubing. 6/18/2016 6/18/2016 0.75 COMPZN RPCOMP THGR P MU the tubing hanger,drain the BOPE 8,552.0 8,599.0 07:15 08:00 stack,land the tubing,and RILDS 6/18/2016 6/18/2016 3.00 COMPZN RPCOMP PRTS P PT the tubing to 3000 psi for 15 0.0 0.0 08:00 11:00 minutes(good test). Bleed the tubing to 1200 psi and pressure up on the IA and observed communication. Bleed the IA to 0 psi and bleed the tubing to 0 psi. Install double plug valve on the tubing. Retest the tubing to 3000 psi for 15 minutes(good test),bleed the tubing to 1200 psi,and PT the IA to 2500 psi for 30 minutes(good test). Bleed the IA to 0 psi and bleed the tubing to 0 psi. Ramp up the pressure on the IA to shear the SOV(sheared at 2483 psi. Pump 2 bbls at 2 BPM= 350 psi to confirm flow through sheared SOV 6/18/2016 6/18/2016 1.00 COMPZN WHDBOP MPSP P Install 3"HP BPV with dry rod. 0.0 0.0 11:00 12:00 Pressure up on the IA to 1000 psi for 10 minutes to test the BPV from below in the direction of flow(good test). 6/18/2016 6/18/2016 3.00 COMPZN WHDBOP NUND P ND the BOP stack. 0.0 0.0 12:00 15:00 SimOps: Flush the mud pumps with fresh water. Blow down the choke, kill,hole fill,and mud lines. Empty and clean the pits. Change out lube pump on the draw works. *Swapped to generator power at 12:45 hours.* Page 13/14 Report Printed: 6/28/2016 • • Operations Summary (with Timelog Depths) 1 L-20 Con ocoPhiilitps Rig: DOYON 142 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(ftKD); 6/18/2016 6/18/2016 1.00 COMPZN WHDBOP NUND P ND the Dutch rise nipple. Stand the 0.0 0.0 15:00 16:00 BOP stack back and secure. 6/18/2016 6/18/2016 1.50 COMPZN WHDBOP NUND P Install the blanking plug into the BPV. 0.0 0.0 16:00 17:30 NU the tubing head adapter and NU the tree. SimOps: Start BWM on the BOP stack at 16:30 hours. 6/18/2016 6/18/2016 1.50 COMPZN WHDBOP PRTS P PT the tubing hanger void to 250/5000 0.0 0.0 17:30 19:00 psi for 15 minutes(good test). Open SSV. SimOps: Continue to work on BWM on the BOP stack. 6/18/2016 6/18/2016 1.50 COMPZN WHDBOP PRTS P RU to PT the tree. Fill the tree with 0.0 0.0 19:00 20:30 diesel and purge the air. PT the tree to 250/5000 psi for 5 minutes(good test). Bleed to 0 psi and RD tree testing equipment. 6/18/2016 6/18/2016 0.50 COMPZN WHDBOP MPSP P Pull the blanking plug and BPV with 0.0 0.0 20:30 21:00 the dry rod. 6/18/2016 6/18/2016 2.00 COMPZN WHDBOP FRZP P PJSM. RU LRS. PT lines to 2500 psi 0.0 0.0 21:00 23:00 (good test). Pump 90 bbls of diesel down the IA taking return up the tubing at 2 BPM(ICP=900 psi and FCP= 1600 psi). Place the tubing and IA in communication allowing the diesel to u-tube and equalize. RD LRS and circulating equipment. Pressures: Tubing= 160 psi and IA= 160 psi. SimOps: Continue to work on BWM on the BOP stack. 6/18/2016 6/19/2016 1.00 COMPZN WHDBOP MPSP P PU and RU the lubricator to the tree. 0.0 0.0 23:00 00:00 SimOps: BWM completed at 11:45 hours. 6/19/2016 6/19/2016 1.50 COMPZN WHDBOP MPSP P PT the lubricator to 1000 psi(good 0.0 0.0 00:00 01:30 test),install the 3"H BPV,and RD the lubricator. 6/19/2016 6/19/2016 1.50 DEMOB MOVE RURD P Secure the tree. Clean and clear the 0.0 0.0 01:30 03:00 cellar. Pump out the cellar box. Rig released at 03:00 hours. Page 14/14 Report Printed: 6/28/2016 lk, KUP OD1 L-20A COriOCO hilkkpst. gle Well Attrib Max AnMD TD • Alaska-Inc a M1Wellbore APVUWI Field Name Wellbore Status ncl9) MD(ftKB) Act Btm(ftKB) C:.xoeophllhps : 500292202701 KUPARUK RIVER UNIT PROD 70.54 7,278.05 10,965.0 --. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 11-20A,6/2912016 7 11 03 AM SSSV:NIPPLE 50 8/2/2015 Last WO: 6/19/2016 3/31/1991 Vertical schomanc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,zs.e ":ti*E Last Tag:SLM 10,580.0 5/4/2012 Rev Reason:WORKOVER;GLV C/O lehallf 6/27/2016 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 4J` CONDUCTOR 16 15.062 35.0 115.0 115.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 6,000.0 3,682.5 40.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread WINDOW A 8 6.000 6,210.0 6,220.0 3,778.9 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread M CONDUCTOR;35.0-115.0- '-'1.°PRODUCTION 7 6.276 35.0 6,500.0 3,901.9 26.00 L-80 BTCM Post S/T Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 5 1/2 4.950 6,047.0 10,491.0 5,911.5 15.50 L-80 HYDRIL 511 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth)T/D)...Wt/Len(1...Grade Top Thread GAS LIFT 3,574.2 LINER A 3 1/2 2.992 10,322.4 10,934.0 9.30 L-80 ABT-MOD Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 10,322.4 5,759.9 27.75 PACKER BAKER SABL-3 PACKER w/TIEBACK EXTENSION 3.000 Tubing Strings ? I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.)Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection )444 Upper Completion 31/2 2.992 29.8 8.622.0 4,735.7 9.30 L-80 EUE 8rd Mod ` " 1 RWO 2016 Completion Details SURFACE;35.06,000.0 L Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) 11 29.8 29.8' 0.05 HANGER Tubing Hanger,McEvoy Gen 4,7"0 3-1/2"EUE 8rd,1 2.950 GAS LIFT;6,034.9 IX. control line port,3"H BPVG ■i. L_ 8,599.1 4,725.7 64.31 LOCATOR 'Locator Sub,Baker GBH-22(bottom of the locator is 2.980 7 spaced out 2') It 8,600.1 4,726.2 64.30 SEAL ASSY Seal Assembly,Baker 80-40(total length=11.82') 2.980 8,602.4 4,727.2 64.28 PBR PBR,Baker,80-40 4.000 • 8,620.3 4,734.9' 64.10 ANCHOR Anchor,Baker 40FA36 KBH-22 3.010 WINDOW A,6,210 0-6,220.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection Isolation Packer RWO 31/2 2.992 8,621.0 10,325.8 5,763.0 9.30 L-80 IBTM 2016 PRODUCTION Post Sri, 35.06,500.0 Completion Details rit Nominal ID GAS LIFT;7,642.6 '„. Top(ftKB) Top(TVD)(MB) Top Incl 9) Item Des Corn (in) 8,621.0 4,735.2 64.09 PACKER Packer,Baker 456-362-300 FAB-1 Permanent Packer 3.000 10,257.1 5,702.7 29.77'NIPPLE Nipple,Halliburton 2.813"X 2.813 GAS LIFT:es435 10,313.2 5,751.7 27.93 LOCATOR Locator Sub,Baker GBH-22(bottom of the locator is 3.910 spaced out 2') 10,314.0 5,752.5 27.89 SEAL ASSY Seal Assembly,Baker 80-40 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection Original Completion 4 2.937 10,316.0 10,341.3 5,776.7 LOCATOR;8,599.1 SEAL ASSY;8,60ll1711 .1 Completion Details ti PBR;8,802.4 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 10,316.0 5,754.2' 27.81 PBR BAKER 80-40 PBR 2.937 ANCHOR;8,620.3 '_ 10,339.6 5,775.1 27.60 ANCHOR KBH-22 ANCHOR SEAL ASSEMBLY 2.780 PACKER;8,620.9 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(51(13) (ftKB) (°) Des Com Run Date ID(in) 10,800.0 6,199.2 20.79 FISH RETAINER Cement retainer pushed to bottom with 7/21/2000 milling 7/21/2000 Perforations&Slots NIPPLE;10,257.1 3. Dens Top IND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 10,574.0 10,604.0 5,988.0 6,016.0 C-4,1L-20A 8/19/2000 6.0 APERF 2 1/2"HC;60 deg ph, alternating BH/PJ 4.. 10,695.0 10,705.0 6,101.0' 6,110.4 UNIT B,1L- 6/6/2000 6.0 SQZ SQUEEZED 7/15/2000 20A 10,742.0 10,762.0 6,145.0 6,163.7 A-6,A-5,1L- 7/30/2000 4.0 RPERF 2 1/2"HC BH,90 deg ph 20A LOCATOR;10,313.1 Stimulations&Treatments Min Top Mao Btm SEAL ASSY;10,314.0 Depth Depth Top(ND) Btm(TVD) PBR;10,318.0 (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com II, 10,695.0 10,705.0 6,101.0 6,110.4 FRAC 2/21/2002 FRAC 79M#16/20 PROPPANT,7.7 ppa on PERFS 1.1 Cement Squeezes Top(ND) Btm(ND) ANCHOR,10,339.6 .B. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn I 10,762.0 10,782.0 6,163.7 6,182.4 Cement 6/6/2000 Squeeze PRODUCTION;8,047.0- 10,695.0 10,705.0 6,101.0 6,110.4 Cement 7/15/2000 10,491.0 Squeeze APERF;10,574.0-10,604.0 Mandrel Inserts SQZ;10,695.0-10,705 0. St FRAC;10,695.0 I ati on Top(ND) Valve Latch Port Size TRO Run RPERF;10,742.0-10,782.0 N Top(ftKB) (ftKB) Make Model OD(in) Sera Type Type (in) (psi) Run Date Com 1 3,574.2 2,602.4 Camco KBG-2- 1 GAS LIFT GLV BTM 0.188 1,304.0 6/23/2016 FISH;10,800.0 -- 9 2 6,034.9 3,697.7 Camco KBG-2- 1 GAS LIFT OV BTM 0.188 0.0 6/23/2016 9 3 7,642.6 4,342.5 Camco KBG-2- 1 GAS LIFT DMY SDK- 0.000 0.0 6/18/2016 9 1A LINER A;10,322.4-10,934.0 Drilling KUP �OD 1 L-20A ConocoPhillips s5 A(sska,inc. cno<orhahp. ... 1L-20A,6/29/2016 7.1 R03AM VerbcaI schema50(actual) HANGER;29.8 11.0. al Mandrel Inserts t lisj i'' tni Top(TVD) N Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model 00(in) Sery Type Type (in) (psi) Run Date Com 4 8,543.5 4,702.0 Camco KBG-2- 1 GAS LIFT DMY SDK- 0.000 0.0 6/18/2016 9 1A Notes:General&Safety J"_/�CONDUCTOR;35.0-1150- End Date Annotation 4/13/2000 NOTE:Sidetracked,set CIBP 8 whipstock@ 6210'in 7"CSG;milled window for sidetrack. 7/21/2000 NOTE:Milled EZSV 8 pushed to bottom(10800'CTM) GAS LIFT;3,574.2 It 2/9/2011 NOTE:View Schematic w/Alaska Schematic9.0 5/4/2012 NOTE:LINER APPEARS TO BE COLLAPSED 4/6/2015 NOTE:WAIVERED WELL,IA X OA COMMUNICATION REVISED I SURFACE;35.06,000.0 - D GAS LIFT;8,034.9 II •J I L. 1 WINDOW A;8,210.06,220.0— .I PRODUCTION Post SF; 35.06,500.0 I GAS LIFT;7,842.6 I .. GAS LIFT;8,543.5 I I ilk LOCATOR;8,599.1 MIR SEAL ASSY;8,600.1 PBR;8,602.4 l'--1 ANCHOR;8,620.3 PACKER;8,620.9 in I I NIPPLE;10,257.1. - I 11 LOCATOR;10,313.1 1 azar SEAL ASSY;10,314.0- PBR;10,316.0 I ANCHOR;10,339.6 __ : PRODUCTION;6,047.0- 10,491.0 APERF;10,574.0-10,604.0 SOZ;10,895.0-10,705.0 FRAC;10,695.0\_I RPERF;10,742.0.10,762.0 FISH;10,800.0 LINER A;10,322.4-10,934.0 i • v OF T1,� • y/,mss, THE STATE Alaska Oil and Gas " � Of LAsKA Conservation Commission 5>t£= 333 West Seventh Avenue " .' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o Main: 907.279.1433 ALA6 "-""" Fax: 907.276.7542 www.aogcc.alaska.gov Sara Heskin Associate Wells Engineer ConocoPhillips Alaska, Inc. scmoo DEC '!t. 4 2016 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1L-20A Permit to Drill Number: 200-036 Sundry Number: 316-336 Dear Ms. Heskin: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this ?2 day of June, 2016. RBDMS jL JUN 2 8 2016 • • RECEIVED STATE OF ALASKA JUN 1 7 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION QTS 1 2 7 //6, APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon LI Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑✓ , Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ✓� Other: Stack Packei: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development Q , 200-036 3.Address. v Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-22027-01 k 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❑✓ ✓ KRU 1L-20A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025660 , Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective DepthepMD: Effective Depth TVD:r4+5 MPSP(psi): Plugs(MD): Junk(MD): 10934' 6325' 10 1 S p a 1 S9g 3 j4 ` 1995 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 115' 115' Surface 5965' 9.625" 6000' 3683' Production S/T 6465' 7" 6500' 3902' Production 4444' 5-1/2" 10491' 5912' Liner 3-1/2" 10934' 6324' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10574'-10604' . 5988'-6016' 3.5" L-80 10341' 10695-10705' , 6101'-6110' 10742'-10762' . 6145'-6164' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV:none Packers:Baker SABL-3 Packer w/tieback extension MD=10322 TVD=5760 12.Attachments: Proposal Summary a Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 . Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/1/2016 OIL Q , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Yes Date: 6/15/2016 GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: Victoria Leopp I 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. Contact Sara Heskin©265-1027 Email sara.heskincop.com Printed Name Sara Heskin Title Associate Wells Engineer � Wm Phone 265-1027 Signature 901/1�6 4/�i Date (0J J CO // V COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ` _ S 3 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 54P tea f h-a 3 CO 'p5 AilelV/a✓ prevr� ftv fr,5i to Z5 OpS'y Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: 1 0— 4 0 f Q i# APPROVED BY Approved by: ya_ M kl..`, COMMISSIONER THE COMMISSION Date: _ 2-2._ (4 1/�� �® R140GaMoAtiing Y / L ����16�0 �1G' I� Submin Form ane Form 10-403 Revised 11/2015 for 12 months from the date of approval. Attachments in Duplicate 4(672 ( RBDMS I,L. JUN 2 8 2016 RECEIVED `✓ JUN 17 2016 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 June 16th,2016 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover Kuparuk Producer 1L-20A(PTD#200-036). Well 1L-20 was drilled and completed in April of 1990 as a Kuparuk A&C-sand producing well. Due to two incidents of stuck drill pipe and collapsed casing,the well was sidetracked in March of 2000 and re-designated as 1L-20A.The Kuparuk A&C-sands were perforated in 2000.Later on,the C-sand was fracked in 2002. In April of 2015,the tubing was permanently patched from 8,659'MD to 8,707'MD across GLM#3. The well failed a waiver compliance tubing integrity fluid level survey(TIFL)in March of 2016.As a result,a leak detect log (LDL)was run and identified multiple tubing leaks—5' - 100' below the existing tubing patch.The objective of the workover is to pull and replace the 3-'/2"upper gas lift completion. The workover on 1L-20A began June 4, 2016. The 3-1/2"upper completion was successfully pulled and replaced; However,when pressure testing the tubing the inner annulus(IA)and tubing pressures tracked, indicating tubing by inner annulus (TxIA) communication. Subsequently, a combination mechanical integrity test (CMIT) IA x T was performed to 2,500 psi.This pressure bled to 2,000 psi in less than 5 minutes,confirming a leak in the packer and/or casing_The decision was made to pull the upper completion and run a test packer to identify the leak location. Upon laying down the 3-1/2"upper completion,the shear out valve was inspected.The condition of the valve indicated it had sheared prematurely and was identified as the cause of the TxIA communication. The test packer confirmed a casing leak below 8,666'MD.As a result,a permanent packer will be installed to isolate the casing leak. The purpose of this letter is to formalize the verbal approval and request a retroactive sundry to complete the workover on 1L-20A by running the 3-1/2"upper completion and stacking a packer to fix the casing leak.The original scope of this producer workover did not require a sundry, thus there is the first documentation provided to the AOGCC. If you have any questions or require any further information, please call me at 907-331-7514 or email me at sara.heskin@conocophillips.com. Sincerely, 0 0'14 Sara Heskin Associate Wells Engineer CPAI Drilling and Wells • • ConocoPhillips 1L-20A Proposed Workover Pull & Replace Tubing, Casing Leak Repair Original PTD: #200-036 General Well Information: Well Type: Kuparuk A&C-Sand Producer MPSP: 1,995 psi from most recent SBHP w/gradient of 0.1 psi/ft to surface Reservoir Pressure/TVD: 2,595 psi at 10,590' RKB/6,003'ND (5/6/2016) EMW:8.4 ppg assuming diesel below GLM 4 Wellhead Type: McEvoy Gen IV 3-Ya"5M BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: CMIT—T x IA to 2500 psi passed April 26, 2016(potentially false positive due to packed off sand down hole) TIFL—Failed 3/13/2016 Start Date: 6/4/2016 Production Engineer: Amanda Bacala Workover Engineer: Sara Heskin (907) 265-1027 sara.heskin@cop.com Current Well Status: Doyon 142 is currently working over the KRU producer 1L-20A. Scope of Work: • Pull the leaking 3-1/2" Upper Completion • Run a new 3-1/2" Upper Completion with a stacked packer Summary of Proposed RWO Procedure: Pre-Rig Work(completed): 1. Pull GLV from KBMM2 mandrel at 3,598' KB and replace with DV. 2. Pull OV from KBG-2-9 mandrel at 6,465' KB and replace with DV. 3. Pull DV from KBG-2-9 mandrel at 9,779' KB. 4. Obtain SBHP with gradient stop per procedure already in progress. 5. Test Tubing and IC PO's 6. Function Test LDS's 7. Set BPV Proposed Rig Workover Procedure(completed): 1. MIRU RWO Rig. 2. Pull BPV. Circulate KWF. Obtain SITP&SICP; if pressure is observed at surface, calculate new KWF and repeat circulation if necessary.Verify well is static prior to proceeding. 3. Install CA-2 Plug on Slickline. 4. Set BPV, ND tree, set blanking plug, NU BOPE, &test BOPE to 250/3,000 psig low/high. 5. Pull blanking plug, pull BPV, screw in landing joint, BOLDS, & unseat tubing hanger. • ConocoPhillips 1L-20A Proposed Workover Pull & Replace Tubing, Casing Leak Repair Original PTD: #200-036 6. P/U on tubing&attempt to pull tubing hanger to the rig floor-tubing will not pull free. 7. R/U E-Line, cut tubing at 10,290'MD. a. E-line cutter stuck through tubing patch-released cutter downhole. b. Fish cutter on slickline-unsuccessful due to sand down hole. 8. P/U on tubing and pull hanger to rig floor, L/D 3-1/2" upper completions to tubing cut at 10,290' MD. a. Fish cutter on 3-1/2" drill pipe b. Perform clean out run with wash pipe-washed out 20'sand 9. Fish seal assembly from PBR on DP using an overshot fishing tool-retrieved tubing stub and seals. 10. M/U &TIH with new 3-Y2" upper completion as per design. 11. Spot corrosion inhibited brine in IA 12. Fully locate poor boy overshot and pick up 2'to space out. 13. Drop ball and rod 14. Pressure test tubing-TxIA communication 15. Pressure test C-MITTxIA Failed-Suspected casing leak 16. L/D 3-1/2" upper completions in preparation for test packer run 17. RIH on DP with test packer assembly-identified casing leak below 8,666' MD To Be Completed Rig Work: 18. RIH on drillpipe and set production packer 19. Spot corrosion inhibited brine in IA to just above the new packer 20. TOOH and lay down drill pipe 21. P/U and run new 3-1/2" upper gas lift completion 22. Slack off to fully locate and space-out seals into the PBR. 23. Lay-down two joints,space-out with tubing pups, M/U tubing hanger. 24. Spot corrosion inhibited brine in IA, land hanger, & RILDS. 25. Pressure-test tubing to 3,500 psi& IA to 3,000 psi. Bleed the IA&then the tubing. Ramp up the IA pressure to quickly to shear the SOV. 26. Back-out landing joint& install BPV. 27. ND BOPE, install blanking plug, NU tree, & pressure test tree. 28. Remove blanking plug and BPV. 29. Freeze protect well through SOV. 30. Set BPV. 31. RDMO RWO Rig. Proposed Post-Rig Work: 1. Pull BPV. 2. RIH and set catcher on top of RHC Plug body in 2.813" DS Nipple 3. Run gas lift design &swap SOV for DV. 4. Retrieve catcher then retrieve RHC Plug body 5. Reset well house(s) & re-attach flow line(s). 6. Turn well over to operations. r. KUP PROD 0 1L-20A ConocoP1 ' Mips o Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°1 MD(ftKB) Act Btm(ftKB) c ,ocoPrv" 500292202701 KUPARUK RIVER UNIT PROD 70.54 7,278.05 10,965.0 - . Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) .. Rig Release Date 1L-20A 5/10/2016 2:55:34 PM SSSV:NIPPLE 50 8/2/2015 Last WO: 4/12/2000 3/31/1991 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,580.0 5/4/2012 Rev Reason:PULL CA-2 PLUG,GLV C/O pproven 5/10/2016 HANGER:29.8 It a l Casing Strings Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread IT CONDUCTOR 16 15.062 35.0 115.0 115.0 62.58 H-40 WELDED �l Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 35.0 6,000.0 3,682.5 40.00 L-80 BTCM -- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(T 0)...Wt/Len(I...Grade Top Thread WINDOWA 8 6.000 6,210.0 6,220.0 3,778.9 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I.. Grade Top Thread -A•A/cONDOc7oR;35.0415.04innni' -i�.�.h.oaJ`PPost RODSURCTION 7 6.276 35.0 6,500.0 3,901.9 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread NIPPLE;531.6IN PRODUCTION 51/2 4.950 6,047.0 10,491.0 5,911.5 15.50 L-80 HYDRIL 511 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len II...Grade Top Thread LINER A 31/2 2.992 10,322.4 10,934.0 9.30 L-80 ABT-MOD Liner Details /� Nominal ID GAS LIFT;3,598.2 - ■ Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) .1 10,322.4- 5,759.9 27.75-PACKER BAKER SABL-3 PACKER WITIEBACK EXTENSION 3.000 Tubing Strings -- Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/21 2.9921 29.81 10 ,341.31 5,776.71 9.30 L-80 I EUEBRDMOD Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl I°) Item Des Com (in) 29.8 29.8 0.05 HANGER 'MCEVOY GEN IV TUBING HANGER ' 3.500 SURFACE;35.06,000.0-+ ^ 531.6 529.1 12.73 NIPPLE CAMCO DS NIPPLE 2.875 10,308.5 5,747.7 28.12'NIPPLE CAMCO DS NIPPLE W/1.81 NIPPLE REDUCER ' 2.812 ! 1: 10,309.5 5,748.5 28.08'LOCATOR NO GO LOCATOR 2.937 10,316.0 5,754.2 27.81 PBR BAKER 80-40 PBR 2.937 10,339.6 5,775.1 27.60 SEAL ASSY KBH-22 ANCHOR SEAL ASSEMBLY 2.780 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl WINDOW A;6,210.0-6,220.0_4 < a. Top(ftKB) (MB) 7) Des Com Run Date ID(in) 8,695.0 4,767.8 64.29 PATCH 3.5"HES PERMANENT PATCH 4/28/2015 GAS LIFT;6,4652 10,308.5° 5,747.6 28.12 RIPPLE REDUCER 1.81 NIPPLE REDUCER 4/27/2015 1.810 PRODUCTION Post Sit; 10,800.0' 6,199.2 20.79 FISH RETAINER Cement retainer pushed to bottom with 7/21/2000 35.0-6,500.0 milling 7/21/2000 GAS LIFT;8,652.4 Cl Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/t PATCH;8,695.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 10,574.0 10,604.0 5,988.0 6,016.0 C-4,1 L-20A 8/19/2000 6.0 APERF 2 1/2"HC;60 deg ph, alternating BH/PJ GAS LIFT;9,779.9F. 10,695.0 10,705.0 6,101.0 6,110.4 UNIT B,1L- 6/6/2000 6.0 SQZ SQUEEZED 7/15/2000 20A 10,742.0 10,762.0 6,145.0 6,163.7 A-6,A-5,1L- 7/30/2000 4.0 RPERF 21/2"HC BH,90 deg ph GAS LIFT;10,268.0 20A Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(WD) NIPPLE REDUCER:10,308.5 yyyTTTTl (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com NIPPLE;10,308.51 =/I r ',` 10,695.0 10,705.0 6,101.0 6,110.4 FRAC 2/21/2002 FRAC 79M#16/20 PROPPANT,7.7 ppa on PERFS LOCATOR;10,309.5 --`�` Cement Squeezes m Top(ND) Blot(ND) PBR;10,316.0 Top(ftKB) Btm(ft6B) (ftKB) (ftKB) Des Start Date Corn 10,762.0 10,782.0 6,163.7 6,182.4 Cement Squeeze 6/6/2000 10,695.0 10,705.0 6,101.0 6,110.4 Cement Squeeze 7/15/2000 Mandrel Inserts St SEAL ASSY;10.339.6 ati s NTop(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Seer Type Type (in) (psi) Run Date Com 1 3,598.2 2,613.2 CAMCO KBMM2 1 GAS LIFT DMY BTM 0.000 0.0 5/6/2016 INT PRODUCTION;6,0470- 2 6,465.3 3,886.7 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 5/6/2016 10,491.0 9 INT _ 3 8,652.4 4,749.1 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.250 0.0 3/24/2015 EXTP APERF;10,574.0-10,604.0- 9 KG 4 9,779.9 5,329.5 CAMCO KBG-2- 1 GAS LIFT OPEN 5/7/2016 9 soz:10,695.0-10,705.0 FRAC;10,695.0 °�✓ 5 10,268.0 5,712.2 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 7/13/2004 9 Notes:General&Safety RPERF;10,742.0-10,762.0- End Date Annotation J 4/13/2000 NOTE:Sidetracked,set CIBP&whipstock@ 6210'in 7"CSG;milled window for sidetrack. 7/21/2000 NOTE:Milled EZSV&pushed to bottom(10800'CTM) FISH;10.800,04 2/9/2011 NOTE:View Schematic w/Alaska Schematic9.0 5/4/2012 NOTE:LINER APPEARS TO BE COLLAPSED 4/6/2015 NOTE:WAIVERED WELL,IA X OA COMMUNICATION REVISED LINER A;10,322.4-10934.0 - - McEvoy IV L-20/`1 11" x 7-1/16" 3K EUE Tbg Head ConocoPhillips i I I KuparukA & C-Sand Producer Proposed RWO 16" 62.5# H-40WLD, 115' MD -0,.. I 1 1� 4 3-1/2" 9.3# L-80 EUE-8RD-AB MOD Tbg, 6000' MD I 1 1 I I 1 1 I I 1 1 I I 1 1 1 3572' MD, Camco 3-1/2"x1" KBG-2-9 GLM I 1 I I I 1 I I I 1 I I I 1 I I 9-5/8"40# L-80 BTCM, 6000' MD ► L . I I Q I 31/2" 9.3# L-80 IBTM Tbg, 6000' - 10322' MD I .- jam- 6047' MD, Baker CPH Liner Top Packer I I -4--T- 6270' MD, Camco 3-1/2"x1" KBG-2-9 GLM 1 7" 426# L-80 BTCM, 6500' MD I 4 8527' MD, Camco 3-1/2"x1" KBG-2-9 GLM 9732' MD, Camco 3-'/2"x1" KBG-2-9 GLM I -8,551' MD, Baker 10-40 PBR 2000 psi shear -8,571' MD Baker 3:1/2" x 5:1/2" F Pkr w/tie I back ext. -10,258' MD, Camco 3-1/2" 2.813"X Nipple w/plug body installed - 10309' MD, 2.937" No Go Locator I I 10316' MD, Baker 10-40 PBR , 1 2000 psi shear Iii 11 !b I CL*,' 10322' MD Baker 3-1/2"x 5:1/2" SABL-3 Pkr w/ a - 1 tie back ext. I I 5-1/2" 15.5# L-80 HYD 511, 6047-10491' MD 1 I I I Kuparuk C-Sand Perforations I 2000 - 10574' - 10604' MD I1 ...0__— 5/06/16 Last BHP Measurement: Kuparuk B-Sand Perforations 0, I I I 2595 psi at 10590' MD, 6003' TVD Sqz. 2000, Fracked 2002 - 10695' - 10705' MD I I Kuparuk A-Sand Perforations 2000- 10742' - 10762' MD I I 1 FISH, 10800' MD ' 1 I 3-1/2" 9.3# L-80 ABT-MOD, 10322-10934' MD —► - IDate: 15-June-2016 Drawn: : Sara Heskin_ „., .... ,,,. ...._____ .. ..... 4- -— .„- , _ ., -,--_,17-.-- ---•-•4*-1-; - , - -..--- - ---L11--.---------- ---:\ . ° 'T .„------..,..„ 7.._,-„....._ „,,, .., Airy ---- - ' 111111. -: — Zv' ' :". '' ---- , --/--- ---- -. "----- 4r , . /, , , , , 0 00110• 11:=Om. .. ,, / 0 )::(/ ' / -/. -'''' ,,, -----'-%-.------- --------if--;--'. witripailiiiitlwab..._ ,,,.--,,,,,,,,, ,,,..,..<•N'2,,,,,.,,,,,,,,:,,,,..;,,,N,\\\,,,..::.,.:,I,..„,,,,,,_.,,,_.. , ' . 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A X z ro wk v L o ash 4 -� �\ Vx,11 \� , O, t pk �- � �;� F K, 0oj / \\\\.\tib \ ` __ �; / . ;r \� „- 000 _ v j / / ' \ 410 )e--_,.---- ses ��.� �� �: � �,,:; iii V/% ,H � � -��r► 2000 _ /i / /� � /� V v of ti -------_-----:/----- , - ,� ._ 1000 y '� �e �y� -r wm 1L-20 A Casing Leak Diagnostics: Leak below 8,666' MD • • Time Log & Summary Printed: 6/15/2016 ConocoPhillips Report Weiivie»+Web Reporting Rig Name: DOYON 142 Well Name: 1L-20 Rig Accept: 6/6/2016 11:00:00 AM Job Type: RECOMPLETION Rig Release: Time Logs Date From To Dur Start End Phase Code Subcode T Comment Depth Depth 24 hr Summary 06/04/2016 Rig releaed from the 3K-27 well at 0900 HRS. Continue ready rig for move to 1L pad. Break down rig, Peak Trucks on location at 0900 HRS. Load up and move rig. Rig on location at 1L at 1730 HRS. Continue spot up over well, laying matting boards. 09:00 00:00 15 0 0 MIRU MOVE MOB P Release rig f/3K-27 Move to 1L-20 Move Derrick Shop pipe shed and rock washer. Lay mats on road to oliktock Y, Move components to Y and shuffle mats around rig and lay on the road to 1L pad. 00:00 03:00 3 0 0 DEMOB MOVE MOB P Continue prepare rig for move. Disconnect Interconnects, and prep rig floor for skidding. Peak Trucks on location at 0900 HRS. Lower and Pin Suspensions. Held PJSM with PEAK drivers. Move and stage rockwasher. Move and stage Mootr complex. 03:00 15:00 12 0 0 MIRU MOVE MOB P Move and stage Pit system. Install tow hitch on sub base. PJSM, Skid rig floor to move position. Lift and secure Stompers. Move Sub base off of the well. DSO and Co. man witness. Begin rig move off of the 3K pad at 1430 HRS. Arrive and stage complexes at CPF3. Waiting on change out and traffic. Inspect moving system and generators. Depart CPF3 at 1800 HRS. Arriving at Oliktok Y at 1930 HRS. Stage complexes. Wait on matting board swap and prepare 1L-20 Location. 06/05/2016 Continue Swapping mats around rig, Reset in fron of rig on 1L access road, Move Complexes from Y to 1L pad, spot sub over well, Spot complexes, Peak hauling remaining complexes from 3K pad, Spot up remaining complexes, Hook up interconnects. 00:00 12:00 12 0 0 MIRU MOVE MOB P Continue moving mats around rig lay mats on road in front of rig, Move Complexes from Y to 1L pad stage pits pump room and generator shed on 1F while spotting Sub. Sub blew road out tool house repair and mat road. Page 1 of 13 Date From To Dur in End Phase Code Subcodel Comment Depth Depth 24 hr Summary 06/05/2016 12:00 00:00 12 0 0 MIRU MOVE MOB P Spot Sub over well move remainig complexes to 1L spot in place, Peak moving remaing equipment from 3k pad, Spot pipshed and rock washer, Work on hooking up interconnects, Work on rig acceptance checklist. 06/06/2016 Continue spot Motor and Pipe shed Modules. Rig up all interconnects. Work on pre acceptance shecklist. RU choke lines, continue work to spot bleed tank, and RU hardlines. Continue trucking moving equipment from 3K to 1L pad. Take on fluid to pits Rig accept @ 1100 hrs, Rig up hard lines to kill well, Bleed gas cap off tubing and IA Reverse circ 8.9 ppg brine staging pumps U 2.5 bpm, Clean fluid at surface, line up to active system to circulate, Begin circulation 50 % losses observed shut down monitor well slight flow shut in well observe pressures, 90 psi on tubing 50 psi on IA, Bleed off gas line up & reverse circ fluid 148 bbls pupmed 110 bbls lost. 2 bpm 90psi 00:00 02:30 2.50 0 0 MIRU MOVE RURD P Continue spot Motor and Pipe Shed complexes. 02:30 06:00 3.50 0 0 MIRU MOVE RURD P Hook up all interconnects, water, steam, Hydraulic and air lines. Work on rig acceptance checklist. Rig crew change. 06:00 07:30 1.50 0 0 MIRU MOVE RURD P Continue work on rig acceptance checklist. Spot and RU hardline to the bleed tank for well kill. 07:30 09:00 1.50 0 0 MIRU MOVE RURD P Take on first load of 8.9 ppg brine, Work on choke line and Take on water and fuel. 09:00 10:30 1.50 0 0 MIRU MOVE RURD P Rig up hard lines to kill well 10:30 11:00 0.50 0 0 MIRU MOVE RURD P Rig up handi berm around cellar Instal beaver slide, Spot cuttings tank and handi berm, Rig accepted @ 1100 hrs 11:00 13:15 2.25 0 0 MIRU MOVE SFTY P Pre Spud meeting with crew and hazard hunt group discussion/review findings 13:15 15:30 2.25 0 0 MIRU WELCTL MPSP P R/U Lubricator and test t/2000 psi, Pull BPV, L/D Lubricator 15:30 16:30 1 0 0 MIRU WELCTL SEQP P Fill Lines and pressure test surface equipment to 2500 psi, TBG 1600 psi IA 900 psi OA 725 psi. 16:30 17:30 1 0 0 MIRU WELCTL KLWL P Bleed gas cap on tubing f/ 1600 psi U 700 fliud back, Bleed IA f/720 psi U 420 psi 17:30 20:15 2.75 0 0 MIRU WELCTL KLWL P Reverse circulate 8.9 ppg brine ICP 1.5 bpm 550 psi FCP @ 2 bpm 110 psi 391 bbls pumped 312 bbls returned loss of 79 bbls 20:15 20:45 0.50 0 0 MIRU WELCTL KLWL P B/D Lines line up to circ on active system 20:45 21:15 0.50 0 0 MIRU WELCTL KLWL P Reverse Circ 50 bbls @ 2 bpm 90 psi slow pumps U 1 bpm 30 psi losses 50 % Loss 23 bbls during circulation 21:15 22:15 1 0 0 MIRU WELCTL OWFF P Monitor Well on trip tank slight flow shut in well monitor psi tubing 90 psi ann 75 psi after 30 min Page 2 of 13 Date From To Dur Irt End Phase Code Subcode ' Comment Depth Depth 24 hr Summary 06/06/2016 22:15 00:00 1.75 0 0 MIRU WELCTL KLWL P Bleed off pressure to tiger tank, line up and reverse circulate @ 2 bpm 75% losses 148 bbls pumped 110 bbls lost 06/07/2016 Continue to reverse circulating 8.9 ppg brine at 3 BPM (270 bbls pumped 178 bbls lost). Observe the well for flow and the well on a slight vac. RU HES slickline, set 1.81" CA-2 plug in nipple reducer at 10308' ORKB, PT to 1000 psi, and RD HES slickline. Set 3" HP BPV with dry rod. Pressure up on the IA to 1000 psi for 10 minutes to test the BPV from below in the direction of flow(good test). ND the tree and ND the tubing head adaptor. Inspect the lift threads (threads are good) and install the HP blanking plug into the BPV. NU the DSA, spacer spool, and the BOP stack. 00:00 01:15 1.25 0 0 MIRU WELCTL CIRC P Continue to reverse circulating 8.9 ppg brine at 3 BPM = 190 psi (270 bbls pumped 178 bbls lost). 01:15 02:00 0.75 0 0 MIRU WELCTL OWFF P Observe the well for flow and the well on a slight vac. SimOps: RD circulating equipment. 02:00 02:30 0.50 0 0 MIRU WHDBOP MPSP P Rig up to set BPV and test in direction of flow. Unable to test in direction of flow discuss options with town engineer. 02:30 06:00 3.50 0 0 MIRU WHDBOP WAIT T Mobilize HES slickline at 02:30 hours to set 1.81" CA-2 plug in nipple at 10308' ORKB. SimOps: Hold pre-spud meeting with rig crew. General housekeeping, maintenance, and painting around the rig. 06:00 10:15 4.25 0 0 MIRU WHDBOP SLKL T Bring slickline tool to the rig floor and RU HES slickline. PT slickline lubricator to 1000 psi (good test). 10:15 12:45 2.50 0 0 MIRU WHDBOP SLKL T RIH and set 1.81"CA-2 plug in nipple reducer set in DS nipple at 10308' ORKB. PT CA-2 plug to 1000 psi (good test), bleed off the pressure, and shear running tool from the plug. PT the plug to 500 psi to confirm the plug is still set (good test). 12:45 15:00 2.25 0 0 MIRU WHDBOP SLKL T POOH with setting tools, drain the lubricator, and RD HES slickline. 15:00 16:30 1.50 0 0 MIRU WHDBOP MPSP T Set 3" HP BPV with dry rod. Pressure up on the IA to 1000 psi for 10 minutes to test the BPV from below in the direction of flow(good test). 16:30 18:00 1.50 0 0 MIRU WHDBOP NUND P PJSM. ND the tree and ND the tubing head adaptor. Inspect the lift threads (threads are good) and install the HP blanking plug into the BPV. 18:00 00:00 6 0 0 MIRU WHDBOP NUND P NU the DSA, spacer spool, and the BOP stack. NU the choke and kill lines to the BOP stack. NU the Dutch riser nipple and flow riser. Page 3 of 13 Date From To Dur Ort End Phase Code Subcode Comment Depth Depth 24 hr Summary 06/08/2016 RU BOPE testing equipment. Conduct initial BOPE test to 250/3000 psi: test 3-1/2"x 6"VBR's (upper pipe rams and lower pipe rams)with 3-1/2"test joint; test annular to 250/2500 with 3-1/2"test joint; conducted Koomey drawdown test(all tested passed). The test was witnessed by AOGCC inspector Guy Cook. RD BOPE testing equipment. RU Weatherford power tubing tongs. Pull the blanking plug and BPV with the dry rod. MU the landing joint, BOLDS, and unseat the tubing hanger but unable to pull the seal assembly free from the PBR pulling up to 210K. RU SLB E-line and RIH with string shot assembly. 00:00 01:00 1 0 0 MIRU WHDBOP NUND P Continue to NU the choke hose removing the extension pup on the HCR choke. 01:00 02:00 1 0 0 MIRU WHDBOP RURD P MU TIW and dart valve. RU BOPE testing equipment. Flush and fill the BOPE with fresh water. 02:00 06:30 4.50 0 0 MIRU WHDBOP BOPE P Conduct initial BOPE test to 250/3000 psi: test 3-1/2" x 6"VBR's (upper pipe rams and lower pipe rams)with 3-1/2"test joint; test annular to 250/2500 with 3-1/2"test joint; conducted Koomey drawdown test (all tested passed). The test was witnessed by AOGCC inspector Guy Cook. Tests: 1) Annular with 3-1/2"test joint (passed) 2) Upper pipe rams with 3-1/2"test joint, upper IBOP, 4" Demco on the mud line, chokes 1, 12, 13 & 14 (passed) 3) Lower IBOP, 4" Demco mezzanine kill line, chokes 9 & 11 (passed) 4) HCR kill, 3-1/2" EUE TIW, chokes 5, 8, & 10 (passed) 5) Manual kill, 3-1/2" PH-6 dart valve, chokes 4, 6, &7 (passed) 6) 3-1/2" PH-6 TIW, choke 2 (passed) 7) HCR choke (passed) 8) Manual choke (passed) 9) Lower pipe rams with 3-1/2" test joint(passed) 10) Blind rams, choke 3 (passed) 11) Super choke (passed) 12) Manual choke (passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure= 3000 psi Accumulator Pressure After Closer= 1775 psi Pressure Gain of 200 psi = 5 seconds Full System =43 Seconds Average N2 (6 Bottles) = 2400 psi 06:30 07:15 0.75 0 0 MIRU WHDBOP RURD P Blow down and RD BOPE testing equipment. Page 4 of 13 Date From To Dur a End Phase Code Subcode Comment Depth Depth 24 hr Summary 06/08/2016 07:15 08:00 0.75 0 0 COMPZN RPCOMP RURD P Bring Weatherford equipment to the rig floor and RU the power tubing tongs. 08:00 09:30 1.50 0 0 COMPZN RPCOMP MPSP P Suck out the BOP stack. Pull the HP blanking plug and BPV with the dry rod. 09:30 10:00 0.50 0 0 COMPZN RPCOMP RURD P MU the landing joint to the tubing hanger, MU the crossover, and MU the top drive. 10:00 11:00 1 0 10326 COMPZN RPCOMP PULL P BOLDS and unseat the tubing hanger but unable to pull the seal assembly free from the PBR pulling up to 210K. 11:00 16:00 5 10326 10326 COMPZN RPCOMP WAIT T Wait for SLB E-line. Continue to work the tubing pulling up to 210K. 16:00 16:45 0.75 10326 0 COMPZN RPCOMP ELNE P Set the tubing string in the slips with 160K. RD pup joints and crossover. MU crossovers for E-line. Change elevators and hang E-line sheave in the elevators. 16:45 19:00 2.25 0 0 COMPZN RPCOMP ELNE T SLB E-line unit got stuck in the soft gravel in front of the beaver slide while spotting their unit. Called roads and pads for a grader and pulled the unit out. Set rig mats in front of the beaver slide and spotted the SLB E- line unit. 19:00 21:00 2 0 0 COMPZN RPCOMP ELNE P Re-head E-line. MU string shot, CCL and weight bars. 21:00 22:45 1.75 0 0 COMPZN RPCOMP ELNE P RU SLB on the rig floor. MU pack-off and head catcher. 22:45 00:00 1.25 0 0 COMPZN RPCOMP ELNE P PU and RIH with string shot assembly. 06/09/2016 Continue to RIH with string shot assembly, fire the string shot from 10282' - 10292' ORKB, and POOH. RIH with 2-1/8" chemical cutter assembly, had to work through tubing patch at 8695' ORKB, fire the chemical cutter at 10290' ORKB, and POOH but unable to get back through the patch. RIH to CA-2 plug, release the tool string with the electronic controlled release device, and POOH with E-line. Attempt to pull the tubing hanger to the rig floor but the tubing is not free (pulled to max pull of 210K). Continue to work the tubing while waiting for additional chemical cutters and the tubing eventually pulled free. Circulate 346 bbls at 6 BPM and at bottoms up fine sand recovered over the shakers. Pulled the tubing hanger to the rig floor and POOH laying down 3-1/2" EUE 8rd tubing from 10224'to 7578' RKB at midnight. 00:00 03:00 3 0 0 COMPZN RPCOMP ELNE P Continue to RIH with string shot assembly. Fire the string shot from 10282'- 10292' ORKB. POOH with string shot assembly. 03:00 04:00 1 0 0 COMPZN RPCOMP ELNE P Lay down string shot assembly and MU 2-1/8"chemical cutter assembly with CCL, weight bars, and centralizers. 04:00 05:30 1.50 0 0 COMPZN RPCOMP ELNE P RIH with centralized chemical cutter assembly with CCL to top of the patch at 8695' ORKB at 100'/minute but unable to get through the patch. Page 5 of 13 Date From To Dur •rt End Phase Code Subcode Comment Depth Depth 24 hr Summary 06/09/2016 05:30 06:00 0.50 0 0 COMPZN RPCOMP ELNE T Attempt to work through the tubing patch with running speed up to 200'/minute but unable to get through the tubing patch. Call town engineer and discuss options. 06:00 07:00 1 0 0 COMPZN RPCOMP ELNE T Work centralized chemical cutter assembly through the tubing patch with a running speed of 300'/minute. 07:00 07:30 0.50 0 0 COMPZN RPCOMP ELNE P Continue to RIH with centralized chemical cutter assembly from 8708' to 10290' ORKB. Set the anchor and cut the tubing with 2-1/8" chemical cutter at 10290' ORKB. 07:30 08:00 0.50 0 0 COMPZN RPCOMP ELNE P POOH with cutter assembly but unable to get through the bottom of the patch at 8708' ORKB. 08:00 12:30 4.50 0 0 COMPZN RPCOMP ELNE T Attempt to work through the tubing patch but unable to. Call town engineer and discuss options. Pressure up on the tubing to 1000 psi, hold for 3 minutes, and bleed to 0 psi. Attempt to pull through the tubing patch unsuccessful. Pressure up on the tubing to 2000 psi, hold for 3 minutes, and bleed to 0 psi. Attempt to pull through the tubing patch unsuccessful. 12:30 13:45 1.25 0 0 COMPZN RPCOMP ELNE T RIH to the CA-2 plug at 10308' ORKB and release the tool string with the electronic controlled release device. 13:45 14:45 1 0 0 COMPZN RPCOMP ELNE P POOH with E-line 14:45 15:15 0.50 0 0 COMPZN RPCOMP ELNE P RD E-line off to the side, RD TIW, and change elevators. 15:15 15:30 0.25 0 10290 COMPZN RPCOMP PULL T Attempt to pull the tubing hanger to the rig floor but the tubing is not free (pulled to max pull of 210K). 10290 10290 COMPZN RPCOMP RURD T MU 6' pupjoint, crossover, and top 15:30 15:45 0.25 drive. 15:45 16:45 1 10290 10290 COMPZN RPCOMP PULL T Continue to work the tubing pulling up to 210K. SimOps: SLB E-line re-heading and obtaining additional chemical cutters. 16:45 19:15 2.50 10290 10260 COMPZN RPCOMP PULL T Establish circulation at 3 BPM = 345 psi and continue to work the tubing pulling up to 210K. Bring the pumps up to 5 BPM = 865 psi continuing to work the tubing pulling up to 210K and the tubing started to slow move upwards with heavy drag. Continue working the tubing with pumps on and pumps off and the pipe moved freely (PU = 135K and SO = 80K). SimOps: SLB E-line re-heading and obtaining additional chemical cutters. Page 6 of 13 Date From To Dur Ort End Phase Code Subcode Comment Depth Depth 24 hr Summary 06/09/2016 19:15 20:15 1 10260 10260 COMPZN RPCOMP CIRC P Circulate 346 bbls at 6 BPM = 1080 psi while working the tubing. At bottoms up fine sand recovered over the shakers. After the circulation PU = 112K and SO = 80K. SimOps: RD SLB E-line. 20:15 20:30 0.25 10260 10260 COMPZN RPCOMP OWFF P Observe the well for flow and the well is static. 20:30 21:00 0.50 10260 10224 COMPZN RPCOMP PULL P Pull the tubing hanger to the rig floor. Break out the top drive, break out the tubing hanger, lay down the tubing hanger, lay down the landing joint, and break out crossover. Blow down the top drive. 21:00 00:00 3 10224 7578 COMPZN RPCOMP PULL P PJSM. POOH laying down 3-1/2" EUE 8rd tubing from 10224'to 7578' RKB at midnight (PU = 89K and SO = 74K). 06/10/2016 Continue POOH laying down 3-1/2"tubing. Recovered the cut joint(length = 15.06'). RU the Dutch riser and HES slickline. RIH with slickline fishing tool string but unable to get into the 5-1/2" liner. Reconfigure the tool string, RIH, engage E-line fish, but unable to jar fish free. POOH and the tool string was packed with sand. RD HES slickline and RD the Dutch riser. Load, strap, and tally 3-1/2" PH-6 work string. Bring Baker fishing tools to the rig floor. 00:00 03:30 3.50 7578 4490 COMPZN RPCOMP PULL P Continue POOH laying down 3-1/2" EUE 8rd tubing from 7578'to 4490' RKB (PU = 68K and SO -65K). 03:30 03:45 0.25 4490 4490 COMPZN RPCOMP RURD P MU 3-1/2" EUE 8rd x 3-1/2" IBT crossover onto the bottom of the 3- 1/2" EUE 8rd TIW. 03:45 09:30 5.75 4490 0 COMPZN RPCOMP PULL P Continue POOH laying down 3-1/2" IBTM tubing from 4490'to surface. Recovered 2.875" DS Nipple, 5 GLMs, 323 joints of tubing, and cut joint(length = 15.06'). 09:30 09:45 0.25 0 0 COMPZN RPCOMP RURD P PU the landing joint and break out 6' pup joint. 09:45 10:45 1 0 0 COMPZN RPCOMP SLKL T RU the Dutch riser for slickline operations. 10:45 13:00 2.25 0 0 COMPZN RPCOMP SLKL T PJSM. RU HES slickline with lubricator. 13:00 14:00 1 0 0 COMPZN RPCOMP SLKL T Slickline kinked, cut, and re-head. MU slickline fishing tool string. PT the lubricator and Dutch riser to 1000 psi. 14:00 15:00 1 0 0 COMPZN RPCOMP SLKL T RIH with slickline fish tool string to the liner top packer at 6047' ORKB but unable to get from the 7"casing into the 5-1/2" casing. POOH with slickline fishing tool string. Page 7 of 13 Date From To Dur Sart End Phase Code Subcode Comment Depth Depth 24 hr Summary 06/10/2016 15:00 15:45 0.75 0 0 COMPZN RPCOMP SLKL T Tool string covered in sand. Change slickline tool configuration to include bell guide. PT the lubricator to 1000 psi. 15:45 16:45 1 0 0 COMPZN RPCOMP SLKL T RIH with slickline bell guide fishing tool string to 10267' ORKB. 16:45 18:30 1.75 0 0 COMPZN RPCOMP SLKL T Engage E-line fish and attempt to jar free without success (sheared GS spear). 18:30 19:30 1 0 0 COMPZN RPCOMP SLKL T POOH with slickline bell guide fishing tool string. 19:30 21:00 1.50 0 0 COMPZN RPCOMP SLKL T RD HES slickline and RD the Dutch riser. 21:00 23:00 2 0 0 COMPZN RPCOMP RURD T Load, strap, and tally 3-1/2" PH-6 work string. SimOps: Install the wear ring, RU Weatherford powe tubing tongs, and prep rig floor for RIH with fishing BHA. 23:00 00:00 1 0 0 COMPZN RPCOMP RURD T Bring Baker fishing tools to the rig floor. 06/11/2016 PU, MU, and RIH with 3" GS spear assembly on 3-1/2" PH-6 work string to tag at 10234' RKB. Engage E-line fish and jar free. Drop 7/8" ball and attempt to open the pump out sub but were unsuccessful. TOOH with 3-1/2" PH-6 work string (pulling wet). Recovered E-line fish and lay down the E-line chemical cutter fish. Break down 3" GS spear assembly. The entire assembly was packed of with scale from the 3-1/2" PH-6 work string. 00:00 00:30 0.50 0 27 COMPZN RPCOMP BHAH T PU and MU BHA#1 -3" GS spear assembly. 00:30 11:45 11.25 27 10234 COMPZN RPCOMP PULD T RIH with BHA#1 on 3-1/2" PH-6 work string to tagged earlier than expected at 10234' RKB (PU = 141K and SO = 80K). 11:45 13:30 1.75 10234 10234 COMPZN RPCOMP JAR T Engage GS spear into bait sub, PU to 160K, and no movement. MU a crossover and MU the top drive. Bring the pumps on and pressured up to 500 psi. Begin jarring on the E-line fish at 180K and after 19 jar hits the E-line fish came free. 13:30 15:30 2 10234 10234 COMPZN RPCOMP OTHR T Drop 7/8" ball for pump out sub and wait 30 minutes for the ball to fall to the ball seat. Pressure the work string to 2000 psi but the pump out sub would not open. Stage up the pump pressure to 4100 psi and the pump out sub still would not open. 15:30 22:00 6.50 10234 121 COMPZN RPCOMP TRIP T TOOH standing back 3-1/2" PH-6 work string from 10234'to 121' RKB (string pulled wet). 22:00 22:15 0.25 121 121 COMPZN RPCOMP SFTY T PJSM for handling E-line fish. 22:15 22:30 0.25 121 51 COMPZN RPCOMP PULD T Lay down 2 joints of 3-1/2" PH-6 work string. Page 8 of 13 Date From To Dur •rt End Phase Code Subcode Comment Depth Depth 24 hr Summary 06/11/2016 22:30 23:15 0.75 51 51 COMPZN RPCOMP BHAH T Pull BHA#1 to surface and recovered the E-line fish. Lay down the E-line chemical cutter fish. Fish was missing the upper bow spring centralizer springs. 23:15 00:00 0.75 51 0 COMPZN RPCOMP BHAH T Break down BHA#1 -3" GS spear assembly. The entire BHA was packed of with scale from the 3-1/2" PH-6 work string. The 7/8" ball was recovered in the 2-3/8" IF x Reg crossover above the pump out sub. 06/12/2016 PU, MU, and TIH with cleanout assembly on 3-1/2" PH-6 work string to 10185' RKB. Wash down from 10185'to 10275' RKB (tagged tubing stub with 7K down). Wash down from 10275' to 10291' RKB. Circulate 56 bbls hi- vis sweep at 6 BPM, circulated the well clean, and recovered fine sand over the shakers. TOOH with cleanout assembly and lay down. PU, MU, and TIH with overshot assembly for 3-1/2"tubing to 9685' RKB at midnight. 00:00 00:45 0.75 0 0 COMPZN RPCOMP BHAH T Clean scale from the 3-1/2" PH-6 work string out of crossovers, pump out sub, oil jar, and bumper sub. 00:45 01:00 0.25 0 0 COMPZN RPCOMP BHAH T Clean the rig floor. Off load fishing tools from GS spear run off the rig floor and bring fishing tools for the cleanout run to the rig floor. 01:00 01:45 0.75 0 57 COMPZN RPCOMP BHAH T PU and MU BHA#2 - cleanout assembly using 1 joint of 3-1/2" PH-6 work string. 01:45 02:00 0.25 57 145 COMPZN RPCOMP PULD T PU and MU two joint of 3-1/2" PH-6 work string. 02:00 07:45 5.75 145 10185 COMPZN RPCOMP TRIP T TIH with BHA#2 to 10185' RKB (PU = 154K and SO = 82K). 07:45 08:00 0.25 10185 10185 COMPZN RPCOMP PULD T PU 2 joints of 3-1/2" PH-6 work string for the pipe shed, MU crossover, and MU the top drive. 08:00 09:30 1.50 10185 10291 COMPZN RPCOMP WASH T Obtain parameters: PU = 154K, SO = 82K, 3 BPM = 665 psi, and rotating weight= 111K at 40 RPM = 6K ft-lbs. Wash down from 10185'to tag at 10275' RKB with 7K down at 3 BPM = 665 psi. Wash down from 10275'to tag at 10291' RKB with 3K down at 5 BPM = 1650 psi, 40 RPM =6K ft-lbs. 09:30 11:00 1.50 10291 10291 COMPZN RPCOMP CIRC T Pump 56 bbls hi-vis sweeps at 6 BPM = 2470 psi with rotating at 40 RMP and circulate the well clean. Recovered fine sand over the shakers. 11:00 11:15 0.25 10291 10275 COMPZN RPCOMP PULD T Lay down 1 joint of 3-1/2" PH-6 work string and break out the crossover. 11:15 11:30 0.25 10275 10275 COMPZN RPCOMP OWFF T Observe the well for flow for 10 minutes and the well is static. SimOps: Blow down the top drive. 11:30 15:15 3.75 10275 57 COMPZN RPCOMP TRIP T TOOH standing back the 3-1/2" PH-6 work string from 10275' to 57' RKB. 15:15 16:00 0.75 57 0 COMPZN RPCOMP BHAH T Lay down BHA#2 - cleanout assembly. Page 9 of 13 Date From To Dur girt End Phase Code Subcode Comment Depth Depth 24 hr Summary 06/12/2016 16:00 17:30 1.50 0 285 COMPZN RPCOMP BHAH T PU and MU BHA#3 -overshot assembly for 3-1/2"tubing to fish the seal assembly. 17:30 00:00 6.50 285 9685 COMPZN RPCOMP TRIP T TIH with BHA#3 to 9685' RKB at midnight 06/13/2016 Continue to TIH with overshot assembly to 10233' RKB. Engage the tubing stub at 10275' RKB and jar the seal assembly free. Open up the pump out sub and TOOH with the overshot assembly. Recovered the seal assembly. PU, MU, and TIH with mule shoe cleanout assembly to 10289' RKB. Cleanout the PBR to 10313' RKB and POOH laying down the 3-1/2" PH-6 work string to 2576' RKB at midnight. 00:00 00:15 0.25 9685 10233 COMPZN RPCOMP TRIP T Continue to TIH with BHA#3 - overshot assembly for 3-1/2"tubing from 9685'to 10233' RKB. 00:15 00:30 0.25 10233 10254 COMPZN RPCOMP PULD T PU 2 joints of 3-1/2" PH-6 work string for the pipe shed with crossover and MU the top drive. 00:30 01:15 0.75 10254 10277 COMPZN RPCOMP FISH T Obtain parameters: PU = 160K, SO = 83K, 1 BPM = 150 psi, 15 RPM = 6K ft-lbs. Wash down at 1 BPM = 150 psi to tag at 10275' RKB with 10K down (did not see pressure increase)and PU with no fish. Attempted three time with and without pumps. PU 15', rotate at 15 RPM = 6K ft-lbs, 1 BPM = 150, SO, and at 10275'torque increased and pump pressure increased 340 psi. Shut down the pumps/rotary and SO to 10277'with 10K down. Straight pull 140K over with no movement. 01:15 01:45 0.50 10277 10270 COMPZN RPCOMP JAR T Jar at 40K over three time with straight pull 140K over then jar at 60K over 4 times with straight pull 140K over and on the 5th jar at 60K over the seals pulled free100K over. Observed the seals dragging out of the PBR and the fluid level dropped. SO and tag 5' high. 01:45 02:30 0.75 10270 10270 COMPZN RPCOMP CIRC T Drop the 7/8" ball for the pump out sub, circulate at 1-2 BPM = 900 psi to seat the ball, and the pump out sub sheared at 1100 psi. Circulate at 2 BPM = 350 psi 02:30 03:00 0.50 10270 10270 COMPZN RPCOMP OWFF T Observe the well for flow and the well is on a vac. Established an estimated 25 bbls/hour loss rate. 03:00 03:15 0.25 10270 10233 COMPZN RPCOMP PULD T Lay down 2 joint of 3-1/2" PH-6 work string and blow down the top drive. 03:15 07:30 4.25 10233 285 COMPZN RPCOMP TRIP T TOOH with BHA#3 from 10233' to 285' RKB. 07:30 08:45 1.25 285 23 COMPZN RPCOMP BHAH T Lay down 3-1/8" drill collars. Page 10 of 13 Date From To Dur •rt End Phase Code Subcode Comment Depth Depth 24 hr Summary 06/13/2016 08:45 09:15 0.50 23 23 COMPZN RPCOMP PULL T Recovered cut joint, 2.813" D nipple with CA-2/nipple reducer installed, and seal assembly. Lay down fish and cleanout sands from the fish. 09:15 10:00 0.75 23 0 COMPZN RPCOMP BHAH T Finish laying down BHA#3 -overshot assembly. Off load fishing tools from the rig floor. 10:00 11:00 1 0 12 COMPZN WELLPR BHAH T Strap mule shoe and crossover. PU and MU BHA#4- mule shoe cleanout assembly. 11:00 15:45 4.75 12 10289 COMPZN WELLPR TRIP T TIH with BHA#4 to 10289' RKB (PU = 155K and SO 85K), 15:45 16:00 0.25 10289 10289 COMPZN WELLPR WASH T Establish circulation and wash down from 10289' into the PBR at 10303'to 10313' RKB at 2 BPM = 165 psi. PU out of the PBR, increase the pump rate to 5 BPM = 1070 psi and cleanout the PBR to 10313' RKB. PU out of the PBR and shut down the pumps. 16:00 16:15 0.25 10289 10289 COMPZN WELLPR OWFF T Observe the well for flow and the well is on a vac. 16:15 00:00 7.75 10289 1300 COMPZN WELLPR PULD T POOH with BHA#4 laying down the 3 -1/2" PH-6 work string from 10289'to 1300' RKB at midnight. 06/14/2016 Continue POOH laying down 3-1/2" PH-6 work string and lay down mule shoe joint. Pull the wear ring. PU, MU, and RIH with 3-1/2" gas lift completion per tally to 10298' RKB. Engage seal assembly into existing PBR, locate out, mark the pipe, and space out. MU the tubing hanger and reverse circulate 248 bbls of corrosion inhibited brine. Land the tubing hanger and RILDS. Drop ball & rod with rollers. Attempt to PT the tubing but the IA is tracking the tubing pressure (suspected failed SOV). Attempt to CMIT-T x IA to 2500 psi but pressure bleeds down to 1000 psi in 15 minutes (suspected 5-1/2" casing leak). Discuss all options with town engineer and decided to POOH with the completion. RD circulating/pressure testing equipment. 00:00 01:45 1.75 1300 12 COMPZN WELLPR PULD T Continue POOH with BHA#4 laying down the 3-1/2" PH-6 work string from 1300'to 10' RKB. 01:45 02:00 0.25 12 0 COMPZN WELLPR BHAH T Lay down mule shoe joint and break out crossover. 02:00 03:00 1 0 0 COMPZN WELLPR RURD T MU wear ring retrieving tool onto a joint of DP, BOLDS, pull the wear ring, lay down the wear ring retrieving tool, and lay down joint of DP. Clean the rig floor. 03:00 03:15 0.25 0 0 COMPZN RPCOMP RURD P Break out 3-1/2" PH-6 crossover from TIW and MU IBT crossover to the TIW for running completion. 03:15 15:00 11.75 0 10298 COMPZN RPCOMP PUTB P PJSM. PU and MU seal assembly, crossover, 1 joint of 3-1/2" IBTM tubing, nipple assembly, 1 joint of 3- 1/2" IBTM tubing, GLM #1, and RIH with 3-1/2" IBTM tubing per tally to 10298' RKB (PU = 111K and SO = 80K). Page 11 of 13 Date From To Dur •rt End Phase Code Subcode Comment Depth Depth 24 hr Summary 06/14/2016 15:00 16:30 1.50 10298 10265 COMPZN RPCOMP HOSO P MU the top drive, pump at 2 BPM = 90 psi, engage the seal assembly into existing PBR, observed pressure increase to 120 psi, shut the pumps off, locate out with 5K down, and mark the pipe for space out. Lay down 3 joints of tubing, MU 4.34' pup, and MU joint of 3-1/2"tubing. 16:30 16:45 0.25 10265 10270 COMPZN RPCOMP THGR P MU the tubing hanger and landing joint with circulating equipment. 16:45 18:30 1.75 10270 10270 COMPZN RPCOMP CRIH P PJSM. Reverse circulate 248 bbls of 8.9 ppg corrosion inhibited brine at 3.5 BPM = 300 psi down the IA taking returns out the tubing. 18:30 18:45 0.25 10270 10270 COMPZN RPCOMP RURD P Drain the BOP stack. 18:45 19:30 0.75 10270 10315 COMPZN RPCOMP THGR P Land the tubing hanger and RILDS. 19:30 22:00 2.50 0 0 COMPZN RPCOMP PRTS T Drop the ball & rod with rollers and allow 15 minutes to fall to seat. Attempt to PT the tubing to 3000 psi but the tubing and IA pressures tracked stopped at 1500 psi and the tubing/IA dropped to 1000 psi in 13 minutes. Double check surface line up and secondary kill hose from the IA. Pressure back up to 1500 psi with the same result. Notified the town engineer. Pressure up on the IA to 2500 psi (the tubing pressure tracked the IA), triple block both sides, and the tubing/IA dropped to 1000 psi in 15 minutes. Reverse circulate 5 bbls down the IA taking returns up the tubing at 1 BPM = 300 psi.getting 1 for 1 returns. 22:00 23:00 1 0 0 COMPZN RPCOMP WAIT T Discuss all options with town engineer and decided to POOH with the completion due to the suspected failed SOV and suspected 5-1/2" casing leak. 23:00 00:00 1 0 0 COMPZN RPCOMP RURD T Blow down and RD circulating/pressure testing equipment. SimOps: BOLDS. 06/15/2016 00:00 00:30 0.50 0 0 COMPZN RPCOMP RURD T Prep the rig floor for TOOH standing back the 3-1/2"tubing. 00:30 02:00 1.50 0 0 COMPZN RPCOMP SLPC P Cut and slip 102' of drilling line. 02:00 02:15 0.25 10315 10276 COMPZN RPCOMP PULL T Pull the tubing hanger to the rig floor, lay down the tubing hanger, and lay down the landing joint. 02:15 04:00 1.75 10276 6858 COMPZN RPCOMP PULL T TOOH standing back the 3-1/2" tubing to 6858' RKB . Page 12 of 13 Date From To Dur in End Phase Code Subcode• Comment Depth Depth 24 hr Summary 06/15/2016 04:00 04:30 0.50 6858 6858 COMPZN RPCOMP PRTS T MU head pin and pressure testing equipment. Attempt to PT the tubing but just established circulation at 2 BPM = 1000 psi. RD pressure testing equipment and head pin. 6858 COMPZN RPCOMP PULL T Lay down GLM and continue TOOH standing back the 3-1/2"tubing. Page 13 of 13 • • Tubing Pressure (psi) ' IA Pressure (psi) - - __ ,, ,„....--7.---- , - , /-____ y �` j_ . � ----"•" " Initial tubing test to 1000_ / . psi-indicates TxIA 1 o ____ communication. ----.� w�. . SOV Failure Confirmed Trouble shoot TxIA: y_ _ Pressure up to 800 psi,...--0 rt' y , y f ... - y'ry �. r _ `.. ,` �:� ' Failed CMIT to -" , ' S . ` 2500ps,;.Indication `;..00d - ,Y 1 r `, r/ " t. ,� of,casing/packer leak � rfh 4• - '.` 9,_,....4.7,-- E 4 I: ' !' I 1/ , I/ , ''. '. 1 , ,, ^ i -/ 0...k.) U.S.,q r,,,,.:„..;:*..,....'-'-'1 I O , I w T, 1, , -4` E ,_ 1 \ ti ` - \ 5j ` yt _ a J • 1L-20A Tubing Pressure Test and Leak .f` , Diagnostics Doyon 142 6/14/2016 - �F .- • • Hi Victoria, Thank you! Please disregard the message I left you. I apologize, I had not seen your email prior to the call. The BOP was tested to 3,000 psi. I began the sundry today, and plan to submit it tomorrow given the rig progress of identifying the leak location. Sincerely, Sarco fte,s1 YV Associate Wells Engineer North Slope Workover Engineering ConocoPhillips Alaska Office: 907-265-1027 sara.heskin a,conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday,June 15, 2016 3:13 PM To: Heskin,Sara E<Sara.E.Heskin(a)conocophillips.com> Subject: [EXTERNAL]1L-20A Work Scope Change Approval Request (PTD 200-036) Sara, Verbal approval is granted to proceed as outlined below for leak identification and running of a stacked packer. What was the BOP tested to? Please submit a sundry for this work as soon as possible. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska OH&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeoo alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.aov • • From: Heskin,Sara E[mailto:Sara.E.Heskingconocoohillips.com] Sent:Wednesday,June 15,2016 2:37 PM To: Loepp,Victoria T(DOA) Cc: Buck, Brian R; Rauchenstein, Rock D; Doyon 142 Company Man; Herbert, Frederick 0; Kanady, Randall B Subject: 1L-20A Work Scope Change Approval Request Good Afternoon Victoria, This is a preemptive email to request approval for a work scope change on the KRU 1L-20 rig workover.The well is a producer with PTD 200-036. The initial purpose of the workover on 1L-20 was to repair tubing leaks identified by a Leak Detect Log(LDL)ranging from 5'-100'below an existing permanent tubing patch at 8,695'MD.The tubing was cut at 10,290'MD and the 3-1/2"upper completion tubing stub and seals were successfully retrieved.Prior to fishing the tubing stub,^'20'of sand was washed out during a clean out run,indicating heavy inner annulus(IA)hole fill. Additionally,there was notable external tubing corrosion found while laying down the upper completion. After running the new 3-1/2"upper completion a tubing test was performed.During this test,the tubing was pressured to 1,500 psi and the IA pressure tracked to 1,500 psi,indicating tubing by inner annulus(TxIA)communication.The pressure bled off to 1,000 psi over the course of 20 minutes indicating both TxIA communication and a leaking packer,casing or PBR.A combination mechanical integrity test(CMIT)IA x T was performed to 2,500 psi and immediately bled to 2,000 psi in less than 5 minutes,confirming a leak.The decision was made to pull the upper completion and prepare to run a test packer to identify the leak location. I am requesting approval to stack a packer at a TBD depth to fix the packer/casing leak.The new packer depth will be determined based on the test packer run results.We expect to have the results of the test packer run later this evening.Upon approval,we anticipate to be running in the hole with the new stacked packer tomorrow morning at earliest. Attached are the following documents for your review: • 1L-20A Tubing&IA Pressure Test Chart • 1L-20A Time Log Summary (June 4—Present) • Schematics for 1L-20A o 1L-20A Proposed Stacked Packer Completion o 1L-20A Original Planned Completion o 1L-20A Pre-Rig General Well info: Well Type: Producer MASP: 1,995 psi from most recent SBHP w/gradient of 0.1 psi/ft to surface Reservoir Pressure/TVD: 2,595 psi at 10,590'RKB/6,003'TVD(5/6/2016) Wellhead type/pressure rating: McEvoy Gen IV 3-%"5M TIFL/MIT results: CMIT—T x IA to 2500 psi passed April 26,2016(potentially false positive due to packed off sand down hole) TIFL—Failed 3/13/2016 Current operations:L/D 3-1/2"Upper Completions Plan forward:PU and MU a test packer BHA to identify the leak location. Due to the original workover scope and well type,no sundry was submitted for 1L-20.Please let me know how would like to proceed and if you need me to submit anything in addition to this notification.I await your approval for the new scope on 1L-20A. If you have any questions or require other documentation please contact me: Office:907-265-1027 Cell:907-331-7514 Sincerely, Associate Wells Engineer North Slope Workover Engineering ConocoPhillips Alaska Office:907-265-1027 sara.heskin,r conocophillips.com • • Bettis, Patricia K (DOA) From: Heskin, Sara E <Sara.E.Heskin@conocophillips.com> Sent: Monday,June 20, 2016 1:19 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1L-20A (PTD 200-036): Sundry Application Hi Patricia, I apologize for the oversight.The effective depth for KRU 1L-20A is 10,580'MD, 5993.65'TVD.Thank you for catching that! Do I need to re-submit the 10-403? Sincerely, Scwov}f P c'ti Associate Wells Engineer North Slope Workover Engineering ConocoPhillips Alaska Office: 907-265-1027 sara.heskin@conocophillips.com From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday,June 20, 2016 1:10 PM To: Heskin, Sara E <Sara.E.Heskin@conocophillips.com> Subject: [EXTERNAL]KRU 1L-20A(PTD 200-036): Sundry Application Good afternoon Sara, On Form 10-403, Box 11, the current effective depth, MD and TVD, for KRU 1L-20A was left off. Please provide this information as soon as possible. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 RECEIVED STATE OF ALASKA AL,-,„ KA OIL AND GAS CONSERVATION CON,.-.,SSION M/--Y 1 3 2013 REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r AkelgoQgutdow n r Performed Suspend r Perforate Other StimulateAlter Casing r r r Change Approved Program r Rug for Redrill Perforate New Pool r Repair Well Re-enter Susp Well r Other: (— 2.Operator Name. 4.Well Class Before Work 5.Permit to Drill Number. ConocoPhillips Alaska, Inc Development ( Exploratory r 200-036 — 3.Address: 6 API Number: Stratigraphic r Service r P O. Box 100360,Anchorage,Alaska 99510 50-029-22027-01 7.Property Designation(Lease Number) 8 Well Name and Number. ADL0025660 KRV 1L-20A 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 10934 feet Plugs(measured) None true vertical 6325 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 10340 true vertical 0 feet (true vertical) 5775 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115' 0 0 SURFACE 5965 9 5/8 6000 3683' 0 0 WINDOW A 10 8 6220 3779' 0 0 PRODUCTION 6465 7 6500 3902' 0 0 PRODUCTION 4444 5 1/2” 10491 5912' 0 0 LINER A 612 3 1/2" 10934 6325' 0 0 Perforation depth: Measured depth 10574-10604, 10742-10762 ., `)015 True Vertical Depth. 5988-6016,6145-6164 (StlEU (III `; 1 8 t- Tubing(size,grade,MD,and TVD) 3.5, L-80, 10340 MD, 5775 TVD 3.5" HES Permanent patch 8695' -8707' MD Packers&SSSV(type,MD,and TVD) SEAL ASSY-KBH-22 ANCHOR SEAL ASSEMBLY @ 10340 MD and 5775 TVD NIPPLE-CAMCO DS NIPPLE @ 532 MD and 529 TVD 12 Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work. Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VV1NJ r WAG r GINJ r SUSP r SPLUG r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt N/A Contact Brent Rogers/ Kelly Lyons Email N1617@conocophillips.com Printed Name Brent Rogers Title Problem Well Supervisor Signature f-f,,./-x Phone:659-7224 Date 05/08/15 Form 10-404 Revised 5/2015 Submit Original Only E EiV D MAY 13 2015 ConocoPhillips },o Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 8, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7t1 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1L-20A (PTD 200-036) for a permanent patch set in the tubing above the packer. Please call Kelly Lyons or myself @ 659-7224 if you have any questions. Sincerely, Brent Rogers ConocoPhillips Problem Well Supervisor Enclosures Name of Recipient Page 2 of 2 05/08/15 Delete the section break above to remove the second page 1L-20A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/27/15 SET 2.812"TO 1.81" NIPPLE REDUCER IN NIPPLE @ 10,308' RKB, SET&TESTED CA-2 IN NIPPLE REDUCER TO 3000#CMIT-TxIA, PULL CA-2 FROM NIPPLE REDUCER, SET D&D HOLE FINDER @ 8708' RKB, TEST AGAINST D&D TO 1500#MIT-T...JOB IN PROGRESS. CMIT-TxIA TO 3000#(against nipple reducer to confirm good set), STARTING TEST PRESSURES = 3000/2800/630#AFTER 15 MINS =2975/2800/630#AFTER 30 MINS = 2975/2800/630#****PASS**** 04/28/15 SET 3.5" HES PERMANMENT PATCH. 8707' RKB BTM ELEMENT, 8695' TOP ELEMENT. DRIFT W/2" CENT DOWN TO 8900'SLM. 04/29/15 SET 1.81" CA-2 @ 10308' RKB. LRS PEFORMED MIT-T,FAILED (see log). LOST 100 PSI IN FIRST 15 MINUTES & 1150 PSI IN SECOND 15. PRESSURED TBG BACK UP BUT SLOWLY FALLS OFF.APPEARS PLUG LEAKING. PULLED 1.81" CA-2 PLUG FROM 10308' RKB. SET 3.5" CATCHER @ 8623' SLM. PULLED 1" GLV FROM ST#2 @ 6465' RKB. ATTEMPTED PULLING ST#1 @ 3598' RKB. UNSUCCESSFUL. PULL TTP & SET NEW GLV DESIGN. R/D LRS. START T/I/0-3040/400/580 1ST 15 MINUTES T/I/0-2900/400/580. LOST 100 PSI 2ND 15 MINUTES T/I/0-1750/390/580. LOST 1150 PSI . 04/30/15 PULLED 1" BK-GLV FROM ST#1 © 3598' RKB. SET 1" GLV BTM INT IN ST#1 @ 3598' RKB (tro 1288, 3/16" port). SET 1" S/O BTM INT IN ST#2 @ 6465' RKB (1/4" orfice). 05/06/15 RE-TIFL- PASSED. Initial T/I/O=230/1190/840. Shut in WH/lift gas, shot IA FL @ 6870' (8652' OV). Stacked out T with lift gas T/I/O= 1060/1080/500; IA FL @ 5697' (inflowed 1173')T FL @ 5452'. Bled IA(root valve) 60 min. gas. T/I/O= 1100/870/475; IA FL @ 5504' (inflowed 193') T FL @ 5308' (inflowed 144'). Continued to bleed IA for 60 min. gas. T/I/O= 1080/650/410; IA FL @ same location. T FL @ 5201' (inflowed 107'). Continued to bleed IA for 25 min. gas. T/I/O= 1090/570/400; IA FL @ same Iocation.T FL @ same location. 15 min. reading T/I/O= 1090/570/400. 30 min. reading T/I/O= 1090/570/400; IA FL @ same location. T FL @ 5145' (inflowed 56). 45 min. reading T/I/O= 1090/570/400. 60 min. reading T/I/0= 1090/570/400. IA FL @ same location. T FL @ same location. Bled IA for 50 min. gas. T/I/O= 1080/440/380; IA FL @ same location. T FL @ 4968' (inflowed 77'). 15 min. reading T/I/O= 1080/440/375. 30 min. reading T/I/O= 1080/440/375; IA FL @ same location. T FL @ same location. 45 min. reading T/I/O= 1080/440/375. 60 min. reading T/I/O= 1080/440/375; IA FL @ same location. T FL @ same location. Final T/I/O= 1080/440/375. Summary A nipple reducer and plug were set with a passing CMIT TxIA following. This shows integrity of the nipple reducer. Then a 12' 3.5" permanent patch was set in the tubing. A gas lift redesign was then installed. The TIFL passed showing patch integrity and that tubing integrity was repaired. 1L-20A DESCRIPTION OF WORK COMPLETED SUMMARY KUP PROD 1 L-20A r `- d ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) c."..itnip, 500292202701 KUPARUK RIVER UNIT PROD 70.54 7,278.05 10,965.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(R) -Rig Release Date 1L-20A,517/201510.33.13 AM SSSV:NIPPLE 100 11/8/2014 Last WO: 4/12/2000 3/31/1991 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date {ILast Tag:SLM 10,580.0 5/4/2012 Rev Reason:REVISE WAIVER NOTE hipshkf 5/7/2015 HANGER;296 Il u�1'J) asmg rings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ttKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread `� ■� CONDUCTOR 16 15.062 35.0 115.0 115.0 62.58 H-40 WELDED Caning Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 6,0000 3,682.5 40.00 L-80 BTCM Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread WINDOW A 8 6.000 6,210.0 6,220.0 3,778.9 2600 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread -/vs.../CONDUCTOR; .0-11s.o- PRODUCTION 7 6.276 35.0 6,500.0 3,901.9 26.00 L-80 BTCM Post SR Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread NIPPLE;531.6 .: PRODUCTION 5 12 4.950 6,047.0 10,491.0 5,911.5 15.50 1-80 HYDRIL 511 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen p...Grade Top Thread II LINER A 31/2 2.992 10,322.4 10,934.0 9.30 L-80 ABT-MOD Liner Details Nominal ID GAS LIFT;3.596.2 Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Corn (in) 10,322.4 5,759.9 27.75 PACKER BAKER SABL-3 PACKER w/TIEBACK EXTENSION 3.000 Tubing Strings Tubing Description String Ma...ID tel Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Iblft) Grade Top Connection TUBING 31/2 2.992 29.8 10,341.3 5,776.7 9.30 L-80 EUE8RDMOD • Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 29.8 29.8 0.05 HANGER McEVOY GEN IV TUBING HANGER 3.500 SURFACE;35.0.6,0000- 531.6 529.1 12.73 NIPPLE CAMCO DS NIPPLE 2.875 ' 10,308.5 5,747.7 28.12 NIPPLE CAMCO DS NIPPLE W/1.81 NIPPLE REDUCER 2.812 _ 10,309.5 5,748.5 2808 LOCATOR NO GO LOCATOR 2.937 • 10,316.0 5,754.2 27.81 PBR BAKER 80-40 PBR 2.937 10,339.6 5,775.1 27.60 SEAL ASSY KBH-22 ANCHOR SEAL ASSEMBLY 2.780 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl WINDOW A;8.210.06,220.0 Top(RKB) (ftKB) 1) Des Com Run Date ID(in) 8,695.0 4,767.8 64.29 PATCH "3.5"HES PERMANENT PATCH 4/28/2015 GAS LIFT;6,465.3 it 10,308.5 5,747.6 28.12 NNIPPLE EDUEER 1.81 NIPPLE REDUCER 4/27/2015 1.810 PRODUCTION Poet srr: 10,800.0 6,199.2 20.79'FISH 'RETAINER Cement retainer pushed to bottom with 7212000 35.0.6,500.0I lif 'milling 7/21/2000 GAS LIFT;8,652.4 t: Perforations&Slots Shot Dens [{ Top(TVD) elm(ND) (shotst PATCH;8,6950 V1 Top(ftKB) Btm(ftKB) (RKB) (RKB) Zone Date t) Type Com ; 10,574.0 10,604.0 5,988.0 6,016.0 C-4,1L-20A 8/19/2000 6.0 APERF 21/2"HC;60 deg ph, alternating BH/PJ GAS LIFT;9.779.9 a; 10,695.0 10,705.0 6,101.0 . 6,110.4 UNIT 6.11- 6/6/2000 6.0 SQZ SQUEEZED 7/15/2000 20A 11 10,742.0 10,762.0 6,145.0 6,163.7 A-6,A-5,11- 7/30/2000 4.0 RPERF 2 1/2"HC BH,90 deg ph GAS LIFT;10,268.0 4 20A i Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(TVD) NIPPLE REDUCER;10.3085 P ((ftKB) (ftKB) (ftKB) (ftKB) Type Date Com NIPPLE;1n,ao6,51 !�,1 10,695.0 10,705.0 6,101.0 6,110.4 FRAC 2/21/2002 FRAC 79M#16/20 PROPPANT,7.7 ppa on PERFS LOCATOR;10,309.5 III P Cement Squeezes PBR;10,316.0 Top)ND) Btto(TVD) Top(BBB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 10,762.0 10,782.0 6,163.7 6,182.4 Cement Squeeze 6/6/2000 10,695.0 10,705.0 6,101.0 6,110.4 Cement Squeeze 7/15/2000 Mandrel Inserts 111.1 _ st SEAL ASSY;10,339.6 - at) on Top(ND) Valve Latch Port SW TRO Run N Top(RKB) (ftKB) Make Model OD(in) Bern Type Type (in) (psi) Run Date Com 3,598.2 2,613.2 CAMCO KBMM2 1 GAS LIFT GLV BTM 0.188 1,288.0 4/302015 INT PRODUCTION;6,047.0. 2 6,465.3 3,886.7 CAMCO KBG-2- 1 GAS LIFT OV BTM 0.250 4/30/2015 10.491D- KG INT 3 8,652.4 4,749.1 CAMCO KBG-2- 4 9,779.9 5,329.5 CAMCO KBG-2- 1 GAS LIFT OV INT 0.250 0.0 3/24/2015 EXTP APERF;10.574.010,604.0- 9 KG 1 GAS LIFT DMY INT 0.000 0.0 7/13/2004 9 FRAC;10,695.0 I r 5 10,268.0 5,712.2 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 7/13/2004 soZ 10.695.0-10.705.0 ,: 9 Notes:General&Safety RPERF;10,742.0-10,762.0- End Date Annotation 4/13/2000 NOTE:Sidetracked,set CIBP&whipstock�a 6210'in 7"CSG;milled window for sidetrack. 7/21/2000 NOTE:Milled EZSV 8 pushed to bottom(10800'CTM) FISH;10,600.0 -. 2/9/2011 NOTE:View Schematic w/Alaska Schematc9.0 5/4/2012 NOTE:LINER APPEARS TO BE COLLAPSED 4/6/2015 NOTE:WAIVERED WELL,IA X OA COMMUNICATION REVISED LINER A;10.322.410.934.0 200-olio \qct\- oo5 WELL LOG A ,`Ji 13 25 'i t'1, TRANSMITTAL D ; DATA LOGGED APR 2 2 2015 --___.�.__..l u. 5/ 2015 -� K NDER PROACTIVE DIAGNOSTIC SERVICES, INC. C To: AOGCC Makana Bender ------ _ 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 (10° — ° 3 f [907) 793-1225 i. �� RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MIT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED JUN 2 5 2015 1) Caliper Report 11-Apr-15 1C-18 1 Report / CD 50-029-22939-00 /2) Caliper Report 13-Apr-15 1L-20A 1 Report / CD 50-029-22027-01 Signed : MA.42-fru1/4.7/r) 6...eiteat Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D1Archives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit docx too-o3Co 25�1k3 ' Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1L-20A p Log Date: April 13, 2015 Field: Kuparuk ' Log No.: 10341 Run No.: 1 State: Alaska API No. 50-029-22027-01 Pipe Description: 3.5 inch 9.2 lb. L-80 EUE 8rd Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 10,243 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : This caliper data is tied into the DS Nipple at 532 feet(Driller's Depth). ' This log was run to assess the condition of the tubing logged with respect corrosive and mechanical damage. ' The caliper recordings indicate the 3.5 inch tubing logged appears to be in good condition with respect to corrosive and mechanical damage with no significant wall penetrations, areas of cross-sectional wall loss, or I.D. restrictions recorded. 1 MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations(> 17%) are recorded throughout the tubing logged. ' MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss(> 5%)are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. 1 1 1 1 E. Gustin J. BruningS. Drake ri . ;,, .(s) v, ' ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford,TX 77497 Phone: (281)431-7100 or(888) 565-9085 Fax: (281)431-7125 E-mail: PDSAnalvsis(&memorylog,com Prudhoe Bay Field Office Phone: (907)659-2307 Fax: (907) 659-2314 1 i Correlation of Recorded Damage to Borehole Profile • Pipe 1 3.5 in. (33.0'-10,243.1') Well: 1L-20A Field: Kuparuk ' Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: April 13,2015 I II. Approx.Tool Deviation ■ Approx. Borehole Profile I 1 - 36 I50 1,588 I 100 3,145 I GLM 1 - I150 4,718 Q a`) _ E "' I 7c GLM 2 200 6,265 a cuI 250 7,851 I GLM 3 300 9,451 I GLM 4 GLM 5 - 324 10,221 I 0 50 100 Damage Profile(%wall)/Tool Deviation(degrees) I IBottom of Survey=324 I I I IPDS Report Overview Clki4S, Body Region Analysis IWell: 1 L-20A Survey Date: April 13,2015 Field: Kuparuk Tool Type: UW MFC 24 No.211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches I Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.2 ppf L-80 EUE 8rd Analyst: J. Paizis Pipe Nom.O.D. Weight Grade&Thread Nom.I.D. Top Depth Bottom Depth I 3.5 in. 9.2 ppf L-80 EUE 8RD 2.992 in. 33 ft. 10,243 ft. IPenetration(%wall) Damage Profile(%wall) 400 Penetration body Metal loss body 300 0 50 100 0.1 200 I100 - _ 46 I 0 0 to 20 to 40 to over 20% 40% 85% 85% 96 I Number of joints analyzed(total=331) GLM 1 (9:00) 331 0 0 0 144 - IDamage Configuration(body) 10 I194 IIIII GLM 2 (8:30) S 244 _ I 0 GLM 3 (6:00) Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole 294 I GLM 4 (10:00) Number of joints damaged (total=2) GLM 5 (6:30) 0 0 2 0 0 Bottom of Survey= 324 I ICh4S. PDS Report Joint Tabulation Sheet I Well: 1L-20A Survey Date: April 13,2015 Field: Kuparuk Analyst: J. Paizis Company: ConocoPhillips Alaska,Inc. Pipe Description Nom.I.D. Body Wall Top Depth Bottom Depth I 3.5 in. 9.2 ppf L 80 EUE 8RD Tubing 2.992 in. 0.254 in. 33 ft. 10,243 ft. Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 0.1 33 0 0.03 11 4 2.97 Pup 1 36 0 0.02 7 2 , 2.95 1.1 66 0 0.02 , 6 2 _ 2.96 Pup I 1.2 70 0 0.03 11 2 2.95 Pup 1.3 76 0 0.02 6 2 2.92 Pup Lt. Deposits. 1.4 84 0 0.01 6 1 2.93 Pup Lt. Deposits. 2 94 0 0.02 9 2 2.94 I 3 125 157 0 0.02 7 2 2.95 4 0 0.02 7 2 2.95 5 188 0 0.03 11 2 2.92 Lt. Deposits. 6 219 0 0.02 , 9 2 , 2.94 I 7 250 0 0.02 9 2 2.92 Lt. Deposits. 8 281 0 0.02 6 2 2.96 9 313 0 0.03 11 2 2,92 Lt. Deposits. 10 344 0 0.03 11 2 2.95 11 375 0 0.02 9 2 2.94 12 407 0 0.03 10 2 2.94 13 438 0 0.02 8 2 2.94 14 469 0 0.02 8 2 2.95 I 15 500 0 0.02 7 1 2.95 15.1 532 0 0 0 0 2.85 Camco DS Nipple 16 533 0 0.03 10 2 2.93 Lt. Deposits. 17 564 0 0.03 10 2 2.92 Lt. Deposits. 18 596 0 0.02 _ 7 2 2.94 I19 627 0 0.02 7 2 2.92 Lt. Deposits. 20 657 0 0.02 7 1 2.95 21 688 0 0.02 8 1 2.94 22 719 0 0.02 9 2 2.93 I23 751 0 0.02 7 2 2.92 Lt. Deposits. 24 782 0 0.02 8 2 2.92 Lt. Deposits. 25 813 0 0.03 10 2 2.94 26 843 0 0.01 5 2 2.95 I 27 874 0 0.03 10 2 2.93 28 905 0 0.03 11 2 2.93 Lt. Deposits. 29 937 0 0.02 8 2 2.95 30 968 0 0.02 6 2 _ 2.94 I 31 999 0 0.02 9 2 2.95 32 1030 0 0.02 7 2 2.93 Lt. Deposits. 33 1061 0 0.02 7 2 2.94 34 1092 0 0.02 8 2 2.94 I 35 1124 0 0.02 6 1 2.94 36 1155 0 0.01 5 2 2.94 37 1185 0 0.03 13 2 2.93 38 1217 0 0.01 5 _ 2 2.91 Lt. Deposits. 39 1248 0 0.02 , 8 2 2.92 Lt. Deposits. I 40 1278 0 0.02 7 2 2.94 41 1307 0 0.02 8 2 2.95 42 1338 0 0.03 13 4 2.94 43 13 70 0 0.02 7 2 2.94 I44 1401 0 0.03 12 4 2.93 IPenetration Body Metal Loss Body I Page 1 I I I Ili PDS Report Joint Tabulation Sheet I Well: 1 L-20A Survey Date: April 13, 2015 Field: Kuparuk Analyst: J. Paizis Company: ConocoPhillips Alaska,Inc. I Pipe Description 3.5 in. 9.2 ppf L-80 EUE 8RD Tubing Nom. I.D. Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 33 ft. 10,243 ft. Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 45 1432 0 0.03 10 2 2.94 im 46 1464 0 0.03 11 2 2.93 Lt. Deposits. il' 47 1494 0 0.02 7 2 2.94 48 1525 0 0.03 10 2 2.93 Lt. Deposits.49 1556 0 0.02 9 2 2.95 50 1588 0 0.03 12 2 2.95 51 1617 0 0.02 7 2 2.95 0 I 52 1647 0 0.02 _ 7 3 2.94 I 53 1678 0 0.02 9 2 2.95 I • 54 1710 0 0.02 9 2 2.93 55 1741 0 0.02 7 3 2.95 I 56 1772 0 0.02 9 1 2.95 C 57 1803 0 0.02 9 3 2.92 Lt. Deposits. 58 1834 0 0,02 7 2 2.94 C 59 1865 0 0.02 9 2 2.95 I 60 1897 0 0.02 8 1 2.94 61 1928 0 0.02 6 1 2.94 62 1959 0 0.02 7 2 2.93 Lt. Deposits. • at 63 1990 0 0.03 10 2 2.92 Lt. Deposits. I 64 2022 0 0.02 9 2 2.93 65 2053 0 0.02 8 2 2.93 66 2083 0 0.02 8 2 2.95 • 67 2114 0 0.02 8 2 2.93 • 68 2146 0 0.02 8 2 2.94 11 I 69 2177 0 0.02 9 3 2.93 C 70 2208 0.04 0.03 10 2 2.93 Lt. Deposits. 71 2240 0 0.03 10 _ 3 2.94 C 72 2271 0 0.02 7 2 2.94 I 73 2302 0 0.03 13 2 2.92 Lt. Deposits. 74 2334 0 0.02 7 3 2.92 Lt. Deposits. ill 75 2365 0 0.02 9 2 2.93 . ■ 76 2396 0 0.03 11 2 2.92 Lt. Deposits. I 77 2428 0 0.02 7 1 , 2.95 78 2459 0.04 0.02 8 2 2,94 • • 79 2490 0 0.03 10 2 2.95 • 80 2522 0 0.02 7 _ 2 2.94 a I 81 2552 0 0.02 9 1 2.96 82 2583 0 0.02 8 2 2.92 Lt. Deposits. U 83 2614 0 0.02 8 2 2.94 INii 84 2645 0 0.02 7 2 2.93 • I 85 2677 0 0.02 7 2 2.94 U 86 2708 0 0.02 6 2 2.93 Lt. Deposits. 87 2739 0 0.02 7 2 2.93 II111 88 2770 0 0.02 7 1 2.95 • 89 2802 0 0.02 9 1 2.94 • I 90 2833 0 0.02 8 2 2.95 U 91 2864 0 0.02 7 2 2.93 Lt. Deposits. N 92 2895 0 0.02 9 1 2.92 Lt. Deposits. • 93 2927 0 0.02 8 1 2.95 • I94 2958 0 0.02 9 2 2.93 Lt. Deposits. • IPenetration Body Metal Loss Body I Page 2 I Ichas. PDS Report Joint Tabulation Sheet I Well: 1L-20A Survey Date: April 13, 2015 Field: Kuparuk Analyst: J. Paizis Company: ConocoPhillips Alaska,Inc. I Pipe Description 3.5 in. 9.2 ppf L-80 EUE 8RD Tubing Nom. I.D. Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 33 ft. 10,243 ft. Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 95 2989 0 0.02 7 2 2.94 96 3020 0 0.02 9 2 2.93 I 97 3052 0 0.02 7 2 2.94 98 3083 0 0.02 7 2 2.93 Lt. Deposits. 99 3114 0 0.02 8 1 2.93 100 3145 0 0.03 10 2 2.92 Lt. Deposits. 101 3177 0 0.02 9 2 2.94 I 102 3208 0 0.02 9 2 2.93 Lt. Deposits. 103 3238 0 0.02 7 2 2.92 Lt. Deposits. 104 3269 0 0.02 9 1 2.95 105 3301 0 0.02 9 1 2.95 I 106 3332 0 0.02 9 2 2.93 107 3363 0 0.03 10 2 2.95 108 3394 0 0.02 8 1 2.94 109 3426 0 0.02 8 2 2.94 I 110 3457 0 0.03 11 2 2.95 111 3488 0 0.02 7 2 2.94 112 3520 0 0.02 6 1 2.95 113 3551 0 0.03 10 2 2.95 I 113.1 3582 0 0.04 . 16 3 2.76 Pup Shallow Line of Pits. Deposits. 113.2 3588 0 0 0 0 2.73 GLM 1 (Latch C@ 9:00) 113.3 3595 0 0.03 10 2 2.94 Pup 114 3601 0 0.03 11 4 2.93 I 115 3632 0 0.02 9 2 2.93 Lt. Deposits. 116 3663 0 0.03 11 2 2.93 117 3694 0 0.02 6 1 2.94 118 3724 0 0.02 9 2 2.93 119 3755 0 0.02 9 2 . 2.93 _ Lt. Deposits. I120 3786 0 0.03 11 3 2.92 Lt. Deposits. 121 3818 0 0.01 5 2 2.95 122 3849 0 0.02 7 2 , 2.94 123 3880 0 0.03 11 2 2.93 Lt. Deposits. I 124 3911 0 0.03 13 2 2.95 125 3943 0 0.03 11 3 2.95 126 3974 0 0.02 6 1 2.94 127 4005 0 0.02 9 3 2.94 I 128 4035 0 0.02 9 1 2.96 129 4065 0 0.02 7 2 2.93 Lt. Deposits. 130 4097 0 0.02 8 2 2.94 131 4128 0 0.02 9 2 2.93 I 132 4159 0 0.03 10 3 2.94 133 4190 0 0.02 8 2 2.94 134 4222 0 0.02 7 3 2.90 Lt. Deposits. 135 4253 0 0.02 9 _ 2 2.97 I 136 4285 0 0.02 9 _ 3 2.94 137 4316 0 0.02 9 4 2.95 138 4347 0 0.02 7 _ 1 2.95 139 4377 0 0.02 9 4 2.95 140 4409 0 0.02 8 3 2.93 I 141 4440 0 0.02 9 3 2.93 Lt. Deposits. IPenetration Body Metal Loss Body I Page 3 I PDS Report Joint Tabulation Sheet I Well: 1L-20A Survey Date: April 13,2015 Field: Kuparuk Analyst: J. Paizis Company: ConocoPhillips Alaska,Inc. I Pipe Description 3.5 in. 9.2 ppf L-80 EUE 8RD Tubing Nom.I.D. Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 33 ft. 10,243 ft. Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 142 4471 0 0.03 11 5 2.94 C 143 4502 0 0.02 9 1 2.95 144 4532 0 0.03 10 2 2.92 Lt. Deposits. U I 145 4563 0 0.02 6 1 2.93 Lt. Deposits. 146 4594 0 0.02 9 2 2.95 • 147 4624 0 0.02 7 2 2.95 • 148 4656 0 0.02 7 3 2.92 Lt.Deposits. C I 149 4687 0 0.02 9 1 2.94 150 4718 0 0.03 12 2 2.93 VO 151 4749 0 0.02 9 2 2.93 • 152 4781 0 0.02 6 2 2.94 i I 153 4812 154 4843 0 0.02 9 2 2.93 Lt.Deposits. 0 0.02 9 2 2.93 Lt. Deposits. •s • 155 4874 0 0.02 7 2 2.93 Lt. Deposits. 156 4906 0 0.01 6 2 2.94 i I 157 4937 0 0.02 7 2 2.94 158 4968 0 0.02 8 2 2.94 U 159 4999 0 0.02 8 2 2.93 V 160 5030 0 0.02 9 1 2.94 • I 161 5062 0 0.03 10 2 2.93 U.Deposits. • 162 5093 0 0.02 7 2 2.93 Lt. Deposits. 163 5124 0 0.02 6 2 2.95 164 5156 0 0.02 7 2 2.93 Lt. Deposits. I 165 5187 0 0.02 8 1 2.94 166 5218 0 0.02 7 1 2.94 _ • 167 5250 0 0.02 7 2 2.94 • 168 5281 0 0.02 7 4 2.95 169 5312 0 0.03 11 3 2.93 Lt. Deposits. I 170 5343 0 0.02 7 2 2.93 171 5375 0 0.02 8 1 2.95 172 5406 0 0.02 9 3 2.95 C 173 5437 0 0.02 9 4 2.92 Lt. Deposits. G 174 5468 0 0.02 7 2 2.94 175 5500 0 0.03 11 4 2.93 Lt. Deposits. C 176 5531 0 0.03 11 3 2.93 Lt. Deposits. 177 5562 0 0.02 9 2 2.89 Lt. Deposits. • I 178 5593 0 0.03 10 2 2.95 • 179 5624 0 0.03 11 4 2.96 r 180 5656 0 0.02 8 4 2.95 C 181 5687 0 0.02 9 3 2.94 I 182 5718 0 0.03 10 3 2.95 183 5749 0 0.02 9 3 2.94 C 184 5781 0 0.02 8 2 2.93 Lt. Deposits. • 185 5812 0 0.02 8 4 2.92 Lt. Deposits. C I 186 5842 0 0.02 9 2 2.94 187 5872 0 0.02 9 4 2.94 C 188 5903 0 0.03 11 2 2.94 189 5933 0 0.02 7 2 2.94 • 190 5963 0 0.02 8 2 2.94 • I 191 5993 0 0.03 10 2 2.95 • IPenetration Body Metal Loss Body I Page 4 I I a. PDS Report Joint Tabulation Sheet I Well: 1L-20A Survey Date: April 13, 2015 Field: Kuparuk Analyst: J. Paizis Company: ConocoPhillips Alaska,Inc. I Pipe Description 3.5 in. 9.2 ppf L-80 EUE 8RD Tubing Nom.I.D. Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 33 ft. 10,243 ft. Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 192 6023 0 0.02 7 4 2.94 193 6053 0 0.02 7 3 , 2.96 I 194 6084 0 0.03 11 2 2.97 195 6114 0 0.02 9 2 2.95 196 6144 0 0.02 8 3 2.95 197 6173 0 0.02 7 2 2.95 198 6204 0 0.02 8 4 2.94 I 199 6234 0 0.02 6 2 2.98 200 6265 0 0.02 8 3 2.94 201 6295 0 0.02 7 2 2.96 202 6323 0 0.02 7 1 2.94 I 203 6353 0 0.02 8 2 2.96 204 6384 0 0.02 8 3 2.93 Lt. Deposits. 205 6414 0 0.03 13 5 2.96 205.1 6446 0 0 0 0 2.85 GLM 2 (Latch @ 8:30) I 206 6452 0 0.04 17 4 2.80 Shallow Line of Pits.Deposits. 207 6482 0 0.02 9 1 2.96 208 6514 0 0.02 7 2 2.96 209 6546 0 0.03 12 2 _ 2.96 I 210 6578 0 0.02 9 2 2.98 211 6609 0 0.02 9 2 2.97 212 6642 0 0.02 8 2 2.98 213 6674 0 0.02 6 1 2.98 I 214 6705 0 0.02 6 2 2.96 215 6737 0 0.02 9 1 2.96 216 6769 0 0.01 5 1 2.97 217 6801 0 0.01 5 2 2.96 218 6833 0 0.03 13 3 2.97 I 219 6863 0 0.02 6 2 2.96 220 6895 0 0.03 11 2 2.97 221 6927 0 0.02 9 2 2.97 , 222 6959 0 0.02 8 1 _ 2.97 I 223 6990 0 0.03 11 2 2.96 224 7022 0 0.01 6 2 2.96 225 7054 0 0.01 6 1 2.96 226 7086 0 0.02 6 3 2.95 I 227 7118 0 0.02 7 2 2.98 228 7148 0 0.02 6 1 2.97 229 7180 0 0.03 10 1 2.97 230 7212 0 0.01 4 1 2.98 1 231 7244 0 0.01 5 2 2.96 232 7277 0 0.01 4 1 2.96 233 7308 0 0.01 4 1 2.98 234 7340 0 0.01 4 1 2.96 I 235 7372 0 0.02 7 4 2.93 236 7404 0 0.01 5 1 2.96 237 7436 0 0.02 7 3 2.95 238 7468 0 0.01 5 1 2.97 239 7500 0 0.02 7 4 2.95 I 240 7531 0 0.01 5 2 2.95 IPenetration Body Metal Loss Body I Page 5 I I I w - PDS Report Joint Tabulation Sheet I Well: 1 L-20A Survey Date: April 13,2015 Field: Kuparuk Analyst: J. Paizis Company: ConocoPhillips Alaska,Inc. I Pipe Description 3.5 in. 9.2 ppf L-80 EUE 8RD Tubing Nom. I.D. Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 33 ft. 10,243 ft. Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 241 7563 0 0.01 5 1 2.96 l 242 7595 0 0.03 11 2 2.96 r I 243 7627 0 0.02 9 1 2.96 244 7659 0 0.01 5 2 2.95 C 245 7691 0 0.01 4 1 2.97 246 7723 0 0.01 5 1 2.97 1 247 7755 0 0.02 8 1 2.97 • I 248 7787 0 0.01 4 1 2.97 249 7819 0 0.01 4 1 2.97 1 250 7851 0 0.01 4 2 2.96 i 251 7883 0 0.01 4 1 2.97 1 I 252 7915 0 0.01 5 1 2.96 253 7947 0 0.01 , 5 2 2.94 254 7979 0 0.01 5 2 2.95 _ 255 8010 0 0.02 7 3 2.95 256 8043 0 0.01 5 2 2.96 C 257 8075 0 0.02 9 1 2.97 258 8107 0 0.01 5 2 2.95 M 259 8138 0 0.01 5 1 2.97 1 I 260 8170 0 0.01 5 2 2.96 C 261 8202 0 0.02 9 2 2.95 262 8234 0 0.02 6 2 2.96 L 263 8266 0 0.01 6 2 2.94 i 264 8298 0 0.01 5 2 2.94 I 265 8330 0 0.01 6 2 2.95 , ` 266 8362 0 0.01 5 1 2.97 267 8394 0 0.01 4 2 2.95 268 8426 0 0.01 4 1 2.97 _ I269 8457 0 0.01 5 1 2.97 270 8489 0 0.01 6 1 2.95 271 8521 0 0.01 6 1 2.97 i 272 8553 0 0.02 9 2 2.96 • I 273 8584 0 0.03 10 2 2.95 273.1 8616 0 0 0 0 2.88 GLM 3 (Latch @ 6:00) •• 274 8622 0 0.02 8 2 2.95 275 8654 0 0.01 5 1 2.95 I 276 8686 0 0.03 11 1 2.98 • 277 8718 0 0.01 5 1 2.97 I 278 8750 0 0.01 5 2 2.94 C 279 8782 0 0.02 8 1 2.97 I 280 8814 0 0.01 6 3 2.96 281 8846 0 0.03 11 1 2.96 282 8878 0 0.02 9 1 2.98 L 283 8910 0 0.01 5 1 2.97 1 284 8942 0 0.02 7 2 2.96 I 285 8974 0 0.01 5 2 2.96 286 9006 0 0.01 6 2 2.95 II 287 9038 0 0.02 9 2 2.97 _ 288 9070 0 0.01 4 1 2.98 i I289 9101 0 0.02 6 1 2.97 i Penetration Body Metal Loss Body IPage 6 I I Cif ilt w PDS Report Joint Tabulation Sheet I Well: 1L-20A Survey Date: April 13, 2015 Field: Kuparuk Analyst: J. Paizis Company: ConocoPhillips Alaska,Inc. I Pipe Description 3.5 in. 9.2 ppf L-80 EUE 8RD Tubing Nom. I.D. Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 33 ft. 10,243 ft. Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 290 9133 0 0.01 5 2 2.95 291 9165 0 0.03 10 2 2.97 I 292 9196 0 0.01 5 2 2.96 293 9228 0 0.02 7 1 2.98 294 9260 0 0.01 5 2 2.96 295 9290 0 0.03 11 3 2.95 296 9323 0 0.02 9 1 2.98 I 297 9355 0 0.03 12 1 2.97 • 298 9387 0 0.03 10 2 2.97 • 299 9419 0 0.01 5 3 2.96 300 9451 0 0.02 6 2 2.95 I 301 9483 0 0.03 11 2 2.97 302 9514 0 0.02 6 1 2.96 303 9546 0 0.02 9 2 2.97 304 9577 0 0.03 10 2 2.97 ■ I 305 9609 0 0.03 12 2 2.96 306 9641 0 0.02 9 2 2.95 307 9672 0 0.01 6 1 2.97 308 9704 0 0.03 10 1 2.96 ' I 308.1 9735 0 0 0 0 2.89 GLM 4 (Latch @10:00) 309 9741 0 0.03 10 2 2.97 310 9772 0 0.01 5 1 2.96 311 9804 0 0.02 6 2 2.96 312 9836 0 0.04 14 3 2.96 I313 9868 0 0.02 9 2 2.97 314 9900 0 0.01 6 2 2.96 315 9931 0 0.02 7 2 2.96 316 9963 0 0.02 6 2 2.95 I 317 9995 0 0.01 6 3 2.95 318 10026 0 0.01 5 2 2.96 319 10058 0 0.03 11 2 2.96 ■ 320 10089 0 0.03 11 3 2.95 I 321 10121 0 0.01 5 2 2.96 322 10152 0.04 0.04 15 3 2.96 323 10184 0 0.02 7 2 2.95 323.1 10215 0 0 0 0 2.90 GLM 5 (Latch @ 6:30) I 324 10221 0 0.04 15 2 2.97 Penetration Body Metal Loss Body I I I I Page 7 I `, • KUP PROD III 1 L-20A COtIOCOPII1IIIp$ Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status n010) MD(ftKB) Act Btm(ftKB) Comm:t dr» 500292202701 KUPARUK RIVER UNIT PROD 70.54 7,278.05 10,965.0 I ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date n-z0A.325/2015e:3623AM SSSV:NIPPLE 100 11/8/2014 LastWO. 4/12/2000 3/31/1991 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date � � Last Tag:SLM 10,580.0 5/4/2012 Rev Reason:PLUG,GLV C/O lehallf 3/24/2015 ....._........._......HANGER:29.e Y.ik r Casing Strings Casing Description OD(in) ID(in) Top(ttKB) Set Depth(MB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread IT CONDUCTOR /6 15.062_ 35.0 115.0 115.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(RKB) Set Depth(ttKB) Set Depth(ND)...WtlLen(I...Grade Top Thread SURFACE 95/8 8.921 35.0 6,000.0 3,682.5 40.00 L-80 BTCM -- Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread i WINDOW A 8 6000 6,210.0 6,220.0 3,778.9 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L,.Grade Top Thread 'S-A-,CONDUCTOR:35.a715.0 -' ✓-�.n_.ai.=EVICTION 7 6.276 35.0 6,500.0 3,901.9 26.00 L-80 BTCM 113 I Casing Description OD(In) ID(in) 'Top(MB) Set Depth MEI) Set Depth)TVD)...Wt/Len(I...Grade Top Thread NIPPLE;531.6 PRODUCTION 512 4.950 6,047.0 10,491.0 5,911.5 15.50 L-80 HYDRIL 511 Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)... WtlLen(I...Grade Top Thread LINER A 3 1/2 2.992 10,322.4 10,934.0 9.30 L-80 ABT-MOD i l Liner Details Nominal ID 0001 0 T SI S96 2 i-1. GB Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des ... (in) 10,322.4 5,759.9 27.75 PACKER -BAKER SABL-3 PACKER w/TIEBACK EXTENSION 3.000 I Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) set Depth(ft..Set Depth(ND)I...Wt(111/ft) Grade Top Connection TUBING I 31/21 2.9921 2981 10,341,31 5,776.71 9.301 L-80 I EUE8RDMOD Completion Details Nominal ID Top(RKB) Top(TVD)iftKB) Top Incl(°) Item Das Com (in) 29.8 29.8 0.05 HANGER McEVOY GEN IV TUBING HANGER 3.500 SURFACE;36.0-6000o- 531.6 529.1 12.73 NIPPLE CAMCO DS NIPPLE 2.875 t 10,308.5' 5,747.7 28.12 NIPPLE CAMCO DS NIPPLE 2.812 - 10,309.5 5,748.5 28.08 LOCATOR NO GO LOCATOR 2937 I 10,316.0 5,754.2' 27.81'PBR BAKER 80-40 PBR 2.937 10,339.6 5,775.1 27.60 SEAL ASSY KBH-22 ANCHOR SEAL ASSEMBLY 2.780 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top loot WINDOW A;6,210.06,720.0 I , Top(ftKB) (RKB) r) Des _ Corn Run Date ID(in) i GAS LIFT;6,465.3 10,308.0 5,747.2 28.14 PLUG CA-2 PLUG(OAL 28") 3/11/2015 10,800.0 6,199.2 20.79 FISH RETAINER Cement retainer pushed to bottom with 7/21/2000 milling 7/21/2000 PRODUCTION PostS/T: Perforations&Slots 35.043,500.0 Shot I GAS LIFT;6, 2.4 Top(TVD) Btm(TVD) (ahofsl Top(RKB) BM(MB)) (RKB) (RKB) Zona Date t) Type Com 10,574.0 10,6040 5,988.0 6,016.0 C-4,1L-20A 8/19/2000 Dens 6.0 APERF 2 1/2"HC;60 deg ph, GAS LIFT:9,779.9 alternating BH/PJ 10,695.0 10,705.0 6,101.0 6,110.4 UNIT B,1L- 6/6/2000 6.0 SQZ SQUEEZED 7/15/2000 I A GAS LIFT;10,768.0 10,742.0 70,762.0 6,145.0 20A 6,163.7 A-66,, A-5,iL- 7/30/2000 4.0 RPERF 2 1/2"HC BH,90 deg ph 20A r - Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Bim(ND) (ftKB) (ftKB) (ftKB) OMB) Date Corn NIPPLE;10,306.5.. 70,695.0 10,705.0 6,101.0 6,110.4 FRAC 2/21/2002 FRAC 79M#16/20 PROPPANT,7.7 ppa on PERFS PLUG;10,308.0 Cement Squeezes LOCATOR;10,309.5 Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (RKB) Des Start Date Corn 10,762.0 10,782.0 6,163.7 6,182.4 Cement Squeeze 6/6/2000 PBR;10,316.0 10,695.0 10,705.0 6,101.0 6,110.4 Cement Squeeze 7/15/2000 Mandrel Inserts st a8 en Top(ND) VCM latah Port Size TRO Run SEAL ASSY.10.339.6 N lop MB) (RKB) Make Model OD(In) Sery Type Type (in) - (psi) Run Date Com 1 3,598.2 2,613.2 CAMCO KBMM2 1.GAS LIFT GLV INT 0.156 1,152.0 2/8/2011 2 6,465.3 3,886.7 CAMCO KBG-2- 1''GAS LIFT GLV INT 0.188 1,182.0 2/8/2011 9 3 8,652.4 4,749.1 CAMCO KBG-2- ( GAS LIFT OV INT 0.250 0.0 3/24/2015 EXTP 9 KG PRODUCTION;6.017.4 10.491.0 4 9,779.9 5,329.5 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 7/13/2004 9 RPERF;10,574.0.10,604.0- 5 10,268.0 5,712.2 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000. 0.0 7/13/2004 9 I FRAC;1o,ss.o -pppJJJ rrr��� Notes:General&Safety 502;70,W5.410,706.0� �' End Date Annotation 4/13/2000 NOTE:Sidetracked,set CIBP 8 whipstock@ 6210'in 7"CSG;milled window for sidetrack. _.., 7/21/2000 NOTE:Milled EZSV 8 pushed to bottom(10800'CTM) RPERF;10,742.410,762.0 7/8/2002 NOTE:WAIVERED WELL,IA X OA COMMUNICATION I -11 tr FISH;10,800.0 2/9/2011 NOTE:View Schematic w/Alaska Schematic9.0 5/4/2012 NOTE:LINER APPEARS TO BE COLLAPSED I I LINER A;10,322.4-10,934.0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~)- _~ ~ Well History File Identifier Organization (done)D Two-Sided III Illlllllll] II III RESCAN DIGITAL DATA OVERSIZED (Scannable) [3 Color items: o Diskettes, No. o Maps: ~"' Grayscale items: [3 Other, No/Type [3 Other items scannable by large scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) [3 Other: [3 Logs of various kinds TOTALPAGES: ~7 NOTES: ORGANIZED BY: BEVERLY BREN~SHERYL MARIA LOWELL Other Project Proofing PROOFEDBY: BEVERLY BRE~SHERYL MARIA LOWELL 13 Staff Proof By: Date: DATE: /t~L(~ /S/~ PAGES: q'~ (at the time of scanning) SCANNED BY: BEVERLY B~ VINCENT SNERYL MARIA LOWELL DATE; /~/{~,///~ ~.,. /SI ReScanned (done) RESCANNED BY.' BEVERLY ~ VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: PAGES: ~7 Quality Checked (done) Rev 1NOTScanned.v4)d /; / /. ~ // J~%% S~hl~1Cl~l'ge~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~~~~~ ~~L ~ ~ ~~~~ Log Description NO.4775 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD o7i1 o/oa 2W-04 12061711 INJECTION PROFILE ja 06/24/08 1 1 1L-20A 10215099 PRODUCTION PROFILE ~QCJ +~ 06/26/08 1 1 1 G-05 12080389 LDL - (p 06/27/08 1 1 3B-10 12061714 INJECTION PROFILE T - t / '- 06/27/08 1 1 2L-327 12061715 SBHP SURVEY 06/28/08 1 1 1J-109 12080390 SBHP SURVEY / ( 06/28/08 1 1 2N-323 12061716 SBHP SURVEY ~ 'fir-- ~ 06/28/08 1 1 2X-15 12080392 SBHP SURVEY G 06!29/08 1 1 2N-303 12061717 SBHP SURVEY 06/29/08 1 1 2L-309 12061718 SBHP SURVEY / 06!29/08 1 i 2X-14 12080391 SBHP SURVEY / 06/29/08 1 1 2X-11 12080393 SBHP SURVEY ej- S~ 06/29/08 1 1 iG-09 12080401 INJECTION PROFILE V -- ( /(~ 07/05/08 1 1 2H-05 12080396 SBHP SURVEY ~° .~- 06/30/08 1 1 2H-12 12080395 SBHP SURVEY ~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY - / 06/30/08 1 1 1D-07 12080398 SBHP SURVEY - .( 07/02/08 1 1 2N-341 12061720 SBHP SURVEY ~ / 06/30/08 1 1 3C-15 11982441 USIT - (5C~ / (0 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE `6 - (p 07/08/08 1 1 1 L-19 12061724 PRODUCTION PROFILE ~ p -b 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ~ 07/09/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~ rte! 1 • • .....~, ~~~...~'~A..._::" ":., - \". ,:..., . ..\ 1 - ~ ..\ -l~-" MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc Permit to Drill No. 2000360 DATA SUBMITTAL COMPLIANCE REPORT 9~6~2002 Well Name/No. KUPARUK RIV UNIT 1L-20A Operator PHILLIPS ALASKA INC. MD 10934 TVD 6327 Completion Dat 6~6~2000 ~' Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22027-01-00 UIC N REQUIRED INFORMATION Mud Log N_9o Sample N._9o Directional Survey N__9o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Media Digital Name (data taken from Logs Portion of Master Well Data Maint) Log Log Scale Media Run No Interval Start Stop OH I Dataset CH Received Number Comments 9577 SRVY RPT DGR/EWR-TVD DGR/EWR-MD SRVY CALC SRVY RPT CBL-PSP MWD Survey 2/5 2/5 FINAL FINAL FINAL FINAL 6139 6177 3715 6191 6508 6147 10200 10871 10935 6280 10935 10935 10935 10811 OH 8/1/2000 Open 8/1/2000 OH 8/1/2000 OH 8/15/2000 OH 8/15/2000 OH 8/31/2000 OH 5/16/2000 CH 6/13/20O0 OH 6/14/2001 9577 SPERRY MPT/GR/EWR4 09577.,-'~139-10871 SPERRY 6177.50-10935.35 3715-6280 6191-10935 BHI 6508-10935.30 3/27/00 THRU SPERRY 6147-10935. BL(C) 10200-10811 MWD Survey, Digital Data Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y'~)~ Chips Received? Analysis R ¢.c.¢.iv~.d ? Daily History Received? Formation Tops Comments: Permit to Drill No. 2000360 DATA SUBMITTAL COMPLIANCE REPORT 9~6~2002 Well Name/No. KUPARUK RIV UNIT IL-20A Operator PHILLIPS ALASKA INC. APl No. 50-029-22027-01-00 MD 10934 TVD 6327 Completion Dat 6/6/2000 Completion Statu 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 5173' FNL, 5062' FEL, Sec. 29, T11 N, R10E, UM At top of productive interval 215' FNL, 2382' FEL, Sec. 33, T11 N, R10E, UM At effective depth At total depth 258' FNL, 2262' FEL, Sec. 33, T11N, R10E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ (asp's 540278, 5949075) (asp's 548239, 5948803) (asp's 548359, 5948757) 10934 feet Plugs (measured) 6325 feet Perforate _ Other _ 6. Datum elevation (DF or KB feet) RKB 122 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 L-20A 9. Permit number / approval number 200-036 / 10. APl number 50-029-22027-01 11. Field / Pool Kuparuk Oil Pool CIBP set @ 6210' EffeCtive depth: measured true vertical Casing Length CONDUCTOR 115' SURF CASING 6000' PROD CASING 6210' PROD CASING 4894' PROD CASING 612' 10835 feet Junk (measured) 6233 feet Size Cemented 16" 245 sx AS 1 9-5/8" 1400 sx AS III & 600 sx Class G 7" 300 sx Class G 260 sx Cl. G Lead, 260 sx Cl. G 5-1/2" Tail 3-1/2" 70 sx Class G Measured Depth 115' 6000' 6210' 10491' 10934' True vertical Depth 115' 3683' 3774' 5912' 6325' Perforation depth: measured 10742'-10782',10695'-10705',10574'-10604' true vertical 6145'-6182', 6101'-6111', 5988'-6016' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 10316' MD. Packers & SSSV (type & measured depth) BAKER SABL-3 LINER PACKER @ 10322' MD. CAMCO DS @ 531' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attachment Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 330 Representative Daily Average Production or Iniection Data Gas-Mcr Water-Bbl 1230 550 433 586 1444 Casing Pressure Tubing Pressure - 176 594 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Gas _ Suspended __ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .... Title: Wells Team Leader Michael Moone)/ Form 10-404 Rev 06/15/88 · ORIGii1AL Questions? Call Mike Mooney 263-4574 Date Prepared b~Sharon Al/sup-Drake 263-4612 SUBMIT IN DUPLICATE Date Comment 1 L-20A Event History 01/21/02 01/28/02 01/29/02 01/30/02 01/31/02 DRIFT TBG W/3'X 1.875" WT BAR+2.66" SWAGE, TAGGED FILL W/NO PROBLEMS @ 10796' RKB, EST 34' RAT HOLE. COMPLETE [TAG] LOGGED CEMENT QUALITY W/SCMT-BB, TAGGED TD @ 10788', LOGGED TD TO ABOVE JEWELRY AND REPEAT PASS, FOUND GOOD QUALITY CEMENT BETWEEN A & C SANDS AND UP TO LINER TOP./POOH, RDMO, LEFT WELL SI. PULLED DV @ 10268' RKB. SET 2.81" A-2 PLUG @ 10308' RKB. IN PROGRESS. [GLV, OPEN-CLOSE A SAND] REPLACE OV W/DV @ 3598' WE. LOAD CSG W/172 BBL SW & 40 BBL DSL CAP. TESTED CSG 3500 PSI, GOOD. IN PROGRESS. PULLED 2.81" A-2 PLUG @ 10308' RKB. PULLED/SET DV @ 3598' RKB; PUMPED 20 BBL DSL INTO IA. TESTED CSG 3500 PSI, GOOD. [PT TBG-CSG] 02/11/02 02/12/02 02/21/02 02/22/02 02/27/02 02/28~02 03/01/02 O3/O7/O2 O3/O8/O2 O3/O9/O2 COMPLETED PUMPING FULL BORE SAND PLUG FOR UPCOMING FRAC. PLACED APP: 800# OF 20/40 SILICA SAND. EST SAND TOP TO BE @ 10635', FULLY COVERING THE A SANDS. TAGGED SAND @ 10,684' RKB [TAG] PUMP FRAC USING 30# LG X-LINKED FLUID @ 20 BPM. PUMP 104,209 LBS OF 16/20 CERAMIC PROPPANT. PRESSURE INCREASED SLOWLY THROUGHOUT JOB FROM 4200 PSI TO 5800 PSI, THEN HAD NWBSO WITH 7.7 PPA ON PERFS, AND 78,898 LBS OF PROPPANT BEHIND PIPE. LEFT 25,311 LB OF PROPPANT IN WELLBORE. PERFORMED A FCC TO 10,807.6 ' CTMD. RETURNS 1-1 ALL DAY. WELL FREEZE PROTECTED TO 4000'. LEFT WELL SHUT IN FOR WIRELINE PREP WORK. [FCC] TAGGED FILL @ 8320' WLM, PULLED 1" DV @ 3598' RKB [GLV] PULLED DV @ 3598' RKB, SET GLV 1/8" PORT/1280 TRO @ 3598' RKB, SET GLV 5/32" PORT/1310 TRO @ 6465' RKB, JOB IN PROGRESS [GLV] BAILED CARBOLITE FROM 8336' TO 8345' WLM. [GLV] CLEANED FILL TO 10,800' CTM W/2" JET-SWIRL NOZZLE USING SEAWATER J313 & 1-1/2# BIOZAN (EST. 40' OF RATHOLE). WASH PASSES MADE ACROSS GLM'S ON WAY CCH. WELL SHUT IN AND FREEZE PROT'D TO 2500'. TAGGED CARBOLITE @ 10,594' RKB, EST. 188' FILL. PULLED DV @ 10,268' RKB. IN PROGRESS. [TAG, GLV] ATTEMPTED PULL DVS. IN PROGRESS. [GLV] 03/10/02 03/11/02 REPLACED DV W/GLV @ 9779' RKB & SET OV @ 10,268' RKB. IN PROGRESS. [GLV] REPLACED DV W/GLV @ 8652' RKB. [GLV] Page 1 of I 3/15/2002 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 March 18, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1L-20A (200-036) Dear Commissioner Oechsli Taylor: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent frac operations on the KRU well 1L-20A. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad 02/19/02 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1820 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 Sepia CD Color 3H-15 INJECTION PROFILE 02/01/02 I 1 1D-140 22066 RST-SIG MA 01/06/02 I 1 1 1 L-20A 22054 SCMT 01/28/02 1 1 C-24 22055 USIT 01/20/02 1 1C-24 22055 SSLT 01/20/02 1 2P-415 21488 BEST DT-SONIC PROCESSING 11/24/01 1 2P-415 21488 ELAN GLOBAL SOLVER (TVD) 11/24/01 1 2P-415 21488 FRACADE ADVISOR MECH PROPERTIES (TVD) 11/24/01 1 2P-417 21243 ELAN ELEMENTAL ANALYSIS 05/12/01 1 2P-417 21243 FRACADE ADVISOR MECH PROPERTIES 05/12/01 I DATE: RECEIVED FEB 19 2002 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. AL_~Oii&GasC0ns. C. anatlis~n STATE OF ALASKA ALAbr~~, OIL AND GAS CONSERVATION COMM,oSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification ol Service Well Oil [~] Gas D Suspended D Abandoned D Service r-1 2. Name of Operator ~ ..~'ll~i, 7. Permit Number Phillips Alaska, Inc. ~", 200-036 3. Address ~ ~,,.~~, ~. APl Number 4. Locationolwellatsudace ~-'" ' ~' 9. Unit or Lease Name 104' FSL, 216' FWL, Sec. 29, T11N, R10E, UM (ASP:540278,5949075) "' . " Kuparuk River Unit At Top Producing Inte~al .~ ~ ../~'.;~. ~ 10. Well Number 215' FNL, 2382' FEL, Sec. 33, T11N, R10E, UM (ASP:548239, 5948803) 1L-20A ~t lotal ~opth ~.~ ' 11. Fio}0 and ~ool 2~1' F~k, ~7' F[k, Soc. ~, T11 ~, ~10fi, ~M {~S~: $48~$$, $~48758) 5. filovation in ~oo~ (indicato KB, DF, otc.) I~. koaso Dasi~nation an0 S~dal ~o. Kuparuk ~ivor ~ool ~KB 30' IeaII ADk 2~0 & 25~$~ ~kK 470 ~2. Dalo Spudded la. Dalo I.D. ~oach~d 14. Dato Go~¢.~ ~usp. O[ ~and. ~5. Water Doplh, i~ o~shom ~. ~o. o~ Complations 26, 2000 April 8, 2000~~- --~~dO~I N/A feet MSL 1 March 1~. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Suwey ~20. Depth where SSSV set 21. Thic~e~ of Permafrost 10934' MD /6327' ~D 10835' MD /6233' ~D YES ~ No ~~ N/A feet MD 1500' (approx.) 22. T~e Electric or Other Logs RUn G~Res/Den/Neu, CBL, CCL 23. CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. G~DE TOP BOSOM HOLE SIZE CEME~ING RECORD~ AMOUNT PULLED 16" 62.5~ H-40 Surfa~ 115' 24" 245 sx AS I 9.625" 36~ J-55 Surfa~ 6000' 12-1/4" 1400 sx AS III & 600 sx Class G 7" 26~ J-55 Surfa~ 10938' 8.5" 300 sx Cla~ G 5.5" 15.5~ L-80 6047' 10941' 7" 260 sx Cla~ G Lead, 260 sx Class G tail 3.5" 9.3~ L-80 103~' 10934' 5.25"x4.75" 70 sx Cla~ G 24. Pedorations open to Produ~ion (MD + TVD ol Top and BoSom and 25. TUBING RECORD intewal, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 10316' 103~' 10742'-10782' MD 6145'-6135' ~D 4 spf 10695'-10705' MD 6101'-6111' ~D 4 spf 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. 10574'-10604' MD 5988'-6016' ~D 6 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10742'- 10782' ~umped 153000~ behind pipe (14400~ 1 ~18) 10695'-10705' w~h 9.6 ppa at lo~ation 27. PRODUCTION TEST Date First Production ~Method of Operation (Flowing, gas li~, etc.) August 12, 2000 Flowing Date of Test Houm Tested Production for OIL-BBL ~S-MCF WATE R-BBL CHOKE SIZE ~ ~S-OIL RATIO 8/21/2000 17.5 hfs Test Pedod > 819 1515 1165 176J 1850 Flow Tubing Casing Pressure Calculated OIL-BBL ~S-MCF WATER-BBL OIL GRAVITY - APl (co~) pre~. 207 psi 648 24-Hour Rate > 1122 2075 1596 not avail~le 28. CORE DATA Brief de~dption of litholo~, porosi~, fractures, ~parent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1o80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKER~ NAME Top Kuparuk C Top Kuparuk A MEAS. DEPTH TRUE VERT. DEPTH 10573' 10731' 5987' 6135' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF A-I-rACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Title Dd I n,q En.qineerin.q Supervisor Questions? Call Bill Lloyd 265-6531 Date INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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, Item 28: If no cores taken, indicate "none". Form 10-407 Date: 06/21/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iL-20A STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUP.~RUK RIVER UNIT SPUD:03/23/00 START COMP: RiG:NABORS 16E WI: 0% SECURITY:0 API NUMBER: 50-029-22027-01 BLOCK: FINAL: 03/22/00 (Df) TD/TVD: 0/0 SUPV:G~R. WHITLOCK 03/23/00 (D2) TD/TVD: 0/0 SUPV:G.R. WHITLOCK 03/24/00 (D3) TD/TVD: 0/0 SUPV:G.R. ?~ITLOCK 03/25/00 (D4) TD/TVD: 0/0 SUPV:G.R. WHITLOCK MW: 0.0 VISC: 0) N/U BOPE 0 PV/YP: 0/ 0 APIWL: 0.0 Move modules off well and pick up mats and berms. Clean up herculite and cellar. Spot modules over well and set mats. Hook up support lines and build berms for cellar. Hook up e!ec lines and insulate breezeways. ~: 0.0 VISC: 0 PV/Y~: 0/ 0 0) RIH W/ DU~IMY MILL ASSEMBLY APIWL: 0.0 N/D tree. Install new tubing spool and test to 3000 psi,Ok. NU BOPE and set test plug' and test BOPE to 250/3500 psi. Test casing to 3500 psi, 0K~ R/U e-line and run CCL tag @ 6231'. RIH with dummy mill assembly. Tag obstruction $ 237' ~ Attempt to rotate past obstruction w/o success. L/D assembly. Top mill showed slight wear, Top mill @ 224'. Run caliper 350' to surface. Obstructicn noted at 224'. M/U 7" casing scraper. MW: 8.6 VISC~ 124 PV/YP: 22/58 0) P/U WHIPSTOCK APIWL: 7.8 Run scraper through restriction @ 237' w/no problems. M/U dummy milling assembly and clean out restriction @ 237' w/no problems. RIH w/mills. Hit hard spot at 530'. Packed off. Worked pipe and established circ. RIH to 6230'. Circ hi-vis sweep. Pump dry job. POOH. RIH w/Baker model "N" CIBP. Set plug at 6210'. Setting tool would not release. RIH with overshot and fishing jars. MW: 8.6 VISC' 71 PV/YP: 18/38 0) RIH W/ DRILLING ASSEMBLY APIWL: 6.8 RIH. Latch onto fish. Jar setting' tool off of CIBP. POOH. L/D fish and overshot. RIH w/whipstock. Set whipstock. Displace brine w/mud. Mill window +20' hole. Perform FIT to 13.5 ppg. POOH 2 stands. Not taking proper fill. Break circ to clean metal shavings off of pipe. POOH. Date: 06/21/00 ARCO ALASKA INC. WELL SUMMLARY REPORT Page: 2 03/26/00 (D5) MW: 8.8 VISC: 51 PV/YP: 14/26 APIWL: 6.4 TD/TVD: 6574/3934 (6574) DRILLING 8 6675' SUPV:G.R. WHITLOCK Breakdown mill assembly. Work through window w/no problems. Drill from 6222' to 6574' 03/27/00 (D6) MW: 9.0 VISC: 49 PV/YP: 14/24 TD/TVD: 7535/4304 ( 961) DRILLING ~ 7890' SUPV:G.R. WHITLOCK APIWL: 5.8 Drill from 6574' to 6633' Hole tried to pack off. Reestablished circulation and circ hole clean. Drill from 6633' to 6665'. Circ barafibre sweep. Drill from 6665' to 6737'. Circ hole clean. POOH to window. RIH w/no problems. Drill from 6737' to 7535' 03/28/00 (D7) MW: 9.0 VISC: 47 PV/YP: 12/23 APIWL: 6.2 TD/TVD: 8410/4657 (875) DRILLING 8 8710' SUPV:G.R. WHITLOCK Drill from 7535' to 8394'. Pump sweep, circ hole clean. POOH to 6100' w/no problems. RIH, no problems. Wash 90' to bottom. Drill from 8394' to 8410' 03/29/00 (D8) MW: 9.0 VISC: 43 PV/YP: 14/15 APIWL: 6.0 TD/TVD: 9305/4935 ( 895) DRILLING ~ 9468' SUPV:G.R. WHITLOCK Drill from 8410' to 9111'. Lost partial returns. Circ LCM around and regained full returns. Drill from 9111' to 9305' 03/30/00 (D9) MW: 9.1 VISC: 47 PV/YP: 14/20 TD/TVD: 9680/5272 ( 375) DRILLING @ 9900' SUPV:G.R. WHITLOCK APIWL: 5.8 Drill from 9305' to 9547'. Circ hi-vis unweighted sweep around followed by hi-vis weighted sweep. Monitor well. Pump out of hole to 8399'. Pump sweep, CBU. RIH, slow. wash 90' to bottom. Pump sweeps and lowered ECD. Drill from 9547' to 9680' 03/31/00 (D10) MW: 9.0 VISC: 47 PV/YP: 15/21 APIWL: 5.2 TD/TVD:10365/5805 ( 685) CIRC AND CONDITIONING MUD 8 10491' SUPV:G.R. WHITLOCK Drill from 9680' to 10365'. Circ hi-vis weighted sweep. 04/01/00 (Dll) TD/TVD:10491/5913 (126) SUPV:G.R. WHITLOCK MW: 9.6 VISC: 47 PV/YP: 18/20 APIWL: 5.0 Drill from 10365' to 10410'. Circ hi-vis weighted sweep around. Drill from 10410' to 1491'. Circ hi-vis weighted sweep around. Increase mud weight to 9.3 ppg. POOH wet to shoe. RIH. Break circ. Circ hi-vis weighted sweep around. Had gas on bottoms up. Increase MW to 9.6 ppg. Pump out of hole. - ,.:~, Date: 06/21/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 04/02/00 (D12) TD/TVD:10491/5913 SUPV:G.R. WHITLOCK MW: 9.6 VISC: 46 PV/YP: 17/21 0) P/U 5-1/2" LINER APIWL: 5.0 Pump out of hole. Monitor well at shoe. CBU. Monitor well. Pump out of hole. Hold safety meeting. Run 4 jts of 5.5" casing. Centralizers tight. POOH to remove centralizers and stop collars. Missing first centralizer and stop collar. Break jt and rack back first two its run. 04/03/00 (D13) TD/TVD:10491/5913 ( SUPV:G.R. WHITLOCK MW: 9.4 VISC: 43 PV/YP: 15/16 0) CIRC APIWL: 5.2 Unable to retrieve wearring. M/U wireline grab on stand of d.p. and fish centralizer and stopring out of wearring. M/U 109 jts 5.5" casing. CBU and reduce MW to 9.4 ppg. RIH with liner hanger to 6186'. Run liner on 4" d.p. Tight from 6441' to 6550'. RIH and tag at 10491'. Circ and condition mud. 04/04/00 (D14) TD/TVD:10491/5913 ( SUPV:FRED HERBERT MW: 11.7 VISC: 47 PV/YP: 21/18 0) P/U 2-7/8" DP. APIWL: 6.2 Circ and condition mud for cement job. PJSM. Pump cement. Did not bump plug. Set packer ~ 6047'. Circ out cement. POOH. Test BOPE to 250/5000 psi. 04/05/00 (D15) TD/TVD:10491/5913 SUPV:FRED HERBERT MW: 11.7 VISC: 54 PV/YP: 19/23 0) CIRC & COND FOR FIT APIWL: 6.2 Circ ~ 5339'. RIH to 10236' Test casing to 3500 psi. Circ out cont. mud. Drill landing collar, cement float collar and cement to 10465' Displace well w/ll.7 ppg mud. 04/06/00 (D16) TD/TVD:10597/6011 SUPV:FRED HERBERT MW: 12.0 VISC: 52 PV/YP: 29/25 106) DRILLING AHEAD APIWL: 3.4 Displace well w/ll.7 ppg mud. Drilling cement and float shoe to 10941' Drilling from 10491' to 10511'. Circ for FIT. Perform Fit to 14.1 EMT. Mud weight 11.7 ppg. Drilling from 10511' to 10569'. Circ out gas cut mud. Circ and raise weight to 12.0 ppg. Monitor well. Work pipe and circ bottoms up. Mud weight cut to 11.2 ppg on bottoms up. Drilling from 10569' to 10597' 04/07/00 (D17) TD/TVD:10870/6268 SUPV:FRED HERBERT MW: 12.0 VISC: 57 PV/YP: 29/38 273) CIRC & COND FOR WIPER TRIP APIWL: 3.4 Drilling from 10597' to 10663'. MWD tools quit working. Attempt to restart. Drilling from 10663' to 10719'. Circ bottoms up. Pump out to shoe, Monitor well, RIH to bottom. Circ bottoms up, gas cut mud to 11.5 ppg. Drilling from 10719' to 10870' ' - · Date: 06/21/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 04/08/00 (D18) MW: 12.3 VISC: 58 PV/YP: 33/33 TD/TVD:10935/6329 ( 65) RIG UP TO RUN LINER. SUPV:FRED HERBERT APIWL: 3.4 Drilling from 10870' to 10935'. Circ sweep around, raise mud weight to 12.3 ppg. Monitor well, pump out to shoe. Monitor well, static. RIH to bottom, no problems. Circ sweep around. Circ and cond mud for liner. POOH to run liner. Pump out to 6013'. Monitor well retrieve rabbit. Circ sweep around @ TO liner. Rig up belly rope for 2-7/8" DP. Drop rabbit. POOH. Rabbit would not fall w/wire on it. Pull out rabbit. Cont. POOH. 04/09/00 (D19) MW: 12.3 VISC: 54 PV/YP: 29/31 APIWL: 3.0 TD/TVD:10935/6329 ( 0) POOH L/D DP SUPV:FRED HERBERT POOH w/2-7/8" DP. PJSM. Run 3.5" liner. Rabbit DP. Continue to RIH w/liner. Circ and cond mud for cement job. 04/10/00 (D20) TD/TVD:10935/6329 SUPV:FRED HERBERT MW: 12.2 VISC: 51 PV/YP: 29/30 0) CIRC ~ TOP OF LINER APIWL: 4.4 Circ & cond mud for cement job. PJSM. Pump cement. Bump plug, check floats. Pressure up and set packer. Release from hanger. Continue to circ and clean up DP. Pump slug and POOH. Rig up to run tubing. PJSM. Run 3.5" completion assembly. 04/11/00 (D21) TD/TVD:10935/6329 SUPV:FRED HERBERT MW: 12.3 VISC: 52 PV/YP: 29/29 0) RUN COMPLETION ASSY. APIWL: 4.0 RIH w/3.5" tubing and completion assembly. Tag tight spot 6217' Work tubing down to 6277' POOH to top of liner and circ. Attempt to work tubing in 5.5" liner. POOH w/tubing. Test casing to 3500. OK. PJSM. Run 3.5" completion string. 04/12/00 (D22) TD/TVD:10935/6329 SUPV:FRED HERBERT MW: 8.6 VISC: 28 PV/YP: 1/ 0 0) RIG RELEASED @ 0300 HRS APIWL: 0.0 Run 3.5" tubing and completion assy. Circ bttms up ~ liner top. Run 3.5" tubing and assy. Latch into packer w/PBR. Shear out of same. Flush out pumps. Pump sweep. Freeze protect well w/diesel. Test tubing and annulus to 3500 psi/10 min OK. ND BOPE. NU tree and test to 5000. 04/13/00 (D23) TD/TVD:10935/6329 SUPV:FRED HERBERT MW: 0.0 VISC: 28 PV/YP: 0/ 0 0) RIG RELEASED ~ 0300 HRS APIWL: 0.0 Test tree to 5000. Secure well. Finish injecting and freeze protecting 1L-28. Rig released from 1L-20A @ 0300 hrs to move to 2T-204. · PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1L-20A(W4-6)) WELL JOB SCOPE JOB NU'MBER 1L-20A DRILLING SUPPORT-CAPITAL 0318001710.3 DATE DAILY WORK UNIT NUMBER 06/06/00 PERFORATE 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 11 YES YES SWS-ELMORE JOHNS FIELD AFC# CC# Signed ESTIMATE AK0051 230DS10LG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 260 PSI 260 PSI 0 PSII 0 PSI DALLY SUMMARY I PERF'D 10742'-10782', 10695'-10705'. I TIME LOG ENTRY 07:30 MIRU SWS 2128, ELMORE,TGSM, REBUILD WEAK POINT IN HEAD, AFTER MULTIPLE PERF RUNS ON 1 D-125. CONTINUE RU. 11:30 RIH W/SWIVEL, CCL, SAFE, 20' X 2.5" GUN-2.6" ROLLER STEM. 12:30 TIE IN TO SWS SCMT. LOG CORRELATION PASS. 12:50 LU TO SHOOT 10762'-10782'. POOH. 14:10 RIH W/GUN 2.20' 15:00 TIE IN AT JEWELRY. 15:10 LU TO SHOOT 10742'-10762'.POOH 16:25 17:15 RIH W/GUN 3, 10'. (ADDED 2.125" OD WT. BAR). TIE IN TO JEWELRY. 17:18 LU TO SHOOT 10695'-10705'. POOH. 18:00 AT SURFACE, RD. LEAVE EQUIP ON LOCATION. 19:00 RDMO Date 07/15/00 Well Na 1L-20A Service Type COILED TUBING Desc of Work CEMENT SQUEEZE Supervisor NEZATICKY Complet r~' Accident I-- Injury I-- Spill F Summary Upcoming F Job Num 0318001710.3 Unit UNIT #2 AFC AK0051 0 Prop 230DS10U Uploaded to SeP Contractor Key Perso Successful r~ Initial Tbg Press 700 Initial Int Csg Press 300 Initial Out Csg Press 0 DS-ROWELL Final Tbg Press 1700 Final Int Csg Press 500 Final Out Csg Press 0 SQUEEZED 30 BBL OF CEMENT INTO TOP PERFS. TOP OF CEMENT AT 10640 FT - 55 FT ABOVE TOP PERFS. FREEZE PROTECTED Fr, 4200 FT [Cement-Poly Squeeze] Date printed: 08/30/00 at: 08:41:33 PHILLIPS Alaska, Inc, KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1L-20A(W4-6)) WELL JOB SCOPE JOB NUMBER 1 L-20A FRACTURING. 0501001048.4 DATE DAILY WORK UNIT NUMBER 07/30/00 PERFORATE 2128 DAY OPERATION COMPLETE SUCCESSFUL 2 YES YES In,tialTbgPress IFinalTbgPress IlnitiallnnerAnn 800 PSI 800 PSI 0 PSI DAILY SUMMARY KEY PERSON SWS-ELMORE Final Inner Ann I 0 PSI I SUPERVISOR CHANEY Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI PERFORATED A5 SAND INTERVAL 10742'-10762' W/2-1/2" BH HSD, BIG HOLE CHGS, 4 JSPF, & 180 DEGREE PHASING. TIME 08:00 09:40 10:40 10:45 11:02 11:14 11:50 12:45 LOG ENTRY MIRU SWS 2128, ELMORE, TGSM, PT 3000#. RIH W/SWIVEL,CCL,SAFE, 2.5"X20', 4 SPF, 180 PHASED,BIG HOLE GUN, W/2.6" ROLLER STEM ON BOT. CHECK UP WEIGHT AT 10300', RIH TO 10400'. LOG TIE IN OVER JEWELRY, 10400'-10200', RIH. RECHECK TIE IN AT 10775'. LU TO SHOOT 10742'-10762'. POOH. AT SURFACE, RD. RDMO. PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1L-20A(W4-6)) WELL 1 L-20A JOB SCOPE FRACTURING. DATE DALLY WORK 08/02/00 FRACTURE TREATMENT OF 'A' SAND DAY OPERATION COMPLETE I SUCCESSFUL 4 YES I YES InitialTbgPress IFinalTbgPress IlnitiallnnerAnn 1200 PSI 1900 PSI 0 PSI DALLY SUMMARY KEY PERSON DS-YOAKUM JOB NUMBER 0501001048.4 UNIT NUMBER SUPERVISOR FERGUSON Final Inner Ann Initial Outer Ann I Final Outer Ann 0 PSI 0 PSII 0 PSI IPUMP BREAKDOWN AND SCOUR STAGES AT 30 BPM WITH GOOD BREAKBACK. PUMP 75 BBL DATAFRAC WITH 50# X/L GEL AND SD FOR ANALYSIS. PUMP PER DESIGN WITH 100 BBL PAD AND LENGTHEN 6 PPA FLAT STAGE FROM 400 TO 450 BBLS. GOOD TSO INITIATION EVIDENT AT 200 BBLS INTO 6 PPA FLAT STAGE. SCREENOUT 58 BLS INTO 90 BBL FLUSH AFTER GOOD TSO. PLACE 153000 #'S BEHIND PIPE. (144,00#'S 12/18) WITH 9.6 PPA AT FORMATION. LEFT 9048#'S IN PIPE.[ Frac- Refrac] TIME 07:30 09:00 09:30 09:55 10:55 11:15 12:30 13:45 14:30 LOG ENTRY ARRIVE LOCATION, DOWELL RU PUMP EQUIPMENT SAFETY MEETING PT LINES TO 9450 PSI PUMP 50# XL STAGES WITH SCOUR FOR BREAKDOWN AND PERFORM SDT FOR FRICTION CALCULATIONS. ISlP=2152 PSI, FG=0.8, XS FRICTION OF 302 PSI AT 16 BPM START DATAFRAC OF 75 BBLS 50# XL AT 15 BPM SD FOR DATAFRAC ANALYSIS. TC=14.5 MINUTES, EFF=68%, PNET=284 PSI. ELECT TO STAY WITH 100 BBL PAD AND LENGTHEN 6 PPA STAGE BY 50 BBLS. START FRAC. GET GOOD INDICATION OF TSO BEGINNING 200 BBLS INTO THE 450 BBL 6 PPA FLAT STAGE. GOOD PRESSURE BUILD THROUGHOUT STAGE GO LONG ON FINAL RAMP, STILL IN TSO MODE. SCREEN OUT 58 BBLS INTO 90 BBL FLUSH. TOTAL PROP PUMPED 153,000 #'S INCLUDING 20/40, PLACED 144,000 #'S OF 12/18 BEHIND PIPE WITH 9.6 PPA ON FORMATION OF 12/18. LEFT 9048 #'S IN PIPE. RDMO PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1L-20A(W4-6)) WELL 1 L-20A DATE 08/18/0O DAY 10 JOB SCOPE FRACTURING. DALLY WORK PERFORATE OPERATION COMPLETE I SUCCESSFUL YESI YES Initial Tbg Press I Final Tbg Press I Initial Inner Ann 900 PSII 950 PSII 1400 PSI DALLY SUMMARY KEY PERSON SWS-SPENCER Final Inner Ann J 1250 PSI I JOB NUMBER 0501001048.4 UNIT NUMBER 2145 SUPERVISOR GOBER Initial Outer Ann I Final Outer Ann 1100 PSII 1100 PSI PERFORATE 10574'-10604' RKB @ 6 SPF/60 DEG PHASING, 2.5" HSD ALTERNATING BIGHOLE/DEEP PENETRATING CHARGES. BH = 35B UP RDX. (LOAD = 10.5 GRAMS, PENE = 5.8" , ENTRANCE = .62")DP = POWER JET 2506. (LOAD = 10.5 GRAMS, PENE = 25.2", ENTRANCE = .32".[Perf] TIME LOG ENTRY 07:30 CALLED DSO FOR MIRU - ARRIVED 1L-20A - SAFETY MEETING 08:30 RIG UP COMPLETED - AWAITING ARRIVAL OF SPECIAL XOVER FOR ROLLERS 11:15 POWER DOWN UNIT, ARM GUN USING SAFE SYSTEM 11:30 PT TO 300 PSI 11:45 PT TO 3000 PSI 12:00 RIH WITH CCL - SAFE FIRING HEAD - 20 FT GUN - 2.6" ROLLERS (3 FEET LONG)TOTAL TOOLSTRING LENGHT = 32.5 FEETGUN LOADED 6 SPF ALTERNATING BIG HOLE AND POWER JET 13:15 AT 10650 FT, BEGIN LOGGING UP A TIE IN PASS FOR GUN #1. - CORRECTED +15 FEET TO THE SWS SCMT DATED MAY 11,2000. 13:30 AWAITING ARRIVAL OF DSO TO BLEED OFF WHP TO AVOID SHOOTING OVERBALANCED 14:00 PRESSURE BLED OFF BUT RISING RAPIDLY. ATTEMPT TO RIH WON'T FALL.ATTEMPT POOH - PULLING TIGHT, BUT EVENTUALLY FREED. PROBABLY FLOWED DEBRIS WHEN BLED OFF PRESSURE. 14:25 14:30 LOG UP TO SHOOT GUN #1. CCL DEPTH AT 10580.3 FT. CCL TO TS = 3.7 FEET. TOP SHOT AT 10584. BOTTOM SHOT = 10604 FT. GUN LOADED 20 FEET @ 6 SPF ALTERNATING BIG HOLE (35B UP RDX) AND DEEP PENETRATING (POWER JET 2506 HMX). INTERVAL=10584'-10604' RKB GOOD SURFACE INDICATION (WEIGHT DECREASE AND PRESSURE INCREASE) OF DETONATION - POOH - PULL WEIGHT INCREASE AT 1890' - RIH 200'- POOH W/NO PROBLEM 15:30 GUN #1 AT SURFACE - CONFIRMED ALL SHOTS FIRED 16:00 RIH WITH GUN #2 16:15 AT 1890 FT, HITTING SOMETHING - TOOL WON'T FALL - PICK UP IS 400 LBS OVER, CALLED WELL SUPERVISOR FOR PUMPING OPTIONS. TIME 17:50 18i05 18:10 18:25 18:40 19:25 19:30 19:50 20:00 20:30 20:45 21:45 LOG ENTRY APC PUMPING CREW MIRU - SAFETY MEETING PT PUMP LINES TO 3500 PSI BEGIN PUMPING AT 2 BPM @ 1600 PSI - LIMITING TO 2500 PSI. PUMPED 4 BBLS METHANOL FOLLOWED BY 14 BBLS DIESEL. PUTS ABOUT 1.5 BBLS PAST STICKY POINT. SHUT DOWN PUMPS. LAST RATE WAS .7 BPM AT 2500 PSI. 1ST ATTEMPT SINCE PUMPING TO RIH PAST 1900- SUCCESSFUL! AT 10200 FT, LOG DOWN COUNTING COLLARS. LOG A TIE IN PASS FOR GUN #2 - 10 FOOTER @ 6 SPF. CHARGES: 35B UP RDX (BIGHOLE) ALTERNATING WITH POWER JET 2506 (DEEP PENETRATING), LOG INTO POSITION TO SHOOT GUN #2 - CCL DEPTH = 10570.3 FT. CCL TO TOP SHOT = 3.7 FEET. INTERVAL = 10574 - 10584 FT RKB. GOOD INDICATION AT SURFACE OF DETONATION AT 500 FEET, RDMO APC PUMPING AT SURFACE - CONFIRMED ALL SHOTS FIRED - BEGIN RIG DOWN CALLED DSO - LEFT PAD ---- '-" SURVEY CALCULATION AND FIELD ...________WORKSHEET Job No. 0450-00019 Sidetrack No. IPageI of 6 i ~J~I,I~,E~, i1~1 Company ARCO ALASKA. lNG. Rig Contractor & No. NABORS- 16E Field KUPARUK RIVER UNIT Well Name & No. PAD 1L/20A Survey Section Name SPERRY MWD BHI Rep. R. BARNARD i ~r~{~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S 104.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SS~: Target Description Target Coord. E/W Slot Coord. E/W 216.00 Magn. Declination 26.560 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m0 10m[-] Vert. Sec. Azim. 102.20 Magn. to Map Corr. 26.560 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) . (FT) (FT) (FT) (Per 100 IT) Drop (-) Left (-) MWD 6508.00 63.61 80.66 3906.23 4506.91 466.71 4711.10 TIE IN POINT 27-MAR-00 MWD 6703.81 66.73 85.67 195.81 3988.49 4674.01 487.75 4887.46 2.82 1.59 2.56 6-3/4" MIXL 1.6 DEG AKO, BICEN ~ 27- MAR-00 MWD 6735.11 66.81 90.98 31.30 4000.84 4701.92 488.59 4916.20 15.59 0.26 16.96 27-MAR-00 MWD 6767.23 66.73 96.34 32.12 4013.52 4731.09 486.71 4945.64 15.34 -0.25 16.69 27-MAR-00 MWD 6800.34 66.93 94.50 33.11 4026.55 4761.31 483.84 4975.94 5.14 0.60 -5.56 27-MAR-00 MWD 6831.51 67.32 96.04 31.17 4038.66 4789.82 481.20 5004.53 4.72 1.25 4.94 27-MAR-00 MWD 6862.75 67.01 97.28 31.24 4050.79 4818.48 477.86 5033.13 3.79 -0.99 3.97 ,, , 27-MAR-00 MWD 6896.34 67.14 98.82 33.59 4063.87 4849.33 473.53 5063.76 4.24 0.39 4.58 27-MAR-00 MWD 6927.71 67.12 102.31 31.37 4076.07 4878.22 468.23 5092.17 10.25 -0.06 11.1 3 27-MAR-C0 MWD 6956.17 66.60 105.27 28.46 4087.25 4904.38 461.99 5117.58 9.74 -1.83 10.40 27-MAR-00 MWD 6989.62 66.17 108.37 33.45 4100.66 4934.92 453.13 5146.92 8.59 -1.29 9.27 27-MAR-00 MWD 7022.07 66.13 109.78 32.45 4113.78 4964.39 443.43 5174.96 3.98 -0.12 4.35 27-MAR-00 MWD 7052.28 66.23 110.78 30.21 4125.98 4991.75 433.85 5200.89 3.05 0.33 3.31 ~,...__ 27-MAR-00 M.WD 7086.08 66.98 109.71 33.80 4139.40 5022.46 423.12 5229.99 3.66 2.22 -3.17 ~ 27-MAR-00 MWD 7116.05 66.73 110.79 29.97 4151.18 5049.75 413.58 5255.85 3.42 -0.83 3.60 ' 27-MAR-00 I~IWD 7147.33 67.07 110.68 31.28 4163.45 5078.20 403.39 5282.75 1.13 1.09 -0.35 27-MAR-00 MWD 7180.71 67.81 110.13 33.38 4176.26 5108.71 392.65 5311.65 2.69 2.22 -1.65 27-MAR-00 MWD 7212.59 68.30 109.94 31.88 4188.17 5138.00 382.51 5339.43 1.63 1.54 -0.60 27-MAR-00 MWD 7244.33 69.67 109.61 31.74 4199.56 5167.38 372.49 5367.31 4.42 4.32 -1.04 . 27-MAR-00 MWD 7278.06 70.54 109,15 33.73 4211,03 5198,84 361,97 5397,23 2,88 2,58 -1,36 :, ~ . ~ '~. -~ ;,. , .... 27-MAR-C0 MWD 7310,00 70.35 108.61 31.94 4221.72 5228,74 352.23 5425.70 1,70 -0,59 -1,69 ~ -'.. ~., ¥~ ;.; ~ .'.'.-. ~..... 27-MAR-00 MWD 7341.35 70.1.7 -109.42 31.35 4232.31 5258.03 342.61 5453.60 2.50 -0.57 2.56 ::.~.:;!i.i .i' ~i.~.: .:.i.~ '...~..::'.":i!~ i?~- ,. 27-MAR-O0 ' MWD 7371.40 69.88 108.91 30.05 4242.58 5286.07 333.34 5480.28 1.86 -0.97 -1.70 ~':'~:!': :;:~ i :i. : · . 27-MAR-O0 ' MWD 7403.59 67.78 ' 108.83 32.19 4254.20 5315.88 323.63 5508.68 6.53 -6.52 -0.25 SURrVE ' tdr CALCULATION AND FIELD WORKSHEET Jo .o. No. ', Page I:Ll[~"-1::3r~..-I Company ARCOA~INC. Rig Contractor & No. NABORS-16E Field KUPARUK RIVER UNIT / Well Name & No. PAD 11-/20A Survey Section Name SPERRY MWD BHI Rep. R, BARNARD J~~ WELL DATA Target TVD (F-r) Target Coord. N/S Slot Coord. N/S 104,00 Grid Correction 0,000 Depths Measured From: RKB ~ MSL ~ SS~ Target Description Target Coord, E/W Slot Coord, E/W 216,00 Magn, Declination 26,560 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buitd\Walk\DL per: 100ft[~ 30m0 10m~ Vert. Sec, Azim, 102,20 Magn, to Map Corr. 26,560 Map North to: OTHER SURVEY DATA Survey Survey Incl, Hole Course' Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) , (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 27-MAR-00 MWD 7435,35 67,95 108.27 ~31.76 4266,17 5345,12 314,28 5536.57 1,72 0.54 -1,76 28-MAR-00 MWD 7469.08 67,94 108.61 33.73 4278,84 5376,20 304,39 5566.23 0,93 -0,03 1,01 28-MAR-00 MWD 7501,36 67,77 108,32 32,28 4291,00 5405,92 294,92 5594,59 0,98 -0.53 -0,90 28-MAR-00 MWD 7535.29 67,63 108,16 33.93 4303,88 5437,13 285,09 5624,40 0,60 -0,41 -0,47 28-MAR-00 MWD 7563,92 67,78 107,74 28,63 4314,74 5463,49 276,93 5649,60 1,45 0,52 -1,47 28-MAR-00 MWD 7596,54 68.19 106,98 32.62 4326,97 5493.61 267.90 5678,47 2,50 1,26 -2,33 28-MAR-00 MWD 7627,55 68,10 106,82 31.01 4338,51 5522,29 259,54 5706,01 0,56 -0,29 -0,52 28-MAR-00 MWD 7661,35 68.26 107,16 33,80 4351,07 5553,56 250,37 5736,02 1,05 0.47 1,01 28-MAR-00 MWD 7693,59 68,45 107,75 32,24 4362,97 5583,40 241,38 5764,60 1,80 0,59 1,83 28-MAR-00 MWD 7725,43 68,16 106,82 31.84 4374,74 5612,87 232,59 5792,85 2,86 -0.91 -2,92 28-MAR-00 MWD 7756,63 68,03 106,76 31.20 4386,38 5641,73 224,23 5820,56 0,45 -0.42 -0,19 28-MAR-00 MWD 7788,83 67,64 106,60 32,20 4398,52 5671,46 215,67 5849,13 1,30 -1.21 -0,50 28-MAR-00 MWD 7820,45 66,40 107,18 31,62 4410,87 5700.47 207,21 5876,98 4,27 -3.92 1,83 -- 28-MAR-00 MWD 7854.11 66.47 106,57 33,66 4424.33 5731.22 198.26 5906.51 1.67 0.21 -1.81 28-MAR-00 MWD 7886.54 66.68 106.42 32.43 4437.22 5760,89 189.81 5935.04 0.77 0.65 -0.46 28-MAR-00 MWD 7916.00 65.98 107.63 29.46 4449,05 5787.78 181,91 5960,84 4.45 -2.38 4.11 28-MAR-00 MWD 7947.36 66.14 107.32 31.36 4461.77 5816.32 173.30 5988.18 1.04 0.51 -0,99 28-MAR-00 MWD 7981.38 65.97 108,27 34,02 4475,58 5847.26 163,80 6017.78 2,60 -0,50 2.79 28-MAR-00 MWD 8012,45 65.73 108.10 31.07 4488,29 5875,46 154.95 6044.72 0.92 -0.77 -0,55 ' : ' ~: ~i ': 28-MAR-00 MWD 8043,24 65.70 106.77 30.79 4500,96 5903,41 146,54 6071,49 3,94 -0,10 -4.32 28-MAR-O0 MWD 8075,59 65.80 106.97 32.35 4514.24 5932.80 137,98 6099.72 0,64 0,31 0.62 ~: ! ...~- ": ~: : -- .... , .. ..:T ;;'~ : ~ 28-MAR-00 MWD 8107,00 65,82 106,18 31.41 4527,11 5961,37 129.81 6127.18 2,30 0,06 -2,52 28-MAR-O0 MWD 8139.79 65.95 105.42 32.79 4540,51 5991.24 121,66 6155.98 2,15 0,40 -2.32 28-MAR-O0 MWD 8171,81 66,13 103,70 32.02 4553,51 . 6020,48 114,31 61 64,30 4,94 0.58 -5,37 II Na e rvey BHI Rep R BA . , . j~ll~~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S 104.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO ssr~ Target Description Target Coord. E/W Slot Coord. E/W 216.00 Magn. Declination 26.560 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft[~ 30m~ lOm[~ Vert. Sec. Azim. 102.20 Magn. to Map Corr. 26.560 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (FT) . (FT) (FT) (FT) (Per 100 ~ Drop (-) Left (-) 28-MAR-O0 MWD 8203.40 66.04 103.98 3~.59 4566.32 6049.34 107.40 6212.34 0.86 -0.28 0.89 28-MAR-O0 MWD 8236.05 66.30 103.48 32.65 4579.51 6079.20 100.31 6241.35 1.61 0.80 -1.53 28-MAR-O0 MWD 8268.33 66.29 103.03 32.28 4592.49 6108.75 93.53 6270.12 1.28 -0.03 -1.39 28-MAR-O0 MWD 8294.80 66.51 101.93 26.47 4603.09 6133.00 88.29 6293.80 3.90 0.83 -4.16 29-MAR-O0 MWD 8331.76 66.93 102.44 36.96 4617.69 6166.95 81.12 6326.99 1.70 1.1 4 1.38 29-MAR-O0 MWD 8363.27 66.44 102.40 31.51 4630.16 6195.89 74.90 6355.25 1.56 -1.56 -0.13 ,. 29-MAR-O0 MWD 8395.14 66.54 101.46 31.87 4642.88 6225.11 68.86 6383.84 2.72 0.31 -2.95 29-MAR-O0 MWD 8428.14 66.39 102.02 33.00 4656.06 6255.37 62.70 6413.46 1.62 -0.45 1.70 29-MAR-O0 MWD 8459.87 66.04 101.71 31.73 4668.85 6284.40 56.73 6441.88 1.42 -1.10 -0.98 29-MAR-O0 MWD 8491.10 65.53 101.57 31.23 4681.66 6312.88 50.99 6469.77 1.68 -1.63 -0.45 29-MAR-O0 MWD 8523.62 65.25 103.13 32.52 4695.20 6342.45 44.66 6498.65 4.45 -0.86 4.80 29-MAR-O0 MWD 8555.52 65.01 103.33 31.90 4708.62 6371.38 38.04 6526.83 0.94 -0.75 0.63 29-MAR-O0 MWD 8586.64 64.44 103.88 31.12 4721.91 6399.52 31.42 6554.18 2.43 -1.83 1.77 29-MAR-O0 M.VVD 8619.43 64.11 104.29 32.79 4736.14 6429.04 24.23 6582.83 1.51 -1.01 1.25 .. 29-MAR-O0 MWD 8651.70 63.70 104.58 32.27 4750.33 6458.00 17.01 6610.89 1.51 -1.27 0.90 29-MAR-O0 ~WD 8681.74 63.88 104.22 30.04 4763.60 6484.93 10.31 6637.00 1.23 0.60 -1.20 29-MAR-O0 MWD 8715.76 64.92 105.58 34.02 4778.30 6515.57 2.42 6666.65 4.73 3.06 4.00 29-MAR-O0 MWD 8747.38 66.06 105.60 31.62 4791.42 6544.29 -5.32 6694.36 3.61 3.61 0.06 29-MAR-O0 MWD 8779.22 67.45 105.14 31,84 4803.98 6573.50 -13,07 6722.57 4.56 4.37 -1.44 ' ~ .... '- ~ ~': ..... 29-MAR-O0 MWD 8812.21 67.92 104.81 32.99 4816.51 6603.99 -20.95 6752.05 1.70 1.42 -1.00 29-MAR-O0 MWD 8843.67 67.60 1 04.86 31.46 4828.42 66,33.08 -28.41 6780.20 1.03 -1.02 0.16 29-MAR-O0 MWD 8874.81 67.38 103.47 31.14 4840.34 6661.83 -35.45 6808.09 4.18 -0.71 -4.46 29-MAR-O0 MWD 8907,60 66.65 103,11 32,79 4853,15 6692.01 -42,39 6837.47 2.44 -2,23 -1.10 29-MAR-O0 MWD 8939.46 65.69 103.69 31.86 4866.02 6721.15 -49.14 6865.82 3.44 -3.01 1.82 ~ & No. PAD 1L/2OA Rig Survey Section Name SPERRY MWD BHI Rep. R. BARNARD ii WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S 104.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SSD Target Description Target Coord. E/W Slot Coord. E/W 216.00 Magn. Declination 26.560 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: 100ft~ 30mQ lOmr-] Vert. Sec. Azim. 102.20 Magn. to Map Corr. 26.560 Map North to: OTHER SURVEY DATA Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) , (FT) (F-r) (FT) (Per lO0 FT Drop (-) Left (-) 29-MAR-00 MWD 8970.73 64.73 102.91 3~.27 4879.13 6749.53 -55.67 6893.44 3.81 -3.07 -2.49 29-MAR-00 MWD 9003.45 64.61 102,68 32.72 4893,13 6779.10 -62.22 6922.28 0.73 -0.37 -0.70 29-MAR-00 MWD 9035.36 64.15 102.86 31.91 4906.92 6807.87 -68.58 6950.35 1.53 -1.44 0.56 _>9-MAR-O0 MWD 9066.43 63.71 102.27 31.07 4920.58 6835.78 -74.66 6977.59 2.22 -1.42 -1.90 29-MAR-O0 MWD 9099.42 63.35 101.06 32.99 4935.28 6865.31 -80.63 7006.51 3.46 -1.09 -3.67 29-MAR-00 MWD 9131.34 62.51 100.34 31.92 4949.81 6893.72 -85.90 7034.43 3.31 -2.63 -2.26 29-MAR-O0 MWD 9163.08 61.50 100.84 31.74 4964.71 6921.74 -91.05 7061.98 3.47 -3.18 1.58 29-MAR-00 MWD 9195.73 60.36 101.40 32.65 4980.57 6950.27 -96.56 7089.98 3.80 -3.49 1.72 29-MAR-00 MWD 9228.28 58.90 102.29 32.55 4997.03 6978.35 -102.32 7117.47 5.07 -4.49 2.73 29-MAR-00 MWD 9260.32 57.52 101.91 32.04 5013.91 7005.58 -108.03 7144.10 4.42 -4.31 -1.19 29-MAR-00 MWD 9292.48 56.35 102.26 32.16 5031.45 7032.53 -113.67 7170.45 3.75 -3.64 1.09 29-MAR-00 MWD 9324.49 55.91 101.58 32.01 5049.29 7059.11 -119.16 7196.45 2.24 -1.37 -2.12 30-MAR-00 MWD 9355.75 55.67 101.38 31.26 5066.87 7084.96 -124.31 7221.79 0.93 -0.77 -0.64 30-MAR-00 MWD 9388.60 55.12 102,27 32.85 5085.52 7112.00 -129.85 7248.25 2.79 -1.67 2.71 · 30-MAR-00 MWD 9420.90 54.14 102.59 32.30 5104.22 7138.33 -135.52 7273.97 3.14 -3.03 0.99 30-MAR-00 IV{WD 9450.86 52.77 102.71 29.96 5122.06 7162.40 -140.79 7297.46 4.58 -4.57 0.40 30-MAR-00 MWD 9483.88 51.75 102.91 33.02 5142.27 7188.51 -146.58 7322.92 3.13 -3.09 0.61 30-MAR-00 MWD 9515,51 50.17 105.37 31.63 5162,19 7213,06 -152,57 7346,74 7.84 -5.00 7.78. 30-MAR-00 MWD 9546,82 49.38 107.48 31,31 5182,42 7236.90 -159,33 7369,67 5.73 -2.52 6.74 30-MAR-O0 MWD 9579.07 50.70 108,44 32.25 5203.13 7261,49 -166,95 7393.18 4.69 4,09 2.98 30- MAR-00 MWD 9611.26 51.17 109.37 32.19 5223.41 7286.32 -175.05 7416.83 2.68 1.48 2.89 30-MAR-00 MWD 9642,64 52.07 108,90 31,38 5242.90 7310,71 -183.31 7439,99 3,16 2,87 1,69 30-MAR-00 MWD 9675,15 52,41 109,41 32.51 5262,81 7336,19 -191.96 7464,20 1,59 1,05 -1,51 31-MAR-O0 MWD 9707,30 50,65 109.78 32,15 5282.80 7361,15 -200.40 7487,91 5,55 -5,47 1,15 ; ~..-- 'I~!~. : Survey Section Name SPERRY IVlWD BHI Rep. R. BARNARD WELL DATA Target TVD (FT) Target Coord, N/S Slot Coord. N/S 104,00 Grid Correction 0,000 Depths Measured From: RKB ~] MSLE] SS[- Target Description Target Coord. E/W Slot Coord. E/W 216,00 Magn, Declination 26,560 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build~Walk\DL per: lOOftl~ 30mE] lOm['-I Vert, Sec, Azim, 102,20 Magn, to Map Corr, 26,560 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (4-) Right (+) Comment Type (FO (DD) (DD) (FO . (FO (FT) (FO (Per 100 FO Drop (-) Left (-) 31 -MAR-O0 MWD 9738,52 48,33 108,15 3.1,22 5303,08 7384,72 -208,12 7510,35 8,42 -7,43 -5.22 31 -MAR-O0 MWD 9771,51 46,66 107,21 32,99 5325,37 7408,93 -215.51 7533.52 5.48 -5.06 -2,85 ~--- 31 -MAR-O0 MWD 9803,91 45,32 105,18 32,40 5347,89 7432.17 -222,01 7555,90 6,12 -4,14 -6,27 31 -MAR-O0 MWD 9835,71 44.77 103,59 31,80 5370,35 7454,66 -227,60 7577,69 3,94 -1,73 -5.00 31-MAR-O0 MWD 9868,50 44,11 102,31 32,79 5393,77 7477,61 -232,75 7600,07 3,39 -2,01 -3,90 31 -MAR-O0 MWD 9900.42 43.63 102,23 31,92 5416,78 7499,73 -237.45 7621,68 1.51 -1,50 -0,25 ... 31 -MAR-O0 MWD 9931,50 42,50 101,66 31,08 5439,48 7520,95 -241,84 7642,44 3,85 -3,64 -1,83 31 -MAR-O0 MWD 9964,29 41.34 101,24 32,79 5463,88 7542,86 -246,19 7663,91 3,64 -3,54 -1,28 31 -MAR-O0 MWD 9995,90 39,92 100,54 31,61 5487,87 7563,44 -250,08 7684,13 4,72 -4,49 -2,21 31-MAR-O0 MWD 10027,64 37.79 99.45 31.74 5512,59 7583,33 -253,54 7703,73 7,05 -6,71 -3.43 31-MAR-O0 MWD 10060,23 36,33 99,65 32.59 5538,59 7602,95 -256,80 7723,10 4,50 -4,48 0,61 31-MAR-O0 MWD 10092,26 34.88 100,72 32,03 5564,63 7621,58 -260,09 7741,45 4,93 -4,53 3,34 31 -MAR-O0 MWD 10123,68 33.57 102.16 31.42 5590.61 7639,25 -263,60 7758,77 4,90 -4.17 4,58 31-MAR-O0 MWD 10156.54 32.47 102.29 32.86 5618.17 7657,16 -267.39 7776,27 3,35 -3,35 0,40 31-MAR-O0 MWD 10188.43 31.72 101.63 31.89 5645.18 7674.10 -270.90 7792,85 2.60 -2.35 -2.07 31-MAR-O0 I~IWD 10219.83 30.61 1 O1.76 31.40 5672.05 7690,35 -274.19 7808.76 3.54 -3,53 0.41 ' '~.' '~ ' ' "'~ . :.... : .. ~ '. .:*.:~.,;. ~.:::.. 31-MAR-O0 MWD 10252.55 29.88 101,91 32.72 5700,32 7706.83 -277.57 7824.89 2.24 -2,23 0.46 : ! · F" "'. ": ": '.'- "' " 31 -MAR-O0 MWD 10284.56 29.11 102.63 32.01 5728.18 7722,59 -280,92 7840,29 2.65 -2,41 2.25 ~-". 31-MAR-O0 MWD 10316,02 27.81 104.33 31,46 5755,83 7737.58 -284.41 7854,87 4.87 -4,13 5,40 01-APR-O0 MWD 10348,75 27.52 104,04 32.73 5784,82 7752.77 -288.13 7869.60 0.98 43,89 43.89 .' 01 -APR-O0 MWD 10380,54 26.53 1 04.78 31.79 5813,14 7767.20 -291.73 7883,59 3,29 -3,11 2,33 06-APR-O0 MWD 10548,47 22,47 107.60 167.93 5965,92 7836,65 -311.01 7950.48 2.52 -2,42 1.68 3-1/8" MACH lXL- 1,6 AKO 06-APR-O0 MWD 10580,30 21,46 108,28 31.83 5995.44 7848,49 -314.67 7961,80 3.27 -3,17 2,14 07-APR-O0' MWD 10618.15 20.79 111.79 37.85 6030.75 7862,00 -319.34 7974.62 3.78 -1.77 9.27 ~ Well Name & No PAD 1Lr2OA Survey Section Name SPERRY MWD BHI Rep R BARNARD ~Jl"~l~ WELL DATA Target TVD (FO Target Coord. N/S Slot Coord. N/S 104.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLr-1 SS~ Target Description Target Coord. E/W Slot Coord. E/W 216.00 Magn. Declination 26.560 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~[ 30mO lOm[~ Vert. Sec. Azim. 102.20 Magn. to Map Corr. 26.560 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FO (DD) (DD) (FT) , (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 08-APR-00 MWD 10935.30 19.00 111.79 317.15 6328.96 7968.41 -359,40 8074.83 0.56 -0,56 0,00 PROJECTED DATA - No Survey · ., I PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 August 30, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 1L-20A (200-036) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on 1L-20A. If you have any questions regarding this matter, please contact me at 265-6120 or Bill Lloyd at 265- 6531. Sincerely, Randy Thomas Kuparuk Drilling Team Leader PA1 Drilling RT/skad North Slope Alaska Alaska State Plane 4 Kuparuk 1L, Slot 1L-20 1L-20A Job No. AKMMO0003, Surveyed: 26 March, 2000 ORIGINAL SURVEY REPORT 22 July, 2000 Your Ref: API-500292202701 Surface Coordinates: 5948979.15 N, 540273.98 E (70° 16' 17.5485" N, 210° 19' 32.6039" E) Kelly Bushing: 120.50ft above Mean Sea Level RECEIVED AUO 01 200~ Naska 0ii & Gas Cons. Com~issi0.n Anchorage O I:!1 L.L. INI~ SERVICES A Halliburton Company Survey Ref: svy9193 Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: API.500292202701 Job No, AKMMO0003, Surveyed: 26 March, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings (ft) (ft) (ft) (ft) (ft) (ft) 6177.50 63.900 87.600 3638.61 3759.11 436.58 N 4417.81 E 5949439.32 N 6191.00 63.694 87.347 3644.57 3765.07 437.11 N 4429.91 E 5949439.92 N 6216.84 63.250 86.802 3656.11 3776.61 438.29 N 4453.00 E 5949441.22 N 6314.00 63.750 84.752 3699.47 3819.97 444,70 N 4539.71 E 5949448.09 N 6411.98 64.490 82.685 3742.24 3862.74 454.34 N 4627.33 E 5949458.20 N 6504.30 63.810 80.738 3782.49 3902.99 6522.29 64,630 81,026 3790.32 3910,82 6590.62 64,650 82.774 3819.58 3940.08 6635.63 66.150 83.926 3838.32 3958.82 6703.81 66.730 85.670 3865.57 3986.07 6735.11 66.810 90.980 3877.93 3998.43 6767.23 66,730 96.340 3890.60 4011.10 6800.34 66.930 94.500 3903.63 4024.13 6831.57 67,320 96.040 3915.77 4036.27 6862.75 67.010 97.280 3927.87 4048.37 6896.34 67,140 98.820 3940.96 4061.46 6927.71 67.120 102.310 3953.15 4073.65 6956,17 66.600 105.270 3964.34 4084.84 6989.62 66.170 108,370 3977.74 4098.24 7022.07 66,130 109.780 3990.86 4111.36 22 July, 2000 - 21:44 Alaska State Plane 4 Kuparuk 1L Global Coordinates Eastings 544688.95 E 544701.O5 E 544724.13 E 544810.79 E 544898.35 E 466.32 N 4709.53 E 5949470.62 N 544980.48 E 468.88 N 4725.53 E 5949473.27 N 544996.46 E 477.58 N 4786.66 E 482.32 N 4827.30 E 487.98 N 4889.54 E 5949482.29 N 545057.54 E 5949487.25 N 545098.15 E 5949493.24 N 545160.35 E Dogleg Rate (°/100ft) 2.27 2.55 1.96 2.04 2.04 4.78 2.31 4.06 2.49 Vertical Section Comment 4225.78 Tie-on Survey MWD Magnetic 4237.49 Window Point 4259.81 Interpolated Az due to drilling next to csg 4343.21 Interpolated Az drilling next to csg 4426.81 Interpolated Az drilling next to csg 4504.63 same as above (Az interpolated between TO and 6508) 4519.72 Interpolated Az (Az interpolated between 6508 an 6703) 4577.63 Interpolated Az (same as 6522) 4616.36 Interpolated Az (same a" 6522) 4675.99 488.82 N 4918.28 E 486.94 N 4947.72 E 484.07 N 4978.02 E 481.42 N 5006.67 E 478.09 N 5035.21E 5949494.24 N 545189.08 E 15.59 4703.90 5949492.51 N 545218.53 E 15.34 4733.07 5949489.80 N 545248.84 E 5.14 4763.30 5949487.31 N 545277.50 E 4,71 4791.86 5949484.13 N 545306.06 E 3,80 4820.46 473.76 N 5065.84 E 468.46 N 5094.25 E 462.22 N 5119.66 E 453.36 N 5149.00 E 443.66 N 5177.05 E 5949479.96 N 545336.71 E 4.24 4851.32 5949474.82 N 545365.14 E 10.25 4880.20 5949468.72 N 545390.59 E 9.74 4906.36 5949460.01N 545419.96 E 8.59 4936.91 5949450.46 N 545448.06 E -2- Continued... Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: API.500292202701 Job No. AKMMO0003, Surveyed: 26 March, 2000 North Slope Alaska Measured Depth (ft) 7052.28 7086.08 7116.05 7147.33 7180.71 Incl. 66.230 66.980 66.730 67.070 67.810 7212.59 7244.33 7278.06 7310.00 7341.35 68.300 69.670 70.540 70.350 70.170 7371.40 7403.59 7435.35 7469.08 7501.36 7535.29 7563.92 7596.54 7627.55 7661.35 69.880 67.780 67.950 67.940 67.770 67.630 67.780 68.190 68.100 68.260 7693.59 7725,43 7756.68 7788,83 7820.45 68.450 68.160 68.030 67.64O 66.400 22 July, 2000 - 21:44 Azim. 110.780 109.710 110.790 110.680 110.130 109.940 109.610 109.150 108.610 109.420 108.910 108.830 108.270 108.610 108.320 108.160 107.740 106.980 106.820 107.160 107.750 106.820 106.760 106.600 107.180 Sub-Sea Depth (ft) 4003.06 4016.49 4028.27 4040.54 4053.34 4O65.26 4076.64 4088.12 4098.81 4109.40 4119.66 4131.29 4143.25 4155.92 4168.09 4180.96 4191.82 4204.05 4215.60 4228.16 4240.05 4251.82 4263.48 4275.61 4287.95 Vertical Depth (ft) 4123.56 4136.99 4148.77 4161.04 4173.84 4185.76 4197.14 4208,62 4219.31 4229.90 4240.16 4251.79 4263.75 4276.42 4288,59 4301.46 4312.32 4324.55 4336.10 4348.66 4360.55 4372.32 4383.98 4396.11 4408.45 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (fi) (ft) (ft) (ft) 434.08 N 5202.97 E 5949441.02 N 545474.03 E 423.35 N 5232.07 E 5949430.45 N 545503.19 E 413.81N 5257.93 E 5949421.05 N 545529.09 E 403.62 N 5284.83 E 5949411.01 N 545556.05 E 392.88 N 5313.73 E 5949400.42 N 545585.00 E 382.75 N 5341.51 E 5949390.44 N 545612.83 E 372.72 N 5369.39 E 5949380.56 N 545640.76 E 362.20 N 5399.31E 5949370.20 N 545670.73 E 352.46 N 5427.79 E 5949360.61 N 545699.26 E 342.84 N 5455.68 E 5949351.15 N 545727.21 E 333.57 N 5482.36 E 5949342.02 N 545753.93 E 323.87 N 5510.76 E 5949332.47 N 545782.38 E 314.51 N 5538.65 E 5949323,26 N 545810.32 E 304.62 N 5568.31 E 5949313.53 N 545840.03 E 295.15 N 5596,67 E 5949304.21 N 545868.43 E 285.32 N 5626.48 E 5949294.55 N 545898.30 E 277.16 N 5651.68 E 5949286.52 N 545923.54 E 268.14 N 5680.55 E 5949277.65 N 545952.45 E 259.77 N 5708.09 E 5949269.43 N 545980.03 E 250.60 N 5738.10 E 5949260.43 N 546010.08 E 241.61N 5766.68 E 5949251.59 N 546038.71E 232.82 N 5794.93 E 5949242.95 N 546067.00 E 224.45 N 5822.69 E 5949234.73 N 546094.80 E 215.90 N 5851.21 E 5949226.34N 546123.37 E 207.44 N 5879.06 E 5949218.03 N 546151.26 E Alaska State Plane 4 Kuparuk 1L Dogleg Rate (°/100ft) 3.05 3.66 3.42 1.13 2.69 1.63 4.42 2.88 1.70 2.50 Vertical Section Comment 4993.73 5024.45 5051.73 5080.19 5110.70 5139.99 5169.36 5200.83 5230.72 5260.02 1.86 6.53 1.72 0.93 0.98 5288.05 5317.87 5347.10 5378.18 5407.90 0.60 1.45 2.50 0.56 1.05 5439.12 5465.48 5495.59 5524.28 5555.55 1.80 2.86 0.45 1.30 4.27 5585.39 5614.86 5643.76 5673.44 5702.45 RECEIVED AUG 0 1 ;!000 Continued... -3- Alaska Oil & G~s 6ohs. Commission Anchorage DriilQuest 2.00.03 Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: API-500292202701 Job No. AKMMO0003, Surveyed: 26 March, 2000 North Slope Alaska Measured Depth (ft) 7854.11 7886.54 7916.00 7947.36 7981.38 Incl. 66.470 66.680 65.980 66.140 65.97O 8012.45 8043.24 8075.59 8107.00 8139.79 65.73O 65.7O0 65.800 65.820 65.950 8171,81 8203.40 8236.05 8268.33 8294.80 66.130 66.040 66.300 66.290 66.510 8331.76 8363.27 8395.14 8428.14 8459.87 66.930 66.440 66.540 66.390 66.040 8491.10 8523.62 8555.52 8586.64 8619.43 65.530 65.25O 65.010 64.440 64.110 Azim. 106.57o lO6.42o lO7.630 107.32o lO8.27o lO8.1oo lO6.77o 106.97o lO6.18o 105.420 lO3.7oo lO3.98o lO3.480 lO3.03o lOl.93o 102,440 102.400 101.460 102.020 101.710 101.570 103.130 103.330 103.880 104.290 Sub-Sea Depth (ft) 4301.41 4314.30 4326.13 4338.86 4352.66 4365.38 4378.04 4391.33 4404.20 4417.59 4430.60 4443.4O 4456.60 4469.57 4480.17 4494.78 4507.25 4519.96 4533.14 4545.94 4558.75 4572.29 4585.71 4598.99 4613.23 Vertical Depth (ft) 4421.91 4434.80 4446.63 4459.36 4473.16 4485.88 4498.54 4511.83 4524.70 4538.09 4551.10 4563.90 4577.10 4590.07 4600.67 4615.28 4627.75 4640.46 4653.64 4666.44 4679.25 4692.79 4706.21 4719.49 4733.73 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 198.49 N 5908.59 E 5949209.23 N 546180.83 190.04 N 5937.12 E 5949200.94 N 546209.41 182.14 N 5962.92 E 5949193.18 N 546235.24 173.53 N 5990.26 E 5949184.72 N 546262.63 164.03 N 6019.86 E 5949175.37 N 546292.28 155.18 N 6046,80 E 5949166.67 N 546319.26 146.77 N 6073.57 E 5949158.41N 546346.07 138.21 N 6101.80 E 5949150.00 N 546374.34 130.04 N 6129.26 E 5949141.97 N 546401.84 121.89 N 6158.06 E 5949133.98 N 546430.68 114.54 N 6186.38 E 5949126.78 N 546459.04 107.63 N 6214.42 E 5949120.02 N 546487.11 100.54 N 6243.43 E 5949113.09 N 546516.16 93.76 N 6272.20 E 5949106.47 N 546544.96 88.52 N 6295.88 E 5949101.35 N 546568.67 81.36 N 6329.07E 5949094.36 N 546601.89 75.13 N 6357.33 E 5949088.29 N 546630.18 69.09 N 6385.92 E 5949082.40 N 546658.80 62.94 N 6415.54 E 5949076.41 N 546688.45 56.97 N 6443.96 E 5949070.59 N 546716.90 51.22 N 6471.85 E 5949064.99 N 546744.82 44.90 N 6500.73 E 5949058.83 N 546773.73 38.27 N 6528.91E 5949052.35 N 546801.94 31.65 N 6556.26 E 5949045.88 N 546829.32 24.46 N 6584.91 E 5949038.85 N 546858.01 Dogleg Rate (°/100ft) Alaska State Plane 4 Kuparuk 1L Vertical Section Comment E 1.67 5733.2O E 0.77 5762.88 E 4.45 5789.76 E 1.04 5818.30 E 2.60 5849.25 E O.92 5877.44 E 3.94 5905.39 E 0.64 5934.79 E 2.30 5963.35 E 2.15 5993.22 E 4.94 6022,46 E 0.86 6051.32 E 1.61 6081.18 E 1.28 6110.73 E 3.90 6134.99 E 1.70 6168.94 E 1.56 6197.87 E 2.72 6227.10 E 1.62 6257.35 E 1.42 6286.39 E 1.68 6314.87 E 4.45 6344.43 E 0.94 6373.37 E 2.43 6401.50 E 1.51 6431.02 RECEIVED 0 1 Continued... 22 July, 2000 - 21:44 -4- Alaska Oil & Gas C,,o~s kr~cho~'a, ge. DrillQuest 2. 00. 03 Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: API-500292202701 Job No. AKMMO0003, Surveyed: 26 March, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8651.70 63.700 104.580 4627.42 4747.92 8681.74 63.880 104.220 4640.69 4761.19 8715.76 64.920 105.580 4655.39 4775.89 8747.38 66.060 105.600 4668.50 4789.00 8779.22 67.450 105.140 4681.07 4801.57 8812.21 67.920 104.810 4693.60 4814.10 8843.67 67.600 104.860 4705.50 4826.00 8874.81 67.380 103.470 4717.43 4837.93 8907.60 66.650 103.110 4730.23 4850.73 8939.46 65.690 103.690 4743.10 4863.60 8970.73 64.730 102.910 4756.21 4876.71 9003.45 64.610 102.680 4770.21 4890.71 9035.36 64.150 102.860 4784.01 4904.51 9066.43 63.710 102.270 4797.66 4918.16 9099.42 63.350 101.060 4812.37 4932.87 9131.34 62.510 100.340 4826.90 4947.40 9163.08 61.500 100.840 4841.79 4962.29 9195.73 60.360 101.400 4857.66 4978.16 9228.28 58.900 102.290 4874.11 4994.61 9260.32 57.520 101.910 4890.99 5011.49 9292.48 56.350 102.260 4908.54 5029.04 9324.49 55.910 101.580 4926.38 5046.88 9355.75 55.670 101.380 4943.95 5064.45 9388.60 55.120 102.270 4962.61 5083.11 9420.90 54.140 102.590 4981.31 5101.81 22 July, 2000 - 21:44 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 17.24 N 6612.97 E 5949031.77 N 546886.11 10.54 N 6639.08 E 5949025.21N 546912.25 2.65 N 6668.73 E 5949017.48 N 546941.93 5.08 S 6696.44 E 5949009.90 N 546969.68 12.84 S 6724.65 E 5949002.30 N 546997.93 20.72 S 6754.13 E 5948994.57 N 547027.45 28.18 S 6782.28 E 5948987.27 N 547055.64 35.22 S 6810.17 E 5948980.38 N 547083.56 42,16 S 6839.55 E 5948973.60 N 547112.97 48.91 S 6867.90 E 5948966.99 N 547141.36 55.44 S 6895.52 E 5948960.61N 547169.01 61.99 S 6924.36 E 5948954.22 N 547197.89 68.35 S 6952.42 E 5948948.01 N 547225.98 74.42 S 6979.66 E 5948942.08 N 547253.25 80.40 S 7008.59 E 5948936.27 N 547282.20 85.67 S 7036.51 E 5948931.14 N 547310.15 90.82 S 7064.06 E 5948926.14 N 547337.72 96.33 S 7092.06 E 5948920.78 N 547365.75 102.09 S 7119.55 E 5948915.17 N 547393.26 107.80 S 7146.18 E 5948909.60 N 547419.92 113.44 S 7172.53 E 5948904.10 N 547446.30 118.93 S 7198.53 E 5948898.75 N 547472.33 124.08 S 7223.87 E 5948893.74 N 547497.69 129.62 S 7250.33 E 5948888.35 N 547524.18 135.28 S 7276.05 E 5948882.82 N 547549.93 Alaska State Plane 4 Kuparuk 1L Dogleg Rate (°/100ft) 1.51 1.23 4.73 3.61 4.56 Vertical Section Comment 6459.98 6486.91 6517.56 6546.28 6575.49 1.70 1.03 4.18 2.44 3.44 6605.97 6635.06 6663.81 6693.99 6723.13 3.81 0.73 1.53 2.22 3.46 6751.51 6781.08 6809.86 6837.76 6867.29 3.31 3.47 3.80 5.07 4.42 6895.71 6923.72 6952.25 6980.33 7007.57 E 3.75 E 2.24 E 0.93 E 2.79 E 3.14 7034.52 7061.09 7086.94 7113.98 7140.32 RECEIVED AUG 0 1 Continued... -5- 'Alaska. Oil & G--.,,s C.o~s. Oommission DrillQuest 2.00. 03 Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: API-500292202701 Job No. AKMMO0003, Surveyed: 26 March, 2000 North Slope Alaska Measured Depth (ft) 9450.86 9483.86 9515.51 9546.82 9579.07 Incl. 52.770 51.750 50.170 49.380 50.700 9611.26 9642.64 9675.15 9707.3O 9738.52 51.170 52.070 52.410 50.650 48.330 9771.51 9803.91 9835.71 9868.50 9900.42 46.660 45.320 44.77O 44.110 43.630 9931.50 9964.29 9995.90 10027.64 1OO60.23 42.5OO 41.340 39.920 37,790 36.330 10092.26 10123.68 10156.54 10188.43 10219.83 34.880 33.570 32,470 31.720 30,610 Azim. lO2.71o lO2.910 lO5.37o lO7.48o lO8.44o lO9.37o lO9.90o lO9.41o lO9.78o lO8.15o 107.210 lO5.18o 103.59o lO2.310 lO2.23o 101.660 101.240 100.540 99,450 99.650 100.720 102.160 102.290 101.630 101.760 Sub-Sea Depth (ft) 4999.15 5019.34 5O39.28 5059.50 5080.21 5100.50 5119.98 5139.89 5159.89 5180.17 5202.46 5224.97 5247.44 5270.85 5293.86 5316.57 5340.97 5364.96 5389.67 5415.68 5441.72 5467.70 5495.25 5522.27 5549.14 Vertical Depth (ft) 5119,65 5139.84 5159.78 5180,00 5200,71 5221.00 5240.48 5260.39 5280.39 5300.67 5322.96 5345.47 5367.94 5391.35 5414.36 5437.07 5461.47 5485.46 5510.17 5536.18 5562.22 5588.20 5615.75 5642.77 5669.64 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 140.55 S 7299.54 E 5948877.67 N 547573.44 146.34 S 7324.98 E 5948872.02 N 547598.91 152.34 S 7348.82 E 5948866.15 N 547622.78 159.10 S 7371.75 E 5948859.52 N 547645.74 166.72 S 7395.26 E 5948852.02 N 547669.29 174.82 S 7418.91 E 5948844.05 N 547692.98 183,08 S 7442.07 E 5948835.91 N 547716.18 191.73 S 7466.28 E 5948827.40 N 547740.43 200,17 S 7489.99 E 5948819.08 N 547764.19 207,89 S 7512.43 E 5948811.49 N 547786.67 215.28 S 7535.60 E 5948804.22 N 547809.88 221.78 S 7557.98 E 5948797.84 N 547832.28 227.37 S 7579.77 E 5948792.37 N 547854.11 232.52 S 7602.15 E 5948787.34 N 547876.50 237.22 S 7623.76 E 5948782.75 N 547898.14 241.61 S 7644.52 E 5948778.47 N 547918.93 245.96 S 7666.00 E 5948774.24 N 547940.42 249.85 S 7686.21E 5948770.46 N 547960.65 253.31 S 7705.81 E 5948767.10 N 547980.27 256.57 S 7725.18 E 5948763.95 N 547999.65 259.86 S 7743.54 E 5948760.75 N 548018.02 263.36 S 7760.86 E 5948757.34 N 548035.36 267.16 S 7778.36 E 5948753.65 N 548052.88 270.67 S 7794.93 E 5948750.22 N 548069.47 273.96 S 7810.84 E 5948747.02 N 548085.40 Dogleg Rate (°/100ft) Alaska State Plane 4 Kuparuk 1L Vertical Section Comment E 4.58 7164.39 E 3.13 7190.48 E 7.83 7215.05 E 5.73 7238.88 E 4.69 7263.48 E 2.68 7288.30 E 3.16 7312.69 E 1.59 7338.18 E 5.55 7363.14 E 8.42 7386.70 E 5.48 7410.91 E 6.12 7434.15 E 3.94 7456.64 E 3.39 7479.60 E 1.51 7501.72 E 3.85 7522.94 E 3.64 7544.84 E 4.72 7565.42 E 7.05 7585.32 E 4.50 7604.93 E 4.93 7623.57 E 4.90 7641.24 E 3.35 7659.14 E 2.60 7676.09 E 3.54 7692.34 RECEIVED AUG 0 i OOC Continued... 22 July, 2000 - 21:44 -6- Alaska Oil ~ Gas Corm. Commission AnChorage DrillQuest 2.00.03 Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: API-500292202701 Job No. AKMMO0003, Surveyed: 26 March, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 10252.55 29.880 101.910 5577.40 5697.90 277.34 S 7826.97 E 5948743.72 N 548101.55 E 10284.56 29.110 102.630 5605.26 5725.76 280.69 S 7842.37 E 5948740.46 N 548116.96 E 10316.02 27.810 104.330 5632.92 5753.42 284.18 S 7856.95 E 5948737.05 N 548131.56 E 10348.75 27.520 104.040 5661.91 5782.41 287.90 S 7871.69 E 5948733.40 N 548146.31 E 10380.54 26.530 104.780 5690.23 5810.73 291.50 S 7885.68 E 5948729.88 N 548160.32 E 10548.47 22.470 107.600 5843.01 5963.51 310.78 S 7952.56 E 5948710.96 N 548227.29 E 10580.30 21.460 108.280 5872.53 5993.03 314.44 S 7963.89 E 5948707.36 N 548238.64 E 10618.15 20.790 111.790 5907.84 6028.34 319.11 S 7976.70 E 5948702.76 N 548251.48 E 10618.18 20.790 111.790 5907.87 6028.37 319.11 S 7976.71 E 5948702.76 N 548251.49 E 10935.35 20.790 111.790 6204.38 6324.88 360.90 S 8081.24 E 5948661.53 N 548356.23 E All 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. Magnetic Declination at Surface is 26.563° (25-Mar-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 102.200° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10935.35ft., The Bottom Hole Displacement is 8089.30ft., in the Direction of 92.557° (True). * Grid Coordinate Scale Factors have been applied to all local coordinates. Dogleg Rate (°/100ft) Alaska State Plane 4 Kuparuk 1L Vertical Section Comment 2.24 7708.82 2.65 7724.58 4.87 7739.56 0.98 7754.75 3.29 7769.19 2.52 7838.63 3.27 7850.48 3.78 7863.99 0.00 7864.00 Last Su~ey 0.00 7975.00 Projected Survey RECEIVED AUG 01 Alaska Oil & G~s C.o~s. uo.,:,:,,,oo .... Anchorage Continued... 22 July, 2000 - 21:44 - 7 - DrillQuest 2.00.03 Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: API-500292202701 Job No. AKMMO0003, Surveyed: 26 March, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1L Comments Measured Depth (ft) 6191.00 6216.84 6314.00 6411.98 6504.3O 6522.29 6590.62 6635.63 10618.18 10935.35 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3765.07 437.11 N 4429.91 E 3776.61 438.29 N 4453.00 E 3819.97 444.70 N 4539.71 E 3862.74 454.34 N 4627.33 E 3902.99 466.32 N 4709.53 E 3910.82 468.88 N 4725.53 E 3940.08 477.58 N 4786.66 E 3958.82 482.32 N 4827.30 E 6028.37 319.11S 7976.71E 6324.88 360.90 S 8081.24 E Comment Window Point Interpolated Az due to drilling next to csg Interpolated Az drilling next to csg Interpolated Az drilling next to csg same as above (Az interpolated between TO and 6508) Interpolated Az (Az interpolated between 6508 an 6703) Interpolated Az (same as 6522) Interpolated Az (same as 6522) Last Survey Projected Survey Survey tool program From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 6177.50 3759,11 6177.50 3759.11 10935,35 6324.88 22 July, 2000 - 21:44 Survey Tool Description AK-3 BP_HM MWD Magnetic -8- DrillQuest 2.00.03 North Slope Alaska Alaska State Plane 4 Kuparuk 1L 1L.20A Surveyed: 26 March, 1900 SURVEY REPORT 4 May, 2000 Your Reft API-500292202701 Surface Coordinates: 5949074.06 N, 540278.01 E (70° 16' 18.4818" N, 149° 40' 27.2640" W) Kelly Bushing: 121.50ft above Mean Sea Level DRILLING SERVIr'Es RECEIVED MAY 16 2000 Alaska Oil & Gas Cons. Commissior~ Anchorage Survey Ref: svy9193 Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: API-500292202701 Surveyed: 26 March, 1900 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6178.50 63.900 87.600 3638.61 3760.11 6190.00 63.694 87.347 3643.68 3765.18 6191.00 63.677 87.326 3644.13 3765.63 6215.84 63.250 86.802 3655.23 3776.73 6216.84 63.255 86.781 3655.68 3777.18 6313.00 63.750 84.752 3698.58 3820.08 6314.00 63.757 84.731 3699.02 3820.52 6410.98 64.490 82.685 3741.35 3862.85 6411.98 64.482 82.664 3741.78 3863.28 6503.30 63.810 80.738 3781.61 3903.11 6504.30 63.856 80.754 3782.05 3903.55 6521.29 64.630 81.026 3789.43 3910.93 6522.29 64.630 81.051 3789.86 3911.36 6589.62 64.650 82.774 3818.70 3940.20 6590.62 64.683 82.800 3819.13 3940.63 6634.63 66.150 83.926 3837.44 3958.94 6635.63 66.158 83.951 3837.84 3959.34 6702.81 66.730 85.670 3864.69 3986.19 6734.11 66.810 90.980 3877.04 3998.54 6766.23 66.730 96.340 3889.72 4011.22 Local Coordinates Northings Eastings (ft) (ft) 436.57 N 4417.81E 437.03 N 4428.12 E 437.07 N 4429.01 E 438.21 N 4451.21 E 438.26 N 4452.10 E 444.62 N 4537,91E 444.70 N 4538.81 E 454,26 N 4625.53 E 454.38 N 4626.43 E 466,24 N 4707.74 E 466.38 N 4708,63 E 468.80 N 4723.73 E 468.94 N 4724.63 E 477,50 N 4784.86 E 477.62 N 4785.76 E 482.24 N 4825.51E 482.34N 4826.42 E 487.90 N 4887.74 E 488.74 N 4916.48 E 486.86 N 4945.92 E Global Coordinates Northings Eastings (ft) (ft) Alaska State Plane 4 Kuparuk 1L Dogleg Vertical Rate Section (°/100ft) (ft) 5949534.27 N 544693.42 E 4225.78 5949534.78 N 544703.72 E 2.667 4235.76 5949534.83 N 544704.62 E 2.552 4236.62 5949536.09 N 544726.81 E 2.552 4258.07 5949536.14 N 544727.70 E 1.957 4258.94 5949542.96 N 544813.48 E 1.957 4341.47 5949543,04 N 544814.37 E 2.043 4342.33 5949553.07 N 544901.04 E 2.043 4425.07 5949553.19 N 544901.94 E 2.036 4425.92 5949565.48 N 544983.19 E 2.036 4502.89 5949565.63 N 544984.07 E 4.780 4503.73 5949568.14 N 544999.17 E 4.780 4517.98 5949568.28 N 545000.06 E 2.312 4518.83 5949577.16 N 545060.25 E 2.312 4575.89 5949577.28 N 545061.14 E 4.064 4576.74 5949582.12 N 545100.87 E 4.064 4614.62 5949582.22 N 545101.78 E 2.495 4615.49 5949588.11 N 545163.07 E 2.495 4674.25 5949589.11 N 545191.80 E 15.591 4702.16 5949587.38 N 545221.26 E 15.336 4731.34 Comment Tie-on Survey Window Point Interpolated Az due to drillir~g next to csg Interpolated Az drilling next o csg Interpolated Az drilling next to csg sa. me a.s.ab, qve. (Az imerpo~atea oetween TO and 6508) !n.terpo!a.ted, Az (Az ~merpolatea between ~""~ an 6703) ~ Interpolated Az (same as 6522) Interpolated Az (same as 6522) 4 May, 2000 - 11:23 -2- RECEIVED MAY 1 (:, ~0~ Continued.,. DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: API-500292202701 Surveyed: 26 March, 1900 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 6799.34 66.930 94.500 3902.75 4024.25 6830.57 67.320 96.040 3914.89 4036.39 6861.75 67.010 97.280 3926,99 4048,49 6895.34 67.140 98.820 3940,08 4061,58 6926,71 67.120 102.310 3952.27 4073.77 6955.17 66.600 105.270 3963.46 4084.96 6988.62 66.170 108.370 3976.86 4098.36 7021.07 66.130 109.780 3989.98 4111.48 7051.28 66.230 110.780 4002.18 4123.68 7085,08 66.980 109.710 4015.60 4137.10 7115.05 66.730 110.790 4027.38 4148.88 7146,33 67.070 110.680 4039.65 4161.15 7179.71 67.810 110.130 4052.46 4173.96 7211.59 68.300 109.940 4064.38 4185.88 7243.33 69.670 109.610 4075.76 4197.26 7277.06 70.540 109.150 4087.24 4208.74 7309.00 70.350 108.610 4097.93 4219.43 7340.35 70,170 109.420 4108.51 4230.01 7370.40 69.880 108.910 4118.78 4240.28 7402.59 67.780 108.830 4130.40 4251.90 7434.35 67.950 108.270 4142.37 4263.87 7468.08 67.940 108.610 4155.04 4276.54 7500.36 67.770 108.320 4167.21 4288.71 7534.29 67.630 108.160 4180.08 4301.58 7562.92 67.780 107.740 4190.94 4312.44 Global Coordinates Northings Eastings (ft) (ft) 483.99 N 4976.22 E 5949584.67 N 545251.57 481.34 N 5004.88 E 5949582.18 N 545280.24 478.01 N 5033.42 E 5949579.00 N 545308.80 473,68 N 5064.05 E 5949574.83 N 545339.45 468.38 N 5092,46 E 5949569.69 N 545367.89 462,14 N 5117.87 E 5949563.59 N 545393.33 453.28 N 5147.20 E 5949554.88 N 545422.71 443.58 N 5175.25 E 5949545.33 N 545450.81 434.00 N 5201.17 E 5949535.89 N 545476.79 423.27 N 5230.28 E 5949525.31 N 545505.95 413.73 N 5256.13 E 5949515.91 N 545531.85 403.54 N 5283.04 E 5949505,87 N 545558.81 392.79 N 5311.93 E 5949495.28 N 545587.76 382.66 N 5339.71 E 5949485,30 N 545615.60 372.64 N 5367.59 E 5949475,42 N 545643.53 362.12 N 5397.51 E 5949465.06 N 545673.51 352.38 N 5425.99 E 5949455.47 N 545702.04 342.76 N 5453.89 E 5949446.01 N 545729.99 333.49 N 5480.56 E 5949436.88 N 545756.71 323.78 N 5508.97 E 5949427.32 N 545785.17 314.42 N 5536.86 E 5949418,11N 545813.11 304.54N 5566.51E 5949408.38 N 545842.82 295.07 N 5594.87 E 5949399.07 N 545871.22 285.24 N 5624.69 E 5949389.40 N 545901.09 277.08 N 5649.89 E 5949381.37 N 545926.34 Dogleg Rate (°/lOOft) Alaska State Plane 4 Kuparuk 1L Vertical Section (ft) E 5.145 4761.56 E 4.712 4790.13 E 3.798 4818.73 E 4.240 4849.58 E 10.251 4878.47 E 9.737 4904.62 E 8.588 4935.17 E 3.976 4964.63 E 3.046 4991.99 E 3.656 5022.71 E 3.417 5050.00 E 1.134 5078.45 E 2.689 5108.96 E 1.633 5138.25 E 4.424 5167.62 E 2.880 5199.09 E 1.701 5228.98 E 2.499 5258.28 E 1.864 5286.32 E 6.528 5316.13 E 1.719 5345.37 E 0.935 5376.44 E 0.985 5406.16 E 0.600 5437.38 E 1.455 5463.74 Comment 4May, 2000-11:23 -3- RECEIVED Continued... DrillQuest 1,05,04e Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: AP1-$00292202701 Surveyed: 26 March, 1900 North Slope Alaska Measured Depth (ft) Incl, Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (fl) (ft) 7595.54 68,190 106.980 4203.17 4324.67 7626.55 68,100 106.820 4214.71 4336.21 7660.35 68.260 107.160 4227.28 4348.78 7692.59 68.450 107.750 4239.17 4360.67 7724.43 68,160 106.820 4250.94 4372.44 7755.68 68.030 106.760 4262.60 4384.10 7787.83 67.640 106.600 4274.73 4396.23 7819.45 66.400 107.180 4287.07 4408.57 7853.11 66.470 106.570 4300.53 4422.03 7885,54 66.680 106.420 4313.42 4434.92 7915.00 65.980 107.630 4325.25 4446.75 7946.36 66.140 107.320 4337.97 4459.47 7980.38 65.970 108.270 4351.78 4473.28 8011.45 65.730 108.100 4364.49 4485.99 8042.24 65.700 106.770 4377.16 4498.66 8074.59 65.800 106,970 4390.44 4511.94 8106.00 65.820 106,180 4403.31 4524.81 8138.79 65.950 105,420 4416.71 4538.21 8170.81 66.130 103,700 4429.71 4551.21 8202.40 66.040 103.980 4442.52 4564.02 8235.05 66.300 103.480 4455.71 4577.21 8267.33 66,290 103.030 4468.69 4590.19 8293.80 66.510 101.930 4479.29 4600.79 8330.76 66.930 102.440 4493.90 4615.40 8362.27 66.440 102.400 4506.37 4627.87 268.05 N 5678.75 E 5949372.50 N 545955.25 E 259.69 N 5706.29 E 5949364.28 N 545982.83 E 250.52 N 5736.30 E 5949355.27 N 546012.89 E 241.53 N 5764.89 E 5949346.44 N 546041.52 E 232.74 N 5793.13 E 5949337.80 N 546069.82 E 224.36 N 5820.89 E 5949329.57 N 546097.62 E 215.82 N 5849.41 E 5949321.18 N 546126.19 E 207.36 N 5877.27 E 5949312.87 N 546154.08 E 198.41 N 5906.79 E 5949304.07 N 546183.66 E 189.96 N 5935.33 E 5949295.78 N 546212.23 E 182.06 N 5961.12 E 5949288.02 N 546238.07 E 173.45 N 5988.46 E 5949279.56 N 546265.46 E 163.95 N 6018.07 E 5949270.21N 546295.11E 155.10 N 6045.00 E 5949261.51N 546322.10 E 146.69 N 6071.78 E 5949253.24 N 546348.92 E 138.13 N 6100.00 E 5949244.84 N 546377.19 E 129.96 N 6127.46 E 5949236.81N 546404.69 E 121.81N 6156.26 E 5949228.82 N 546433.53 E 114.45 N 6184.58 E 5949221.61N 546461.89 E 107.55 N 6212.62 E 5949214.85 N 546489.97 E 100.46 N 6241.63 E 5949207.92 N 546519.02 E 93.68 N 6270,40 E 5949201.30 N 546547,82 E 88.44 N 6294.09 E 5949196.18 N 546571,53 E 81.27 N 6327,27 E 5949189.20 N 546604.76 E 75.05 N 6355,53 E 5949183.12 N 546633,05 E Dogleg Rate (°/100ft) 2.499 0.560 1.047 1.800 2.863 0.453 1.298 4:270 1.674 0.774 4.449 1,038 2.601 0.920 3.939 0.643 2,295 2.152 4.941 0.859 1.611 1.277 3.898 1.702 1.559 Alaska State Plane 4 Kuparuk 1L Vertical Section (ft) Comment 5493.86 5522.54 5553.81 5583.65 5613.12 5642.o2 5671.7o 5700.72 5731.47 5761.14 5788.02 5816.56 5847.51 5875.70 5903.65 5933.05 5961.62 5991.49 6020.72 6049.59 6079.44 6108.99 6133.25 6167.2o 6196.14 RECEIVED ~IAY 1 6 2000 Continued... 4 May, 2000 - 11:23 -4- Alaska 011 & Gas Co~s. CommJsmon Anchorage DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: API-500292202701 Surveyed: 26 March, 1900 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 8394.14 66.540 101.460 4519.08 4640.58 8427.14 66.390 102.020 4532.26 4653.76 8458.87 66.040 101.710 4545,05 4666.55 8490.10 65.530 101.570 4557,86 4679.36 8522.62 65.250 103.130 4571.41 4692.91 8554.52 65.010 103.330 4584.82 4706.32 8585.64 64.440 103.880 4598.11 4719.61 8618.43 64.110 104.290 4612.34 4733.84 8650.70 63.700 104.580 4626.54 4748.04 8680.74 63.880 104.220 4639.80 4761.30 8714.76 64.920 105.580 4654.50 4776.00 8746.38 66.060 105.600 4667.62 4789.12 8778.22 67.450 105.140 4680.19 4801.69 8811.21 67.920 104.810 4692.71 4814.21 8842.67 67.600 104.860 4704.62 4826.12 8873.81 67.380 103.470 4716.54 4838.04 8906.60 66.650 103.110 4729.35 4850.85 8938.46 65.690 103.690 4742.22 4863.72 8969.73 64.730 102.910 4755.33 4876.83 9002.45 64.610 102.680 4769.33 4890.83 9034.36 64.150 102.860 4783.13 4904.63 9065.43 63.710 102.270 4796.78 4918.28 9098.42 63.350 101.060 4811.49 4932.99 9130.34 62.510 100.340 4826.01 4947.51 9162.08 61.500 100.840 4840.91 4962.41 69.01N 6384.12 E 62,85 N 6413.75 E 56.88 N 6442.16 E 51.14 N 6470.06 E 44.81N 6498.94 E 38.19 N 6527.11E 31.57 N 6554.46 E 24.38 N 6583.11 E 17.16 N 6611.18 E 10.46 N 6637.28 E 2.57 N 6666.93 E 5.17 S 6694.64 E 12.92 S 6722.85 E 20.81 S 6752.33 E 28.26 S 6780.48 E 35.30 S 6808.37 E 42.24 S 6837.75 E 48.99 S 6866.10 E 55.53 S 6893.73 E 62.08 S 6922.57 E 68.43 S 6950.63 E 74.51S 6977.87 E 80.48 S 7006.79 E 85.76 S 7034.72 E 90.91S 7062.27 E Alaska State Plane 4 Kuparuk 1L Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (fi) (°/lOOft) (ft) 5949177.24 N 546661.67 E 2.723 6225.36 5949171.24 N 546691.33 E 1.621 6255.61 5949165.42 N 546719.77 E 1.420 6284.65 5949159.82 N 546747.70 E 1.683 6313.13 5949153.65 N 546776.61 E 4.445 6342.69 5949147.18 N 546804.82 E 0.943 6371.63 5949140.71 N 546832.21 E 2,431 6399.76 5949133.67 N 546860.90 E 1.511 6429.29 5949126.60 N 546889.00 E 1.505 6458.25 5949120.04 N 546915.14 E 1.231 6485.18 5949112.31 N 546944.83 E 4.727 6515.82 5949104.72 N 546972.58 E 3.606 6544.54 5949097.12 N 547000.83 E 4.563 6573.75 5949089.39 N 547030.36 E 1.699 6604.24 5949082,09 N 547058.55 E 1.028 6633.32 5949075.20 N 547086.48 E 4.184 6662.07 5949068.41N 547115.89 E 2.445 6692.25 5949061.81 N 547144.28 E 3.443 6721.39 5949055.43 N 547171.94 E 3.815 6749.77 5949049.03 N 547200.81 E 0.734 6779.35 5949042.82 N 547228.91 E 1.529 6808.12 5949036.90 N 547256.18 E 2.217 6836.03 5949031.08 N 547285.13 E 3.460 6865.56 5949025.95 N 547313.09 E 3.310 6893.97 5949020.95 N 547340.66 E 3.473 6921.98 Comment 4May, 2000-11:23 -5- RECEIVED !. 6 000 Continued... DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: API-500292202701 Surveyed: 26 March, 1900 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9194.73 60.360 101.400 4856.77 4978.27 9227.28 58.900 102.290 4873.23 4994,73 9259.32 57.520 101.910 4890.11 5011.61 9291.48 56.350 102.260 4907.66 5029.16 9323.49 55.910 101.580 4925.50 5047.00 9354.75 55.670 101.380 4943.07 5064.57 9387.60 55.120 102.270 4961.73 5083.23 9419.90 54.140 102.590 4980.42 5101.92 9449.86 52.770 102.710 4998.26 5119.76 9482.86 51.750 102.910 5018.46 5139.96 9514.51 50.170 105.370 5038.40 5159.90 9545.82 49.380 107.480 5058.62 5180.12 9578.07 50.700 108.440 5079.33 5200.83 9610.26 51.170 109.370 5099.62 5221.12 9641.64 52.070 109.900 5119.10 5240.60 9674.15 52.410 109.410 5139.01 5260.51 9706.30 50.650 109.780 5159.01 5280.51 9737.52 48.330 108.150 5179.29 5300.79 9770.51 46.660 107.210 5201.58 5323.08 9802.91 45.320 105.180 5224.09 5345.59 9834.71 44.770 103.590 5246.56 5368.06 9867.50 44.110 102.310 5269.97 5391.47 9899.42 43.630 102.230 5292.98 5414.48 9930.50 42.500 101.660 5315.69 5437.19 9963.29 41.340 101.240 5340.08 5461.58 Local Coordinates Northings Eastings (ft) (ft) 96.41 S 7090.27 E 102.17 S 7117.75 E 107.88 S 7144.38 E 113.52 S 7170.73 E 119.01 S 7196.74 E 124.16S 7222.07 E 129.70 S 7248.54 E 135.37 S 7274.26 E 140.64 S 7297.74 E 146.42 S 7323.19 E 152.42 S 7347.02 E 159.18 S 7369.95 E 166.80 S 7393.47E 174.90 S 7417.11E 183.17 S 7440,28 E 191.81S 7464,48 E 200.25 S 7488,20 E 207.97 S 7510,64 E 215.36 S 7533.81 E 221.86 S 7556.18 E 227.45 S 7577.98 E 232.60 S 7600.35 E 237.30 S 7621.97 E 241.69 S 7642.73 E 246.04 S 7664.20 E Global Coordinates Northings Eastings (ft) (ft) Alaska State Plane 4 Kuparuk 1L 5949015.60 N 547368.69 5949009.98 N 547396.21 5949004.42 N 547422.87 5948998.92 N 547449.25 5948993.57 N 547475.28 5948988.56 N 547500.64 5948983.16 N 547527.14 5948977.63 N 547552.89 5948972.48 N 547576.40 5948966.83 N 547601.88 5948960.96 N 547625.75 5948954.33 N 547648.71 5948946.83 N 547672.26 5948938.86 N 547695.95 5948930.72 N 547719,16 5948922.20 N 547743,41 5948913.89 N 547767.17 5948906.29 N 547789,65 5948899.02 N 547812.86 5948892.64 N 547835.27 5948887.17 N 547857.10 5948882.14 N 547879.50 5948877.55 N 547901.14 5948873.27 N 547921.92 5948869.04 N 547943.42 Dogleg Vertical Rate Section (°/100ft) (ft) E 3.800 6950.51 E 5.068 6978.60 E 4.424 7005.83 E 3.751 7032.78 E 2.236 7059.36 E 0.932 7085.21 E 2.789 7112.24 E 3.140 7138.58 E 4.584 7162.65 E 3.128 7188.74 E 7.833 7213.31 E 5.730 7237.15 E 4.686 7261.74 E 2.676 7286.56 E 3.159 7310.95 E 1.585 7336.44 E 5.548 7361.40 E 8.424 7384.97 E 5.481 7409.17 E 6.116 7432.42 E 3.938 7454.90 E 3.394 7477.86 E 1.514 7499.98 E 3.845 7521.20 E 3.640 7543.11 RECEIVED Comment Continued.., 4 May, 2000 - 11:23 -6- DrillQuest 1.05,04e Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: AP1-$00292202701 Surveyed: 26 March, 1900 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Alaska State Plane 4 Kuparuk 1L 9994.90 39,920 100.540 5364.07 5485,57 249.93 S 7684.41 E 10026.60 37.790 99.450 5388.76 5510,26 253.39 S 7703.99 E 10059.20 36.330 99.650 5414.77 5536.27 256.65 S 7723,37 E 10091.20 34.880 100.720 5440.79 5562.29 259.94 S 7741.70 E 10122.60 33.570 102.160 5466.75 5588.25 263.44 S 7759.01 E 10155.50 32.470 102.290 5494.34 5615,84 267.23 S 7776.53 E 10187.40 31.720 101.630 5521,36 5642.86 270.75 S 7793.12 E 10218.80 30.610 101.760 5548,23 5669.73 274.04 S 7809.03 E 10251.50 29.880 101.910 5576.48 5697.98 277.42 S 7825.15 E 10283.50 29.110 102.630 5604.33 5725.83 280.77 S 7840.54 E 10315.00 27.810 104.330 5632.03 5753.53 284.26 S 7855.14 E 10347.70 27.520 104.040 5660.99 5782.49 287.98 S 7869,86 E 10379.50 26.530 104.780 5689.31 5810.81 291.58 S 7883,85 E 10547.40 22.470 107.600 5842.07 5963.57 310,85 S 7950,73 E 10579.30 21.460 108.280 5871,65 5993.15 314.53 S 7962.08 E 10617.10 20.790 111.790 5906.92 6028.42 319,18 S 7974.87 E 10934.30 19.000 111.790 6205.17 6326,67 359.25 S 8075,10 E 5948865.26 N 547963.65 5948861.90 N 547983.25 5948858.75 N 548002.64 5948855,56 N 548020.99 5948852.15 N 548038.32 5948848.45 N 548055.86 5948845.02 N 548072.46 5948841.82 N 548088.39 5948838.52 N 548104.53 5948835.26 N 548119.94 5948831.84 N 548134,56 5948828.20 N 548149.30 5948824.68 N 548163.31 5948805,76 N 548230.29 5948802.15 N 548241.66 5948797.56 N 548254.48 5948758.03 N 548354.92 Dogleg Vertical Rate Section (°/100ft) (ft) All 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. Magnetic Declination at Surface is 26.562° (26-Mar-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 102.200° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10934.30ft., The Bottom Hole Displacement is 8083.09ft., in the Direction of 92.547° (True). E 4.718 7563.68 E 7.057 7583.55 E 4.494 7603.18 E 4.932 7621.80 E 4.905 7639.45 E 3.350 7657.38 E 2.595 7674,33 E 3.542 7690.58 E 2.244 7707.05 E 2,649 7722.80 E 4.862 7737.81 E 0.978 7752.98 E 3.288 7767.42 E 2.516 7836.86 E 3.265 7848,73 E 3.786 7862,22 E 0.564 7968.65 RECEIVED 1 6 ]000 Comment Continued... 4 May, 2000-11:23 -7- DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 1L-20A Your Ref: AP1-$00292202701 Surveyed: 26 March, 1900 North Slope Alaska Alaska State Plane 4 Kuparuk 1L Comments Measured Depth (ft) 6178.50 6191.00 6216.84 6314.00 6411.98 6504.30 6522.29 6590.62 6635.63 Station Coordinates TVD Northings Eastings (ft) (fi) (fi) 3760.11 436.57 N 4417.81 3765.63 437.07 N 4429.01 3777.18 438.26 N 4452.10 3820.52 444.70 N 4538.81 3863.28 454.38 N 4626.43 3903.55 466.38 N 4708.63 3911.36 468.94 N 4724.63 3940.63 477.62 N 4785.76 3959.34 482.34 N 4826.42 Comment Tie-on Survey Window Point Interpolated Az due to drilling next to csg Interpolated Az drilling next to csg Interpolated Az drilling next to csg same as above (Az interpolated between TO and 6508) Interpolated Az (Az interpolated between 6508 an 6703) Interpolated Az (same as 6522) Interpolated Az (same as 6522) Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 10934.30 6326.67 Survey Tool Description AK-3 BP_HM RECEIVED h~AY 1 G ~OOC, 4May, 2000-11:23 -8- Alaska Oil & G~. O_.o,.qs. (;om.~,issioD DrillQuest 1.05.04e 01 -Aug-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1L-20A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 6,177.50' MD 6,191.00' MD 10,935.35' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 0 1 2000 Ai~sk8 Oil & Gas Cons. Gommission Anchorage 04-May-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Problem sidetracking - first stations Interp. Az's Re: Distribution of Survey Data for Well 1L-20A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 6,147.00' MD 6,191.00' MD 10,935.35' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs August 01, 2000 1L-20A, AK-MM-00003 1 LDWG formatted Disc with verification listing. API#: 50-029-22027-01 PLEASE ACKNOWLEDGE' RECEII~r' BY SIGNING ~RE.TURNING A LETTER TO TIlE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date: AUG 0 1 ?.000 Alaska 0il h Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company WELL LOG TRANSMITTAL To: State of Alaska August 01, 2000 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs oo.o3 1L-20A, AK-MM-00003 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-SUn Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1L-20A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22027-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22027-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia AUG 1 5 2000 Alaska 0ii & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company 6/7/00 Schhmberger NO. 214 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 1L-20A 20223 CB L/PS P/SCMT 000511 1 2C-02 C~ I f- LEAK DETECTION LOG 000521 I 1 2C-03 ¥ LEAK DETECTION LOG 000529 I 1 .3K-04j INJECTION PROFILE W/PSP 000521 I 1 30-06 WATER INJECTION PROFILE 000528 I 1 1D-125 PERF RECORD W/STATIC BHP 000530 I 1 .... ~--;2oo. oSfo - 19~' Iq~ SIGNED: ~ DATE: JUN 1 ;5 2000 Alaska Ut~ & Gas 15~:~s. u0mmissi0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. ThanlA~lgkorage Re: 1L-20a Sidetrick Permit to Drill - request to Exp, ?TD 200-036 Subject: Re: 1L-20a Sidetrick Permit to Drill - request to Expedite PTD 200-036 Date: Thu, 23 Mar 2000 10:23:51 -0900 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: William B Lloyd <WLLOYD~mail.aai.arco.com> CC: tom_maunder~admin.state.ak.us, Sharon Allsup-Drake <SALLSUP~mail.aai.arco.com> Bill, PTD 1L-20A was approved 3/22/00. Blair William B Lloyd wrote: Dear Mr. Wondzell: Nabors 16e is currently running tubing completion on the recently drilled 1L-26a sidetrack in Kuparuk. As it stands, this well has completed operations some 8 days ahead of schedule, and will be ready to move to the next well, well 1L-20a sidetrack, either late tonight or early tomorrow morning. Due to the exceptional performance on the 1L-26a well, we are requesting expedited approval of the submitted permit for 1L-2Oa, in order to avoid costly standby charges. Please advise if this will be possible. Approved permits can be sent to Ms. Sharon Allsup-Drake or, if notified prior to close of your day, we can send someone over to pick the approved permit up. I appreciate your consideration on this matter. Sincerely, William B. Lloyd Senior Drilling Engineer Arco Alaska, Inc. 1 of 1 3/23/00 10:24 AM TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COPlPllSSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 995010-0360 Re: Kuparuk River Unit 1L-20A ARCO Alaska, Inc. Permit No: 200-036 Sur Loc: 104'FSL, 216'FWL, Sec. 29, T11N, R10E, UM Btmhole Loc. 279'FNL, 2123'FEL. Sec. 33, T11N, R10E, UM Dear Mr. Alvord: Encloscd is thc approved application for pcrmit to drill the abovc rcfcrcnccd well. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1L-20A. Please note that an)' disposal of fluids generated from this drilling operation which arc pumPed down the surface/production casing annulus of a well approved for annular disposal on Drill Site IL 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 of a single well or to use that well for disposal purposes for a period longcr than one year. The permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling opcrations until all other required permitting determinations arc made. Blowout 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 witness a test of BOPE installed prior to drilling new hole. Notice may be given bx' contacting thc Commission petroleum field inspector on the North Slope pager at 659-3607. · r Chair BY ORDER OF TH.~,COMMISSION DATED this ~ I ~ day of March, 2000 dlffEnclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1L-20a Sidetrick Permit to Drill - request to Expedite Subject: 1L-20a Sidetrick Permit to Drill - .~ Expedite Date: Tue, 21 Mar 2000 10:15:05 -1000 From: "William B Lloyd" <WLLOYD@mail.aai.arco.com> To: Blair Wondzell <blair_wondzell@admin.state.ak. us> CC: tom_maunder@admin.state.ak, us, "Sharon AIIsup-Drake" <SALLSUP@mail.aai.arco.com> Dear Mr. Wondzell' Nabors 16e is currently running tubing completion on the recently drilled 1L-26a sidetrack in Kuparuk. As it stands, this well has completed_operations some 8 days ahead of schedule, and will be ready to move to the next well, well 1L-20a si e r , er a e onight or earlytomorrow morning. Due to the exceptional performance on the 1L-26a well, we are requesting expedited approval of the submitted permit for 1L-20a, in order to avoid oostly standby charges. Please advise if this will be possible. Approved permits can be sent to Ms. Sharon AIIsup-Drake or, if notified prior to dose of your day, we can send someone over to pick the approved permit up. I appreciate your consideration on this matter. Sincerely, William B. Lloyd Senior Drilling Engineer Arco Alaska, Inc. 1 of 1 3/21/00 10:33 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 --- la. ~/pe ofwork: Drill [] Redrill D I"' lb. TyPe ofwell:' Exploratory [~ StratigraphicTest D'" Development Oil Re-entry F~ Deepen D Service F1 Development Gas F1 single zone r~l Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 121 feet 3. Address 6. Proper~ Designation ¢c~ Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL25660 ALK 470 ~¢~2¢~ Kuparuk River Pool .. 4. Location of well at surface 7. Unit or prope~ Name 11. Type Bond (see 2o AAC 25.0251) 104' FSL, 216' FWL, Sec. 29, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 252' FNL, 2217' FEL, Sec. 33, T11 N, R10E, UM 1L-20A ¢U-630610 At total depth 9. Approximate spud date Amount 279' FNL, 2123' FEL, Sec. 33, T11 N, R10E, UM March 30, 2000 $200,000 12. Distance to hearst proper~ line ~ 13. Distance to nearest well 14. Number of acres in proper~ 15. Proposed depth (MD and TVD) 2217 G Targ~ feet~ none feet 2560 11000 ' MD / 6270 ' TVD 16. To be completed for deviated wells 17. Anticipated pre,ute (see 2o AAC 25.035 (e)(2)) Kickoff depth: 6193 MD M~imum hole angle 67 o M~imum surface 2228 psig At total depth (TVD) 2644 psig 18. Casing program Se~ing Depth size Specifications Top Bottom Quanti~ of Cement Hole Casin~ Weight Grade Couplin~ Length MD TVD MD TVD (include sta~e data) 7" 5.5" 15.5¢ L-80 Hydril-511 4587' 6043' 3702' 10630' 5922' 1400 sx Class G 4.75" 3.5" 9.3¢ L-80 BTC-MOD 520' 10480' 5786' 11000' 6270' 75 sx Class G isidetrack - top of window ~6180' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 11715 feet Plugs (measured) true vertical 6278 feet Effective Depth: measured 10778 feet Junk (measured) true vertical 5809 feet Casing Length Size Cemented Measured depth True Vedical depth Conductor 16" 245 sx AS I 115' 115' Surface 9.625" 1400 sx AS III & 600 sx Class G 6000' 3684' Intermediate Production 7" 300 sx ClanG 1093~~~ ~~ Liner Perforation depth: measured None ORIGINAL true vertical None& 20. Attachments Filing fee ~ Property Plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program Drilling fluid program ~ Time MS depth plot ~Refraction analysis ~ Seabed report ~ 20 ~C 25,050 requirements 21. I hereby cedi~ that the foregoing is true and correct to the best of my knowledg~ Quest/o~s? Carl Biff Lloyd 265-653 Cbip AIvord Pr~D~r~d bv .~harnn AIL~u~-Dr~k~ Commission Use Onl} Permit Number I APl number cover letter I for other requirements Conditions of approval Samples required ~ Yes ~' No Mud Icg required B Yes .~ No Hydrogen sulfide measures U Yes ~No/~ Directional survey required ~Yesu No Required working pressure for BOPE ~2M;' ~ 3M; ~ 5M; ~ IOM;~ ~ Other: ORIGINAL SIGNED BY ~obsR r~ ¢' !.,: ~..~s(~i~so~ by order of Approved by Commissioner the commission Date ~ Form 10-401 Rev. 12/1/85 · Submit in triplicate I Well Name: I 1 L-20a Well Plan Summary Type of Well (producer or injector): I Producer Surface Location: 104' FSL, 216' FWL, Sec. 29, T11 N-R10E KOP: 539' FSL, 643' FEL, Sec. 29, T11N-R10E Target #1 Start Location: 252' FNL, 2217' FEL, Sec. 33, T11N-R10E Target #2 Start Location: 268' FNL, 2162' FEL, Sec. 33, TllN-R10E Bottom Hole Location: 279' FNL, 2123' FEL, Sec. 33, T11N-R10E I AFE Number: I AK0051 I Rig: I Nabors 16e I Estimated Start Date: 103/30/00 I I Operating days to complete: I 23.8 KOP MD: TD MD: 6193' 11000' KOP TVD: TD TVD: 3767' 6000' ss F~KB/ 1121' Surface Elevation I6' {a.m.s.I) Well Design (conventional, slimhole, etc.): I Conventional Sidetrack Producer. IObjective: I Sidetrack from suspended 1L-20 well bore; to optimally drain one Kuparuk C4 target and I one Kuparuk A5 target Formation Markers Formation Tops MD TVD, Remarks Tie-In Survey 6179 3761 ., : ,. KOP 6193 3767 Begin build rate @ 3/100 @ 6209' MD C80 6605 3931 End 3/100 build @ 6521' MD (Max angle 67°) C50 9505 5075 Begin 3/100 drop & turn @ 9162' MD C40 9891 5316 C30 10310 5640 C20 - Mid HRZ 10435 5747 Base HRZ 10535 5835 K-1 Marker 10630 5922 5-1/2" Intermediate Casing Point Top Kuparuk C4 10695 5981 Target #1; Start 4/100' Drop & Turn Top C3 10741 6024 Top A6 10845 6122 Top A5 10861 6137 Target #2; End 4/100' Drop & Turn Top Miluveach Shale 10938 6211 TD 11000 6270 Hole angle of 16.75°@ TD Casinq/Tubin Proqram Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/FVD MD/TVD 7" 5-1/2" 15.5# L-80 Hyd-511 4587' 6043'/3702' 10630'/5922' 4-3/4" 3-1/2" 9.3# L-80 BTC-Mod 520' 10480'/5786' 11000'/6270' SC tubing 3-1/2" 9.3# L-80 E U E-mod 10480' Surf. 10480'/5786' General Mud Program Intermediate Mud Properties: LSND 7" hole section Density Viscosity Yield 10 sec 10 min pH APl HTH P (PPG) Point gel gel Filtrate Filtrate 9.1 - 9.4 45-50 16-22 4 - 7 6 - 8 8-9 4-6 10-13 Production Mud Properties: LSND 7" hole section Density Viscosity Yield 10 sec 10 min pH API~ HTHP (PPG) Point gel gel Filtrate Filtrate 11.7 45-50 28 - 33 8 - 12 10 - 15 9.5 4-6. 10-13 Drilling Fluid.System Triple Derrick Shale Shakers Pit Level Indicator (Visual and Audio Alarm) Desander, Desilter, Mud Cleaner Trip Tank Centrifuge Fluid Flow Sensor Degasser Fluid Aqitators Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.oRECEIVED · Well Proximity Risks: There are no close approach issues in this well plan. Directional · ;;..,~.. t)9 2000 Alaska 0il & Gas Cons. C0mmimi0n Anc~0ralle KOP: Maximum Hole Angle: Close Approach Well: Cement +6193' MD (estimated) 67° None First Stage Second Stage Casing/Liner Sx / Wt / Yield Sx / Wt ! Yield Comments 5-1/2" Drlg 622 / 15.8/1.2 None 150' liner lap, TOC 200' above TOL, Class Liner "G" cement, 50% excess in open hole 3-1/2" Prod. 75 / 15.8/1.2 None 150' liner lap, TOC 200' above TOL, Class Liner "G" cement, 50% excess in open hole Lo_Cl__Cli n __cl Program LWD Logging: 7" Hole 4-3/4" Hole Open Hole Logs (eline): 7" Hole 4-3/4" Hole Cased Hole Logs (eline): MWD / GR / Res Real Time MWD / GR / None GR / Res / Den-Neu None Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics for Nabors 16e are on file with AOGCC. Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a KOP leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11:.psi/ft. This shows that formation breakdown Would occur at.a surface pressure of 2,228 psi. .~ .. MAsP = (3777 ft)(0.70 -.0.11) ." - -- 2,228 psi · BaSed on Of[set well data, reservoir pressures in the Kuparuk sands in the vicinity of 1L pad are expected to be ~3,450 psi (0.58 psi/ft). Assuming a 150 psi oVerbalance is required'to safely drill and trip in this formation,, then a required mud weight of 11.7 ppg can be predicted as the maximum mud weight needed to safelY drill in this formation, assuming a :',TVD of 5950'. ' Target (Kuparuk C) (3450+1'50)/(0.052'5950)=11.7. Hazards · High .ECD's (in excess of 14 ppg) while drilling in the reservoir below the 5-1/2" casing will require a good. FIT test at the shoe. In addition, wellbore breathing and stuck pipe risks escalate at higher mud weights. C sand/A sand differential is 0.13 ppg and'is not anticipated to be a concern due to lower permeability in the A sand interval. · There is 1 known fault in the intermediate interval (~4619' TVD in the Colville Shale), anticipated to be 15' - 30" throw. Historically, faulting in shale intervals do not result in difficulties however, any lost circulation across the faults will be controlled with non-productive zone LCM pills. Stuck pipe mitigation efforts should be reviewed and in place prior to drilling this interval · There is one, small potential fault in the A4 interval. Although not identified with certainty, LCM pills may be required in the event losses are encountered. Stuck pipe mitigation efforts should be reviewed and in place prior to drilling this interval · Lost circulation across the fault, into the reservoir matrix, or wellbore "breathing" into exposed shales as a function of excessive ECD (equivalent circulating density). ECD will be controlled with flow rate and pipe rotation, and monitored with the addition of a PWD (pressure-while-drilling) sub in the BHA. Disposal Incidental fluids developed from drilling operations will be disposed down the 1L-28 annulus on the same pad. The 1L-28 open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The maximum volume of fluids to be pumped down the annulus of the 1L-28 well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe of 1 L-28 is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (3951') + 1,500 psi Max Pressure - 4,965 psi The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi NA 5,750 psi 4,888 psi 7" 26 L-80 3 LTC-IVlod 5,410 psi. 4,599 psi 7,240 psi' 6,154 psi 31/2''* 9.3 L-80. 2 .. 8rd EUE Hod 10,530 psi ' 8¢95:1. psi ' 10,160 psi 8'636 psi Fluids to be dispOsed of in the annulus will be limited to drilling wastes associated with'drilling a:well as defined in 20 AAC 25.080 (h). 1L-20a Short Well Summary Pre-Rig Work: NOTE: If any problems are observed with the 7" packoff during pre-rig operations, notify the Operations Drilling Engineer, Nabors 16e Company Representative and the wellhead manufacturer. Repairs will be made prior to initiation of rig work. 1. MIRU wireline and tag PBTD. TOC above BP estimated at 6290'. 2. Pressure test 10" x 7" casing packoff to 2000 psi. Test 7" casing to 3000 psi for 30 minutes. 3. Make gauge ring/junk basket run to PBTD. Ri_q 1. Work If unable to get down with gauge ring/junk basket during pre-rig operations, make a dummy mill run to 8600' MD. Otherwise, PU 7" CIBP on wire line, RIH and set @ 6198' MD. Test 7" and bridge plug to 3500 psi. 2. PU Baker Bottom Trip Anchor whipstock and BHA and RIH. Install ditch magnets in troughs. RIH to -6100' and establish string parameters. Continue in.hole to CIBP and orient and set base of whipstock @ 6193' MD. ', ~ ,. 3. Displace well to milling/drilling fluid. Shear whipstock bolt and begin milling window in 7". Mill until 29' of BHA is in..the open hole. Circulate well clean until no metal is seen in returns. Perform LOT to a minimum of 12.5 ppg. POOH and LD milling assembly." ' .. · 4. PU' 6,, x 7" bicenter bit and BHA and RIH. Displace Wellbore to new 9.0 ppg drilling fluid. Perform PWD baseline tests and drill 7" wellbore to the K1 marker at 10630' MD. Use MWD/GR/in real time for evaluation. CCM and TOOH for 5-1/2" liner. 5. Run 51/2" solid liner to TD and cement back to window. 6. PU 4-3/4" bit and BHA on 2-7/8" DP and RIH. Test liner to 3500 psi and drill landing and float collar. ' Displace well to new, 11.7 ppg LSND drilling fluid. Drill Kuparuk C sand and A sand targets to TD of 11000'. Run MWD/GR/Res/Den/Neu in real time for evaluation. CCM for 3-1/2" (special clearance) liner. 7. Run 3-1/2" solid liner to TD and cement back to window. R1/,, 8. Run v.2 L-80 standard Kuparuk gas lift completion. Circulate freeze protection to 2200'. Sting SBE into PBR on top of 3-1/2" liner top packer. 9. Set and test TWCV to 1000 psi. ND BOPE, NU Tree. Pull TWCV and set/test BPV. RDMO. TOC @ 629O' MD Bridge Plug @ 6657' MD TOC @ 10,778' MD Retainer @ 10,910' 7", 26#, J-55 casing 10,938' MD TOF @ 11,040' MD Bit, MWD, Collars 1 joint 5-1/2" L-80 Hyd 811 Liner, joints 5-1/2" L-80 Hyd 51 ! Liner, 5-1/2" Hyd 511 Float Shoe TD. @ 11,715'MD MAC 11/17/99 1 L-20A Proposed pletion 3-1/2' 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE 8rd pin down 3-1/2", 9 3#. L~80 EUE 8rd tubing to surface 3~1/2' Camco 'DS' landing nipple with 2,875" ID No-Go profile set at +/-500' MD Liner top and Whipstock Depth's are based on Original RKB to the hanger from the 7" Csg Detail, These depths are consistent with Nabors 16e RKB. 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to 'DS' landing nipple w/ 3-1/2" x 1" Camco 'KBMM' mandrels w/DV's, spaced out as follows: GLM# M~D TVD 1 TBD TBD 2 TBD TBD Note: Each GLM should have 6' L~80 handling pups installed on top and bottom. 5-1i2" liner top @ 9-5/8", 36#, 5-55 casing @ 6000' MD Sidetrack KOP @ +/-6i93~ MD CIBP @ 6198'MD TOC @ 6290' MD Bridge Plug @ 6657' MD Face Liner Top; Baker 6' Tieback Recepticle. Baker 5-1/2" x 7" 'CPH' Mechanical Set ~iner Top isolation Packer. Baker 5-1/2" x 7" 'HMC' Hydraulic Liner Nanger with 5-t/2" Hyd-511 pin down 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to 'DS' landing nipple w/ 3-t/2" x 1" Camco 'KBG-2-9' mandrels (Max O.D. 4.725", Min I.D. 2.90~') w/DV's, spaced out as follows: GLM# ~ TVD 3 TBD TBD 4 TBD TBD 5 TBD TBD 6 TBD TBD Note; Each GLM should have 6' L-80 handling pups installed on top and bottom, 3-1/2" Camco 'DS' landing hippie with 2.812" ID No Go Profile 1 joint 3-1/2" L-80 9.3# EUE 8rd Mod tubing, TOC @ 10,778' MD Retainer @ 10,910' 7', 26#, J-55 casing @ I0,938' MD TOF @ 11,040' MD Bit, MWD, Collars T.D, @ I1,715' MD Baker '45-40' special clearance PBR w/ 10' of effective stroke (4,80" O,D. w/40" ID. seal bore - seals 3,0" LDO, Model 'KBH' Anchor Seal Assembly made up on bottom (2,78" kD,) and 6' handling pup installed on top of PBR. 5-1/2" Hyd 5tl Landing Colb I joint 5-1/2" b80 Hyd-511 Liner 5-1/2" Nyd-511 Float Collar 2 joints 5q/2" L-80 Hy@511 Liner 5-t/2" Hyd-511 Float Shoe 5-1/2" 15.5# L-80 Hyde511 Liner @ +/-10,630' MD Future C / A Sand Perfs Baker 3-1/2" x 5" 'SABL*3' permanent packer run as liner top packer. (Minimum I.D, through packer 3-1/2" BTC-Mod Landing Collar t joint 3-1/2" L-80 BTC-Mod Liner 3-1/2" BTC-Mod Float Collar 2 joints 3-1/2' L-80 BTC-Mod Liner 3-1/2" BTC~Mod Float Shoe 3-!/2'~ L-80 BTC-Mod Liner @ +/-11,000' MD AI~ 3-1/2~' liner and equipment to be BTC-Mod Special Clearance! WBL/MAC/BDN 3f3/00 Plot Refmence ~s 20A Ve~on #6 . Coorcl;nates are ;n leet reference slot True Vert[cel Del~ths ore reference RKB (Nobors 16E). INTR~ ARCO Alaska, Inc. Structure: Pad 1L Well : 20A Field : Kuparuk River Unit Location : North Slope, Alaska 5600 4000 4400 4800 5200 56oo 6000 I 6400 6800 Sidetrack Pt.: 559' FSL, 643' FEL SEC. 29, T11N,RIOE East (feet) -> 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 I I I I AVERA(tE ANGLE ~ ~ 67.36 DEG ~ ~ ~ '~ .... I TARGET #1: I ~'%z'~ J 252' FNL, 2217' FEL DLS:DLS 3.003 O0 degdeg per~ ft ~ 482.4 42.25 36 26 TARGET #2: J · J 268' FNL, 2162' FEL I Begin ~ro; ZTurn ~/~ Top A6 ~ 12Ol Target-Top AS/EOC Top A4 T/ M~luveoch TD-Casing Pt 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 5600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 9200 Vertical Section (feet) -> · Azimuth 102.15 with reference 0.00 N, 0.00 E from slot #20A 800 400 ~ 0 " 400 ~ v 800 Crected by rlxse FOR: LLOYD Dote plotted: 15-Feb-2000 Plot Reference ie 20A Ve~ion t~6 . Coord~notes ere rn feet reference slot t~20A- True Vert~ccl Depths ore reference RKB (Nabors 16E IN'TE~ ARCO Alaska, Inc. Structure: Pad 1L Well : 20A Field : Kuparuk River Unit Looaflon: North Slope, Alaska East (feet) 5000 3300 5600 3900 4200 4500 4800 5100 5400 5700 6000 6300 6600 6900 7200 7500 7800 8100 9400 9700 9000 9300 9600 2100 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 I 2100 1800 .~'"~~ 1800  3300 1500 1500 , oo ~ / 5300 900 / 5700 ~---'""'"""~4900 ~ .... / 4900 4500 ~ 5300_~ ~ 4900 900 ~ ~ 4~00 ~ ~.49~0 ~ ~53....00 ~ ~5~00 600 600 900 ~ 900 ~~ 4500 1200 1200 ~:-, 5300 ~Tnn ,z ~-~ 6100 5300 5700 ~ 4900 'E~ 6100 5300 5700 ~5oo ~ -~ ~5oo 1 ~0 ~ , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , 1800 ~00 3300 3600 3900 4200 4500 4800 5100 5400 5700 6000 6300 6600 6900 7200 75~ 78~ 81~ 8400 8700 9000 9300 9600 East (feet) -> 6OO ~-- 300 o -i-- 0 Z 300 600 A I Z 300 0 o 300 330 320 ARCO Alaska, Inc. Structure : Pad 1L Well : 20A Field : Kuparuk River Unit Location : North Slope, Alaska 340 TRUE NORTH 350 0 10 711 2O 3O 4O 310 5O 300 6O 290 7O 280 8O 270 9O 260 100 250 110 240 120 230 220 210 200 1go 180 170 Normal Plane Travelling Cyl[nder- Feet 130 160 150 140 All depths shown (]re Measured depths on Reference Well Cre~ted by rlx~e FOR: LLOYD Dote plotted: 16-Feb-2000 Plot Reference Is 20A Version ~16 . Coordinote~ ore [n feet reference slot tI~20A. True Vertlcol Depths om reference RKB (Nobors 16E). ~NTEO Point Tie-In Survey Top of Whipstock Base of Whipstock Mill Bury Depth Begin 5 Deg/lO0' Bui EOC C80 Bgn Fnl Drp & Trn C50 C40 C30 1 C20 - Mid HRZ 1 Base HRZ 1 End Drop / Csg Pt 1 K- 1 Morker 1 Torget-Top C4 1 Begin Drop & Turn 1 Top C5 1 Top A6 1 Target-Top AS/EOC 1 Top A4 1 T/ Miluveach 1 TD-Casing Pt 1 ARCO Alaska, Inc. Sfrucfure: Pod 1L Well: 20A Field: Kuporuk River Unif Locofion : Norfh Slope, Alosko PROFILE COMMENT DATA MD Inc Dir TVD North East V. Sect 6179.02 65.90 87.60 5760.62 456.58 4417.82 4226.98 6180.01 65.90 87.58 3761.05 456.61 4418.71 4227.84 6195.00 64.59 89.65 5766.70 456.90 4450.41 4259.21 6209.00 65.44 92.1 5 5775.45 456.67 4444.91 4255.45 6209.02 65.44 92.15 3775.46 436.67 4444.95 4253.45 6521.1 6 67.36 102.15 5898.69 400.95 4728.22 4557.92 6605.09 67.56 102.15 5931.00 384.64 4803.95 4615.59 9162.56 67.56 102.15 4915.49 -112.21 711 t.23 6975.56 9505.07 57.08 102.57 5075.00 - 176.97 7407.03 7278.36 9891.15 45.51 105.17 5516.00 -245.85 7700.28 7579.11 051 0.26 32.95 104.18 5640.00 -306.05 7957.39 7845.56 0435.22 29.21 104.62 5747.00 -322.08 8019.87 7908.01 0554.64 26.25 105.05 5835.00 -535.91 8064.58 7954.21 0629.40 23.40 105.56 5921.00 -344.40 8102.94 7995.92 0630.49 23.40 105.56 5922.00 -344.52 8103.35 7994.35 0694.80 25.40 105.56 5981.02 -551.57 8127.96 8019.84 0694.82 25.40 105.56 5981.04 -551.57 8127.97 8019.85 0741.51 21.54 105.56 6024.00 -556.14 8145.08 8057.59 0845.27 17.58 105.56 6122.00 -565.42 8178.44 8072.15 0860.99 16.75 105.56 61 37.02 -366.66 8182.88 8076.75 0888.12 16.75 105.56 6165.00 -568.76 8190.41 8084.56 0958.25 16.75 105.56 6211.00 -572.64 8204.55 8098.98 1000.88 16.75 105.56 6270.98 -577.48 8221.72 8117.01 Deg/lO0 1.87 1.87 15.20 15.20 3.00 3.00 0.00 0.00 3.00 3.00 3.00 3.00 3.00 3.00 0.00 4.00 4.00 4.00 4.00 0.00 0.00 0.00 0.00 ARCO Alaska, Inc. Pad 1L 20A slot #20A Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 20A Version #6 Our ref : prop3807 License : Date printed : 15-Feb-2000 Date created : 7-Jan-2000 Last revised : 15-Feb-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 16 17.459,w149 40 33.55 Slot location is n70 16 18.482,w149 40 27.262 Slot Grid coordinates are N 5949074.064, E 540278.094 Slot local coordinates are 104.00 N 216.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1L,20A Kuparuk River Unit. North Slope. A1 Measured Inclin. Azimuth True Vert R Depth Degrees Degrees Depth C 6179.00 63.90 87.60 3760.61 6179.02 63.90 87.60 3760.62 6180.01 63.90 87.58 3761.05 6193.00 64.59 89.63 3766.70 6200.00 64.96 90.74 3769.68 6209.00 65.44 92.15 3773.45 6209.02 65.44 92.15 3773.46 6300.00 65.93 95.09 3810.93 6400.00 66.54 98.30 3851.23 6500.00 67.21 101.48 3890.52 aska ECTANGU LAR OORD I NATES 436.58 N 4417.81E 436.58 N 4417.82 E 436.61 N 4418.71 E 436.90 N 4430.41 E 436.88 N 4436.74 E 436.67 N 4444.91 E 436.67 N 4444.93 E 431.43 N 4527.66 E 420.75 N 4618.54 E 404.95 N 4709.12 E 6521.16 67.36 102.15 3898.69 400.95 N 4728.22 E 6605.09 67.36 102.15 3931.00 384.64 N 4803.95 E 7000.00 67.36 102.15 4083.03 307.92 N 5160.25 E 7500.00 67.36 102.15 4275.52 210.77 N 5611.38 E 8000.00 67.36 102.15 4468.00 113.63 N 6062.50 E 8500.00 67.36 102.15 4660.49 16.48 N 6513.62 E 9000.00 67.36 102.15 4852.98 80.66 S 6964.74 E 9162.36 67.36 102.15 4915.49 112.21 S 7111.23 E 9200.00 66.23 102.19 4930.32 119.50 S 7145.05 E 9300.00 63.23 102.31 4973.00 138.69 S 7233.41E 9400.00 60.23 102.43 5020.35 157.56 S 7319.43 E 9500.00 57.24 102.56 5072.25 176.05 S 7402.87 E 9505.07 57.08 102.57 5075.00 176.97 S 7407.03 E 9600.00 54.24 102.70 5128.54 194.11 S 7483.51 E 9700.00 51.24 102.85 5189.08 211.70 S 7561.12 E 9800.00 48.24 103.01 5253.70 228.77 S 7635.49 E 9891.15 45.51 103.17 5316.00 243.83 S 7700.28 E 9900.00 45.24 103.19 5322.22 245.27 S 7706.42 E 10000.00 42.25 103.38 5394.45 261.15 S 7773.71 E 10100.00 39.25 103.60 5470.20 276.37 S 7837.17 E 10200.00 36.26 103.85 5549.26 290.90 S 7896.65 E 10300.00 33.26 104.14 5631.40 304.68 S 7951.96 E 10310.26 32.95 104.18 5640.00 306.05 S 7957.39 E 10400.00 30.27 104.48 5716.42 317.69 S 8002.96 E 10435.22 29.21 104.62 5747.00 322.08 S 8019.87 E 10500.00 27.27 104.89 5804.07 329.88 S 8049.51 E 10534.64 26.23 105.05 5835.00 333.91S 8064.58 E 10600.00 24.28 105.39 5894.11 341.23 S 8091.48 E 10629.40 23.40 105.56 5921.00 344.40 S 8102.94 E 10630.49 23.40 105.56 5922.00 344.52 S 8103.35 E PROPOSAL LISTING Page 1 Your ref : 20A Version~/~ Last revised : 15-Feb-2000 Dogleg Vert Deg/lOOft Sect 0.00 4226.96 1.87 4226.98 Tie-In Survey 1.87 4227.84 Top of Whipstock 15.20 4239.21 Base of Whipstock 15.20 4245.41 15.20 4253.43 Mill Bury Depth 3.00 4253.45 Begin 3 Deg/lO0' Build & Turn 3.00 4335.44 3.00 4426.53 3.00 4518.40 3.00 4537.92 EOC 0.00 4615.39 C80 0.00 4979.86 0.00 5441.32 0.00 5902.78 0.00 6364.25 0.00 6825.71 0.00 6975.56 Bgn Fnl Drp & Trn 3.00 7010.15 3.00 7100.57 3.00 7188.63 3.00 7274.10 3.00 7278.36 C50 3.00 7356.73 3.00 7436.31 3.00 7512.60 3.00 7579.11 C40 3.00 7585.41 3.00 7654.54 3.00 7719.79 3.00 7780.99 3.00 7837.96 3.00 7843.56 C30 3.00 7890.56 3.00 7908.01 C20 - Mid HRZ 3.00 7938.63 3.00 7954.21 Base HRZ 3.00 7982.05 3.00 7993.92 End Drop / Csg Pt 0.00 7994.35 K-1 Marker 10694.78 23.40 105.56 5981.00 351.37 S 8127.95 E 0.00 10694.80 23.40 105.56 5981.02 351.37 S 8127.96 E 4.00 10694.82 23.40 105.56 5981.04 351.37 S 8127.97 E 4.00 10741.31 21.54 105.56 6024.00 356.14 S 8145.08 E 4.00 10779.76 20.00 105.56 6059.95 359.79 S 8158.21 E 4.00 8019.84 1L-20A T/C4 Rvsd 7-Jan-O0 8019.84 Target-Top C4 8019.85 Begin Drop & Turn 8037.59 Top C3 8051.20 10845.27 17.38 105.56 6122.00 365.42 S 8178.44 E 4.00 8072.15 Top A6 10860.97 16.75 105.56 6137.00 366.66 S 8182.87 E 4.00 8076.75 1L-20A T/A5 7-Jan-O0 10860.99 16.75 105.56 6137.02 366.66 S 8182.88 E 0.00 8076.75 Target-Top A5/EOC 10888.12 16.75 105.56 6163.00 368.76 S 8190.41E 0.00 8084.56 Top A4 10938.25 16.75 105.56 6211.00 372.64 S 8204.33 E 0.00 8098.98 T/ Miluveach All data is in feet unless otherwise stated. Coordinates from slot#20A and TVD from RKB (Nabors 16E) (121.00 Ft above mean sea level). Bottom hole distance is 8230.39 on azimuth 92.63 degrees from wellhead. Total Dogleg for wellpath is 64.45 degrees. Vertical section is from S 0.00 W 0.00 on azimuth 102.15 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L,20A Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 20A Version#6 Last revised : 15-Feb-2000 Dogleg Vert Deg/lOOft Sect 11000.00 16.75 105.56 6270.13 377.41S 8221.48 E 0.00 8116.75 11000.88 16,75 105.56 6270.98 377.48 S .8221.72 E 0.00 8117.01TD-Casing Pt 11000.90 16.75 105.56 6271.00 377,48 S 8221.73 E 0.00 8117.01 All data is in feet unless otherwise stated. Coordinates from slot#20A and TVD from RKB (Nabors 16E) (121.00 Ft above mean sea level). Bottom hole distance is 8230.39 on azimuth 92.63 degrees from wellhead. Total Dogleg for wellpath is 64.45 degrees. Vertical section is from S 0.00 W 0.00 on azimuth 102.15 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L,20A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 20A Version#6 Last revised : 15-Feb-2000 Comments in wellpath .... MD TVD Rectangular Coords. Comment 6179.02 3760 62 436.58 N 4417.82 E Tie-In Survey 6180.01 3761 6193.00 3766 6209.00 3773 6209.02 3773 6521.16 3898 6605.09 3931 9162.36 4915 9505.07 5075 9891.15 5316 10310.26 5640 10435.22 5747 10534.64 5835 10629.40 5921 10630.49 5922 10694.78 5981 10694.80 5981 10694.82 5981 10741.31 6024 10845.27 6122 10860.97 6137 10860.99 6137 10888.12 6163 10938.25 6211 11000.88 6270 05 436.61 N 4418.71 E Top of Whipstock 70 436.90 N 4430.41 E Base of Whipstock 45 436.67 N 4444.91 E Mill Bury Depth 46 436.67 N 4444.93 E Begin 3 Deg/lO0' Build & Turn 69 400.95 N 4728.22 E EOC O0 384.64 N 4803.95 E C80 49 112.21 S 7111.23 E Bgn Fnl Drp & Trn O0 176.97 S 7407.03 E C50 O0 243.83 S 7700.28 E C40 O0 306.05 S 7957.39 E C30 O0 322.08 S 8019.87 E C20 - Mid HRZ O0 333.91 S 8064.58 E Base HRZ O0 344.40 S 8102.94 E End Drop / Csg Pt O0 344.52 S 8103.35 E K-1 Marker O0 351.37 S 8127.95 E 1L-20A T/C4 Rvsd 7-Jan-O0 02 351.37 S 8127.96 E Target-Top C4 04 351.37 S 8127.97 E Begin Drop & Turn O0 356.14 S 8145.08 E Top C3 O0 365.42 S 8178.44 E Top A6 O0 366.66 S 8182.87 E 1L-20A T/A5 7-2an-O0 02 366.66 S 8182.88 E Target-Top A5/EOC .00 368.76 S 8190.41E Top A4 .00 372.64 S 8204.33 E T/ Miluveach .98 377.48 S 8221.72 E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 3760.61 436.58N 4417.81E 6180.00 3761.05 436.61N 4418.70E 7" Window n/a 3760.61 436.58N 4417.81E 11000.90 6271.00 377.48S 8221.73E Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1L~20A T/C4 Rvsd 7-J 548407.000,5948766.000,0.0000 5981.00 351.37S 8127.95E lO-May-1999 1L-20A T/A5 7-Jan-O 548462.000,5948751.000,0.0000 6137.00 366.66S 8182.87E 7-2an-2000 RECEIVED ARCO Alaska, Inc. Pad 1L, 20A Kuparuk River Unit,North Slope, A1 aska PROPOSAL LISTING Page 1 Your ref : 20A Version#6 Last revised : 15-Feb-2000 Measured Inclin Azimuth True Vert R E C TAN G U LA R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 6179,00 63.90 87.60 3760.61 6179.02 63.90 87.60 3760.62 6180.01 63.90 87.58 3761.05 6193.00 64.59 89.63 3766.70 6200,00 64.96 90.74 3769.68 6209.00 65.44 92.15 3773.45 6209.02 65.44 92.15 3773.46 6300.00 65.93 95.09 3810.93 6400.00 66.54 98.30 3851.23 6500.00 67.21 101.48 3890.52 436.58N 4417.81E 0.00 4226.96 544693.08 5949534.10 436.58N 4417.82E 1.87 4226.98 544693.10 5949534.11 436,61N 4418,71E 1.87 4227.84 544693.98 5949534.15 436.90N 4430.41E 15.20 4239.21 544705.68 5949534.49 436.88N 4436.74E 15.20 4245,41 544712.01 5949534.51 436.67N 4444.91E 15.20 4253.43 544720.18 5949534.34 436.67N 4444.93E 3.00 4253.45 544720.20 5949534.34 431.43N 4527.66E 3.00 4335.44 544802.95 5949529.55 420.75N 4618.54E 3.00 4426.53 544893.88 5949519.35 404.95N 4709,12E 3.00 4518.40 544984,53 5949504.03 6521.16 67.36 102.15 3898.69 6605.09 67.36 102.15 3931.00 7000.00 67.36 102.15 4083.03 7500.00 67.36 102.15 4275.52 8000.00 67.36 102.15 4468.00 400.95N 4728.22E 3.00 4537.92 545003.65 5949500.14 384.64N 4803.95E 0.00 4615.39 545079.46 5949484.23 307.92N 5160.25E 0,00 4979.86 545436,13 5949409,41 210.77N 5611.38E 0,00 5441.32 545887,72 5949314.68 113.63N 6062.50E 0.00 5902.78 546339.31 5949219.95 8500.00 67.36 102.15 4660.49 9000.00 67.36 102.15 4852.98 9162.36 67.36 102.15 4915.49 9200.00 66.23 102.19 4930.32 9300.00 63.23 102.31 4973.00 16.48N 6513.62E 0.00 6364.25 546790.90 5949125.21 80.66S 6964.74E 0.00 6825.71 547242.48 5949030.48 112.21S 7111.23E 0.00 6975.56 547389,13 5948999.72 119.50S 7145.05E 3.00 7010.15 547422.98 5948992.60 138.69S 7233.41E 3.00 7100.57 547511.43 5948973.89 9400.00 60.23 102.43 5020.35 9500.00 57.24 102.56 5072.25 9505.07 57.08 102.57 5075.00 9600.00 54.24 102.70 5128.54 9700.00 51.24 102.85 5189.08 157.56S 7319.43E 3.00 7188.63 547597.54 5948955.48 176.05S 7402,87E 3.00 7274.10 547681.07 5948937.44 176.97S 7407.03E 3.00 7278.36 547685.23 5948936.54 194.11S 7483.51E 3.00 7356.73 547761.80 5948919.81 211.70S 7561.12E 3.00 7436.31 547839.49 5948902.63 9800.00 48.24 103.01 5253.70 9891.15 45,51 103.17 5316.00 9900.00 45.24 103.19 5322.22 10000.00 42.25 103.38 5394.45 10100.00 39.25 103.60 5470.20 228.77S 7635.49E 3.00 7512.60 547913,94 5948885.96 243.83S 7700.28E 3.00 7579.11 547978.81 5948871.25 245.27S 7706.42E 3.00 7585.41 547984.95 5948869.84 261.15S 7773.71E 3.00 7654.54 548052.32 5948854.32 276.37S 7837.17E 3,00 7719.79 548115.86 5948839.44 10200.00 36.26 103.85 5549.26 10300.00 33.26 104.14 5631.40 10310.26 32.95 104.18 5640.00 10400.00 30.27 104.48 5716.42 10435.22 29.21 104.62 5747.00 290.90S 7896.65E 3.00 7780.99 548175.40 5948825.23 304,68S 7951.96E 3.00 7837.96 548230.78 5948811.74 306.05S 7957.39E 3.00 7843.56 548236.22 5948810.40 317.69S 8002.96E 3.00 7890.56 548281.85 5948799.01 322.08S 8019.87E 3.00 7908.01 548298.78 5948794.71 10500.00 27.27 104.89 5804.07 10534.64 26.23 105.05 5835.00 10600.00 24.28 105.39 5894.11 10629.40 23.40 105.56 5921.00 10630.49 23,40 105.56 5922.00 329.88S 8049.51E 3.00 7938.63 548328.46 5948787.06 333.91S 8064.58E 3.00 7954.21 548343.54 5948783.11 341.23S 8091.48E 3.00 7982.05 548370.48 5948775.94 344.40S 8102.94E 3.00 7993.92 548381.95 5948772.83 344.52S 8103.35E 0.00 7994.35 548382.37 5948772.72 10694.78 23.40 105.56 5981.00 10694.80 23.40 105.56 5981.02 10694.82 23.40 105.56 5981.04 10741.31 21.54 105.56 6024.00 10779.76 20.00 105,56 6059.95 351.37S 8127.95E 0.00 8019.84 548407.00 5948766.00 351.37S 8127.96E 4.00 8019.84 548407.01 5948766.00 351.37S 8127.97E 4,00 8019.85 548407.02 5948766.00 356.14S 8145.08E 4.00 8037.59 548424.16 5948761.32 359.79S 8158.21E 4.00 8051.20 548437.31 5948757.73 10845.27 17.38 105.56 6122.00 10860.97 16.75 105.56 6137.00 10860.99 16,75 105.56 6137.02 10888.12 16.75 105.56 6163.00 10938.25 16.75 105.56 6211.00 365.42S 8178.44E 4.00 8072.15 548457.56 5948752.21 366.66S 8182.87E 4.00 8076.75 548462.00 5948751.00 366.66S 8182.88E 0.00 8076.75 548462.01 5948751.00 368.76S 8190.41E 0.00 8084.56 548469.55 5948748.94 372.64S 8204.33E 0.00 8098.98 548483.49 5948745.14 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot#20A and TVD from RKB (Nabors 16E) (121.00 Ft above mean sea level), Bottom hole distance is 8230.39 on azimuth 92.63 degrees from wellhead. Total Dogleg for wellpath is 64.45 degrees, Vertical section is from S 0.00 W 0.00 on azimuth 102.15 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L,20A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 20A Version#6 Last revised : 15-Feb-2000 Measured Inclin Azimuth True Vert R E C TAN G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 11000.00 16.75 105.56 6270.13 377.41S 8221.48E 0.00 8116.75 548500.66 5948740.46 11000.88 16.75 105.56 6270.98 377.48S 8221.72E 0.00 8117.01 548500.90 5948740.39 11000.90 16.75 105.56 6271.00 377.48S 8221.73E 0.00 8117.01 548500.91 5948740.39 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot#20A and TVD from RKB (Nabors 16E) (121.00 Ft above mean sea level). Bottom hole distance is 8230.39 on azimuth 92.63 degrees from wellhead. Total Dogleg for wellpath is 64.45 degrees. Vertical section is from S 0.00 W 0.00 on azimuth 102.15 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L,20A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 20A Version t~i5 Last revised : 15-Feb-2000 Comments in wel 1 path MD TVD Rectangul ar Coords. Comment 6179.02 3760 62 436.58N 4417.82E Tie-In Survey 6180.01 6193.00 6209.00 6209.02 6521.16 6605.09 9162.36 9505.07 9891.15 10310.26 10435.22 10534.64 10629.40 10630.49 10694 78 10694 80 10694 82 10741 31 10845 27 10860 97 10860 99 10888 12 10938 25 11000 88 3761 05 3766 70 3773 45 3773 46 3898 69 3931 O0 4915 49 5075 O0 5316 O0 5640 O0 5747.00 5835.00 5921.00 5922.00 5981.00 5981.02 5981.04 6024.00 6122.00 6137.00 6137.02 6163.00 6211.00 6270.98 436.61N 4418.71E Top of Whipstock 436.90N 4430.41E Base of Whipstock 436.67N 4444.91E Mill Bury Depth 436.67N 4444.93E Begin 3 Deg/lO0' Build & Turn 400.95N 4728.22E EOC 384.64N 4803.95E C80 112~21S 7111.23E Bgn Fnl Drp & Trn 176.97S 7407.03E C50 243.83S 7700.28E C40 306.05S 7957.39E C30 322.08S 8019.87E C20 - Mid HRZ 333.91S 8064.58E Base HRZ 344.40S 8102.94E End Drop / Csg Pt 344.52S 8103.35E K-1 Marker 351.37S 8127.95E 1L-20A T/C4 Rvsd 7-Jan-O0 351.37S 8127.96E Target-Top C4 351.37S 8127.97E Begin Drop & Turn 356.14S 8145.08E Top C3 365.42S 8178.44E Top A6 366.66S 8182.87E 1L-20A T/A5 7-Jan-O0 366.66S 8182.88E Target-Top A5/EOC 368.76S 8190.41E Top A4 372.64S 8204.33E T/ Miluveach 377.48S 8221.72E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 3760.61 436.58N 4417.81E 6180.00 3761.05 436.61N 4418.70E 7" Window n/a 3760.61 436.58N 4417.81E 11000.90 6271.00 377.48S 8221.73E Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1L-20A T/C4 Rvsd 7-J 548407.000,5948766.000,0.0000 5981.00 351.37S 8127.95E lO-May-1999 1L-20A T/A5 7-Jan-O 548462.000,5948751.000,0.0000 6137.00 366.66S 8182.87E 7-Jan-2000 ARCO Alaska, Inc. Pad 1L,20A Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C 0 0 R D I N 6179.00 63.90 87.60 3760.61 436.58 N 6179.02 63.90 87.60 3760.62 436.58 N 6180.01 63.90 87.58 3761.05 436.61 N 6193.00 64.59 89.63 3766.70 436.90 N 6200.00 64.96 90.74 3769.68 436.88 N 6209.00 65.44 92.15 3773.45 436.67 N 6209.02 65.44 92.15 3773.46 436.67 N 6300.00 65.93 95.09 3810.93 431.43 N 6400.00 66.54 98.30 3851.23 420.75 N 6500.00 67.21 101.48 3890.52 404.95 N 6521.16 67.36 102.15 3898.69 400.95 N 6605.09 67.36 102.15 3931.00 384.64 N 7000.00 67.36 102.15 4083.03 307.92 N 7500.00 67.36 102.15 4275.52 210.77 N 8000.00 67.36 102.15 4468.00 113.63 N 8500.00 67.36 102.15 4660.49 16.48 N 9000.00 67.36 102.15 4852.98 80.66 S 9162.36 67.36 102.15 4915.49 112.21 S 9200.00 66.23 102.19 4930.32 119.50 S 9300.00 63.23 102.31 4973.00 138.69 S 9400.00 60.23 102.43 5020.35 157.56 S 9500.00 57.24 102.56 5072.25 176.05 S 9505.07 57.08 102.57 5075.00 176.97 S 9600.00 54.24 102.70 5128.54 194.11S 9700.00 51.24 102.85 5189.08 211.70 S 9800.00 48.24 103.01 5253.70 228.77 S 9891.15 45.51 103.17 5316.00 243.83 S 9900.00 45.24 103.19 5322.22 245.27 S 10000.00 42.25 103.38 5394.45 261.15 S 10100.00 39.25 103.60 5470.20 276.37 S 10200.00 36.26 103.85 5549.26 290.90 S 10300.00 33.26 104.14 5631.40 304.68 S 10310.26 32.95 104.18 5640.00 306.05 S 10400.00 30.27 104.48 5716.42 317.69 S 10435.22 29.21 104.62 5747.00 322.08 S 10500.00 27.27 104.89 5804.07 329.88 S 10534.64 26.23 105.05 5835.00 333.91S 10600.00 24.28 105.39 5894.11 341.23 S 10629.40 23.40 105.56 5921.00 344.40 S 10630.49 23.40 105.56 5922.00 344.52 S 10694.78 23.40 105.56 5981.00 351.37 S 10694.80 23.40 105.56 5981.02 351.37 S 10694.82 23.40 105.56 5981.04 351.37 S 10741.31 21.54 105.56 6024.00 356.14 S 10779.76 20.00 105.56 6059.95 359.79 S 10845.27 17.38 105.56 6122.00 365.42 S 10860.97 16.75 105.56 6137.00 366.66 S 10860.99 16.75 105.56 6137.02 366.66 S 10888.12 16.75 105.56 6163.00 368.76 S 10938.25 16.75 105.56 6211.00 372.64 S PROPOSAL LISTING Page 1 Your ref : 20A Version#6 Last revised : 15-Feb-2000 U L A R Vert Ellipse Semi Axes Minor A T E S Sect Major Minor Vert. Azi. 4417.81 E 4226.96 169.91 48.62 63.40 84.34 4417.82 E 4226.98 169.91 48.62 63.40 84.34 4418.71 E 4227.84 169.96 48.62 63.41 84.34 4430.41 E 4239.21 170.66 48.66 63.47 84.36 4436.74 E 4245.41 171.04 48.68 63.51 84.38 4444.91 E 4253.43 171.53 48.70 63.56 84.40 4444.93 E 4253.45 171.53 48.70 63.56 84.40 4527.66 E 4335.44 176.55 48.94 64.05 84.74 4618.54 E 4426.53 182.18 49.23 64.60 85.21 4709.12 E 4518.40 187.91 49.56 65.16 85.78 4728.22 E 4537.92 189.13 49.64 65.28 85.90 4803.95 E 4615.39 194.28 49.98 65.77 86.34 5160.25 E 4979.86 218.47 51.59 68.10 88.44 5611.38 E 5441.32 251.57 53.83 71.22 90.58 6062.50 E 5902.78 286.37 56.02 74.49 92.25 6513.62 E 6364.25 322.34 58.11 77.90 93.56 6964.74 E 6825.71 359.13 60.10 81.44 94.60 7111.23 E 6975.56 371.22 60.72 82.61 94.89 7145.05 E 7010.15 373.98 60.87 82.88 94.95 7233.41 E 7100.57 381.03 61.27 83.56 95.11 7319.43 E 7188.63 387.74 61.69 84.21 95.26 7402.87 E 7274.10 394.10 62.11 84.83 95.40 7407.03 E 7278.36 394.40 62.13 84.86 95.40 7483.51 E 7356.73 400.08 62.54 85.41 95.52 7561.12 E 7436.31 405.66 62.97 85.95 95.64 7635.49 E 7512.60 410.83 63.40 86.46 95.74 7700.28 E 7579.11 415.16 63.79 86.88 95.83 7706.42 E 7585.41 415.58 63.83 86.92 95.84 7773.71E 7654.54 419.90 64.26 87.34 95.92 7837.17 E 7719.79 423.79 64.67 87.71 96.00 7896.65 E 7780.99 427.26 65.07 88.05 96.07 7951.96 E 7837.96 430.32 65.46 88.35 96.13 7957.39 E 7843.56 430.59 65.50 88.37 96.14 8002.96 E 7890.56 432.98 65.84 88.61 96.19 8019.87 E 7908.01 433.77 65.96 88.69 96.20 8049.51E 7938.63 435.24 66.19 88.83 96.24 8064.58 E 7954.21 435.90 66.30 88.90 96.25 8091.48 E 7982.05 437.14 66.51 89.02 96.28 8102.94 E 7993.92 437.67 66.61 89.07 96.29 8103.35 E 7994.35 437.69 66.61 89.08 96.29 8127.95 E 8019.84 438.85 66.82 89.19 96.31 8127.96 E 8019.84 438.85 66.82 89.19 96.31 8127.97 E 8019.85 438.85 66.82 89.19 96.31 8145.08 E 8037.59 439.51 66.96 89.26 96.33 8158.21E 8051.20 440.06 67.07 89.32 96.34 8178.44 E 8072.15 440.78 67.24 89.40 96.36 8182.87 E 8076.75 440.95 67.28 89.41 96.36 8182.88 E 8076.75 440.95 67.28 89.41 96.36 8190.41 E 8084.56 441.25 67.35 89.45 96.37 8204.33 E 8098.98 441.80 67.49 89.51 96.38 All data is in feet unless otherwise stated. Coordinates from slot#20A and TVD from RKB (Nabors 16E) (121.00 Ft above mean sea level). Bottom hole distance is 8230.39 on azimuth 92.63 degrees from wellhead. Vertical section is from S 0.00 W 0.00 on azimuth 102.15 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L, 20A Kuparuk River Unit, North Slope, A1 aska PROPOSAL LISTING Page 2 Your ref : 20A Version#6 Last revised : 15-Feb-2000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 11000,00 16.75 105.56 6270.13 377.41S 11000.88 16,75 105.56 6270.98 377.48 S 11000.90 16.75 105.56 6271.00 377.48 S 8221.48 E 8116.75 442.48 67.65 89.58 96.39 8221.72 E 8117.01 442.49 67.65 89.58 96.39 8221.73 E 8117.01 442.49 67.65 89.58 96.39 POSITION UNCERTAINTY SUMMARY Depth Posi ti on Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 6179 Photomechanical Magnetic INTEQ ...... ~]~ .... ~i~ .... ~]~ 6179 11001 ARCO (H.A. Mag) User specified 442.49 67.65 89.58 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. RECEIVED ,,.Oc) ;. 2.000 Alaska Oil & Gas Cons. Commis ion ,Anchorage All data is in feet unless otherwise stated. Coordinates from slot#20A and TVD from RKB (Nabors 16E) (121.00 Ft above mean sea level). Bottom hole distance is 8230.39 on azimuth 92.63 degrees from wellhead. Vertical section is from S 0.00 W 0.00 on azimuth 102.15 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L,20A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 20A Version#6 Last revised : 15-Feb-2000 Comments in wellpath MD TVD Rectangul ar Coords. Comment 6179 6180 6193 6209 6209 6521 6605 9162 9505 9891 10310 10435 10534 10629 10630 10694 10694 10694 10741 10845 10860 10860 10888 10938 11000 02 3760.62 436.58 N 01 3761.05 436.61 N O0 3766.70 436.90 N O0 3773.45 436.67 N 02 3773.46 436.67 N 16 3898.69 400.95 N 09 3931.00 384.64 N 36 4915.49 112.21 S 07 5075.00 176.97 S 15 5316.00 243.83 S 26 5640.00 306.05 S 22 5747.00 322.08 S 64 5835.00 333.91 S 40 5921.00 344.40 S 49 5922.00 344.52 S 78 5981.00 351.37 S 80 5981.02 351.37 S 82 5981.04 351.37 S 31 6024.00 356.14 S 27 6122.00 365.42 S 97 6137.00 366.66 S 99 6137.02 366.66 S 12 6163.00 368.76 S 25 6211.00 372.64 S 88 6270.98 377.48 S 4417.82 4418.71 4430.41 4444.91 4444.93 4728.22 4803.95 7111.23 7407.03 7700.28 7957 39 8019 87 8064 58 8102 94 8103 35 8127 95 8127 96 8127 97 8145 08 8178 44 8182 87 8182 88 8190 41 8204 33 8221 72 E Tie-In Survey E Top of Whipstock E Base of Whipstock E Mill Bury Depth E Begin 3 Deg/lO0' Build & Turn E EOC E C80 E Bgn Fnl Drp & Trn E C50 E C40 E C30 E C20 - Mid HRZ E Base HRZ E End Drop / Csg Pt E K-1 Marker E 1L-20A T/C4 Rvsd 7-Jan-O0 E Target-Top C4 E Begin Drop & Turn E Top C3 E Top A6 E 1L-20A T/A5 7-Jan-O0 E Target-Top A5/EOC E Top A4 E T/ Miluveach E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 3760.61 436.58N 4417.81E 6180.00 3761.05 436.61N 4418.70E 7" Window n/a 3760.61 436.58N 4417.81E 11000.90 6271.00 377.48S 8221.73E Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1L-20A T/C4 Rvsd 7-~ 548407.000,5948766.000,0.0000 5981.00 351.37S 8127.95E lO-May-1999 1L-20A T/A5 7-2an-O 548462.000,5948751.000,0.0000 6137.00 366.66S 8182.87E 7-Jan-2000 ARCO Alaska, Inc. Pad 1L 20A slot #20A Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ REPORT Your ref : 20A Version#6 Our ref : prop3807 License : Date printed : 14-Feb-2000 Date created : 7-Jan-2000 Last revised : lO-Feb-2000 Field is centred on'n70 16 18.576,w150 5 56.536 Structure is centred on n70 16 17.459,w149 40 33.55 Slot location is n70 16 18.482,w149 40 27.262 Slot Grid coordinates are N 5949074.064, E 540278.094 Slot local coordinates are 104.00 N 216.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 2000 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-9353'>, PGMS <0-7478'> PGMS <0-10125'> PGMS <0-7810'> PGMS <0-9100'>, PGMS <0-6700'> PGMS <0-7668'> PGMS <0-8839'>, 19 PGMS <0-7830'>, 16 PGMS <0-6704'>, 15 PGMS <0-8103'>, 12 PGMS <0-9369'>, 11 PGMS <0-8470'> ,6 PGMS <0-7795'> ,5 PGMS <0-6721'>, 2 PGMS <0-7800'>,,18 PGMS <0-6469'>,,14 25 Pad 1L ,1Pad 1L ,9 Pad 1L ,8 Pad 1L 10 Pad 1L ,7 Pad 1L ,4 Pad 1L Pad 1L Pad 1L Pad 1L Pad 1L Pad 1L Pad 1L Pad 1L Pad 1L Pad 1L Pad 1L PGMS <O-12550'>,,21,Pad 1L PGMS <O-10176'>,,22,Pad 1L Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 28-0ct-1998 )5267.5( 6179.0 10467.6 9-May-1991 )5331.3( 6179.0 6179.0 9-May-1991 )1398.9( 6179.0 6179.0 9-May-1991 )1697.1( 6179.0 6179.0 9-May-1991 )687.0( 6179.0 6179.0 9-May-1991 )3534.0( 6179.0 6179.0 9-May-1991 )5031.8( 6179.0 6179.0 9-May-1991 )3293.1( 6179.0 6179.0 9-May-1991 )5404.7( 6179.0 6179.0 9-May-1991 )4806.0( 6179.0 6179.0 9-May-1991 )2327.3( 6179.0 6179.0 9-May-1991 )1485.8( 6179.0 9822.8 9-May-1991 )2469.8( 6179.0 9900.0 9-May-1991 )3916.9( 6179.0 6179.0 9-May-1991 )4668.0( 6179.0 6179.0 1-Ju1-1991 )4873.6( 6179.0 9811.4 1-Ju1-1991 )4453.4( 6179.0 6179.0 20-Jun-1991 )348.9( 10033.3 10033.3 9-May-1991 )2863.0( 6179.0 10343.9 PGMS <0-7950'>,,13,Pa( PGMS <O-8700'>,,17,Pad IL PGMS <0-9241'>,,24,Pad 1L PGMS <0-10345'>,,23,Pad 1L PGMS <O-8475'>,,3,Pad 1L PMSS <O-4285'>,,3PB1,Pad 1L PMSS <6116 - 7571'>,,3A,Pad 1L PMSS <0-11500'>,,20,Pad 1L PMSS <O-10065'>,,26,Pad 1L PGMS <O-12532'>,,20X,Pad 1L PMSS <0-11770'>,,28,Pad 1L 26A Version#8,,26A,Pad 1L 18-Feb-1999 )5148 18-Feb-1999 )5638 18-Feb-1999 )5655 18-Feb-1999 )5586 6-Apr-1999 )5430 6-Apr-1999 )5430 14-Ju1-1999 )5430 12-May-1991 )0 27-Jan-2000 )4520 22-0ct-1999 )0 30-Dec-1999 )1026 7-Feb-2000 )6067 3( 6179 2( 6179 4( 6179 9( 6179 5( 6179 5( 6179 6( 6179 O( 7020 8( 6179 O( 7140 3( 6179 O( 10694 0 0 0 0 0 0 0 0 0 0 0 8 6179.0 6179.0 10888.1 6179.0 6179.0 6179.0 6179.0 10478.4 9060.0 7140.0 10920.0 10694.8 ARCO Alaska, Inc. Pad 1L.20A Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 2 Your ref : 20A Version#6 Last revised : lO-Feb-2000 Reference wel 1 path Object wellpath : PGMS <O-10125'>,,9,Pad 1L M.D. T.V.D. Hori z Mi n' m E11 i pse Rect Coordinates M.D. T.V.D. Rect Coordi nates Bearing Di st Sep' n 6200.0 3769.7 6300.0 3810.9 6400.0 3851.2 6500.0 3890.5 6600.0 3929.0 436.9N 4436.7E 5874.4 3817.0 1973.5N 431.4N 4527.7E 5958.0 3863.8 2006.3N 420.8N 4618.5E 6033.6 3906,0 2036.3N 404.9N 4709.1E 6116.7 3952.2 2069.4N 385.6N 4799.4E 6193.2 3994.5 2099.9N 3577.6E 330.8 1761.1 )1406.0( 3638.6E 330.6 1809.2 )1446.6( 3693.7E 330.2 1862.3 )1492.7( 3754.4E 330.2 1919.8 )1542.6( 3810.3E 330.0 1980.3 )1595.8( 6700.0 3967.5 6800.0 4006.0 6900.0 4044.5 7000.0 4083.0 7100.0 4121.5 366.2N 4889.6E 6266.3 4035.0 2129.3N 346.8N 4979.8E 6343.5 4077.9 2160.4N 327.3N 5070.0E 6421.2 4120.9 2191.7N 307.9N 5160.3E 6499.3 4164.7 2223.2N 288.5N 5250.5E 6578.4 4210.2 2254.5N 3863.6E 329.8 2041.0 )1649.6( 3919.8E 329.7 2101.9 )1703.1( 3976.3E 329.6 2162.9 )1756.6( 4032.9E 329.5 2223.9 )1810,2( 4089.5E 329.4 2285.0 )1863.9( 7200.0 4160.0 7300.0 4198.5 269.1N 5340.7E 6657.5 4257.5 2285.2N 249.6N 5430.9E 6737.3 4305.0 2316.1N 4145.0E 329.3 2346.0 )1917.6( 4201.1E 329.2 2407.1 )1971.3( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot#20A and TVD from RKB (Nabors 16E) (121.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 92.48 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L,20A Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 3 Your ref : 20A Version#6 Last revised : lO-Feb-2000 Reference wel 1 path Object wellpath : PGMS <0-7810'>,,8,Pad 1L M.D. T.V.D. Rect Coordinates Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 6200.0 3769.7 436.9N 6300.0 3810.9 431.4N 6400.0 3851.2 420.8N 6500.0 3890.5 404.9N 6600.0 3929.0 385.6N 4436.7E 6026.0 4847.3 4527.7E 6107.4 4910.6 4618.5E 6190.8 4975.4 4709.1E 6270.0 5037.1 4799.4E 6347.0 5097.2 796.2N 2975.6E 283.8 1850.7 )1706.2( 808.8N 3025.2E 284.1 1899.7 )1752.9( 821.8N 3076.0E 284.6 1950.5 )1801.1( 834.3N 3124.0E 285.2 2002.9 )1850.7( 846.4N 3170.7E 285.8 2056.6 )1901.5( 6700.0 3967.5 366.2N 4889.6E 6409.7 5146.3 856.4N 3208.4E 286.3 2111.0 )1953.3( RECEIVED ',,~ 0 9 2000 Alaska Oil & Gas Cons. Commisiton Anchorage All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot#20A and TVD from RKB (Nabors 16E) (121.00 Ft above mean sea level), Vertical section is from wellhead on azimuth 92.48 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L,20A Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 4 Your ref : 20A Version¢~6 Last revised : lO-Feb-2000 Reference wellpath Object wellpath : PGMS <O-9100'>.,10,Pad 1L M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordi nates Bearing Di st Sep' n 6200.0 3769.7 6300.0 3810.9 6400.0 3851.2 6500.0 3890.5 6600.0 3929.0 436.9N 4436.7E 6244.6 4359.4 763.9N 431.4N 4527.7E 6325.8 4410.6 777.8N 420.8N 4618.5E 6421.4 4471.0 794.5N 404.9N 4709.1E 6513.7 4528.9 811.0N 385.6N 4799.4E 6605.9 4586.4 828.0N 3882.5E 300.5 872.9 )692.1( 3943.9E 300.7 905.7 )720.4( 4016.2E 301.8 941.6 )750.3( 4086.1E 303.1 980.1 )781.8( 4156,2E 304.5 1020.5 )814.5( 6700.0 3967.5 6800.0 4006.0 6900.0 4044.5 7000.0 4083.0 7100.0 4121.5 366.2N 4889.6E 6695.7 4642.0 844.8N 346.8N 4979.8E 6787.7 4698.6 862.3N 327.3N 5070.0E 6881.6 4756.1 880.4N 307.9N 5160.3E 6973.1 4811.6 898.1N 288.5N 5250.5E 7044.9 4855.4 912.3N 4224.7E 305.7 1061.1 )847.4( 4295.0E 307.0 1102.0 )880.3( 4367.1E 308.2 1142.9 )913.1( 4437.5E 309.2 1183.9 )945.9( 4492.7E 309.5 1225.5 )980.5( 7200.0 4160.0 7300.0 4198.5 7400.0 4237.0 7500.0 4275.5 7600.0 4314.0 269.1N 5340.7E 7115.2 4899.4 926.1N 249.6N 5430.9E 7204.0 4955.9 942.8N 230.2N 5521.2E 7294.6 5013.7 959.6N 210.8N 5611.4E 7385.1 5071.1 976.5N 191.3N 5701.6E 7474.9 5127.8 993.7N 4545.8E 309.6 1269.0 )1017.4( 4612.2E 310.3 1313.2 )1054.3( 4679.9E 310.9 1357.5 )1091.2( 4747.8E 311.6 1401.8 )1128.0( 4815.3E 312.2 1446.2 )1164.8( 7700.0 4352.5 7800.0 4391.0 7900.0 4429.5 8000.0 4468.0 8100.0 4506.5 171.9N 5791.8E 7541.7 5169.9 1006.9N 152.5N 5882.0E 7601.0 5207.9 1019.0N 133.1N 5972.3E 7676.0 5257.0 1034.5N 113.6N 6062.5E 7748.2 5305.2 1049.3N 94.2N 6152.7E 7836.9 5364.2 1067.7N 4865.5E 312.0 1491.1 )1203.6( 4909.4E 311.7 1537.6 )1244.8( 4963.8E 311.8 1585.7 )1286.6( 5015.5E 311.8 1634.8 )1329.9( 5079.2E 312.2 1684.0 )1372.1( 8200.0 4545.0 8300.0 4583.5 8400.0 4622.0 8500.0 4660.5 8600.0 4699.0 74.8N 6242.9E 7928.1 5424.4 1086.9N 55.3N 6333.2E 8011.3 5479.0 1104.7N 35.9N 6423.4E 8080.6 5524.9 1119.9N 16.5N 6513.6E 8135.2 5561.6 1132.1N 2.9S 6603.8E 8204.2 5608.1 1147.9N 5144.9E 312.7 1733.1 )1413.7( 5205.2E 312.9 1782.0 )1455.7( 5254.9E 312.8 1831.8 )1500.0( 5293.4E 312.4 1883.0 )1546.7( 5341.7E 312.4 1935.0 )1593.2( 8700.0 4737.5 8800.0 4776.0 8900.0 4814.5 9000.0 4853.0 9100.0 4891.5 22.4S 6694.1E 8288.3 5664.9 1167.7N 41.8S 6784.3E 8380.0 5726.4 1189.5N 61.2S 6874.5E 8453.8 5776.0 1206.9N 80.7S 6964.7E 8521.9 5822.9 1222.2N 100,1S 7055.0E 8590.1 5871.6 1235.7N 5400.5E 312.6 1987.3 )1638.7( 5465.0E 313.0 2039.6 )1683.4( 5516.8E 313.0 2091.9 )1729.8( 5563.8E 312.9 2145.0 )1777.9( 5609.5E 312.7 2198.7 )1827.2( 9200.0 4930.3 9300.0 4973.0 9400.0 5020.4 119.5S 7145.0E 8700.2 5953.0 1253.1N 138.7S 7233.4E 8782.9 6015.0 1264.0N 157.6S 7319.4E 8835.8 6055.0 1270.9N 5681.6E 313.2 2252.0 )1874.2( 5735.2E 313.1 2301.8 )1919.8( 5769.1E 312.7 2348.3 )1963.6( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot#20A and TVD from RKB (Nabors 16E) (121.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 92.48 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L,20A Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 5 Your ref : 20A VersionS6 Last revised : lO-Feb-2000 Reference wel 1 path Object wellpath : PGMS <0-9369'>..11.Pad 1L M.D. T.V.D. Rect Coordinates Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 6200 6300 6400 6500 6600 .0 3769.7 .0 3810.9 .0 3851.2 .0 3890.5 .0 3929.0 436.9N 4436.7E 431.4N 4527.7E 420.8N 4618.5E 404.9N 4709.1E 385.6N 4799.4E 6072.7 4306.5 1158.1S 3797.8E 201.8 1800.1 )1488.7( 6153.0 4355.2 1167.2S 3861.0E 202.6 1815.6 )1498.4( 6232.0 4403.2 1177.4S 3922.8E 203.5 1828.3 )1505.4( 6348.9 4474.2 1192.4S 4014.5E 203.5 1837.0 )1506.7( 6457.7 4540.3 1205.2S 4100.0E 203.7 1842.1 )1505.1( 6700 6800 6900 7000 7100 .0 3967.5 .0 4006.0 .0 4044.5 .0 4083.0 .0 4121.5 366.2N 4889 346.8N 4979 327.3N 5070 307.9N 5160 288.5N 5250 .6E 6563.3 4604.4 1216.8S 4183.1E 204.1 1846.8 )1503.4( .8E 6676.1 4672.8 1228.5S 4272.0E 204.2 1851.3 )1501.2( .OE 6781.9 4736.7 1238.6S 4355.7E 204.5 1855.2 )1499.1( .3E 6884.7 4798.7 1248.2S 4437.2E 204.9 1859.2 )1497.2( .5E 6987.3 4860.2 1257.6S 4518.7E 205.3 1863.2 )1495.5( 7200 7300 7400 7500 7600 .0 4160.0 269.1N 5340 .0 4198.5 249.6N 5430 .0 4237.0 230.2N 5521 .0 4275.5 210.8N 5611 .0 4314.0 191.3N 5701 .7E 7046.5 4896.1 1263.2S 4565.5E 206.8 1868.3 )1496.9( .9E 7090.8 4923.5 1268.3S 4599.9E 208.7 1876.3 )1502.2( .2E 7172.2 4974.8 1278.8S 4662.3E 209.6 1886.5 )1508.3( .4E 7261.8 5031.2 1290.4S 4730.9E 210.4 1897.3 )1514.7( .6E 7355.9 5090.4 1302.9S 4803.0E 211.0 1908.7 )1521.7( 7700.0 7800.0 7900.0 8000.0 8100.0 4352.5 171.9N 5791 4391.0 152.5N 5882 4429.5 133.1N 5972 4468.0 113.6N 6062 4506.5 94.2N 6152 .8E 7470.0 5162.1 1317.8S 4890.4E 211.2 1920.2 )1528.1( .OE 7562.1 5220.1 1329.0S 4961.1E 211.9 1931.4 )1535.3( .3E 7662.8 5283.6 1341.5S 5038.3E 212.3 1943.1 )1543.1( .5E 7765.7 5348.8 1353.3S 5117.1E 212.8 1954.9 )1551.1( .7E 7867.9 5413.6 1364.6S 5195.3E 213.3 1966.6 )1559.4( 8200.0 4545.0 74.8N 6242 8300.0 4583.5 55.3N 6333 8400.0 4622.0 35.9N 6423 8500.0 4660.5 16.5N 6513 8600.0 4699.0 2.9S 6603 .9E 8029.1 5514.0 1380.8S 5320.3E 212.4 1977.1 )1564.7( .2E 8140.4 5582.0 1390.3S 5407.8E 212.6 1985.7 )1570.1( .4E 8260.6 5655.4 1399.5S 5502.7E 212.7 1994.0 )1575.4( .6E 8358.4 5715.0 1406.0S 5579.9E 213.3 2001.8 )1581.0( .8E 8458.4 5775.8 1412.8S 5659.0E 213.8 2010.0 )1587.1( 8700.0 4737.5 22.4S 6694 8800.0 4776.0 41.8S 6784 8900.0 4814.5 61.2S 6874 9000.0 4853.0 80.7S 6964 9100.0 4891.5 100.1S 7055 .1E 8572.5 5845.3 1419.7S 5749.2E 214.1 2018.0 )1593.4( .3E 8676.3 5908.1 1425.2S 5831.7E 214.6 2025.6 )1599.6( .5E 8733.0 5942.0 1429.1S 5877.0E 216.1 2034.1 )1607.2( .7E 8775.5 5967.9 1432.7S 5910.5E 217.9 2045.2 )1618.0( .OE 8861.6 6021.0 1441.9S 5977.6E 218.8 2058.3 )1629.9( 9200.0 4930.3 119.5S 7145 9300.0 4973.0 138.7S 7233 9400.0 5020.4 157.6S 7319 9500.0 5072.2 176.0S 7402 9600.0 5128.5 194.1S 7483 .OE 8937.5 6066.9 1451.2S 6037.3E 219.8 2071.8 )1642.1( .4E 9008.4 6109.4 1461.9S 6093.1E 220.8 2083.9 )1652.4( .4E 9096.7 6161.3 1477.8S 6162.7E 221.2 2093.5 )1658.3( .9E 9172.2 6204.5 1493.6S 6222.6E 221.9 2100.2 )1660.9( .5E 9267.7 6258.1 1515.7S 6298.5E 221.9 2104.0 )1658.2( 9700.0 5189.1 211.7S 7561.1E 9800.0 5253.7 228.8S 7635.5E 9900.0 5322.2 245.3S 7706.4E 10000.0 5394.5 261.1S 7773.7E 10100.0 5470.2 276.4S 7837.2E 9367.4 6314.0 1538.9S 6377.7E 221.7 2104.2 )1650.9( 9369.0 6314.9 1539.3S 6378.9E 223.8 2103.0 )1649.5( 9369.0 6314.9 1539.3S 6378.9E 225.7 2102.9 )1649.9( 9369.0 6314.9 1539.3S 6378.9E 227.5 2103.9 )1652.1( 9369.0 6314.9 1539.3S 6378.9E 229.1 2105.9 )1656.1( 10200 10300 10400 10500 10600 .0 5549.3 290.9S 7896.6E 9369.0 .0 5631.4 304.7S 7952.0E 9369.0 .0 5716.4 317.7S 8003.0E 9369.0 .0 5804.1 329.9S 8049.5E 9369.0 .0 5894.1 341.2S 8091.5E 9369.0 6314.9 1539.3S 6378.9E 230.6 2109.1 )1661.8( 6314.9 1539.3S 6378.9E 231.9 2113.3 )1669.2( 6314.9 1539.3S 6378.9E 233.0 2118.5 )1678.2( 6314.9 1539.3S 6378.9E 234.1 2124.7 )1688.8( 6314.9 1539.3S 6378.9E 235.0 2132.0 )1700.8( 10700 10800 10900 11000 .0 5985.8 .0 6079.0 .0 6174.4 .0 6270.1 351.9S 8129.9E 9369.0 361.6S 8164.8E 9369.0 369.7S 8193.7E 9369.0 377.4S 8221.5E 9369.0 6314.9 1539.3S 6378.9E 235.9 2141.1 )1715.2( 6314.9 1539.3S 6378.9E 236.6 2152.1 )1732.1( 6314.9 1539.3S 6378.9E 237.2 2163.6 )1749.4( 6314.9 1539.3S 6378.9E 237.8 2178.8 )1771.0( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot#20A and TVD from RKB (Nabors 16E) (121.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 92.48 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L,20A Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 6 Your ref : 20A Version#6 Last revised : lO-Feb-2000 Reference wel 1 path Object wellpath : PGMS <0-12550'>,,21,Pad 1L M.D. T.V.D. Hori z Mi n' m E11 i pse Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 6200.0 6300.0 6400.0 6500.0 6600.0 3769.7 3810.9 3851.2 3890.5 3929.0 436.9N 4436.7E 5979.6 3662.9 958.1S 4102.1E 193.5 1438.5 )1054.8( 431.4N 4527.7E 6084.5 3715.2 982.9S 4189.6E 193.4 1457.3 )1062.8( 420.8N 4618.5E 6194.3 3767.9 1008.2S 4282.6E 193.2 1470.3 )1063.9( 404.9N 4709.1E 6305.5 3818.2 1033.3S 4378.5E 192.9 1477.5 )1058.7( 385.6N 4799.4E 6421.6 3867.1 1058.6S 4480.6E 192.4 1480.2 )1047.8(. 6700.0 6800.0 6900.0 7000.0 7100.0 3967.5 4006.0 4044.5 4083.0 4121.5 366.2N 4889.6E 6527.6 3910.0 1081.0S 4575.0E 192.3 1482.1 )1036.9( 346.8N 4979.8E 6632.1 3952.2 1102.8S 4668.1E 192.1 1483.6 )1025.9( 327.3N 5070.0E 6748.7 3999.9 1126.2S 4771.8E 191.6 1484.5 )1012.9( 307.9N 5160.3E 6884.5 4058.3 1151.2S 4891.9E 190.4 1483.8 )996.7( 288.5N 5250.5E 7005.4 4111.3 1170.8S 4998.8E 189.8 1480.9 )979.7( 7200.0 7300.0 7400.0 7500.0 7600.0 4160.0 4198.5 4237.0 4275.5 4314.0 269.1N 5340.7E 7111.7 4156.3 1187.3S 5093.6E 189.6 1477.2 )963.3( 249.6N 5430.9E 7220.2 4201.7 1203.7S 5190.8E 189.4 1473.0 )946.0( 230.2N 5521.2E 7329.3 4247.1 1219.4S 5288.7E 189.1 1468.1 )928.0( 210.8N 5611.4E 7434.9 4290.8 1234.1S 5383.8E 189.0 1462.7 )909.6( 191.3N 5701.6E 7539.3 4333.5 1248.3S 5478.0E 188.8 1457.0 )890.8( 7700.0 7800.0 7900.0 8000.0 8100.0 4352.5 4391.0 4429.5 4468.0 4506.5 171.9N 5791.8E 7650.9 4378.5 1262.9S 5579.1E 188.4 1450.8 )870.9( 152.5N 5882.0E 7756.7 4420.7 1276.3S 5675.1E 188.2 1444.0 )850.8( 133.1N 5972.3E 7865.1 4464.3 1289.4S 5773.5E 188.0 1436.7 )830.1( 113.6N 6062.5E 7977.1 4509.7 1302.1S 5875.1E 187.5 1428.6 )808.5( 94.2N 6152.7E 8085.5 4553.8 1313.4S 5973.5E 187.3 1419.7 )786.2( 8200.0 8300.0 8400.0 8500.0 8600.0 4545.0 4583.5 4622.0 4660.5 4699.0 74.8N 6242.9E 8192.1 4596.6 1323.9S 6070.6E 187.0 1410.2 )763.4( 55.3N 6333.2E 8300.1 4639.5 1334.2S 6169.1E 186.7 1400.3 )740.1( 35.9N 6423.4E 8405.0 4680.5 1343.7S 6265.2E 186.5 1389.9 )716.3( 16.5N 6513.6E 8507.8 4720.6 1352.8S 6359.5E 186.4 1379.2 )692.4( 2.9S 6603.8E 8609.5 4760.1 1361.5S 6452.7E 186.3 1368.3 )668.2( 8700.0 8800.0 8900.0 9000.0 9100.0 4737.5 4776.0 4814.5 4853.0 4891.5 22.4S 6694.1E 8713.3 4800.5 1370.1S 6548.0E 186.2 1357.1 )643.8( 41.8S 6784.3E 8817.3 4841.0 1378.4S 6643.4E 186.0 1345.6 )619.0( 61.2S 6874.5E 8919.0 4880.3 1386.3S 6736.9E 185.9 1333.8 )593.9( 80.7S 6964.7E 9021.2 4919.3 1394.1S 6831.0E 185.8 1321.9 )568.6( 100.1S 7055.0E 9125.7 4958.9 1401.6S 6927.4E 185.6 1309.5 )542.8( 9200.0 9300.0 9400.0 9500.0 9600.0 4930.3 4973.0 5020.4 5072.2 5128.5 119.5S 7145.0E 9227.5 4996.8 1408.8S 7021.7E 185.5 1296.9 )516.7( 138.7S 7233.4E 9329.2 5033.6 1415.8S 7116.2E 185.2 1283.9 )490.2( 157.6S 7319.4E 9429.1 5069.2 1422.6S 7209.3E 185.0 1270.8 )463.7( 176.0S 7402.9E 9529.3 5105.0 1429.3S 7302.7E 184.6 1257.7 )437.7( 194.1S 7483.5E 9629.8 5140.9 1435.6S 7396.3E 184.0 1244.6 )412.9( 9700.0 9800.0 9900.0 10000.0 10100.0 5189.1 5253.7 5322.2 5394.5 5470.2 211.7S 7561.1E 9728.5 5176.0 1441.6S 7488.4E 183.4 1232.1 )390.1( 228.8S 7635.5E 9823.9 5209.8 1447.2S 7577.3E 182.7 1220.6 )370.8( 245.3S 7706.4E 9920.6 5244.3 1452.5S 7667.6E 181.8 1210.4 )356.9( 261.1S 7773.7E 10014.2 5277.9 1457.3S 7754.7E 180.9 1202.0 )349.6( 276.4S 7837.2E 10102.3 5309.3 1461.7S 7837.0E 180.0 1196.2 )350.7( 10200.0 10300.0 10400.0 10500.0 10600.0 5549.3 5631.4 5716.4 5804.1 5894.1 290.9S 7896.6E 10187.2 5339.1 1465.7S 7916.3E 179.0 1193.6 )361.6( 304.7S 7952.0E 10265.2 5366.1 1469.4S 7989.5E 178.2 1195.1 )382.8( 317.7S 8003.0E 10341.1 5392.0 1473.0S 8060.7E 177.1 1201.4 )414.4( 329.9S 8049.5E 10416.4 5417.1 1476.6S 8131.6E 175.9 1213.0 )455.7( 341.2S 8091.5E 10497.7 5444.7 1480.1S 8208.0E 174.2 1229.9 )505.3( 10700.0 10800.0 10900.0 11000.0 5985.8 6079.0 6174.4 6270.1 351.9S 8129.9E 10567.3 5468.6 1482.9S 8273.3E 172.8 1251.8 )559.8( 361.6S 8164.8E 10676.9 5507.7 1486.4S 8375.6E 169.4 1279.1 )621.9( 369.7S 8193.7E 10778.9 5547.8 1487.6S 8469.4E 166.1 1310.9 )687.4( 377.4S 8221.5E 10856.7 5580.4 1488.0S 8540.1E 164.0 1345.6 )751.4( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot#20A and TVD from RKB (Nabors 16E) (121.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 92.48 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska. Inc. Pad 1L, 20A Kuparuk River Unit. North Slope, A1 aska CLEARANCE LISTING Page 7 Your ref : 20A Version#6 Last revised : lO-Feb-2000 Reference wel 1 path Object wellpath : PMSS <0-11500'>,,20,Pad 1L M.D. T.V.D. Rect Coordinates M.D. T.V.D. Hori z Mi n' m E11 i pse Rect Coordi nates Bearing Di st Sep' n 6200.0 3769.7 6300.0 3810.9 6400.0 3851.2 6500.0 3890.5 6600.0 3929.0 436.9N 4436.7E 6204.0 3769.8 431.4N 4527.7E 6303.1 3813.6 420.8N 4618.5E 6400.1 3856.5 404.9N 4709.1E 6494.6 3898.5 385.6N 4799.4E 6586.5 3939.4 437.4N 4436.6E 348.9 0.6 )0.0( 443.5N 4525.4E 349.2 12.5 )0.0( 452.5N 4611.8E 348.1 32.9 )0.0( 464.2N 4695.7E 347.2 61.3 )0.0( 478.4N 4776.8E 346.3 96.0 )0.0( 6700.0 3967.5 6800.0 4006.0 6900.0 4044.5 7000.0 4083.0 7100.0 4121.5 366.2N 4889.6E 6678.2 3981.2 346.8N 4979.8E 6768.9 4023.9 327.3N 5070.0E 6859.0 4067.7 307.9N 5160.3E 6950.6 4111.8 288.5N 5250.5E 7041.5 4154.3 493.8N 4856.9E 345.6 132.5 )0.0( 509.9N 4935.2E 344.7 170.0 )0.0( 526.6N 5012.3E 343.8 208.7 )0.0( 544.2N 5090.5E 343.6 248.1 )0.0( 562.4N 5168.8E 343.4 287.7 )6.2( 7200.0 4160.0 7300.0 4198.5 7400.0 4237.0 7500.0 4275.5 7600.0 4314.0 269.1N 5340.7E 7132.7 4195.5 249.6N 5430.9E 7222.6 4235.0 230.2N 5521.2E 7312.6 4274.2 210.8N 5611.4E 7402.2 4313.4 191.3N 5701.6E 7491.5 4352.6 581.1N 5248.0E 343.4 327.5 600.2N 5326.5E 343.4 367.6 619.6N 5405.1E 343.4 408.1 639.4N 5483.2E 343.4 448.9 659.3N 5561.0E 343.3 490.2 )16.5( )29.6( )44.9( )63.5( )85.9( 7700.0 4352.5 7800.0 4391.0 7900.0 4429.5 8000.0 4468.0 8100.0 4506.5 171.9N 5791.8E 7580.5 4391.7 152.5N 5882.0E 7669.1 4430.9 133.1N 5972.3E 7759.9 4471.1 113.6N 6062.5E 7853.3 4512.6 94.2N 6152.7E 7947.0 4554.3 679.5N 5638.3E 343.2 531.8 )111.5( 700.ON 5715.2E 343.0 573.8 )139.6( 721.1N 5793.7E 343.1 616.0 )168.1( 742.5N 5874.6E 343.4 657.9 )196.2( 763.6N 5955.8E 343.6 699.4 )224.8( 8200.0 4545.0 8300.0 4583.5 8400.0 4622.0 8500.0 4660.5 8600.0 4699.0 74.8N 6242.9E 8040.1 4595.8 55.3N 6333.2E 8132.3 4636.6 35.9N 6423.4E 8224.6 4677.2 16.5N 6513.6E 8313.8 4716.0 2.9S 6603.8E 8399.5 4752.9 784.3N 6036.5E 343.8 740.7 )254.1( 804.6N 6116.7E 343.9 781.7 )283.9( 824.9N 6197.1E 344.0 822.7 )313.8( 844.6N 6275.0E 343.9 863.6 )344.8( 864.0N 6349.7E 343.7 905.1 )377.5( 8700.0 4737.5 8800.0 4776.0 8900.0 4814.5 9000.0 4853.0 9100.0 4891.5 22.4S 6694.1E 8484.6 4789.4 41.8S 6784.3E 8569.2 4825.3 61.2S 6874.5E 8668.1 4867.2 80.7S 6964.7E 8775.0 4912.5 100.1S 7055.0E 8874.7 4954.9 883.9N 6424.1E 343.4 947.1 )410.8( 904.3N 6497.9E 343.2 989.8 )444.9( 928.1N 6584.3E 343.6 1032.4 )474.6( 952.6N 6677.9E 344.5 1074.0 )501.5( 974.2N 6765.6E 344.9 1114.4 )529.6( 9200.0 4930.3 9300.0 4973.0 9400.0 5020.4 9500.0 5072.2 9600.0 5128.5 119.5S 7145.0E 8967.6 4994.5 993.7N 6847.2E 345.0 1154.1 )559.0( 138.7S 7233.4E 9046.3 5028.4 1010.7N 6916.3E 344.6 1193.6 )591.5( 157.6S 7319.4E 9131.1 5065.1 1029.5N 6990.4E 344.5 1232.6 )621.7( 176.0S 7402.9E 9215.4 5101.8 1048.7N 7063.8E 344.5 1271.1 )651.5( 194.1S 7483.5E 9302.4 5139.9 1068.9N 7139.3E 344.8 1309.1 )680.0( 9700.0 5189.1 9800.0 5253.7 9900.0 5322.2 10000.0 5394.5 10100.0 5470.2 211.7S 7561.1E 9392,2 5179.4 1089.8N 7217.3E 345.2 1346.2 )706.9( 228.8S 7635.5E 9481.2 5218.6 1110.5N 7294.5E 345.7 1382.4 )733.5( 245.3S 7706.4E 9562.4 5254.4 1129.3N 7364.9E 346.0 1418.0 )761.6( 261.1S 7773.7E 9634.9 5286.3 1146.6N 7427.6E 346.2 1453.7 )792.3( 276.4S 7837.2E 9705.0 5317.1 1164.3N 7488.1E 346.4 1490.2 )825.0( 10200.0 5549.3 10300.0 5631.4 10400.0 5716.4 10500.0 5804.1 10600.0 5894.1 290.9S 7896.6E 9772.6 5346.6 1182.1N 7546.2E 346.6 1527.6 )859.7( 304.7S 7952.0E 9822.3 5368.2 1195.7N 7588.9E 346.4 1566,0 )900.7( 317.7S 8003.0E 9923.7 5412.1 1224.2N 7675.7E 348.0 1605.4 )930.6( 329.9S 8049.5E 10099.0 5489.8 1266.5N 7827.1E 352.1 1642.1 )944.2( 341.2S 8091.5E 10175.1 5523.7 1282.4N 7893.2E 353.0 1677.1 )978.6( 10700.0 5985.8 10800.0 6079.0 10900.0 6174.4 11000.0 6270,1 351.9S 8129.9E 10248.3 5556.0 1297.5N 7957.2E 354.0 1713.3 )1015.7( 361.6S 8164.8E 10318.6 5586.7 1311.9N 8018.8E 355.0 1750.6 )1055.8( 369.7S 8193.7E 10379.4 5612.9 1324.4N 8072.2E 355.9 1788.8 )1099.6( 377.4S 8221.5E 10435,3 5637.8 1336.3N 8120.8E 356.6 1829.5 )1147,1( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot#20A and TVD from RKB (Nabor$ 16E) (121.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 92.48 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ M.D, 6200.0 6300.0 6400.0 6500.0 6600.0 6700.0 6800.0 6900.0 7000.0 7100.0 7200.0 7300.0 7400.0 7500.0 7600.0 7700.0 7800.0 7900.0 8000.0 8100.0 8200.0 8300.0 8400.0 8500.0 8600.0 8700.0 8800.0 8900.0 9000.0 9100.0 9200.0 9300.0 9400.0 9500.0 9600.0 9700.0 98OO.0 9900.0 10000.0 10100.0 10200.0 10300.0 10400.0 10500.0 10600.0 10700.0 10800.0 10900.0 11000.0 ARCO Alaska, Inc. Pad 1L,20A Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 8 Your ref : 20A Version#6 Last revised : lO-Feb-2000 Reference wel 1 path Object wellpath : PGMS <O-12532'>,,20X,Pad 1L T.V.D. Hori z Mi n' m E11 i pse Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Di st Sep' n 3769.7 3810.9 3851.2 3890.5 3929.0 436.9N 4436.7E 6324.7 3809.4 652.4N 4398.0E 349.8 222.5 )0.0( 431.4N 4527.7E 6426.3 3852.2 660.3N 4489.7E 350.6 235.6 )0.0( 420.8N 4618.5E 6524.4 3893.3 667.6N 4578.4E 350.8 253.6 )0.0( 404.9N 4709.1E 6621.1 3933.7 675.0N 4666.1E 350.9 276.9 )0.0( 385.6N 4799.4E 6715.6 3973.1 682.6N 4751.6E 350.9 304.0 )0.0( 3967. 4006. 4044. 4083. 4121. 366.2N 4889.6E 6806.8 4011.8 690.6N 4833.8E 350.2 332.2 )0.0( 346.8N 4979.8E 6898.0 4051.4 699.6N 4915.5E 349.7 361.5 )0.0( 327.3N 5070.0E 6991.3 4092.4 709.7N 4998.7E 349.4 391.9 )0.0( 307.9N 5160.3E 7093.4 4136.5 720.5N 5090.1E 350.3 421.9 )0.0( 288.5N 5250.5E 7192.6 4178.1 729.7N 5179.7E 350.9 450.4 )0.0( 4160.0 269.1N 5340.7E 7290.4 4218.4 738.5N 5268.3E 351.2 478.6 )1.5( 4198.5 249.6N 5430.9E 7390.5 4258.7 747.1N 5359.6E 351.8 506.1 )8.7( 4237.0 230.2N 5521.2E 7487.6 4296.7 755.1N 5448.5E 352.1 533.2 )15.4( 4275.5 210.8N 5611.4E 7581.7 4333.4 763.0N 5534.8E 352.1 560.5 )24.1( 4314.0 191.3N 5701.6E 7676.6 4370.4 771.3N 5621.9E 352.2 588.2 )35.1( 4352 4391 4429 4468 4506 .5 171.9N 5791.8E 7770.7 4406.9 779.8N 5708.1E 352.2 616.0 )47.4( .0 152.5N 5882.0E 7864.1 4443.0 788.5N 5793.8E 352.1 644.2 )61.0( .5 133.1N 5972.3E 7956.3 4478.6 797.5N 5878.5E 352.0 672.8 )75.9( .0 113.6N 6062.5E 8048.0 4513.7 806.9N 5962.7E 351.8 701.9 )91.8( .5 94.2N 6152.7E 8141.6 4549.2 817.1N 6048.7E 351.8 731.6 )107.6( 4545 4583 4622 4660 4699 74.8N 6242.9E 8233.3 4583.4 827.5N 6133.1E 351.7 761.7 )124.7( 55.3N 6333.2E 8324.6 4617.2 838.3N 6217.3E 351.6 792.2 )142.4( 35.9N 6423.4E 8416.2 4650.7 849.6N 6301.7E 351.5 823.2 )160.6( 16.5N 6513.6E 8507.5 4683.7 861.1N 6386.1E 351.4 854.5 )179.1( 2.9S 6603.8E 8598.3 4716.2 873.1N 6469.9E 351.3 886.4 )198.6( 4737 4776 4814 4853 4891 .5 22.4S 6694.1E 8686.7 4747.8 885.4N 6551.6E 351.1 918.9 )219.5( .0 41.8S 6784.3E 8803.7 4789.8 900.6N 6659.8E 352.5 950.7 )230.4( .5 61.2S 6874.5E 8897.3 4823.9 911.6N 6746.2E 352.5 981.3 )248.1( .0 80.7S 6964.7E 8987.0 4856.5 922.5N 6829.1E 352.3 1012.3 )267.4( .5 100.1S 7055.0E 9076.3 4888.7 933.9N 6911.6E 352.1 1043.8 )287.3( 4930 4973 5020 5072 5128 .3 119.5S 7145.0E 9165.6 4920.8 945.6N 6994.1E 351.9 1075.8 )307.6( .0 138.7S 7233.4E 9255.2 4952.7 957.8N 7076.9E 351.9 1107.7 )327.9( .4 157.6S 7319.4E 9349.0 4986.3 970.8N 7163.5E 352.1 1139.6 )347.2( .2 176.0S 7402.9E 9442.1 5021.4 983.6N 7248.9E 352.4 1170.9 )366.9( .5 194.1S 7483.5E 9527.9 5053.8 995.7N 7327.3E 352.5 1202.4 )389.6( 5189.1 211.7S 7561.1E 9612.6 5085.5 1008.1N 7404.8E 352.7 1234.1 )413.8( 5253.7 228.8S 7635.5E 9699.3 5118.1 1021.2N 7484.2E 353.1 1266.3 )439.1( 5322.2 245.3S 7706.4E 9782.3 5149.3 1034.0N 7560.0E 353.5 1299.1 )467.7( 5394.5 261.1S 7773.7E 9863.5 5179.8 1046.7N 7634.2E 353.9 1332.7 )499.1( 5470.2 276.4S 7837.2E 9944.5 5210.1 1059.7N 7708.2E 354.5 1367.2 )533.4( 5549.3 5631.4 5716.4 5804.1 5894.1 290.9S 7896.6E 10020.2 5238.5 1072.1N 7777.1E 355.0 1403.1 )572.4( 304.7S 7952.0E 10097.0 5268.6 1085.2N 7846.6E 355.7 1440.3 )613.9( 317.7S 8003.0E 10173.4 5300.3 1098.7N 7914.9E 356.4 1478.9 )658.4( 329.9S 8049.5E 10248.2 5332.7 1112.3N 7980.8E 357.3 1518.9 )705.6( 341.2S 8091.5E 10319.2 5363.4 1125.4N 8043.5E 358.1 1560.4 )756.6( 5985.8 6079.0 6174.4 6270.1 351.9S 8129.9E 10386.2 5392.2 1137.8N 8102.7E 359.0 1603.9 )811.3( 361.6S 8164.8E 10450.0 5419.3 1149.9N 8159.2E 359.8 1649.2 )869.4( 369.7S 8193.7E 10504.5 5442.2 1160.2N 8207.6E 0.5 1696.1 )932.2( 377.4S 8221.5E 10564.5 5467.3 1171.8N 8260.8E 1.5 1745.3 )995.8( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from $1ot#20A and TVD from RKB (Nabors 16E) (121.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 92.48 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L,20A Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 9 Your ref : 20A Version~i5 Last revised : lO-Feb-2000 Reference wellpath Object wellpath : PMSS <0-11770'>,.28,Pad 1L M.D. T.V.D. Horiz Min'm Ellipse Rect Coordi nates M.D. T.V.D. Rect Coordi nates Bearing Di si~ Sep' n 6200.0 3769.7 6300.0 3810.9 6400.0 3851.2 6500.0 3890.5 6600.0 3929.0 436.9N 4436.7E 5953.0 3342.5 1814.1N 3995.5E 342.2 1508.0 )1031.6( 431.4N 4527.7E 6040.9 3380.5 1848.6N 4066.8E 342.0 1551.2 )1062.9( 420.8N 4618.5E 6104.4 3406.7 1874.1N 4118.7E 341.0 1599.9 )1102.7( 404.9N 4709.1E 6199.1 3445.3 1912.4N 4196.2E 341.2 1653.4 )1143.0( 385.6N 4799.4E 6281.1 3479.0 1945.2N 4263.3E 341.0 1709.4 )1187.2( 6700.0 3967.5 6800.0 4006.0 6900.0 4044.5 7000.0 4083.0 7100.0 4121.5 366.2N 4889.6E 6340.9 3503.5 1969.4N 4312.2E 340.2 1766.0 )1235.1( 346.8N 4979.8E 6397.7 3526.6 1993.2N 4358.5E 339.3 1823.9 )1284.7( 327.3N 5070.0E 6472.4 3556.8 2024.9N 4418.9E 339.0 1882.4 )1332.6( 307.9N 5160.3E 6549.8 3588.4 2057.9N 4481.3E 338.8 1941.2 )1380.2( 288.5N 5250.5E 6655,2 3631.8 2102.8N 4566.3E 339.3 2000.0 )1424.0( 7200.0 4160.0 7300.0 4198,5 7400.0 4237.0 7500.0 4275.5 7600.0 4314.0 269.1N 5340.7E 6813.4 3699.1 2165.6N 4694.9E 341.2 2055.8 )1457.8( 249.6N 5430.9E 6872.2 3724.6 2188.5N 4742.7E 340.5 2111.3 )1504.4( 230.2N 5521.2E 7001.8 3781.9 2238.6N 4847.6E 341.5 2166.6 )1541.6( 210.8N 5611.4E 7103.0 3825.4 2275.6N 4931.1E 341.8 2220.2 )1580.8( 191.3N 5701.6E 7168.7 3853.2 2300.0N 4985,5E 341.2 2274,1 )1624.8( 7700.0 4352.5 7800.0 4391.0 7900.0 4429.5 8000.0 4468.0 8100.0 4506.5 171.9N 5791.8E 7246.4 3886.3 2329.2N 5049.4E 341.0 2328.6 )1668.0( 152.5N 5882.0E 7350.3 3931.4 2367.8N 5134.6E 341.4 2382.8 )1707.4( 133.1N 5972.3E 7416.7 3960.3 2392.4N 5189.2E 340.9 2436.8 )1751.4( 113.6N 6062.5E 7474.9 3984.7 2414.5N 5237.2E 340.3 2491.8 )1797.6( 94.2N 6152.7E 7560.3 4020.3 2447.3N 5307.5E 340.2 2547.1 )1840.5( 8200.0 4545.0 8300.0 4583.5 8400.0 4622.0 74.8N 6242.9E 7650.0 4058.4 2481.4N 5381.3E 340.3 2602.1 )1882.6( 55.3N 6333.2E 7713.7 4085.8 2505.9N 5433.2E 339.8 2657.6 )1928.6( 35.9N 6423.4E 7797.1 4122.2 2538.7N 5500.8E 339.8 2713.8 )1972,8( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot#20A and TVD from RKB (Nabors 16E) (121.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 92,48 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L 20A slot #20A Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 20A Version#6 Our ref : prop3807 License : Date printed : 15-Feb-2000 Date created : 7-Jan-2000 Last revised : lO-Feb-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 16 17.459,w149 40 33.55 Slot location is n70 16 18.482,w149 40 27.262 Slot Grid coordinates are N 5949074.064, E 540278.094 Slot local coordinates are 104.00 N 216.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path PGMS <O-9353'>,,25,Pad 1L PGMS <O-7478'>,,1,Pad 1L PGMS <0-10125'>,,9,Pad 1L PGMS <0-7810'>,,8,Pad 1L PGMS <0-9100'>,,lO,Pad 1L PGMS <0-6700'> PGMS <0-7668'> PGMS <0-8839'>, PGMS <0-7830'>, PGMS <0-6704'>, PGMS <0-8103'>, PGMS <0-9369'>, PGMS <0-8470'> PGMS <0-7795'> PGMS <0-6721'> PGMS <0-7800'>, PGMS <0-6469'>, PGMS <0-12550'> PGMS <0-10176'> PGMS <0-7950'>, PGMS <0-8700'>, PGMS <0-9241'>, PGMS <0-10345'> PGMS <0-8475'> ,7,Pad 1L ,4,Pad 1L 19,Pad 1L 16,Pad 1L 15,Pad 1L 12,Pad 1L 11,Pad 1L ,6,Pad 1L ,5,Pad 1L ,2,Pad 1L 18,Pad 1L 14,Pad 1L ,21,Pad 1L ,22,Pad 1L 13,Pad 1L 17,Pad 1L 24,Pad 1L ,23,Pad 1L ,3,Pad 1L PMSS <0-4285'>,,3PB1,Pad 1L PMSS <6116 - 7571'>,,3A,Pad 1L PMSS <O-11500'>,,20,Pad 1L Closest approach with 3-D Minimum Distance method Last revised Di 28-0ct-1998 9-May-1991 9-May-1991 9-May-1991 9-May-1991 9-May-1991 9-May-1991 9-May-1991 9-May-1991 9-May-1991 9-May-1991 9-May-1991 9-May-1991 9-May-1991 9-May-1991 1-Ju1-1991 1-~u1-1991 20-~un-1991 9-May-1991 18-Feb-1999 18-Feb-1999 18-Feb-1999 18-Feb-1999 6-Apr-1999 6-Apr-1999 14-Ju1-1999 12-May-1991 stance 5353.6 5363.8 1752.4 1841.1 867.2 3645.6 5113.2 3550.6 5439.4 4876.5 2548.6 1795.8 2725.4 4084 7 4731 9 4988 7 4549 3 1193 6 3164 0 5197 8 5669 9 5700 3 5630 3 5464 9 5464 9 5464 9 O0 M,D. 6179.0 6179.0 6179.0 6179.0 6179.0 6179.0 6179.0 6179.0 6179 0 6179 0 6179 0 6179 0 6179 0 6179 0 6179 0 6179 0 6179 0 10222 2 6179 0 6179 0 6179 0 6179 0 6179 0 6179 0 6179 0 6179 0 6179 0 Diverging from M.D. 6179 0 6179 0 6179 0 6179 0 6179 0 6179 0 6179 0 6179 0 6179 0 10853 1 6179.0 9857.0 6179.0 6179.0 6179.0 6179.0 6179.0 10222.2 6179.0 6179.0 6179.0 6179.0 11000.9 6179.0 6179.0 6179.0 6179.0 PMSS <0-10065'>,,26,P~ PGMS <0-12532'>,,20X,Paa 1~ PMSS <0-11770'>,,28,Pad 1L 27-Jan-2000 22-0ct-1999 30-Dec-1999 4718.9 221.1 1500.2 6179.0 6179.0 6179.0 6179.0 6179.0 6179.0 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 March 2, 2000 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill: KRU 1L-20a Surface Location: 104' FSL 216' FWL Sec 29 T11N RIOE, UI~! Target Location: 252' FNL, 2217' FEL Sec. 33, T11N, RIOE, UM Bottom Hole Location: 279' FNL, 2123' FEL Sec. 33, T11N, RIOE, UM Dear Commissioner Christenson, ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1L 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 1L pad. The well ~is designated as a conventional sidetracked produCtion well, exiting from the existing 7" intermediate casing of the 1L-26 :well. A 5-1/2" intermediate liner will be run and cemented. A 4-3/4" wellbore will then be drilled through the Kuparuk Cand... A sand targets and a 3-1/2" solid production liner/:,will be run and cemented." The .... :well will be completed with 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) 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. 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 encountered in this well. However, H2S monitoring equipment willBl~l...~,~_,. functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. AJaska Oil & Gas Cons. Commission Anchor~e Robert Christenson Application for Permit to Drill - 1L-20a Page 2 9) 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 Meg Kremer, Geologist 265-6460 The anticipated spud date for this well is March 30, 2000. If you have any questions or require further information, please contact Bill Lloyd at (907) 265- 6531 or Chip Alvord at (907) 265-6120. · Senior Drilling Engineer CC: Kuparuk J.L-20a Well File Chip Alvord ATO-1030 Jeff Corwith ATO-1284 PO Box1., :;.~ :02776 AnChorage, AK 995 (''Amount Not To Exceed $25.,000.00") To the order o[: o3-o9-oo STATE OF ALASK~ Date kL~SB'~ OIL L GAS CONSERVATION COM~M. ISS,_'~DN 3001 PORCUPINE DRIVE ~NCHOR3kGE AK 99501 '* .... '"''*'''I00.00' Amoun[ Void after 90 days ~ Two s gnatures required '") for amounts over $5,000.00 WELL PERMIT CHECKLIST ,,// COMPANY WELL NAME //._. -~z~/---/ PROGRAM: exp ,~ dev ~/redrll __ serv ~ wellbore seg ann. disposal para req ~ FIELD & POOL INIT CLASS ?'- ~/d___- GEOL AREA ADMINISTRATION . 2. 3. 4. 5. . 7. 8. 9. 10. 11. Il A P~P~I~ DATE 12. I ._~/") ~)../o.E~ 13. I~ENGINEERING 14. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... ._.~ DATE GEOLOGY N (~ (~N (~N .... i ~!N ( Y~N Y~N ~N ~U DATE Y 15. Surface casing protects all known USDWs ........... Y 16. CMT vol adequate to circulate on conductor & surf csg ..... Y 17. CMT vol adequate to tie-in long string to surf csg ........ ~ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to -~;;~(~L_~ psig. 27. Choke manifold complies w/APl RP-53 (May 8~) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... / ~(~ N 31. Data presented on potential overpressure zones ...... .,~.~ Y N ~'~ UNIT# ~////C/~_~ ON/OFF SHORE 32. Seismic analysis of shallow gas zones ............ ,,~;~. Y N 33. Seabed condition survey (if off-shore) ............ ~/-7' y N 34. Contact name/phone for weekly progress reports [exploratory only~]/Y/? N · ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (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 GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Comments/Instructions: O Z O ITl Z -! '1' mali Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX, ., No 'special'effort has been made to chronologically organize this category of information. .o Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Jul 28 13:01:12 2000 Reel Header Service name ............. LISTPE Date ..................... 00/07/28 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 ..................... 00/07/28 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: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD MWD RUN 2 AK-MM-00003 P. SMITH G. WHITLOCK 1ST STRING 1L-20A 500292202701 ARCO Alaska, Inc. Sperry Sun 19-JUL-00 MWD RUN 3 AK-MM-00003 TOM MCGUIRE FRED HERBERT 29 lin Ri0 104 216 120.50 120.50 86.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.500 7.000 6191.0 RECEIVED 01 Alask~ Oil & Gas Cons. Commisslo_n ~;hora~e 2ND STRING 4.750 5.500 10491.0 3RD STRING 4.750 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN t IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 2, 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL OF D. SCHWARTZ (7-13-00) OWING TO LACK OF PARENT WELL TIE-IN. MWD DATA FOR THIS WELL IS CONSIDERED PDC. KICKOFF POINT FROM THE PARENT WELL IS AT 6191~MD, 3765VTVD. 5. MWD RUNS 1-3 REPRESENT WELL 1L-20A WITH API#: 50-029-22027-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10935'MD, 6325'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. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/28 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 6139.0 ROP 6222.5 RPD 10480.0 RPM 10480.0 RPS 10480.0 RPX 10480.0 FET 10480.0 $ STOP DEPTH 10871 0 10934 5 10885 5 10885 5 10885 5 10885 5 10885 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ # REMARKS: BIT RUN NO MERGE TOP MERGE BASE 2 6139.0 10491.0 3 10491.0 10935.0 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DE?T FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 6139 10934.5 8536.75 9592 ROP MWD FT/H 1.18 2527.43 92.477 9425 GR MWD API 53.34 514.08 126.377 9465 RPX MWD OHMM 0.87 1298.18 11.4165 812 RPS MWD OHMM 1.06 2000 60.8922 812 RPM MWD OHMM 1.03 1984.33 40.2839 812 RPD MWD OHMM 1.14 1984.32 40.5444 812 FET MWD HR 2.0172 127.39 9.47865 812 First Reading 6139 6222.5 6139 10480 10480 10480 10480 10480 Last Reading 10934.5 10934.5 10871 10885.5 10885.5 10885.5 10885.5 10885.5 First Reading For Entire File .......... 6139 Last Reading For Entire File ........... 10934.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/28 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 ....... 00/07/28 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: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6139.0 10407.5 ROP 6222.5 10491.0 $ # LOG HEADER DATA DATE LOGGED: 01-APR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: .41 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10491.0 TOP LOG INTERVAL {FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 26.5 MAXIMUM ANGLE: 70.5 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: TOOL NUMBER 65041 6.500 6191.0 LSND 9.10 47.0 9.5 1900 5.8 .000 .000 .000 .000 .0 118.0 .0 .0 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 ...................... -999.25 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 MWD020 FT/H 4 1 68 4 2 GR MWD020 A?I 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 6139 10491 8315 8705 ROP MWD020 FT/H 2.78 2527.43 99.7827 8538 GR MWD020 API 53.37 514.08 129.533 8538 First Reading 6139 6222.5 6139 Last Reading 10491 10491 10407.5 First Reading For Entire File .......... 6139 Last Reading For Entire File ........... 10491 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/28 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 ....... 00/07/28 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: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10408.0 10871.0 RPD 10480.0 10885.5 RPM 10480.0 10885.5 RPS 10480.0 10885.5 RPX 10480.0 10885.5 FET 10480.0 10885.5 ROP 10491.5 10934.5 $ 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 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: 07-APR-00 Insite .43 Memory 10935.0 20.8 24.9 TOOL NUMBER 74165 74165 4.750 10491.0 Water Based 12.00 52.0 10.5 1700 3.4 1.000 .520 .560 1.450 68.0 136.9 68.0 68.0 $ 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 10408 10934.5 ROP MWD030 FT/H 1.18 190.92 GR MWD030 API 53.34 251.65 RPX MWD030 OHMM 0.87 1298.18 RPS MWD030 OHMM 1.06 2000 RPM MWD030 OHMM 1.03 1984.33 RPD MWD030 OHMM 1.14 1984.32 FET MWD030 HR 2.0172 127.39 Mean 10671.3 22.1543 97.3123 11.4165 60.8922 40.2839 40.5444 9.47865 First Last Nsam Reading Reading 1054 10408 10934.5 887 10491.5 10934.5 927 10408 10871 812 10480 10885.5 812 10480 10885.5 812 10480 10885.5 812 10480 10885.5 812 10480 10885.5 First Reading For Entire File .......... 10408 Last Reading For Entire File ........... 10934.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/07/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 00/07/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File