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201-161
RECEIVED STATE OF ALASKA AAA OIL AND GAS CONSERVATION COMMION NOV 17 2017 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ AC)( te shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Cony ESP to jet pump D 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development l Exploratory ❑ 201-161 • 3.Address: P. O. Box 100360,Anchorage, Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-029-23037-00 7.Property Designation(Lease Number): 8.Well Name and Number: KfZU 1C-102 ADL 25649 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,570 feet Plugs measured 5849 feet true vertical 3,753 feet Junk measured None feet Effective Depth measured 10,551 feet Packer measured 5793, 6042 feet 3,753 feet true vertical 3626, 3715 feet Casing Length Size MD TVD Burst Collapse Conductor 121 feet 16 " 161' MD 161 TVD Surface 6,477 feet 7 5/8" 6,518' MD 3801 TVD B-Sand Liner 4,509 feet 4 " 10,551' MD 3753 TVD Perforation depth Measured depth 6547-10466 feet True Vertical Depth 3802-3752 feet • Tubing(size,grade,measured and true vertical depth) 3.5" L-80 5,893' MD 3,662'TVD Packers and SSSV(type,measured and true vertical depth) PACKER= BAKER 47D2 FHL 5,793' MD 3,626'TVD PACKER=BAKER SCR-1 Liner Top Packer 6,042' MD 3,715'TVD SSSV: NONE N/A • 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED DEC 222017 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut-In Shut-In Shut-In Shut-In Shut-In Subsequent to operation: Shut-In Shut-In Shut-In Shut-In Shut-In 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-452 Contact Name: Ron Phillips Authorized Name: Ron Phillips Contact Email: Ron.L.Phillips©cop.com Authorized Title: Senior Wells Engineer RBDv/IS , 1 7 2011 Contact Phone: (9 �/) 65-6312 Authorized Signature: y p� r Date: /�S/J Fnrm 1n-&na A��av--car&/9n17 Cnhmit Original Only 0-1--/ -17-j/7--2 , (l/M;/ • • Operations Summary (with Timelog Depths) 1C-102 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK8) End Depth(ftKB)' 10/15/2017 10/15/2017 1.00 MIRU MOVE RURD P Prep rig floor to skid. Move support 0.0 0.0 02:00 03:00 trailers from around rig and stage on pad. 10/15/2017 10/15/2017 1.00 MIRU MOVE RURD P PJSM. Skid rig floor to moving 0.0 0.0 03:00 04:00 position. 10/15/2017 10/15/2017 2.00 MIRU MOVE MOB P PJSM. Move the rig off of well 1C-109 0.0 0.0 04:00 06:00 and stage on the pad. 10/15/2017 10/15/2017 2.00 MIRU MOVE RURD P PU mats from around 1C-109 and set 0.0 0.0 06:00 08:00 mats around 1C-102. 10/15/2017 10/15/2017 2.50 MIRU MOVE MOB P PJSM. Move and spot the rig over 0.0 0.0 08:00 10:30 well 1C-102. Shim up the rig and set down. 10/15/2017 10/15/2017 1.00 MIRU MOVE RURD P PJSM. Skid the rig floor into drilling 0.0 0.0 10:30 11:30 position. Spot and berm the cutting box. 10/15/2017 10/15/2017 2.50 MIRU MOVE RURD P Install the boiler and generator 0.0 0.0 11:30 14:00 exhaust stacks on the roof. Install the cutting auger chute. Secure stairs and landing. Set the beaver slide. RU the gas buster u-tube and blooey lines. *Rig accepted at 14:00 hours* 10/15/2017 10/15/2017 3.00 MIRU WELCTL RURD P RU circulating lines for the well kill 0.0 0.0 14:00 17:00 operations. Load the pits with 8.5 ppg 3%KCI. 10/15/2017 10/15/2017 1.50 MIRU WELCTL KLWL P 0 psi on IA and tubing.Test lines to 0.0 0.0 17:00 18:30 2500 psi.Reverse circulate110 bbls filtered 8.5 ppg 3%KCL brine.6 bpm, 1100 psi.No returns. 10/15/2017 10/15/2017 0.25 MIRU WELCTL KLWL P Bullhead 30 bbls filtered 8.5 ppg 3% 0.0 0.0 18:30 18:45 KCL brine down tubing.4 bpm,540 psi. 10/15/2017 10/15/2017 1.25 MIRU WELCTL OWFF P Monitor well. No pressure or returns 0.0 0.0 18:45 20:00 from tubing. IA had 75-100 psi w,steady flow to flow back tank.Flow back 40 bbls of diesel. 10/15/2017 10/15/2017 1.50 MIRU WELCTL MPSP T Investigate and discover that BPV had 0.0 0.0 20:00 21:30 not been pulled. Rig up lubricator and test to 1500 psi.Pull BPV.25 psi on tubing. 10/15/2017 10/15/2017 0.50 MIRU WELCTL KLWL T Reverse circulate110 bbls filtered 8.5 0.0 0.0 21:30 22:00 ppg 3%KCL brine.6 bpm,450 psi.58 bbls returns to flow back tank. 10/15/2017 10/15/2017 0.25 MIRU WELCTL KLWL T Bullhead 50 bbls filtered 8.5 ppg 3% 0.0 0.0 22:00 22:15 KCL brine down tubing.5 bpm,550 psi. 10/15/2017 10/15/2017 1.00 MIRU WELCTL OWFF T Monitor well. IA=325 psi Tbg=300 psi 0.0 0.0 22:15 23:15 with both dropping to 75 psi in 30 mins.Bleed off 13 bbls from IA and tbg to 0 psi with no flow in 15 mins. 10/15/2017 10/16/2017 0.75 MIRU WELCTL OWFF P IA and tubing on slight vacuum. 0.0 0.0 23:15 00:00 Perform fluid level shots.Fluid at-30' on both tubing and IA.Sim-ops/Blow down lines. 10/16/2017 10/16/2017 0.75 MIRU WELCTL OWFF P Continue to monitor pressures in IA 0.0 0.0 00:00 00:45 and tbg.Both on slight vacuum.Take second fluid level shot.Tbg at-48' and IA at-30'. 10/16/2017 10/16/2017 0.25 MIRU WHDBOP MPSP P Install HP BPV and test dart. 0.0 0.0 00:45 01:00 Page 1/9 Report Printed: 11/1/2017 • S Operations Summary (with Timelog Depths) 1C-102 Conoccehiiiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P T X Operation (ftKB)', End Depth(ftKE) 10/16/2017 10/16/2017 1.00 MIRU WHDBOP NUND P ND the tree and tubing head adapter. 0.0 0.0 01:00 02:00 Nipple up 13-5/8"spacer spool. 10/16/2017 10/16/2017 3.50 MIRU WHDBOP NUND P Nipple up BOP stack. NU the kill line. 0.0 0.0 02:00 05:30 Center the BOP stack. Install the riser. 10/16/2017 10/16/2017 2.50 MIRU WHDBOP RURD P Clean up the cellar. MU the floor 0.0 0.0 05:30 08:00 valves and top drive crossover for testing. Grease the IBOP. RU to test BOPE. Shell test the BOP stack to 250/2500 psi(good test). 10/16/2017 10/16/2017 7.00 MIRU WHDBOP BOPE P Conduct initial BOPE test: test 3-1/2" 0.0 0.0 08:00 15:00 x 6"VBR's(upper pipe rams)to 250/2500 psi with 3-1/2"and 5-1/2" test joints;test 3-1/2"x 6"VBR's (lower pipe rams)to 250/2500 psi with 3-1/2"and 5-1/2"test joints;test annular to 250/2500 with 3-1/2"and 5- 1/2"test joints;conducted Koomey drawdown test(all tested passed). The tests were witnessed by AOGCC inspector Brian Bixby. Tests: 1) 3-1/2"x 6"VBR's(lower pipe rams) with 3-1/2"test joint(Passed) 2) Annular with 3-1/2"test joint,upper IBOP,3"Demco(valve 20),choke valves 1, 12, 13&14(Passed) 3) 3-1/2"x 6"VBR's(upper pipe rams)with 3-1/2"test joint,lower IBOP,kill HCR,choke valves 9&11 (Passed) 4) Manual kill,4"HT-38 FOSV,choke valves 5,8&10(Passed) 5) 4"HT-38 dart valve,choke valves 4,6&7(Passed) 6) 3-1/2"EUE 8rd FOSV,choke valve 2(Passed) 7) Blind rams,choke valves 1 &3 (Passed) 8) 3-1/2"x 6"VBR's(lower pipe rams) with 5-1/2"test joint(Passed) 9) Annular with 5-1/2"test joint (Passed) 10) 3-1/2"x 6"VBR's(upper pipe rams)with 5-1/2"test joint(Passed) 11) Super choke(Passed) 12) Choke HCR(Passed) 13) Manual choke(Passed) 14) Adjustable choke(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3050 psi Accumulator Pressure After Closer= 1750 psi Pressure Gain of 200 psi=42 seconds Full System=195 Seconds Average N2(6 Bottles)=2075 psi 10/16/2017 10/16/2017 1.00 MIRU WHDBOP RURD P RD BOPE testing equipment.Blow 0.0 0.0 15:00 16:00 down choke and kill lines. Page 2/9 Report Printed: 11/1/2017 = Operations Summary (with Timelog Depths) 1C-102 conatiiii;ps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Tune End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK8) End Depth(ftKE)'; 10/16/2017 10/16/2017 0.50 MIRU WHDBOP MPSP P Make up T-bar.Pull test dart.Pull 0.0 0.0 16:00 16:30 BPV.Set isolation sleeve. 10/16/2017 10/16/2017 1.00 COMPZN RPCOMP RURD P Make up landing joint to hanger and 0.0 5,887.0 16:30 17:30 top drive.BOLDS. 10/16/2017 10/16/2017 0.50 COMPZN RPCOMP PULL P Pick up and pull hanger free at 150K. 5,887.0 5,883.0 17:30 18:00 Close annular preventer.Pull up and release packer at 190K.Rig up to circulate to flow back tank. 10/16/2017 10/16/2017 1.50 COMPZN RPCOMP CIRC P Pump 200 bbls 8.5 ppg 3%KCL 110° 5,883.0 5,883.0 18:00 19:30 brine down tubing taking returns up IA to flow back tank.3 bpm, 120 psi. Started getting returns after 15 bbls pumped.Final circ pressure at 3 bpm=170 psi.Returned 140 bbls of mixed diesel,crude and brine. 10/16/2017 10/16/2017 1.00 COMPZN RPCOMP OWFF P Monitor pressures.IA dropped from 5,883.0 5,883.0 19:30 20:30 170 psi to 45 psi with sporadic gas and fluid to flow back tank.Tubing static.Bleed back 10 bbls. 10/16/2017 10/16/2017 1.00 COMPZN RPCOMP CIRC P Pump 100 bbls 8.5 ppg 3%KCL 110° 5,883.0 5,883.0 20:30 21:30 brine down tubing taking returns up IA to flow back tank.2 bpm,25 psi. Returned 51 bbls diesel,crude and brine. 10/16/2017 10/16/2017 0.50 COMPZN RPCOMP OWFF P Monitor IA returns at flow back tank. 5,883.0 5,883.0 21:30 22:00 Sporadic returns diminishing to none after 15 mins. Pressure at 0 psi. Tubing static. 10/16/2017 10/16/2017 0.25 COMPZN RPCOMP OWFF P Open annular preventer.Monitor well. 5,883.0 5,883.0 22:00 22:15 Fluid slowly dropping in annulus. 10/16/2017 10/16/2017 0.75 COMPZN RPCOMP PULL P Pulll hanger to rig floor.PU=9OK w/10- 5,883.0 5,853.0 22:15 23:00 15K occasional overpull.Disconnet the ESP cable from the tubing hanger,lay down the landing joint and tubing hanger. 10/16/2017 10/17/2017 1.00 COMPZN RPCOMP TRIP P TOOH standing back 3-1/2"tubing 5,853.0 5,694.0 23:00 00:00 spooling ESP cable removing cannon clamps from 5853'MD to 5694'MD. Pump 5 bbls 8.5 ppg 3%KCL brine in hole every 1/2 hr+pipe displacement. 10/17/2017 10/17/2017 1.75 COMPZN RPCOMP TRIP P Continue to TOOH standing back 3- 5,694.0 5,061.0 00:00 01:45 1/2"tubing spooling ESP cable removing cannon clamps from 5694' MD to 5061'MD. Pump 5 bbls 8.5 ppg 3%KCL brine in hole every 1/2 hr+pipe displacement. 10/17/2017 10/17/2017 2.75 COMPZN RPCOMP PULL P POOH laying down 3-1/2"tubing 5,061.0 3,555.0 01:45 04:30 spooling ESP cable removing cannon clamps from 5061'MD to 3555'MD. 10/17/2017 10/17/2017 0.75 COMPZN RPCOMP ALFT P Disconnect ESP cable from the 3,555.0 3,555.0 04:30 05:15 Weatherford packer,test the cable and splice back together. 10/17/2017 10/17/2017 0.75 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 3,555.0 3,147.0 05:15 06:00 tubing spooling ESP cable removing cannon clamps from 3555'to 3147' MD. 10/17/2017 10/17/2017 0.50 COMPZN RPCOMP SVRG P Service the top drive and draw works. 3,147.0 3,147.0 06:00 06:30 Page 3/9 Report Printed: 11/1/2017 • A.1-7Operations Summary (with Timelog Depths) r 1C-102 fkif ConocoPhilllps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op,Code Activity-Code Time P-T-X Operation (ftKB) End Depth MKS)'; 10/17/2017 10/17/2017 0.50 COMPZN RPCOMP RGRP T Change out the skate buggy control 3,147.0 3,147.0 06:30 07:00 on the rig floor. 10/17/2017 10/17/2017 5.00 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 3,147.0 91.0 07:00 12:00 tubing spooling ESP cable removing cannon clamps from 3147'to 91'MD. 10/17/2017 10/17/2017 1.50 COMPZN RPCOMP ALFT P The ESP cable was damaged below 91.0 0.0 12:00 13:30 the WeIILift discharge gauge unit. Cut the ESP cable,PU to the motor lead splice and cut the cable. RIH to 91' MD and lay down the ESP assembly. 10/17/2017 10/17/2017 1.00 COMPZN RPCOMP RURD P Secure the ESP cable and spool back 0.0 0.0 13:30 14:30 to the unit. Clean and clear the floor. SimOps: DHD shot a fluid level of 30'. 10/17/2017 10/17/2017 1.75 COMPZN RPCOMP RURD P Strap and tally the 3-1/2"tubing in the 0.0 0.0 14:30 16:15 derrick. PJSM. RD the ESP elephant trunk and sheave. 10/17/2017 10/17/2017 0.25 COMPZ1 WHDBOP BHAH P PU and MU G-lock set RBP. 0.0 23.0 16:15 16:30 10/17/2017 10/17/2017 1.50 COMPZ1 WHDBOP TRIP P TIH with RBP on 3-1/2"EUE 8rd 23.0 956.0 16:30 18:00 tubing from the derrick to 956'MD(PU &SO=47K). 10/17/2017 10/17/2017 0.75 COMPZ1 WHDBOP MPSP P Set the G-lock set RBP at 951'MD 956.0 951.0 18:00 18:45 (COE)and release the running tool. 10/17/2017 10/17/2017 0.50 COMPZ1 WHDBOP TRIP P TOOH with the RBP running tool and 951.0 0.0 18:45 19:15 lay down. 10/17/2017 10/17/2017 0.75 COMPZ1 WHDBOP MPSP P RU pressure testing equipment. PT 0.0 0.0 19:15 20:00 the RBP and 7-5/8"casing to 1000 psi for 5 minutes(good test). RD pressure testing equipment. 10/17/2017 10/17/2017 0.25 COMPZ1 WHDBOP RURD P Blown down the choke/kill/hole fill 0.0 0.0 20:00 20:15 lines. 10/17/2017 10/17/2017 2.25 COMPZ1 WHDBOP NUND P PJSM. ND the BOP stack and set on 0.0 0.0 20:15 22:30 the stump. SimOps: Clear the floor cannon clamps. 10/17/2017 10/17/2017 1.25 COMPZ1 WHDBOP NUND P ND the existing Vetco wellhead. NU 0.0 0.0 22:30 23:45 new Gen 2 Mod 3 Vetco wellhead. 10/17/2017 10/18/2017 0.25 COMPZ1 WHDBOP PRTS P PT the casing hanger void to 5000 psi 0.0 0.0 23:45 00:00 for 10 minutes(good test). 10/18/2017 10/18/2017 3.50 COMPZ1 WHDBOP NUND P PJSM. NU the BOP stack. NU the kill 0.0 0.0 00:00 03:30 line. Install the turn buckles. Install the riser and mouse holes. 10/18/2017 10/18/2017 1.25 COMPZ1 WHDBOP BOPE P Install the test plug and RU BOPE 0.0 0.0 03:30 04:45 testing equipment. Fill the stack with fresh water and purge air from the system. PT the break and kill line to 250/2500 psi for 5 minutes each(good tests). RD testing equipment and pull the test plug. 10/18/2017 10/18/2017 0.25 COMPZ1 WHDBOP BHAH P PJSM. PU and MU the G-lock set 0.0 13.0 04:45 05:00 RBP retrieving head. Page 4/9 Report Printed: 11/1/2017 Operations Summary (with Timelog Depths) 1C-102 ConocaPhitiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth MKS) 10/18/2017 10/18/2017 1.00 COMPZ1 WHDBOP TRIP P TIH with the RBP retrieving head to 13.0 970.0 05:00 06:00 970'MD. MU top drive and close annular. Engage RBP,open bypass sleeve(no pressure)and release the G-lock set RBP. PU 20',SO past the setting depth to ensure it is released and open annular. 10/18/2017 10/18/2017 1.25 COMPZ1 WHDBOP PULD P POOH laying down 3-1/2"tubing from 970.0 23.0 06:00 07:15 970'to 23'MD. 10/18/2017 10/18/2017 0.25 COMPZ1 WHDBOP BHAH P Lay down G-lock set RBP and 23.0 0.0 07:15 07:30 retrieving head. 10/18/2017 10/18/2017 2.00 COMPZ1 RPCOMP RURD P RU 4-1/2"casing power tongs to run 3 0.0 0.0 07:30 09:30 -1/2"lower completion equipment below 5-1/2"casing. Load jewelry into the pipe shed and place in running order. 10/18/2017 10/18/2017 0.25 COMPZ1 RPCOMP SFTY P PJSM with all parties involved on 0.0 09:30 09:45 running 5-1/2"internally coated(TK- 15XT)casing. 10/18/2017 10/18/2017 2.25 COMPZ1 RPCOMP PUTB P PU, MU and RIH with WLEG, 1 joint of 0.0 250.0 09:45 12:00 3-1/2"tubing,nipple assembly, 1 joint of coated tubing,FHUPBR assembly, 1 joint of coated tubing,GLM assembly. 1 joint of coated tubing,and SBE assembly. Clean and repair die marks with coating. 10/18/2017 10/18/2017 0.25 COMPZ1 RPCOMP RURD P Change over to 5-1/2"running 250.0 250.0 12:00 12:15 equipment. 10/18/2017 10/18/2017 6.75 COMPZ1 RPCOMP PUTB P PU, MU and RIH with 5-1/2, 15.5#,L- 250.0 5,893.0 12:15 19:00 80,Hydril 563 internal coated casing from 250'to 5893'MD(PU= 116K and SO=76K) 10/18/2017 10/18/2017 1.00 COMPZI RPCOMP RURD P MU crossovers and cement line to the 5,893.0 5,893.0 19:00 20:00 5-1/2"casing. 10/18/2017 10/18/2017 0.50 COMPZ1 RPCOMP PACK P Pressure up to 2500 psi to set the FHL 5,893.0 5,893.0 20:00 20:30 packer and hold for 3 minutes. Continue to pressure up to 3500 psi and hold for 2 minutes. Bleed the pressure down to 2000 psi and PU to 140K to shear the PBR. 10/18/2017 10/18/2017 0.50 COMPZ1 RPCOMP PRTS P PT the 7-5/8"x 5-1/2"annulus to 1000 5,893.0 5,893.0 20:30 21:00 psi for 10 minutes(good test). 10/18/2017 10/18/2017 0.50 COMPZ1 RPCOMP HOSO P Lay down joints#144 and#143. 5,893.0 5,720.0 21:00 21:30 10/18/2017 10/18/2017 0.75 COMPZ1 RPCOMP THGR P PU and MU the tubing hanger and 5,720.0 5,740.0 21:30 22:15 landing joint. MU the tubing hanger to the 5-1/2"casing with circulating equipment. 10/18/2017 10/18/2017 0.25 COMPZI RPCOMP CIRC P Establish circulation at 2 BPM=40 5,740.0 5,774.0 22:15 22:30 psi,SO,engage the seal assembly, pumps off,bleed off the pressure and PU 6'. 10/18/2017 10/18/2017 1.25 COMPZ1 RPCOMP CRIH P PJSM. Close the annular and reverse 5,774.0 5,774.0 22:30 23:45 circulate 70 bbls of corrosion inhibited water with 3%KCI at 4 BPM=300 psi followed by 43 bbls of diesel at 2 BPM =750 psi. Pumps off. Page 5/9 Report Printed: 11/1/2017 • • Operations Summary (with Timelog Depths) 1C-102 ConcicoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr): Phase Op Code Activity Code Time P 1'X Operation (ftKB) End Depth(ftKB) 10/18/2017 10/19/2017 0.25 COMPZ1 RPCOMP HOSO P SO through the annular and engage 5,774.0 5,790.0 23:45 00:00 the seal assembly. Open the annular, land the 5-1/2"casing hanger and RILDS. 10/19/2017 10/19/2017 0.25 COMPZ1 RPCOMP PRTS P PT the casing hanger void to 5000 psi 0.0 0.0 00:00 00:15 (good test). 10/19/2017 10/19/2017 1.00 COMPZ1 RPCOMP PRTS P PT the 7-5/8"x 5-1/2"annulus to 2500 0.0 0.0 00:15 01:15 psi for 30 minutes(good test). 10/19/2017 10/19/2017 0.50 COMPZ1 RPCOMP PRTS P PT the 5-1/2"casing to 3500 psi for 10 0.0 0.0 01:15 01:45 minutes. 10/19/2017 10/19/2017 1.00 COMPZ1 RPCOMP RURD P RD circulating lines. Break out 0.0 0.0 01:45 02:45 crossovers from the landing joint. Lay down the bail extensions and send off the rig floor. Clear the floor of 5-1/2" handling equipment. Unload remaining 5-1/2"casing joints and landing joint from the pipe shed. 10/19/2017 10/19/2017 1.25 COMPZN RPCOMP RURD P Load the pipe shed with completion 0.0 0.0 02:45 04:00 jewelry. Mobilize PTS spooling unit and Tec wire spool to the rig floor. RU spooling unit and sheave. 10/19/2017 10/19/2017 0.25 COMPZN RPCOMP SFTY P PJSM with all parties involved on 0.0 0.0 04:00 04:15 running 3-1/2"external coated(TK- 750R)/internal coated(TK-15XT) tubing completion. 10/19/2017 10/19/2017 0.50 COMPZN RPCOMP PUTB P PU and MU seal assembly and 1 joint 0.0 57.0 04:15 04:45 of coated 3-1/2"tubing. Clean and repair die marks with coating. 10/19/2017 10/19/2017 1.25 COMPZN RPCOMP OTHR P PU and MU the gauge carrier,install 57.0 85.0 04:45 06:00 the PTS gauge and PT to 10000 psi for 30 minutes(good test). 10/19/2017 10/19/2017 6.00 COMPZN RPCOMP PUTB P Continue to RIH with completion on 85.0 1,242.0 06:00 12:00 coated 3-1/2"tubing from 85'to 1242' MD spooling TEC wire adding stainless steel bands above/below the coupling plus mid-joint.Clean and repair die marks with coating. 10/19/2017 10/20/2017 12.00 COMPZN RPCOMP PUTB P Continue to RIH with completion on 1,242.0 3,704.0 12:00 00:00 coated 3-1/2"tubing from 1242'to 3704'MD at midnight spooling TEC wire adding stainless steel bands above/below the coupling plus mid- joint.Clean and repair die marks with coating. 10/20/2017 10/20/2017 8.50 COMPZN RPCOMP PUTB P Continue to RIH with completion on 3,704.0 5,573.0 00:00 08:30 coated 3-1/2"tubing from 3704'to 5573'MD spooling TEC wire adding stainless steel bands above/below the coupling plus mid-joint.Clean and repair die marks with coating. 10/20/2017 10/20/2017 1.50 COMPZN RPCOMP HOSO P Continue to RIH to tag at with seals at 5,573.0 5,620.0 08:30 10:00 5665'MD with 3K down. SO to no-go at 5681'MD with 10K down. Lay down joints#179, 178, 177 and 176. MU space out pups(8.16', 10.19'and 10.20')and joint#176. 10/20/2017 10/20/2017 0.50 COMPZN RPCOMP THGR P PU the tubing hanger and set in the 5,620.0 5,620.0 10:00 10:30 mouse hole. MU the landing joint to the tubing hanger and MU the tubing hanger to the string. Page 6/9 Report Printed: 11/1/2017 • • 0 Operations Summary (with Timelog Depths) .. ,'; 1C-102 Conclio:Whillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time: End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (fEB) End Depth(ftK5)'. 10/20/2017 10/20/2017 0.50 COMPZN RPCOMP ALFT P Cut the Tec wire,feed through the 5,620.0 5,630.0 10:30 11:00 tubing hanger and secure with swedge lock fitting top/bottom. 10/20/2017 10/20/2017 0.25 COMPZN RPCOMP SFTY P PJSM on reverse circulating corrosion 5,630.0 5,630.0 11:00 11:15 inhibitor and diesel freeze protect. 10/20/2017 10/20/2017 0.75 COMPZN RPCOMP SEQP P PT surface lines to 3500 psi(good 5,630.0 5,630.0 11:15 12:00 test)and PT LRS lines to 4000 psi (good test). 10/20/2017 10/20/2017 0.50 COMPZN RPCOMP CRIH P Reverse circulate 50 bbls of 8.5 ppg 5,630.0 5,630.0 12:00 12:30 corrosion inhibitor with 3%KCI at 2.5 BPM=360 psi. 10/20/2017 10/20/2017 0.75 COMPZN RPCOMP FRZP P With LRS pump 65 bbls of diesel at 3 5,630.0 5,630.0 12:30 13:15 BPM=500 psi up to 5 BPM= 1100 psi. Open the Annular and bleed back 5.5 bbls of diesel to the cuttings tank. Drain the BOP stack. 10/20/2017 10/20/2017 0.50 COMPZN RPCOMP THGR P SO,land the tubing hanger and 5,630.0 5,669.0 13:15 13:45 RILDS. PT the upper tubing hanger void to 5000 psi for 10 minutes(good test). SimOps: BLow down the injection line,cement line and 2"line to the cuttings tank. 10/20/2017 10/20/2017 2.25 COMPZN RPCOMP THGR T PT the lower tubing hanger void to 5,669.0 5,669.0 13:45 16:00 5000 psi but unable to hold pressure. BOLDS and pull the tubing hanger to the rig floor. Remove 0-rings and install new 0-rings. Land the tubing hanger and RILDS. 10/20/2017 10/20/2017 1.00 COMPZN RPCOMP THGR T Attempt to test the lower tubing 5,669.0 5,669.0 16:00 17:00 hanger void but unable to get a passing test. BOLDS,PU with 35K over pull,check the LDS,found one not all the way out,BOLDS and pull the tubing hanger to the rig floor. Inspect the tubing hanger and found it was damaged from the LDS not being fully backed out. 10/20/2017 10/20/2017 1.00 COMPZN RPCOMP WAIT T Discuss options with town engineer 5,669.0 5,630.0 17:00 18:00 and Vetco personnel. 10/20/2017 10/20/2017 0.50 COMPZN RPCOMP ALFT T Back out the Tec wire swedge lock 5,630.0 5,630.0 18:00 18:30 fitting from the tubing hanger and pull the Tec wire back through the tubing hanger. 10/20/2017 10/20/2017 0.50 COMPZN RPCOMP THGR T Break out the tubing hanger and set in 5,630.0 5,620.0 18:30 19:00 the mouse hole. Break out the landing joint and lay down the tubing hanger. Load the damaged tubing hanger,new 10'coated pup and spare tubing hanger onto a truck. Send the truck to Dead horse to have the crossover removed from the damaged tubing hanger,buck onto the spare tubing hanger with new 10'coated pup. Page 719 Report Printed: 11/1/2017 • • Operations Summary (with Timelog Depths) X 1C-102 Conoca'hillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKS) 10/20/2017 10/20/2017 0.75 COMPZN RPCOMP WAIT T Wait for new tubing hanger to arrive 5,620.0 5,620.0 19:00 19:45 from Deadhorse. SimOps: Clear the rig floor of PTS equipment,Tec wire spool and spooling unit. 10/20/2017 10/20/2017 3.25 COMPZN RPCOMP WAIT T Wait for new tubing hanger to arrive 5,620.0 5,620.0 19:45 23:00 from Deadhorse. SimOps: PJSM. Install the front booster support frame(Star Wars) onto the front of the rig. Clean the pits. 10/20/2017 10/21/2017 1.00 COMPZN RPCOMP WAIT T Wait for new tubing hanger to arrive 5,620.0 5,620.0 23:00 00:00 from Deadhorse. SimOps: Clean the pits and general housekeeping. 10/21/2017 10/21/2017 1.00 COMPZN RPCOMP WAIT T Wait for new tubing hanger to arrive 5,620.0 5,620.0 00:00 01:00 from Deadhorse. SimOps: Clean the pits and general housekeeping. 10/21/2017 10/21/2017 0.50 COMPZN RPCOMP RURD T Off load the tubing hanger from the 5,620.0 5,620.0 01:00 01:30 truck and mobilize to the rig floor. 10/21/2017 10/21/2017 0.75 COMPZN RPCOMP THGR T Dress spare tubing hanger with new O 5,620.0 5,620.0 01:30 02:15 -rings and seals. MU the landing joint and MU the tubing hanger to the string. 10/21/2017 10/21/2017 0.50 COMPZN RPCOMP ALFT T Feed the Tec wire through the tubing 5,620.0 5,630.0 02:15 02:45 hanger. MU swedge lock connections on bottom and top of the tubing hanger. 10/21/2017 10/21/2017 1.00 COMPZN RPCOMP THGR T Land the tubing hanger and RILDS. 5,630.0 5,669.0 02:45 03:45 PT the lower and upper tubing hanger void to 5000 psi(good tests). 10/21/2017 10/21/2017 1.25 COMPZN RPCOMP PRTS P PJSM with rig crew and LRS. RU 0.0 0.0 03:45 05:00 LRS and PT line to 4000 psi(good test). PT the IA to 3500 psi for 30 minutes(good test). 10/21/2017 10/21/2017 0.25 COMPZN WHDBOP MPSP P Install HP BPV with dry rod. 0.0 0.0 05:00 05:15 10/21/2017 10/21/2017 0.25 COMPZN WHDBOP NUND P Pull the mouse hole. Blow down the 0.0 0.0 05:15 05:30 choke,kill and hole fill lines. 10/21/2017 10/21/2017 2.00 COMPZN WHDBOP NUND P Pull the riser,ND the BOP stack,set 0.0 0.0 05:30 07:30 back on the stump and secure for transport. SimOps: Retract#2 conveyor. 10/21/2017 10/21/2017 1.00 COMPZN WHDBOP NUND P Inspect upper LDS that damaged the 0.0 0.0 07:30 08:30 tubing hanger. SimOps: Continue to retract#2 conveyor. 10/21/2017 10/21/2017 1.00 COMPZN WHDBOP NUND P Install the plug off tool into the HP 0.0 0.0 08:30 09:30 BPV. NU the tubing head adapter and NU the tree. PT the adapter spool to 250/5000 psi for 10 minutes(good test). Page 8/9 Report Printed: 11/1/2017 • kr • Operations Summary (with Timelog Depths) tea., 1C-102 ComicoPhillips t` Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code' Time P-T X Operation (ftKB)_ End Depth(ftKS) 10/21/2017 10/21/2017 2.50 COMPZN WHDBOP NUND P Terminate PTS Tec wire on the 0.0 0.0 09:30 12:00 wellhead. Perform final electrical checks and PT connection(good test). SimOps: Prep to skid the rig floor. 10/21/2017 10/21/2017 1.25 COMPZN WHDBOP PRTS P PJSM. RU LRS. Fill the tree with 0.0 0.0 12:00 13:15 diesel and PT to 250/5000 psi(good test). 10/21/2017 10/21/2017 0.25 COMPZN WHDBOP MPSP P Pull the plug off tool and HP BPV with 0.0 0.0 13:15 13:30 the dry rod. 10/21/2017 10/21/2017 0.50 COMPZN WHDBOP FRZP P Top off the tubing with diesel with 0.0 0.0 13:30 14:00 LRS. 10/21/2017 10/21/2017 1.00 COMPZN WHDBOP PRTS P With LRS PT the tubing to 3000 psi for 0.0 0.0 14:00 15:00 30 minutes(good test). RD LRS. 10/21/2017 10/21/2017 0.25 COMPZN WHDBOP MPSP P Install H BPV with the dry rod. 0.0 0.0 15:00 15:15 10/21/2017 10/21/2017 0.75 DEMOB MOVE RURD P RD testing equipment and blow down 0.0 0.0 15:15 16:00 the lines. Install gauges on tree. Secure the tree,wellhead and cellar. Rig released at 16:00 hours. Page 9/9 Report Printed: 11/1/2017 ti • l • ConocoPhillips ti IC-1 02 West Sak Producer ESP to Jet Pump Well Details: w/ Liner Install API: 50-029-23037-00 Final COMPLETION PTD: 201-161 Wellhead: Vetco Gen III 5M a 4 Casing/Tubing Details: 16"62#H-40 Conductor to 161' MD 7-5/8" 29.7# L-80 Surface to 6,518' MD 5-1/2" 15.5# L-80 Liner(Internally plastic coated TK- 15XT)to 5,655' MD q ti 3-1/2" 9.3#L-80 Tubing (Internally plastic coated TK- 15XT and Externally plastic coated TK-750R) to 5,655' MD S 4 � Misc Details: Max Inclination: 70.3° at ZXP Packer Max Dogleg: 9.1°/100' at 2,160' KB Last Tagged Fill: N/A Total Depth: 10,570' KB 3-1/2" CMU 2.813" BX @ 5,537' MD (Jet Pump Location) ti 2-7/8" PTS Gauge Carrier @ 5,600' MD Baker SBE @ 5,655' MD 3-1/2"x1" KBMG GLM © 5,721' MD "� �.r Baker 7-5/8"x 3-%" FHL Packer @ 5,793' MD WI 10'80/40 PBR Assembly 3-1/2"WLEG @ 5,894' MD Baker Flanged Hook Hanger @ 5,936' MD ■ ■ Existing SCR-1 Liner Top Packer @ 6,042' MD G s � w , D and B Sand Laterals Date: October 13,2017 Drawn By: Ron Phillips KUPIND 1C-102 ConocoPhillips <. Well Attribute Max Angle•D TD Ala5ka.It1C. Wellbore APi/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CgnacaTMigips . 500292303700 WEST SAK PROD 93.45 7,199.84 10,570.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 10-106 11/16(20171135:24 AM SSSV:NONE 5 11/10/2014 Last WO. 10/21/2017 45.31 10/13/2001 Vertical.:homa6o.(aclual) "Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RECOMPLETION jennalt 11/15/2017 HANGER;35.4 `_?I='. Casing Strings IICasing Description OD(in) ID(in) Top(ftKB) Set Depth(ORB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread HANGER;39.0 III ` CONDUCTOR 16 15.062 40.0 161.0 161.0 62.50 H-40 WELDED Casing Description OD(in) ID 5n) Top(ftKB) Set Depth(ORB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 412 6,518.2 3,801.5 29.70 L-80 BTC-MOD '' ■■1� ,g Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ,,,,,,,,,,,,,,,,,,,,,,,,,,,e„uue,,,,,,. ,t $+ n. ,...8-SAND LINER 4 3.548 6,042.4 10,550.9 3,752.9 9.50 L-80 SLHT i Liner Details I Nominal ID Top MB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) nom.. 6,042.4 3,715.4 70.39 PACKER BAKER MODEL SCR-1 LINER TOP PACKER 4.000 w/MILLOUT EXTENSION CONDUCTOR;40.0-161.0 6,047.2 3,717.0 70.55 EXTENSION 4.000 6,050.2 3,717.9 70.65 KOIV BAKER KOIV,MODEL'C' 4.000 6,052.2 3,718.6 70.71 XO 5x4.5 4.500 6,090.3 3,730.8 71.97 SLEEVE BAKER'CMD'SLIDING SLEEVE 3.413 SI 6,132.4 3,743.4 73.34 XO 4.5x4 4.000 Tec Wire Guide Sub;5,536.3 1.1i. 10,530.0 3,752.6 89.38 XO 4.5x5 5.000 Sliding Sleeve;5,537.2` i:. Jet Pump;5,537.0_ S Tubing Strings Tee Wire Guide Sub;5,541.3 eel, ,.;/, Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO-2017 31/2 2.912 35.4 5,669.2 3,580.7 9.30 L-80 EUE 8rd Mod Completion Details Nominal ID 11, Top(ftKB) Top(ND)(ftKB) Top!noir) Item Des Com (in) 35.4 35.4 0.00 HANGER Tubing Hanger,Vetco Gray,Gen 1 3.900 TUlxng-Pup;5.5057AR 38.0 38.0 0.00 XO Reducing Crossover Pup Joint,41/2"x 3-1/2"NOT Coated 2.992 Gauge/Pump Sensor,5,599.8 ..� 5,536.3 3,527.5 63.54 Tec Wire Tec Wire Guide Sub,Baker,Mod Box x Pin 3.000 Guide Sub 00 Enlarging;5,610.5 A, 5,537.2 3,527.9 63.59 Sliding Sleeve Sliding Sleeve,Baker,CMU with 2.813"BX profile,NOT 2.807 Coated 5,541.3 3,529.7 63.82 Tec Wire Tec Wire Guide Sub,Baker,Mod Box x Pin 3.000 Guide Sub LOCATOR;5,648.7 5,583.8 3,547.7 65.86 XO Reducing X-0,3-1/2"x 2-7/8"NOT Coated 2.441 Q, 00 Threads.5,052.9_ ili 5,599.8 3,554.2 66.38 Gauge/Pump Gauge Carrier with PTS Gauge 2.441 SEAL ASSY;5,699.2` Sensor SBE;5,654.8 %' 5,610.5 3,558.4 66.72 XO Enlarging Crossover,2-7/8'x 3-1/2"Pin NOT Coated 2.441 00 Reducing;5,674.6 5,648.7 3,573.1 67.96 LOCATOR Locator,Baker,GBH-22(BTM of locator spaced out 2.960 5.71') 5,649.2 3,573.3 67.97 ISEAL ASSY Seal Assembly,Baker,80-40 2.960 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection GAS LIFT;5,721.4 _111 { LINER WO-2017 51/2 4.870 39.0 5,893.6 3,662.3 15.50 L-80 Hydril 563 E! Completion Details li e Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 39.0 39.0 0.00 HANGER Mandrel Casing Hanger,Vetco Gray 4.950 LOCATOR,5,776.6iiii 59.9 59.9 0.00 Liner Casing,5-1/2",15.55,L-80,Hydrill 563 Internally Coated 4.870 SEAL ASSY;5,777.0 PBR;•5,780.0_444 PACKER;5,793.4 5,654.9 3,575.4 68.16 SBE SBE,80-40,5"Hydril 521 Pin x 4-1/2"Hydril 521 Box 4.000 5,674.6 3,582.7 68.49 XO Reducing Crossover,4-1/2"Hydril 521 Pin x 3-1/2"EUE 8rd Pin 2.930 5,776.7 3,619.9 68.73 LOCATOR Locater,Baker,GBH-22(bottom of locater spaced out 3') 2.990 XO Redwing;5,846.7 i f I 5,777.0 3,620.0 68.73 SEAL ASSY Seal Assembly,Baker,80-40 2.990 X NIPPLE;5,848.8 • � 5,780.0 3,621.1 68.73 PBR PBR,Baker,80-40 4.000 XO Enlarging;5,849.7 ��� 5,793.4 3,626.0 68.73 PACKER Packer,Baker,47D2 FHL(shear release=60K) 2.930 5,846.7 3,645.3 68.73 XO Reducing Crossvoer,3-1/2"EUE 8rd Mod Box x 2-7/8"EUE 8rd 2.430 Box Mule Shoe;5,893.1 5,848.8 3,646.1 68.73 X NIPPLE Nipple,Halliburton,2.313"X profile 2.311 5,849.7 3,646.4 68.73 XO Enlarging Crossover,2-7/8"EUE 8rd Mod Box x 3-1/2"EUE 8rd Pin 2.420 D-SAND LINER,59357- 10,566 0 5,893.1 3,662.2 68.66 Mule Shoe WLEG,3-1/2",9.3#,L-80,EUE 8rd Mod Box Up 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl 4 . Top(ftKB) (ftKB) r) Des Com Run Date ID(in) ON 5,537.0 3,527.8 63.58 Jet Pump 2.81"X-LOCK ON JET PUMP(PH-1129 RATIO 10/23/2017 8B)AND SHOCK,SPARTEK GAUGE(OAL 7'-11") Perforations&Slots Shot Dens I Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) _ (ftKB) Zone Date ft) Type Com 6,547.0 10,466.0 3,801.8 3,752.1 WS B,1C- 12/12/2008 50.0 SLOTS Alternating 37'screens 8 102 31'blank pipe Mandrel Inserts St 1 ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 5,721.4 3,599.8 Camco KBMG 5.39 GAS LIFT DMY BK 0.000 0.0 10/21/2017 SURFACE;41.2-6,518.2 Notes:General&Safety SLOTS;6,547.0-10,466.0 1--0,I End Date Annotation 0 7/20/2002 NOTE:MULTI-LATERAL WELL. B-SAND(1C-102),D-SAND(1C-102L1) 7/14/2009 NOTE:View Schematic w/Alaska Schematic9.0 J 5/24/2012 NOTE:ESP FEED-THRU PACKER NECESSITES SLOW BLEED OFF OF PRESSURE IN IA 0-SAND LINER;6,042.4- 4/12/2016 NOTE:WO 10,550.9 -: ,, KUP .D 1C-102 ConotcoPhillips qg AM Ica.Inc. conocdnndhps-.''` ... Annotation End Date IC-102,110 612017 11:35 25A Last WO: .. ...)amts mahc C.:3J HANGER;35.4—.E%,, Notes:General&Safety End Date Annotation HANGER,39.0 'ry 1!i 10/21/2017 NOTE:RECOMPLETION CONDUCTOR;40.0-161.0 i Tec Wire Guide Sub;5,536.3 -_;�■P Sliding Sleeve;5,537.2 ; Jet Pump',5,537.0 Tec Wee Guide Sub;5,541.3 �'il•4 ME Tubing-Pup;5,595.7 Gauge/Pump Sensor;5,599.8 141 XO Enlarging;5,610.5 I I LOCATOR,5,648.7 �' 00 Threads,5,6529 SEAL ASSY;5,649.2 L . SBE;5,654.8 -� ab XO Reducing;5,674.6 GAS LIFT;5,721.4 LOCATOR;5,776.6 SEAL ASSY;5,777.0 PBR;5,7800 PACKER;5,793.4 XO Reducing;5,846.7 X NIPPLE;5,848.8 00 Enlarging ;5,849.7 4 Mule Shoe,5,893.1 0-SAND LINER,5,935.7- 10.566.0 SURFACE;41.2-6,518.2 SLOTS;8,547.0-10,468.0 B-SAND LINER;6,042.4- 10,550.9 ,042.410,550.9 5w,\\\1%7yes THE STAT• Alaska Oil and Gas w OfA LAsKAConservation Commission == 4tritt „r2 = 333 West Seventh Avenue ®� � GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS1 Fax: 907.276.7542 www.aogcc.alaska.gov Ron Phillips Senior Wells Engineer ConocoPhillips Alaska, Inc. ISA NED NOV 2 Inlet, P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-102 Permit to Drill Number: 201-161 Sundry Number: 317-452 Dear Mr. Phillips: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French �l- Chair DATED this 1 day of October, 2017. RBDMS LIvUCI 1 3 2017 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing E Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 2 Other:Cony ESP to jet pump ❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development Q • 201-161 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-23037-00 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1C-102 • Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025649 ' Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): I Plugs(MD): Junk(MD): 10570' 3753' 10,551' 3,753' 554 none none Casing Length Size MD ND Burst Collapse Structural Conductor 121' 16" 161' 161' RECEIVED Surface 6477' 7.625" 6518' 3802' Intermediate SEP 2 5 2U1/ Production O✓S /0//-4,!i? Liner 4509' 4" 10551' 3753' AOG `�-p Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6547'-10466' - 3802'-3752' 3.5" L-80 5887 (slotted liner) Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): SSSV: none PACKER-WFT HYDROW II FEED THRU - MD=2510 TVD=1998 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development E• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/10/2017 Commencing Operations: OIL ❑✓ , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Ron Phillips Contact Name: Ron Phillips Authorized Title: Senior Wells Engineer Contact Email: Ron.L.Phillips@conocophillips.com 4�f Contact Phone: 265-6312 Authorized Signature: eg / " q Date: ! ipl0 17 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 (7- 4/5 2 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: Bop ftsf fo Z500 P5--1- 4-va vi v I do 1- iprt v�h 1-Z Pr s t f° 2 5 0 0�5—�5 Post Initial Injection MIT Req'd' Yes ❑ No ifr RC3D MS L L OCT 1 3 2017 Spacing Exception Required? Yes ❑ No a' . Subsequent Form Required: /6 — 1 0 IOW APPROVED BY 1© 1.7_ 111, Approved by: �/ • 'MISSIONER THE COMMISSION Date: Submit Form and / ntt„cl,i i ic„ta;II D„pl�catv t 7 415 /?-t/`ZJ0d 0 Pr b '' A -e 9 aK7 • • v ConocoPhillips Alaska RECEIVED P.O. BOX 100360 5 ANCHORAGE,ALASKA 99510-0360 SEP 2 2017 22 September 2017 AOGCC Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to work over Kuparuk(West Sak) Producer 1C-102(PTD#201-161). 1C-102 was drilled and completed in 2001 with an ESP.The ESP failed and was subsequently replaced via a RWO in 2012,2014,and 2016.The ESP failed again in 2016 and a RWO is planned for later in 2017 to convert the artificial lift method from ESP to Jet Pump. This is a single casing well so a new tie-back liner will be installed to provide an additional steel barrier for the Jet Pump. The planned workover scope includes pulling the existing ESP completion,changing out the wellhead to accommodate the liner,installing a 5-1/2"liner from surface,and installing a new 3-1/2"Jet Pump completion. If you have any questions or require any further information,please contact me at 265-6312. Sincerely, P.,...1/41:: Re."' Ron Phillips Senior Wells Engineer CPAI Drilling and Wells • • 1C-102 Rig Workover • P&R Tbg w/Liner Install (PTD#:201-161) Current Status: Shut-in Scope of Work: Pull the existing completion down to liner top packer. Change wellhead. Install 5-1/2"liner and 3- 1/2"jet pump completion. General Well info: Well Type: Producer ✓' MPSP: 554 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 933 psi/3,802' TVD(4.72 ppg EMW)measured on 11/23/2012 Wellhead type/pressure rating: Vetco Gen II,5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-T to 1000 psi PASSED—04/18/2016 Earliest Estimated Start Date: October 10,2017 Production Engineer: Marina Krysinski Workover Engineer: Ron Phillips(265-6312/Ron.L.Phillips@ConocoPhillips.com) Pre-Rig Work 1. Pull DV from GLM above packer for circulation point. 2. Inspect pad and work area for hazards. Complete the PJSM. Workover Procedure 1. MIRU. 2. Circulate KWF throughout well. Obtain SITP&SICP, if pressure is seen at surface,calculate new KWF, weight up,and repeat circulation as necessary.Verify well is dead. 3. Set BPV,ND tree,NU BOPE and test to 250/2,500 psi. a. If the lower pipe rams are unable to be tested because of the blanking plug position,the lower pipe rams will be tested upon pulling the completion. 4. Pull BPV, screw in landing joint,BOLDS's,pull the tubing hanger. 5. POOH laying down 3-1/2"ESP completion. 6. RIH and set RBP at 100'.Pressure test from above to verify plug is set. 7. ND BOP stack.ND existing Vetco tubing head. 8. NU new Vetco wellhead to accommodate liner and tubing. Test flange seal to rated capacity. 9. NU BOP stack and test break to 250/2,500 psi. 10. Retrieve RBP. 11. RIH with 5-1/2"liner assembly to SBE located below liner top packer. Fully locate and space out at surface. 12. Pump corrosion inhibited fluid to fill the OA from the SBE to surface.Land liner hanger in wellhead. 13. RIH with 3-1/2"jet pump completion to SBE located at the liner bottom. Space out and MU tubing hanger. 14. Pump corrosion inhibited fluid in the IA from the SBE to surface.Land the tubing hanger,RILDS. 15. PT the tubing.Hold pressure on tubing and pressure test IA and chart.Bleed tubing pressure quickly to shear the SOV. 16. Pull the landing joint,install BPV. 17. ND BOPS. 18. NU tree.Pull BPV and install tree test plug. Test tree and pull test plug. 19. Freeze protect well with diesel. 20. RDMO. 1 • • 1C-102 Rig Workover P&R Tbg w/Liner Install (PTD#:201-161) Post-Rig Work 1. RU Slickline to pull SOV. Install jet pump. 2. Reset well house(s)and flowlines of adjacent wells. 3. Turn well over to operations. 2 • • 11'`� ConocoPhillips West Sak Producer ESP to Jet Pump w/ Liner Install Well Details: PROPOSED API: 50-029-23037-00 PTD: 201-161 COMPLETION Wellhead:Vetco Gen III 5M Casing/Tubing Details: 16"62#H-40 Conductor to 161' KB 7-5/8"29.7#L-80 Surface to 6,518' KB 5-1/2"26#L-80 Liner to 5,982' KB 3-1/2"9.3#L-80 Tubing to 5,983' KB Misc Details: Max Inclination: 70.3°at ZXP Packer Max Dogleg: 9.1°/100'at 2,160' KB Last Tagged Fill: N/A Total Depth: 10,570' KBu,, - - 5,865' MD-3-1/2" KBG 2-9 GLM H 5,913' MD-3-1/2"CMU 2.813" DS (Jet Pump Location) 5,948' MD-3-1/2" PTS Gauge Carrier 5,986' MD Baker SBE ' 6,031' MD-3-1/2"CMU 2.813" BX U6,042' MD- Existing ZXP Liner Top Packer .. D and B Sand Laterals Date:September 22,2017 I Drawn By: Ron Phillips �, a KUP IFD 1C-102 ConocoPhillips { Well Attribu Max Angleillk TD Alaska Inc 1. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Corroc01hIt)ips 500292303700 WEST SAK PROD 93.45 7,199.84 10,570.0 .-. .. Comment H2S(ppm) Date Annotation ' End Date KB-Grd(ft) -Rig Release Date 1C-102,9mn0172;14.25 PM SSSV:NONE 5 11/10/2014 Last WO: 4/12/2016 45.31 10/13/2001 Veracal schematic.tactual) "Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O,SET ESP PUMP,DBD pproven 4/25/2016 PACKOFF 8 3 1/2"SLIPSTOP HANGER,26.9- A)jk'' Casing Strings Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(TVD[.. Wt/Len(I...Grade Top Thread WI CONDUCTOR 16 15.062 40.0 161.0 161.0 62.50 H-40 WELDED • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ORB) Set Depth(TVD)... Wt/Len K..Grade Top Thread Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth( ' , ,, „` ,.,, ND)... 29'70 L-80 BTC-MOD .,"".,,.,,""x,,,,,,,",1"'1"11jMji,•,"" SURFACE 75/8 6.875 41.2 6,518.2 3,801.5 WtlLen I7...Grade Top Thread B-SAND LINER 4 3.548 6,042.4 10,550.9 3,752.9 9.50 L-80 SLUT CONDUCTOR;40.0-161.0 • - Liner Details Nominal ID Top)ftKB) Top(ND)(ftKB) Top'noir) Item Des Com (in) . 6,042.4 3,715.4 70.39 PACKER BAKER MODEL SCR-1 LINER TOP PACKER 4.000 w/MILLOUT EXTENSION 6,047.2 3,717.0 70.55 EXTENSION 4.000 II 6,050.2 3,717.9 70.65 KOIV BAKER KOIV,MODEL'C' 4.000 GAS LIFT,2,364.4 II 6,052.2 3,718.6 70.71 XO 5x4.5 4.500 6,090.3 3,730.8 71.97 SLEEVE BAKER'CMD'SLIDING SLEEVE 3.413 6,132.4 3,743.4 73.34 XO 4.5x4 4.000 10,530.0 3,752.6 89.38 X0 4.5x5 5.000 Tubing Strings PACKER,2,510.2 '° • 'kis'sir Tubing Description String Ma...ID(in) Top(ftKR) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection 2016 POR Centrilift 31/2 2.992 26.9 5,887.0 3,659.9 9.30 L-80 EUE TTC-PCP ° Completion Details Nominal ID GAS LIFT;2,624.4 Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Corn (in) 26.9 26.9 0.00 HANGER 'Vetco Gray 10.75"x 3.5"x 2.10-5 Tubing Hanger w/367- 2.950 ft Pup jt 2,510.2 1,998.3' 64.20 PACKER 'ESP Feed-Thru Packer,WET Hydrow II 2.920 II 5,796.6 3,627.1 ' 68.73 GAUGE 'WeIILift Discharge Gauge Unit.(S/N:Z192-000900) 2.992 GAS LIFT.5,742.1 I - 5,856.2 3,648.7 68.73'ESP Intake 'TIC Receiving XO Coupling w/perforated intake 2.992 in, (P/N:CSE8442XA)12978448 11 5,861.0 3,650.5 68.72 Seal Tandem Seal Section.(S/N:12064506/12064731) 5,874.7 3,655.5 68.69 Gear Box Gear Reduction Unit.(S/N:12071904)11.42:1 GAUGE,5,796.6 5,876.6 3,656.1 68.69 ESP Motors 8 ESP Motor,562MSP1,75 HP/1350/34(S/N:13967257) Cables ^'. 5,883.3 3,658.6 68.67 GAUGE WeIILift Motor Gauge Unit.(S/N:Z192-01114) SLIPSTOP;5,803.0 5,885.1 3,6593 68.67 CENTRALIZE Motor Centralizer.(P/N:C63569) R PACKOFF,5,804.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl _ Top(ftKB) (ORB) (") Des Corn Run Date ID(in) ESP PUMP,5,812.0 1,1 5,803.0' 3,629.5 68.73 SLIPSTOP 3.5"SLIPSTOP 4/23/2016 5,804.0 3,629.8 68.73 PACKOFF 3.5"DBD PACKOFF(OAL-93") 4/23/2016 5,812.0 3,632.7 68.73 ESP PUMP PCPESP PUMP W/TEST PORT(All OAL-43'5") 4/23/2016 ESP Intake,5,856.2 I!1111 Seal,5,860.9 Perforations&Slots Shot Gear Box;5,874 7 Dens ESP Motors&Cables;5,876.5 .�f 7o Btm ftKB Top(ND) Btm(ND) (shots/ Top(ftKB)) (ftKB) (ftKB) (MB) Zone Date ft) Type Com GAUGE;5,883.3 i: 6,547.0 10,466.0 3,801.8 3,752.1 WS B,1C- 12/12/2008" 50.0 SLOTS Alternating 37'screens& CENTRALIZER,5,885.1 ) 102 31'blank pipe Mandrel Inserts St ati D-SAND LINER,5,936.1- • on 10,566.5 Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,384.4 1,944.1 Camco KBMM/ 1 ESP DMY BEK 0.000 0.0 4/17/2016 BK-5 2 2,624.4 2,048.4 Camco KBMG/ 1 ESP DMY BK-5 0.000 0.0 4/11/2016 =.-4- BK-5 "Ito 3 5,742.1 3,607.4 Camco KBMG/ 1 ESP SOV BK-5 ' 0.000 0.0 4/17/2016 2000 = BK-5 #tbg shear Notes:General&Safety End Date Annotation 7/20/2002 NOTE.MULTI-LATERAL WELL. B-SAND(1C-102),D-SAND(1C-102L1) I I 7/14/2009 NOTE:View Schematic w/Alaska Schematic9.0 5/24/2012 NOTE:ESP FEED-THRU PACKER NECESSITES SLOW BLEED OFF OF PRESSURE IN IA. I SURFACE,41.2-,518.2 SLOTS,6,547.0-10,466.0 , IC B-SAND LINER 6,042.4- ,/ 10,550.9 STATE OF ALASKA 0 AOKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations Fracture Stimulate E Pull Tubing E Operations Shutdown 1"- Performed: Performed: Suspend E Perforate 1 Other Stimulate Alter Casing fT Change Approved Program Plug for Redrill fT Perforate New Pool fRepair Well is` Re-enter Susp Well fT Other: Pull/Replace ESP F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory f 201-161 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23037-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649 KRU 1C-102 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 10570 feet Plugs(measured) None true vertical 3753 feet Junk(measured) None Effective Depth measured 10551 feet Packer(measured) 2510,6042 true vertical 3753 feet (true vertical) 1998, 3715 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121 16 161 161 SURFACE 6477 7.625 6518 3802 B-SAND LINER 4509 4 10551 3753 RECEIVED Perforation depth: Measured depth: 6547-104666NNE�1 a MAY 11 2016 True Vertical Depth: 3802-3752 Ise L� AOG CC Tubing(size,grade,MD,and ND) 3.5, L-80, 5887 MD, 3660 TVD Packers&SSSV(type,MD,and ND) PACKER-WEATHERFORD PACKER @ 2510 MD AND 1998 ND PACKER-BAKER SCR-1 LINER TOP PACKER @ 6042 MD AND 3715 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation Shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: F Daily Report of Well Operations FExploratory Development Service Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas T WDSPL fT Printed and Electronic Fracture Stimulation Data fT GSTOR fT WINJ r WAG fT GINJ f SUSP fT SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Andrew Beat @ 265-6341 Email Andrew.T.Beataa,conocophillips.com Printed Name Andrew B-- 1►Il le Senior Wells Engineer Signature f\. - • Date / I t /I, (0 Form 10-404 Revised 5/2015 V`T/_ 5723//b RBDMS LI— MAY 1 2 2016 Submit Original Only A'3 f2-t//6 0 • y_' DrillingOperations Summary (with Timelog Depths) _� &Wells 1C-102 Conoccehitllps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ItKB) 4/6/2016 4/7/2016 24.00 MIRU MOVE MOB P Mob from 3F-12 to 1C-102 00:00 00:00 4/7/2016 4/7/2016 14.00 MIRU MOVE MOB P Continue to MIRU.Rig accepted @ 00:00 14:00 14:00hrs 4/7/2016 4/7/2016 1.50 MIRU WELCTL RURD P Install secondary valves and pick up 14:00 15:30 lubricator. 4/7/2016 4/7/2016 1.00 MIRU WELCTL MPSP P PT lubricator to 1000 psi.Pulled BPV. 15:30 16:30 Tbg=300 psi IA= 150 psi. 4/7/2016 4/7/2016 3.50 MIRU WELCTL RURD P RU kill line to well.PT to 2500 psi. 16:30 20:00 4/7/2016 4/7/2016 1.50 MIRU WELCTL KLWL P Bled off pressure both side. Pumped 20:00 21:30 22 BBLs Hi-Vis sweep.followed by 1131 BBIs of seawater/3%KCL.@ 4 BPM @ 420 psi. 4/7/2016 4/7/2016 0.50 MIRU WELCTL OWFF P IA on vac Tbg 32 Psi. 21:30 22:00 4/7/2016 4/7/2016 1.00 MIRU WELCTL CIRC T REvesed circulated 100 BBLs of sea 22:00 23:00 water @ 3 BPM @ 300 psi with 100 psi back pressure on tbg. 4/7/2016 4/8/2016 1.00 MIRU WELCTL OWFF T Flow check.Tubing Built up to 60 psi 23:00 00:00 in 1 HR. 4/8/2016 4/8/2016 4.50 MIRU WELCTL OTHR T PT RBP to 500 psi for 5 Min's.Good 00:00 04:30 test.Bled off pressure and let equalize do to diesel migration. Pumped 15 BBIs of sea water down IA to clear diesel.Recovered 10 BBLs of oil/ Diesel mix then clean sea water. 4/8/2016 4/8/2016 0.50 MIRU WELCTL OWFF T Flow check for 30 min's 04:30 05:00 4/8/2016 4/8/2016 0.50 MIRU WHDBOP MPSP P Install BPV. 05:00 05:30 4/8/2016 4/8/2016 1.50 MIRU WHDBOP NUND P ND tree and adaptor 05:30 07:00 4/8/2016 4/8/2016 3.00 MIRU WHDBOP NUND P Install BOPE and NU. Install riser and 07:00 10:00 turn buckles. 4/8/2016 4/8/2016 2.00 MIRU WHDBOP RURD P Prepare cellar and well head for BOP 10:00 12:00 test and RU test jt.And grease HCR/ Manual valves 4/8/2016 4/8/2016 4.00 MIRU WHDBOP BOPE P Conduct Initial BOP Test @ 250/ 12:00 16:00 2,500 psi. 24 hr Notice was given to AOGCC @ 09:08 hrs on 4-5-16 and Right to witness was waived by Lou Grimaldi at 10:13 hrs on 4-5-16. with 3-1/2 test joint. 4/8/2016 4/8/2016 0.50 MIRU WHDBOP RURD P RD testing equipment. 16:00 16:30 4/8/2016 4/8/2016 0.50 MIRU WHDBOP MPSP P Pulled BPV. 16:30 17:00 4/8/2016 4/8/2016 4.00 COMPZN RPCOMP PULL P Installed landing jt.Pulled up on 0.0 0.0 17:00 21:00 hanger to 190 K hanger did not move. Pulled up to 220 K wrapped head with steam blanket and heated up hanger. Popped free Page 1/4 Report Printed: 4/28/2016 • • °~,, Drilling Operations Summary (with Timelog Depths) 1, &Wells 1 C-1 02 GonocoPhithps if OSEA,,,, Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/8/2016 4/8/2016 2.00 COMPZN RPCOMP CIRC P Released packer @ 40K over string 0.0 0.0 21:00 23:00 110K.Attempted to bull head Kill fluid down IA with out success.worked packer up and down to get the element to relax. Pressure up multi able time to 8-900 psi.Well taking fluid hydrostatic after hole fill. Pressure up to 2500 psi SOV did not shear. 4/8/2016 4/9/2016 1.00 COMPZN RPCOMP RURD P RU ESP sheaves 0.0 23:00 00:00 4/9/2016 4/9/2016 3.00 COMPZN RPCOMP RURD P Continue to rig up Centrilift ESP 00:00 03:00 equipment 4/9/2016 4/9/2016 1.50 COMPZN RPCOMP CIRC P Pumped 70 BBL's filter sea water out 03:00 04:30 of trip tank did not fill hole.kicked on pump and pumped 120 more bbls with pump @ 4 BPM with annular open. 4/9/2016 4/9/2016 1.00 COMPZN RPCOMP BOPE P Reland tbg hanger and test annular to 04:30 05:30 250/2500 psi. 4/9/2016 4/9/2016 2.00 COMPZN RPCOMP OWFF P Shoot fluid level shots at 05:30 07:30 06:00 hrs=570-ft 07:00 hrs=720-ft 4/9/2016 4/9/2016 0.50 COMPZN RPCOMP PULL P Unland hanger @ 170k and pull to 07:30 08:00 floor,Break out landing joint,laydown in pipe shed,pull side port blanking plug,drift hanger with 2.875"OD drift- good. Lay down TBG hanger. 4/9/2016 4/9/2016 0.25 COMPZN RPCOMP SFTY P Held Pre-job safety meeting with 0.0 0.0 08:00 08:15 crews involved with pulling of ESP completion. Discuss threading cable through the sheeve hanging in the derrick. Well control issues, displacement. 4/9/2016 4/9/2016 3.25 COMPZN RPCOMP TRIP P POOH with 3-1/2 TBG to 1st GLM at 0.0 2,385.0 08:15 11:30 25 stands,lay down open pocket GLM, pull stand 26,rack back. TBG dry,disconnect penetrator at packer. Pulll and laydown packer. 4/9/2016 4/9/2016 0.50 COMPZN RPCOMP OTHR P Tie ESP cable together from packer 2,385.0 2,385.0 11:30 12:00 splice. 4/9/2016 4/9/2016 4.50 COMPZN RPCOMP TRIP P POOH with stand 27,lay down GLM 2,385.0 5,834.0 12:00 16:30 #2 w/DMY valve installed. Continue to POOH standing back completion string. Note dry pipe to last 500-ft of TBG pulled. 4/9/2016 4/9/2016 2.50 COMPZN RPCOMP PULL P Laid down ESP. 5,834.0 0.0 16:30 19:00 4/9/2016 4/9/2016 0.50 COMPZN RPCOMP SVRG P Service Top Drive 0.0 0.0 19:00 19:30 4/9/2016 4/9/2016 3.50 COMPZN RPCOMP RURD P Swap ESP spools in spooler unit. 0.0 0.0 19:30 23:00 4/9/2016 4/10/2016 1.00 COMPZN RPCOMP ALFT P Pick up ESP motor/Pump 0.0 0.0 23:00 00:00 massembly.Open ports and drain oil. 4/10/2016 4/10/2016 2.00 COMPZN RPCOMP ALFT P RIH with 2-10 ft pups, 1 JT, Gauge 0.0 0.0 00:00 02:00 W/pups., 1 JT fill tbg and pressure tet to 500 psi. 4/10/2016 4/10/2016 1.50 COMPZN RPCOMP ALFT P Picked up ESP assembly.&service 0.0 0.0 02:00 03:30 with new oil. Page 2/4 Report Printed: 4/28/2016 • • . . Operations Summary (with Timelog Depths) , Drilling &WeUs 1 C-1 02 ±ConocoPtviiips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/10/2016 4/10/2016 3.00 COMPZN RPCOMP ALFT P Splice in tech wire from Sensor to 0.0 97.0 03:30 06:30 discharge gauge. Install Cannon pump and motor clamps. 4/10/2016 4/10/2016 2.75 COMPZN RPCOMP ALFT P PU jt with WRP installed and PT to 97.0 129.0 06:30 09:15 500 psi. good test 4/10/2016 4/10/2016 6.00 COMPZN RPCOMP TRIP P Continue to RIH from 129-ft to 3368-ft 129.0 3,368.0 09:15 15:15 pressure testing tubing to 500 psi every 1,000-ft while we are megging. 4/10/2016 4/10/2016 0.25 COMPZN RPCOMP PUTB P PU Weatherford 7-5/8 Hydrow-II 3,368.0 3,393.0 15:15 15:30 packer and space out for packer splice. 4/10/2016 4/10/2016 4.50 COMPZN RPCOMP PUTB P Conduct packer feed thru splice 3,393.0 3,393.0 15:30 20:00 4/10/2016 4/11/2016 4.00 COMPZN RPCOMP TRIP P Continue to RIH with ESP completion 3,393.0 5,384.0 20:00 00:00 as per detail 4/11/2016 4/11/2016 1.25 COMPZN RPCOMP TRIP P Continue to RIH with ESP completion. 5,384.0 5,843.0 00:00 01:15 Pick up hanger 98 Cannon clamps and 10 SSbands in hole. 4/11/2016 4/11/2016 2.25 COMPZN RPCOMP THGR P Complete surface splice. 5,843.0 5,843.0 01:15 03:30 4/11/2016 4/11/2016 0.50 COMPZN RPCOMP THGR P Land tbg hanger.Up wt=95 K down= 5,843.0 5,887.0 03:30 04:00 55 K. 4/11/2016 4/11/2016 0.50 COMPZN WHDBOP MPSP P Install BPV 0.0 0.0 04:00 04:30 4/11/2016 4/11/2016 3.00 COMPZN WHDBOP WAIT T Wait on phase weather 0.0 0.0 04:30 07:30 4/11/2016 4/11/2016 2.00 COMPZN WHDBOP NUND P ND BOPE 0.0 0.0 07:30 09:30 4/11/2016 4/11/2016 4.00 COMPZN WHDBOP NUND P NU tree&PT to 250/5000 psi. 0.0 0.0 09:30 13:30 4/11/2016 4/11/2016 0.50 COMPZN WHDBOP MPSP P Pulled TWC 0.0 0.0 13:30 14:00 4/11/2016 4/11/2016 2.00 COMPZN WHDBOP CRIH P RU circulation equipment in cellar. 14:00 16:00 Clear work floor of equipment 4/11/2016 4/11/2016 2.00 COMPZN WHDBOP CRIH P Spotted CI treated sea water down IA 16:00 18:00 220 BBLs 4/11/2016 4/11/2016 2.50 COMPZN WHDBOP PRTS P Set packer @ 3500 psi.Held pressure 18:00 20:30 Bled pressure down to 1500 psi. PT IA 2500 psi for 30 min's.Slow bleed pressure off IA in 500 psi increments hold for 10 min's each stage. Bled off Tbg.Shear sov 4/11/2016 4/11/2016 3.00 COMPZN WHDBOP FRZP P RU LRS:PJSM 20:30 23:30 Freeze protect well with 107 BBL's of diesel. RD LRS. 4/11/2016 4/12/2016 0.50 COMPZN WHDBOP MPSP P Installed BPV.Secured well 23:30 00:00 Page 3/4 Report Printed: 4/28/2016 Operations Summary (with Timelog Depths) &Wells 1C-1 02 ConocoPhiti ps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS) 4/12/2016 4/12/2016 6.00 DEMOB MOVE RURD P Blow down mud cleaning equipment 0.0 0.0 00:00 06:00 pumps and water lines. Clean pits, Rig floor and under table in prep for move. Clean and clear cellar. RD Tongs, Install A-leg brace change oil in draw works,inspect chains and keepers. Inspect drag chain,change out 2 pillow block bearings,inspect and service skate. Start to prep rig for move to 1Q-26. Release Nabors 7ES at 06:00 hrs on 4 -12-16 Page 4/4 Report Printed: 4/28/2016 KUP OD 1C-102 Con©thPhiHHips Well Attrib Max Angle&MD TD E Alaska.Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) t otos , 500292303700 WEST SAK PROD 93.45 7,199.84 10,570.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-102,5/220161:5251 AM SSSV:NONE 5 11/10/2014 Last WO: 4/12/2016 45.31 10/13/2001 Vertical schematic(actual) 'Annotation Depth(ftKB) End Date Annotation .Last Mod By End Date Last Tag: Rev Reason.GLV C/O,SET ESP PUMP,MD pproven 4/25/2016 HANGER;26 G.-. }',� PACKOFF&3 1/2"SLIPSTOP Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 40.0 161.0 161.0 62.50 H-40 WELDED "1I f r ,:. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread ``� J 0++°SURFACE 75/8 6.875 41.2 6,518.2 3,801.5 29.70 L-80 BTC-MOD •-• �-� Casing Description SOD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR,40.0-161.0 B-SAND LINER 4 3.548 6,042.4 10,550.9 3,752.9 9.50 L-80 SLHT Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°I Beer Des Com lin) 6,042.4 3,715.4 70.39 PACKER BAKER MODEL SCR-1 LINER TOP PACKER 4.000 w/MILLOUT EXTENSION 6,047.2 3,717.0 70.55 EXTENSION 4.000 6,050.2 3,717.9 70.65 KOIV BAKER KOIV,MODEL'C' 4.000 GAS LIFT;2,384.4 ill 6,052.2 3,718.6 70.71 XO 504.5 4.500 6,090.3 3,730.8 71.97 SLEEVE T BAKER'CMD'SLIDING SLEEVE 3.413 la 6,132.4' 3,743.4 73.34 XO 4.5x4 4.000 II 10,530.0 3,752.6 89.38 XO 4.505 5.000 PACKER;2,510.2 Tubing Strings Tubing Description String Ma...ID(in) Top(ft8B) Set Depth(ft..Set Depth(ND)(...Wt(Ibft) Grade Top Connection 2016 P&R Cenirilifl 31/2 2.992 TTC-PCP 26.9 5,887.0 3,659.9 9.30 L-80 ELM f Completion Details GAS LIFT;2,6244 Nominal ID Top)ftKB) Top)TVD)(ftKB) Top not(°) Item Des Com lin) lal26.9 26.9 0.00 HANGER Vetco Gray 10.75"x 3.5"x 2.10-ft Tubing Hanger w/367- 2.950 ft Pup jt 2,510.2 1,998.3 64.20 PACKER ESP Feed-Thru Packer,WFT Hydrow II 2.920 GAS LIFT;5,742.1 g 5,796.6 3,627.1 68.73 GAUGE WeIlLift Discharge Gauge Unit.(S/N:2192-000900) 2.992 5,856.2 3,648.7 68.73 ESP Intake TTC Receiving XO Coupling w/perforated intake 2.992 (P/N:CSE8442XA)12978448 it 5,861.0 3,650.5 68.72 Seal Tandem Seal Section.(S/N:12064506/12064731) 5,874.7 3,655.5 68.69 Gear Box Gear Reduction Unit.(S/N:12071904)11.42:1 GAUGE;5,796.6 em►, 5,876.6 3,656.1 68.69 ESP Motors 8 ESP Motor,562MSP1,75 HP/1350/34(S/N:13967257) 11 Cables ',. 5,883.3 3,658.6 68.67 GAUGE WeIILift Motor Gauge Unit.(S/N:Z192-01114) SLIPSTOP;5,803.0 5,885.1 3,659.3 68.67 CENTRALIZE Motor Centralizer.(P/N:C63569) gg R PACKOFF;5,804.0 d. 1Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ,e Top(TVD) Top Incl Top(ftKB) (ftKB) 1') Des Com Run Date ID(in) ESP PUMP,5,812.0 f5,803.0 3,629.5 68.73 SLIPSTOP 3.5"SLIPSTOP 4/23/2016 5,804.0 3,629.8 68.73 PACKOFF 3.5"DBD PACKOFF(OAL-93") 4/23/2016 il 5,812.0 3,632.7 68.73 ESP PUMP PCPESP PUMP W/TEST PORT(All OAL-43'5") 4/23/2016 ESP Intake;5,858.2 (tilt I Seal,5,0800 Perforations&Slots Shot Gear Boz,5,874.7 Dens Top(TVD) Btm(ND) (shots/ ESP Motors 8 Cables;5,876.51) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type co. GAUGE,5,883.3 6,547.0 10,466.0 3,801.8 3,752.1 WS B,1C- 12/12/2008 50.0 SLOTS Alternating 37'screens 8 = 102 31'blank pipe CENTRALIZER;5,885.1 Mandrel Inserts St ati D-SAND LINER;5,936.1- • on Top(ND) Valve Latch Port Size TRO Run 10,566.5 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 2,384.4 1,944.1 Camco KBMM/ 1 ESP DMY BEK 0.000 0.0 4/17/2016 BK-5 2 2,624.4 2,048.4 Camco KBMG/ 1 ESP DMY BK-5 0.000 0.0 4/11/2016 •' _ BK-5 3 5,742.1 3,607.4 Camco KBMG/ 1 ESP SOV BK-5 0.000 0.0 4/17/2016 2000 .,SI BK-5 #tbg I shear Notes:General&Safety End Date Annotation 7/20/2002 NOTE.MULTI-LATERAL WELL' B-SAND(1C-102),D-SAND(1C-102L1) 7/14/2009 NOTE:View Schematic w/Alaska Schematic9.0 I 5/24/2012 NOTE:ESP FEED-THRU PACKER NECESSITES SLOW BLEED OFF OF PRESSURE IN IA. SURFACE;41 2-6,5113.2-.1 SLOTS;6,547.0.10,486.0 o n0 so B-SAND LINER,6,042.4 l 10,550.9 111.1e-ti( cC PM 2 1 k2 t o Regg, James B (DOA) From: Buck, Brian R <Brian.R.Buck@conocophillips.com> Sent: Thursday, April 14, 2016 8:49 AM e � To: DOA AOGCC Prudhoe Bay 1 G Cc: Herbert, Frederick 0; Kanady, Randall B Subject: 1C-102 BOPE Use Attachments: 1C-102 BOPE Letter 4 13 16.pdf Please find attached a letter to close out COP's email notification of BOP use. The anticipated packer gas never seemed to migrate to surface and no pressure increase was seen on the annular. However, this is being sent to close out the original email notification. Please let me know if you have any questions/concerns. Thank you, Brian Buck Completions and Workover Supervisor office:907-265-6826, cell:907-223-6320,home:907-868-4834,fax:918-662-6213;700 G St.,ATO-1500;Anchorage,AK 99501 %CAWED SEP 2 12016 1 • ConocoPhi'lips Alas Ka P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 13,2016 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003,this letter is to follow up the email notification of BOPE usage on Nabors 7ES with a written report.Although the BOP equipment was not used to prevent the flow of fluids from the well,this report is being submitted for completeness in order to close out the original email notification. Time of BOPE Use:4/8/2016 at 21:00 hours Well Location: 1C-102 API Number: 50-029-23037-00 PTD Number: 201-161 Rig Name: Nabors 7ES Operator Contact:Brian Buck. (o)907-265-6826.(c)907-223-6320.Brian.r.buck@conocophillips.cotn Operations Summary: On 4/8/2016 at 21:00 hours,the annular was shut in as a preventative measure rho unseating the packer since gas under the packer was expected to migrate up the annulus when the packer was released. When the packer was released,however,no gas migrated and multiple attempts to bullhead past the packer resulted in pressuring up against the packer to 800-900 psi. Then the well was pressured up to 2500 psi in attempt to shear a shear out valve(SOV)in the tubing string. The SOV did not shear. As the well was dead,the rig began to rig up to pull the completion out of the hole. While rigging up,the packer relaxed and the well started taking fluid.The rig pumped 190 bbls of seawater down the annulus.The rig then retested the annular to 250 psi and 2500 psi as stated in the email notification. BOPE Used: Annular Reason for BOPE Use: Preventative in anticipation of trapped gas that did not migrate and to bullhead into the reservoir to ensure the well was dead. Actions To Be Taken:The annular was retested on 4/9/2016 at 04:30 hours. After bullheading fluid,the well was observed to be dead by being shut in and observing zero pressures on the gauges. We subsequently tripped out of the hole with the completion. If you have any questions or require any further information,please contact me at 265-6826. Sincerely, Brian Buck Completions and Rig Workover Supervisor CPAI Drilling and Wells c + • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 5C26 BOPE Test Report Ix?\41 Submit to: jim.reqqalaska.qov AOGCC.Inspectors a(�,alaska.gov phoebe.brooks(a,alaska.gov Contractor: Nabors Rig No.: 7ES DATE: 4/9/16 Rig Rep.: K. Barr/D. Johnston Rig Phone: 907-659-7847 Operator: CPAI Op. Phone: 907-659-7844 Rep.: R. Dolcater/A. Romero E-Mail n2364Qconocophillips.com Well Name: 1C-102 PTD# 2011610 Sundry# Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Test Pressure(psi): Rams: 250/2500 Annular: 250/2500 - Valves: 250/2500 —MASP: 428 . MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 1 NT Housekeeping P Rig P - Lower Kelly 1 NT PTD On Location P Hazard Sec. P - Ball Type 2 NT Standing Order Posted P Misc. NA Inside BOP 1 NT FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P NT Annular Preventer 1 13-5/8"GK P - Pit Level Indicators P NT #1 Rams 1 2-7/8"x 5" NT Flow Indicator P NT #2 Rams 1 Blind Rams NT Meth Gas Detector P NT #3 Rams 1 2-7/8"x 5" NT H2S Gas Detector P NT #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3-1/8"Gate NT Inside Reel valves 0 NA HCR Valves 2 3-1/8"Gate NT Kill Line Valves 2 3-1/8"&2" NT Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) NT CHOKE MANIFOLD: Pressure After Closure(psi) NT Quantity Test Result 200 psi Attained (sec) NT No.Valves 16 NT Full Pressure Attained(sec) NT Manual Chokes 1 NT Blind Switch Covers: All stations Yes Hydraulic Chokes 1 NT Nitgn. Bottles#&psi(Avg.): NT CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 1.0 -Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Re-Test Annular Annular due to bull heading. AOGCC Inspection 24 hr Notice Yes Date/Time 4/8/16 @08:30 Waived By Lou Grimaldi ' Test Start Date/Time: 4/9/2016 5:00:00 AM (date) (time) Witness Test Finish Date/Time: 4/9/2016 6:00 Form 10-424(Revised 11/2015) Nabors 7ES 4-9-16 Annular retest.xlsx ' STATE OF RE ALP OIL AND GAS CONSERVATION COMIDSION C IVED REPORT OF SUNDRY WELL OPERATIONS APR 0 2 2012 1. Operations Performed: Abandon r Repair w ell f Plug Perforations J Perforate I " r, � • g r Tubing Fr. Stimulate - Frac W aiver r Time Alter Casin P Tubin Alaska Ex c ten n ie Comt7 ' s ��ttlong „j 1 Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended-Wet r " 40 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development rj Exploratory f _ - 201 -161 3. Address: 6. API Number: Stratigraphic r Service E P. O. Box 100360, Anchorage, Alaska 99510 ^ 50 029 - 23037 - 00 - ct 7. Property Designation (Lease Number): 8. Well Name and Number,_ ADL 25649 1C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): L - none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 10570 feet Plugs (measured) None true vertical 3753 feet Junk (measured) None Effective Depth measured 10566' feet Packer (measured) 2509, 6042 true vertical 3753' feet (true vertucal) 1998, 3714 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121 16 161 161 SURFACE 6477 7.625 6518 3801 B -SAND LINER 4509 4 10551 3753 Perforation depth: Measured depth: 6547' - 10466' True Vertical Depth: 3802' -3752' $L p i E APR 01 0� .... 1 Tubing (size, grade, MD, and TVD) 3.5, L -80, 5884 MD, 3658 TVD r `Li Packers & SSSV (type, MD, and TVD) HYDROW -II DUAL STRING PACKER - WEATHERFORD HYDROW 11 DUAL - STRING PACK R @ 2509 MD and 1998 TVD ',i BAKER SCR -1 PACKER @ 6042 MD and 3714 TVD NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 186 67 72 -- 279 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 — Service r Stratigraphic r 16. Well Status after work: vOil Gas I- WDSPL r Daily Report of Well Operations XXXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Ian Toomey 263 -4773 Printed Name Ian Toomey Title Wells Engineer Signature - Phone: 263 -4773 Date 3 - 3 U _/ ` , L RBDMS APR 0 3 1 ri Only Form 10 -404 Revised 11/2011 Submit Original final O y KUP • 1C-102 lir Da Conoco Phillips &Wee - Well Attributes Max Angle & MD TD Wellbore API /UWI Field Name Well Status Incl (°) MD (ftKB) Act Btm (ftKB) Inc. Alaska, 500292303700 WESTSAK PROD 93.45 7,199.84 10,570.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NONE 5 9/25/2011 Last WO: 45.31 10/13/2001 Well Confiq - 1C-102 3/25/2012 2. 15'31 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: WORKOVER ninam 3/25/2012 Casing Strings Casing Description String O . String ID _. Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String String Top Thrd HANGER, 25 CONDUCTOR 16 15.062 40.0 161.0 161.0 62.50 H WELDED ( Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 7 5/8 6.875 41.2 6,518.2 3,801.4 29.70 L - 80 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd B -SAND LINER 4 3.548 6,042.4 10,550.9 3,752.9 9.50 L -80 SLHT l Liner Details Top Depth CONDUCTOR, (TVD) Top Ind Nonni... 40-181 Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 6,042.4 3,713.8 70.73 PACKER BAKER MODEL SCR -1 LINER TOP PACKER w/MILLOUT EXTENSION 4.000 6,0472 3,715.6 70.87 EXTENSION 4.000 6,050.2 3716.6 70.96 KOIV BAKER KOIV, MODEL 'C' 4.000 ,'�. 6,052.2 3,717.4 71.02 XO 5x4.5 - 4.500 6,090.3 3,730.5 72.12 SLEEVE BAKER 'CMD' SLIDING SLEEVE 3.413 6,132.4 3,743.4 73.34 X04.5x4 4.000 '.. 10,530.0 3,752.6 89.38 X04.5x5 5.000 GAS LIFT, IC 2,384 Tubing Strings I I I Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd II TUBING 3 1/2 2.992 25.4 5,884.0 3,657.5 9.30 L -80 EUE Completion Details / Top Depth r (TVD) Top 1661 Noml... ACKER, 2,09 Top (ftKB) (ftKB) ( °) Item Description Comment ID (In) 25.4 25.4 -4.16 HANGER VETCO TUBING HANGER 2,508.6 1,997.6 64.17 PACKER 3.500 ESP FEED -THRU PACKER, WEATHERFORD HYDROW 11 3.250 DUAL -SRING PACKER 5,793.9 3,626.1 68.73 GAUGE WELLLIFT DISCHARGE GAUGE UNIT (SM: 11937004) 2.992 G Fr. 5,851.8 3,647.2 68.73 INTAKE TTC RECEIVING XOCOUPLING w/ PERFORATED INTAKE 2.992 2.621 (S/N:11990187) 5,856.3 3,646.1 66.80 SEAL TANDEM SEAL SECTION (S/N's: 11623190 -B, 11623222 -1) 5,870.1 3,651.8 67.06 Reduction GEAR REDUCTION UNIT (S/N: 11985669) II 5,871.9 3,652.6 67.10 MOTOR ESP MOTOR, 562MSP1 60/1240/29 (S/N: 12057559) GAUGE, 5,794 5,880.2 3,656.0 67.26 GAUGE WELLLIFT MOTOR GAUGE UNIT (S/N: 192- 00767) 5,882.1 3,656.7 67.29 Centralizer MOTOR CENTRALIZER (P/N: C63569) III Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (MB) (ftKB) Zone Date (.hComment . Type Comment INTAKE. 5.852 6,547 10,466 3,801.6 3,752.1 WS B, 1C 12/12/2008 50.0 SLOTS Alternating 37' screens & 31' blank SEAL, 5,856 .. pipe Reduction, 5870 MOTOR 5,872 Notes: General & Safety GAUGE, 5,880 End Date Annotation Central¢er, 7/20/2002 NOTE: MULTI - LATERAL WELL: B - SAND (1C - 102), D - SAND (1C 102L1) 5, SURFACE, 41 - 7/14/2009 NOTE: View Schematic w/ Alaska Schematic9.0 8,518 i. SLOTS, 8,547 AND I - / LSND LINER, , 8,042- - 01 AND DLSAND LINER, 5,936 - 10,0,588 U Mandrel Detains Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type Un) (psi) Run Date Com... 1 2,384.1 1,944.0 64.79 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 2/27/2012 2 2,621.4 2,047.1 63.76 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/27/2012 s 0 RA 11 0 6 008 TD (1C-102). 1 1 0,570 1C -102 and 1C -102L1 Well Work DATE SUMMARY 12/28/11 PRE RWO T -POT BONNET( SED ), T -PPPOT BONNET ( PASSED ), -POT UPPER BODY ( PASSED ), T -PPPOT UPPER BODY ( PASSED ), T -POT LOWER BODY ( PASSED ), T -PPPOT LOWER BODY ( PASSED ), GLS TEST ( PASSED ), GLS -PP TEST ( PASSED ), FT -LDS ALL NORMAL. 2/6/12 BAILED FILL. PULLED SLIPSTOP @ 5784' SLM. IN PROGRESS. 2/7/12 REPLACED SOV @ 5663' RKB w/ DV, RAN PACKOFF TEST TOOL TO 5783' SLM, PASS MITT TO 2500 PSI, PULLED TEST TOOL, EQUILIZED 4 1/2 D &D PACKK OFF ASSY', IN PROGRESS. 2/8/12 PULLED 4 1/2 D &D PACKOFF ASSY' @ 5783' SLM, PULLED 37.44' ESP @ 5792' SLM, LRS PUMP 155 BBLS HOT DIESEL DOWN IA & 90 BBLS HOT DIESEL DOWN TUBING, BPV HAS BEEN CALLED TO INSTALL, JOB COMPLETE. • • Con ©c ©Phillips Time Log & Summary Wellview Web Reporting Report Well Name: 1C-102 Rig Name: NORDIC 3 a - Job Type: RECOMPLETION Rig Accept: 2/22/2012 2:00:00 AM Rig Release: 3/4/2012 8:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/21/2012 24 hr Summary Rig Move 1E-05A to 1C-102. Set -up Rig Mats. 12:00 16:00 4.00 MIRU MOVE DMOB P Rig Move 1E -05Ato 1C -102. Stop at 1 E and Spine road access. 16:00 19:00 3.00 MIRU MOVE MOB P Standby for aircraft arrival and departure, field crew changeouts. 19:00 23:30 4.50 MIRU MOVE MOB P Continue Rig move 1E and Spine road access to 1C pad. 23:30 00:00 0.50 MIRU MOVE RURD P Move in mats, Build mat ramp to climb up on double mats. 02/22/2012 Spot Riq over well. Accept Riq (a), 02:00 hrs. MIRU all support equipment, Pull BPV. Pressure Test hard line, manifold and hoses. Reverse circulate well with hot 8.6 ppg filtered seawater with 3% KCI, Monitor well. Load and tally 3 -1/2" Drill pipe, 4 -3/4" Drill collars while waiting on filtered fluids. 00:00 03:30 3.50 MIRU MOVE RURD P Build mat ramp to climb up on double mats. Spot and level rig on double mats, berm up. Waiting on rig support equipment and KWF from MI filter skid. Nordic Rig 3 accepted at 02:00 hrs on 02/22/2012 03:30 12:00 8.50 MIRU MOVE RURD T Waiting on Support. Support Crew on location to RU Hard line from Rig to Kill Tanks. First Load of 8.6 ppg Brine on Location. 12:00 14:15 2.25 MIRU MOVE RURD P PJSM. Starting Rigging Up hard line and Un- loading fluid onto rig pits. Crane on Location to Load empty spool and spooling equipment. 14:15 15:00 0.75 MIRU RISER MPSP P PJSM. Load Lubricator and Pull BPV. 15:00 15:30 0.50 COMPZ WELCTL PRTS P PJSM. Discuss hazard for Testing lines. Fluid pack and PT Hard -line to 325/ 15:30 16:45 1.25 COMPZ WELCTL OWFF P Call DSO and Security. Open well and obtain Initial TBG & IAP. 690 psi on TBG and 690 psi IA. Open Choke and Bleed gas cap down to kill tank. 16:45 18:00 1.25 COMPZ WELCTL CIRC P Started seeing fluid back to kill tank. Line up mud pump to reverse circulate down IA taking returns up tbg at 5 bpm, 300 psi. After 100 bbls pump had 60 psi on IA and 0 on TBG, no returns at kill tank. After 181 bbls down TBG, shut in IA and bullheaded 109 bbls down tubing. Page 1 of 11 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:00 1.00 COMPZ WELCTI OWFF P Monitor well for flow. SITP after 15 mins was 270 psi. Call and discuss results with town engineer. Monitor well for 15 more minutes, SI TP /IAP = 210/240 psi continue to monitor well, Call and discuss with town engineer about building filtered volumes in pits and tanks. 19:00 21:00 2.00 COMPZ WELCTI KLWL P Line up and circulate another Inner annular volume at 5 bpm, ICP 240 psi, TBG at 0 psi after 80 bbls, FCP 70 psi on IA. Shut down after 180 bbls, Bullhead 40 bbls down TBG 5 bpm at 70 psi, IA climbing from 70 to 230 psi. Shut down, SI TP /IAP= 0/250 psi. 13 bbl return to kill tank. 21:00 22:00 1.00 COMPZ WELCTI OWFF T Monitor well while building filtered fluid volumes in pits and tanks. SI TP /IAP= 0/240 psi after 15 mins. T /IA= 0/240 psi after 30 minutes, gas at surface on IA. Bleed gas from IA slowly for 30 min, T /IA= 0/0 psi, shut in and monitor pressures 30 mins, SI TP /IAP= 0/0 (light vac on TBG, small amount of steady gas from IA) Load and Tally 3 -1/2" DP, 4 -3/4" DC's. 22:00 00:00 2.00 COMPZ WELCTI KLWL T Wait on Filtered Seawater from MI filter skid, Transports having trouble loading seawater at CPF -1, traveling to CPF -3 to load and come back to filter skid on 1D pad. Continue to load and tally DP and DC's. Tubing= 0 psi, has very slight vac, IA= 0 psig, steady small amount of gas. 02/23/2012 continue to load and tally DP, DC's while waiting on fitered KWF. Take on KWF to pits. Circulate 8.6 ppg filtered seawater. Install BPV. ND and Inspect Tree. Set Blanking Plug. NU 13 -5/8" 5M BOPE. Test BOPE 250/3000. Pull BPV and Blanking Plug. Install landing joint. BOLDS. 00:00 00:45 0.75 COMPZ WELCTI KLWL T Wait on Filtered Seawater from MI filter skid, Transports traveling to CPF -3 to load and come back to filter skid on 1D pad. Continue to load and tally DP and DC's. Tubing= 0 psi, has very slight vac, IA= 0 psig, steady small amount of gas. 00:45 01:45 1.00 COMPZ WELCTI KLWL T 290 bbls filtered seawater on site, off load to pits. 290 bbls total in pits. Tubing= 0 psi, static IA= 0 psig, steady small amount of gas. Page 2 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 03:45 2.00 COMPZ WELCTL KLWL T Wait on Filtered Seawater from MI filter skid, Transports traveling to CPF -3 to load and come back to filter skid on 1D pad. Continue to load and tally DP and DC's. 03:45 04:45 1.00 COMPZ WELCTL KLWL T 290 bbls filtered seawater on site, off load to pits. 580 bbls total in pits. Tubing= 0 psi, static IA= 0 psig, steady small amount of gas. 04:45 07:00 2.25 COMPZ WELCTI KLWL T Wait on Filtered Seawater from MI filter skid, Transports traveling to CPF -3 to load and come back to filter skid on 1D pad. Continue to load and tally DP and DC's. 07:00 08:00 1.00 COMPZ WELCTL KLWL P Enough fluid on location to start well kill. Circulate 110 bbls of 8.6 ppg KCL down TBG at 5 bpm, 60 psi, still no returns, swap over and circulate 180 bbls down IA to flush completion at 5 bpm, 60 psi. 08:00 08:30 0.50 COMPZ WELCTL OWFF P Monitor well for flow. 08:30 09:00 0.50 COMPZ WELCTL MPSP P PJSM. Set BPV. 09:00 11:30 2.50 COMPZ WHDBO NUND P Nipple Down Tree and hang in cellar. Inspect Lifting threads and install blanking plug. 11:30 11:45 0.25 COMPZ WHDBO SFTY P PJSM. Discuss hazard for NU BOPE. 11:45 16:00 4.25 COMPZ WHDBO NUND P NU XO and 13 -5/8" 5M BOP Fgiiipment and riser with 2 -3/8" Solid body rams in top set and 2 -7/8" x 5 1/2" VPR's in the lower set. 16:00 22:30 6.50 COMPZ WHDBO BOPE P Fluid Pack BOP Stack & Perform Initial BOP Test 250/3000 psi for {{�� Ram's, Choke Manifold, and Annular. �J� Tested VBR's with 3 -1/2" and 4 -1/2" test joint and Annular with 2 -3/8" and 4 -1/2" test joint. Perform Koomey draw down test. Audio Alarms was also tested and Witness By AOGCC Rep. Bob Noble. Rig down pressure test equipment. 22:30 22:45 0.25 COMPZ WHDBO SFTY P PJSM- Discuss hazard for pulling blankig plug and BPV. 22:45 23:15 0.50 COMPZ WHDBO MPSP P PU MU blanking plug retrieval tool, pull blanking plug, Pull BPV. Set Side Port Isolation sleeve. 23:15 23:30 0.25 COMPZ WHDBO SFTY P PJSM- Discuss hazards with un- landing TBG hanger. 23:30 00:00 0.50 COMPZ WHDBO THGR P PU MU Landing Joint to Top Drive, screw in to TBG hanger, BOLDS. 02/24/2012 Un -seat Tubing Hanger. Circulate Well. Pull Tunging Hanger to floor. RU to pull the 4 1/2" ESP /HT Completion. TOOH with 4 1/2" Tubing while spooling up ESP /HT/TEC Cables. Lay down ESP Assembly. Clean and Clear pipe shed. Set Wear Ring. Load and tally 2 -3/8" PH -6 Tubing. Bring in Baker equipment. PU MU 7 -5/8" Casing Scraper / Clean Out BHA #1. Page 3 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 COMPZ WHDBO THGR P Attempted to pull the Tubing Hanger frPP Worked up to 80% of the tubing tensile strength plus Top Drive weigh (201 K). Continue to work to pull free. No -Joy. Wrap TBG head with steam blanket, Pulled free in 20 mins at 175k, PU 7 -ft, UP wt 138k. 01:00 02:30 1.50 COMPZ WHDBO CIRC P Bullhead 200 bbls 130° filtered KWF down the IA 4 bpm at 40 psi and 90 bbls of same filtered KWF down the TBG 4 bpm at 40 psi. BDTD. Well on vac. monitor well. 02:30 02:45 0.25 COMPZ WHDBO SFTY P PJSM- Discuss hazards pulling TBG hanger to floor and ESP pulling procedures with Centrilift reps. 02:45 04:30 1.75 COMPZ RPCOM THGR P Pull TBG hanger to floor, inspect for re -use. Check ESP cable for continuity. PU 1 stand of 4 -1/2" TBG. Rig up ESP / Heat Trace and TEC wire over sheaves to spoolers. 04:30 09:00 4.50 COMPZ RPCOM PULL P TOOH standing back 4 -1/2" TBG on ODS spooling ESP /HT/TEC wire laying down all jewelry as it presents itself, tracking all clamps pulled and pumping triple displacement on every 5 stands. 09:00 10:00 1.00 COMPZ RPCOM OTHR T Stop and Make Repairs to ESP Spooler. The guard for the cable was not tracking during spooling operation. 10:00 15:00 5.00 COMPZ RPCOM PULL P Continue to T,QOH s anding.� Clt 4 -1/2" TBG on ODS spooling ESP / HT/TEC wire laying down all jewelry as it presents itself, tracking all clamps pulled and pumping triple displacement on every 5 stands. Total Cannon Remove From Completion - (452) 5' Mid Joint dual channel, (7) 3' Mid -jt dual channel, (4) 4' mid -jt dual channel, (12) 2' mid -jt dual channel, (96) cross cplg dual channel, (49) cross cplg single channel, (1) end shoe dual channel. (1) Motor Protectorlizer (2) Pump Protectorlizers 15:00 18:00 3.00 COMPZ RPCOM PULD P Reached Intake Screen Section. PJSM. "Recommended Practices for ESP Dismantle, Inspection & Failure Analysis (DIFA)" Start the Dismantle Process. 18:00 20:30 2.50 COMPZ RPCOM OTHR P Clean and clear floors. Load out ESP equipment. Bring in Baker equipment. Change floors over to 2 -3/8" running equipment. Set Wear Ring. Page 4of11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 20:45 0.25 COMPZ RPCOM SFTY P PJSM- discuss hazards of running small pipe, use dog collar for light pipe, watch hand placement, communication. 20:45 00:00 3.25 0 3,171 COMPZ RPCOM PULD P PU MU 7 -5/8" Casina Scraper / Cjean Out Assembly BHA #1- e° k Muleshoe, 2 -3/8" PH -6 tbg (145jts), e ,�/ X P x P XO, 7 -5/8" Casing Scraper, Bit Sub, 4 -3/4" Lubricated Bumper Sub, 4 -3/4" Oil Jar, 4 -3/4" Drill collars (6 jts), 4 -3/4" Intensifier. 32/25/2012 PU MU 7 -5/8" Casing Scraper / Clean Out Assembly BHA #1. Clean out / Fluff and Stuff "B" sand liner to 10,500 -ft. TOOH with BHA #1. 00:00 02:00 2.00 3,171 4,649 COMPZ RPCOM PULD P Continue to PU MU 7 -5/8" Casing Scraper / Clean Out Assembly BHA #1- Muleshoe, 2 -3/8" PH -6 tbg (jts 100 thru 145) 02:00 03:00 1.00 4,649 4,649 COMPZ RPCOM OTHR P Change over floors. 03:00 04:30 1.50 4,649 4,870 COMPZ RPCOM PULD P PJSM- Continue MU BHA #1 - XO, P x P XO, 7 -5/8" Casing Scraper, Bit Sub, 4 -3/4" Lubricated Bumper Sub, 4 -3/4" Oil Jar, 4 -3/4" Drill collaars (6 jts), 4 -3/4" Intensifier. 04:30 08:00 3.50 4,870 7,066 COMPZ RPCOM TRIP P TIH with BI-HA #1 on1 /Zo2riil Pjpe. slowing down thru hook hanger at 5,936 -ft and SCR -1 liner top packer at 6,042 -ft 08:00 08:45 0.75 7,066 7,066 COMPZ RPCOM CIRC P Stop at 7,066 -ft and Circulate one Annular Volume (190 bbls) at 4 bpm, 40 psi. Pumped 143 bbls and Lost 250 bbls due to the well being on a vac. 08:45 12:00 3.25 7,066 10,501 COMPZ RPCOM TRIP P Continue in Hole with 7 5/8" Scraper and Mule shoe Assembly 12:00 17:00 5.00 10,501 4,905 COMPZ RPCOM TRIP P No problem working down to 10,500 -ft with Scraper & Mule Shoe Assembly. Up Wt 145k / Dn Wt 67k. Start TOOH standing back Drill Pipe and Laying down 2 3/8" PH6 TBG and Scraper Assembly. 17:00 19:00 2.00 4,905 4,905 COMPZ RPCOM OTHR P Secure well. Crane on site. PJSM- change out ESP cable spools old for new, off load heat trace cable and spooler. 19:00 20:00 1.00 4,905 4,649 COMPZ RPCOM PULD P Lay down BHA #1- Intensifier, DC's, Oil Jars, Bumper Sub, Bit Sub, & 7 -5/8" Casing Scraper, XO, XO. 20:00 21:00 1.00 4,649 4,649 COMPZ RPCOM OTHR P Change over floors to 2 -3/8" equipment. 21:00 00:00 3.00 4,649 2,823 COMPZ RPCOM TRIP P Single down 2 -3/8" PH6 tbg from 4,649 -ft stillpumin2lriple displacement every 5 stds, 20 bbls every hour. Page 5 of 11 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/26/2012 24 hr Summary TOOH with BHA #1. MU & TIH with 7 -5/8" Lock -set RBP / Test Plug Assembly BHA #2. Test 7 -5/8" Casing 1500 psi, Passed. TOOH with BHA #2. Single down and kick out 4 -1/2" De- completion. Load, drift and tally 3 -1/2" ESP completion w/ Feed -thru packer. 00:00 03:00 3.00 2,823 0 COMPZ RPCOM TRIP P Continue to single down 2 -3/8" PH6 _ thg from 2 823 -ft 03:00 03:45 0.75 0 0 COMPZ RPCOM OTHR P Change over floors to 3 -1/2" equipment. Load out PH6 tbg. clean and clear floors. 03:45 04:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Discuss hazards of MU and running RBP and Test plug. Cold weather assessment for anyone working outside -53° wind chill, Loader shut down due to -37° ambient temperatures. 04:00 04:30 0.50 0 35 COMPZ RPCOM PULD P PU MU 7 -5/8" RBP - ' • Assembly BHA #2- 7 -5/8" Model "G" Lock set RBP, Model "L" Retrieving head, 7 -5/8" Retrievamatic Test PKR. 04:30 08:30 4.00 35 5,812 COMPZ RPCOM TRIP P TIH with BHA #2 (test packer & RBP) on 3 -1/2" Drill Pipe down to 5,812 -ft � 08:30 09:00 0.50 5,812 5,812 COMPZ RPCOM PLUG P Set RBP at 5,812 -ft. Release and PUH one stand, and set Test Packer. 09:00 09:45 0.75 5,812 5,812 COMPZ RPCOM PRTS P RU testing equipment. PT between RBP and Test Packet to 1500 psi for 15 minutes. Bleed down pressure and Pressure test 7 5/8" CSG to 1500 psi for 15 minutes. Both test passed. 09:45 10:00 0.25 5,812 5,812 COMPZ RPCOM PLUG P Release Test Packer, PUH one stand, RIH, latch and release RBP and let elements relax. 10:00 14:00 4.00 5,812 0 COMPZ RPCOM TRIP P TOOH w/ RBP and Test Packer. 14:00 14:30 0.50 0 0 COMPZ RPCOM PULD P Lay Down Test Packer and RBP and Un -load from pipe shed. 14:30 16:30 2.00 0 0 COMPZ RPCOM PULD P Kick out un- needed drill pipe and PH6 2 3/8" tubing. Load 3 1/27 completion equipment. 16:30 21:00 4.50 0 5,830 COMPZ RPCOM TRIP P TIH with 64 stands of 4 1/2" De- completion 21:00 00:00 3.00 5,747 2,790 COMPZ RPCOM TRIP P TOOH sideways laying down TBG and un- loading to secondary containment to 2,584 -ft 02/27/2012 Continue to single down and kick out 4 -1/2" De- completion. Pull Wear Ring. Slip and Cut. Wait on Weather. Load, drift and tally 3 -1/2" ESP completion. Run TTC -ESPCP 3 -1/2" Tubing Completion with Feed -thru Packer. 00:00 02:30 2.50 2,790 0 COMPZ RPCOM TRIP P TOOH sideways laying down TBG and un- loading to secondary containment. Pull Wear Ring. 02:30 03:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM- hazards during slip and cut operations. 03:00 05:00 2.00 0 0 COMPZ RPCOM SLPC P Slip and Cut 84 -ft Drill Line Page 6 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 06:30 1.50 0 0 COMPZ RPCOM OTHR P Continue to load, drift and tally 3 -1/2" completion equipment, review completion tally and running order. 06:30 13:00 6.50 0 0 COMPZ RPCOM OTHR T Shut down Loader operation due to cold weather condition -38 deg. 13:00 13:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Discuss hazards with handling and running ESP completion with Centrilift and Weatherford Reps. 13:15 16:15 3.00 0 43 COMPZ RPCOM PULD P PU Motor centralizer, welllift sensor and motor. PU gear reduction unit and MU to motor section and Service same. MU motor lead extension cable and TEC wire. 16:15 17:15 1.00 43 85 COMPZ RPCOM RCST P Start Lowering ESP into well while attaching the MLE cable to the ESP assembly. Stop and Install the Welllift discharge gauge unit and connect the TEC wire from the motor gauge unit. 17:15 19:30 2.25 85 85 COMPZ RPCOM RCST T Machined channel for #1 size cable not wide enough on DGU, disassemble from string, off load to Centrilift Rep. truck, Centrilift to repair off site. 19:30 19:45 0.25 85 85 COMPZ RPCOM SFTY P PJSM- Discuss hazards with handling and running ESP completion with Centrilift reps and Nordic night crews. Review running order. 19:45 21:15 1.50 85 185 COMPZ RPCOM RCST P MU DGU to completion string and continue with Install of the Welllift discharge gauge unit and connect the TEC wire from the motor gauge unit. Installed 2 ea. 1 -1/2" SS flat bands, 1 above and 1 below DGU to hold ESP cable in channel. TIH 4 jts and MEG cable, all good as per Centrilift rep. 21:15 00:00 2.75 185 2,182 COMPZ RPCOM RCST P TIH with 3 -1/2" ESP completion installing Cannon Clamps every other collar keeping accurate account of all clamps installed. MEG wire at jt #36 at 1,182 -ft, jt #68 at 2,182 -ft. X2/28/2012 Continue to Run TTC -ESPCP 3 -1/2" Tubing Completion with Feed -thru Packer. Make Final Splice. Land Tubing Hanger. Test Pack -off. Continue 20 bbls down well every hour while waiting on weather. 00:00 02:00 2.00 2,182 3,365 COMPZ RPCOM RCST P Continue to TIH with 3 -1/2" ESP completion installing Cannon Clamps every other collar to first GLM, then every collar to packer keeping accurate account of all clamps installed. 02:00 07:00 5.00 3,365 3,390 COMPZ RPCOM PULD P PU & MU Weatherford WFT Hydrow -II packer, check integrity, MU cable assembly through packer, check integrity. Page 7of11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 12:00 5.00 3,390 32 COMPZ RPCOM RCST P Continue to TIH with 3 -1/2" ESP completion installing Cannon Clamps every collar to top GLM, then every other collar to surface keeping accurate account of all clamps installed. Up wt 77k, Dn wt 58k 12:00 15:00 3.00 32 32 COMPZ RPCOM OTHR P PU TBG Hanger and install penetrators. Space out and make final splice. 15:00 16:00 1.00 0 0 COMPZ RPCOM HOSO P Land TBG hanger 120k Up wt, 65k Dn wt. RILDS Final Clamp count: 102 ea Cannon Single channel cross clamps (every other collar MLE to surface) 4 ea Cannon Seal clamps (across Tandam seal sections) 2 ea 1 -1/2" SS Flat bands (lea. above and below DGU) 16:00 17:00 1.00 0 0 COMPZ RPCOM PRTS P PT Inner and Outer Hanger Pack offs at 250/5,000 psi. Pull ISO sleeve and reinstall landing joint. 17:00 00:00 7.00 0 0 COMPZ RPCOM PULD T Change over floors and single down 3 -1/2" DP in mouse hole to pipe shed (23 stands) Continue to pump10 bbls down Tubing and 10 bbls down IA every hour for hole fill while waiting on weather. J2/29/2012 Continue 20 bbls down well every hour while waiting on weather. Review well program, audit rig for repair and maintenance. 00:00 06:00 6.00 0 0 COMPZ RPCOM CIRC T Continue to single down remainder of 3 -1/2" DP in mouse hole to pipe shed. Continue to pump 10 bbls down Tubing and 10 bbls down IA every hour for hole fill while waiting on weather. Review well program, audit rig for repair and maintenance. 06:00 12:00 6.00 0 0 COMPZ RPCOM CIRC T Continue to pump 10 bbls down Tubing and 10 bbls down IA every hour for hole fill while waiting on weather. Review well program, audit rig for repair and maintenance. Page 8 of 11 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 0 0 COMPZ RPCOM CIRC T Continue to pump 10 bbls down Tubing and 10 bbls down IA every hour for hole fill while waiting on weather. Temperature reached -35° for 3 hrs during the afternoon, but still unable to operate. Everybody is on call, standing by.. Review well program, audit rig for repair and maintenance. 18:00 00:00 6.00 0 0 COMPZ RPCOM CIRC T Continue to pump 10 bbls down Tubing and 10 bbls down IA every hour for hole fill while waiting on weather. Review well program, audit rig for repair and maintenance. 03/01/2012 Continue 20 bbls down well every hour while waiting on weather. RU Slickline. Freeze Protect Tubing. Set WRP and Test. Load IA with 60 bbls Gelled Diesel, IA pressured up. Confer with town engineer. Set WF Hvdrow - ll Packer. 00:00 06:00 6.00 0 0 COMPZ RPCOM CIRC T Continue to pump 10 bbls down Tubing and 10 bbls down IA every hour for hole fill while waiting on weather. Review well program, audit rig for repair and maintenance. 06:00 14:00 8.00 0 0 COMPZ RPCOM CIRC T Continue to pump 10 bbls down Tubing and 10 bbls down IA every hour for hole fill while waiting on weather. Review well program, audit rig for repair and maintenance. 14:00 14:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Discuss hazards with getting back to work after extended period of cold weather. 14:15 15:30 1.25 0 0 COMPZ RPCOM OTHR P Roudup Slickline crew, ETD and WRP. Off load 3 -1/2" DP. Load Slickline lubricator all ready on site. 15:30 15:45 0.25 0 0 COMPZ RPCOM SFTY P Discussed hazards of Slickline rig up, running WRP. 15:45 18:00 2.25 0 0 COMPZ RPCOM SLKL P RU HES Slickline unit 214, pressure test equipment 500 psi. 18:00 19:15 1.25 0 2,623 COMPZ RPCOM SLKL P RIH w/ 3" OK -1 and JK running tool, locate GLM #1 at 2,623- ft- POOH to change out tools. Pupm 25 bbls diesel down TBG. 19:15 20:45 1.50 0 2,654 COMPZ RPCOM SLKL P RIH w/ 2.78" OD WRP on HES 1- 11/16" Down hole Power Unit, set top of WRP at 2,650 -ft- POOH, change out tools. 20:45 21:15 0.50 0 2,650 COMPZ RPCOM SLKL P RIH w/ 2.75" Catcher ( "G" FN, 29" OAL) on 3" GS; set at 2,648 -ft. POOH (Noticed fluid level at 1,050 -ft) Page 9 of 11 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 21:45 0.50 0 0 COMPZ RPCOM PRTS P Test WRP to 500 psi (9.8 bbls to fill TBG) lost 100 psi in 15 min. bleed to 0 psi to get air out of system. 21:45 22:15 0.50 0 0 COMPZ RPCOM PRTS P Stand lubricator back, RU head pin and test equipment, retest WRP to 500 psi, good 22:15 23:45 1.50 0 0 COMPZ RPCOM CIRC P Line up on IA, pressured up to 500 psi immediatly, Check and remove ice plug from hose, circulate gelled diesel down IA 3 bpm at 70 psi, pressure building at 60 bbls, shut down at 1000 psi, bleeds back very slowly, bleed back to 0 psi and pressure back up to 1000 psi, Confer with town engineer, Bleed IA to 0 psi. line up pump to TBG. 23:45 00:00 0.25 0 0 COMPZ RPCOM PACK P Initiate packer setting, pressure TBG to 3000 psi. pressure dropped to 2700 psi in 10 min, bump TBG pressure back to 3000 psi X3/02/2012 Set WF Hydrow -II Packer. Pull DV in Top GLM at 2,384 -ft. Circulate TBG / IA 110 bbls Gelled Diesel. Set DV at 2,384 -ft. Pressure test IA 1500 psi. RD Slickline. De- pressure IA per Centrilift schedule. RD landing Joint. Drain BOP stack. Install TWCV. ND BOPE. Check Cable integrity. NU Tubing head adapter and Tree. Test tree. Test Hanger void /pack -off. Make final cable integrity checks. Pull TWCV, Install BPV. Clean cellar. Move postponed while waiting on weather. 00:00 01:00 1.00 0 0 COMPZ RPCOM PACK P Continue setting packer, TBG at 3000 psi, TBG at 2950 psi in 20 minutes, packer set, bleed TBG to 0 psi, RD test equipment. 01:00 02:00 1.00 0 2,387 COMPZ RPCOM SLKL P PJSM- RU lubricator and RIH w/ 3" OK -1 & 1.25" JDC; latch at 2,387 -ft and POOH w/ DV on BK, Change out Tools. 02:00 03:00 1.00 0 0 COMPZ RPCOM CIRC P Circulate 110 bbls gelled diesel down _ IA taking returns thru choke to kill tank 2 bpm at 150 psi ICP, 100 psi FCP. 03:00 03:30 0.50 0 2,387 COMPZ RPCOM SLKL P RIH w/ 3" OK -1 & DV on BK; set at 2,387 -ft- POOH 03:30 04:30 1.00 0 0 COMPZ RPCOM SLKL P PJSM- Discuss hazards of rigging down Slickline equipment. RD Slickline. ;} l 04:30 05:00 0.50 0 0 COMPZ RPCOM PRTS P Pressure test IA 1500 psi. chart 30 . r minutes, good. 05:00 08:00 3.00 0 0 COMPZ RPCOM PRTS P Start Centrilift time /pressure schedule for bleeding IA to 0 psi. RD test equipment. 08:00 09:00 1.00 0 0 COMPZ WHDBO THGR P Lay down landing joint. Set TWCV. 09:00 11:00 2.00 0 0 COMPZ WHDBO NUND P ND BOPE 11:00 12:00 1.00 0 0 COMPZ WHDBO DHEQ P Make ESP cable integrity tests, good. 12:00 13:30 1.50 0 0 COMPZ WHDBO NUND P NU Tree. 13:30 14:30 1.00 0 0 COMPZ WHDBO DHEQ P Make final ESP cable integrity tests, all systems go. All completed forms and readings in well file and folder. Page 10 of 11 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 15:30 1.00 0 0 COMPZ WHDBO PRTS P Pressure test tree 5000 psi 15 min on chart. test tubing hanger void 5000 psi. RD test equipment. 15:30 16:30 1.00 0 0 COMPZ WHDBO THGR P Pull TWCV and install 3" Type "H" BPV 16:30 18:30 2.00 0 0 COMPZ MOVE OTHR P Off load fluids, load tools. Clean and prep cellar for move. preform pre move warm up procedures for rig hydraulics. 18:30 00:00 5.50 0 0 COMPZ MOVE MOB T Cold Weather Shutdown procedures back in effect. Wait on Weather. Review well program, audit rig for repair and maintenance. 03/03/2012 Move postponed while waiting on weather. Review well program, audit rig for repair and maintenance. 00:00 06:00 6.00 0 0 COMPZ MOVE MOB T Continue to wait on weather over well 1C-102, continue to warm rig hydraulics. Review well program, audit rig for repair and maintenance. 06:00 18:00 12.00 0 0 COMPZ MOVE MOB T Continue to wait on weather over well 1C-102. Review well program, audit rig for repair and maintenance. 18:00 00:00 6.00 0 0 COMPZ MOVE MOB T Continue to wait on weather over well 1C -102. Review well program, audit rig for repair and maintenance. 03/04/2012 Move postponed while waiting on weather. RDMO Nordic Rig 3. 00:00 04:00 4.00 0 0 COMPZ MOVE MOB T Continue to wait on weather over well 1C -102. Review well program, audit rig for repair and maintenance. 04:00 08:00 4.00 0 0 COMPZ MOVE MOB P Cold weather restrictions lifted. start warming, circulating rig hydraulics, rolling tires. finish building ramp to move off well 102 and over well 109. Released Nordic 3 at 08:00 hrs on 3 -4 -12 Page 11 of 11 • Page 1 of 2 Regg, James B (DOA) • (1-6 -zoo 16 v From: NSK Prod Engr Specialist [n1139 @conocophillips.com] Sent: Friday, August 05, 2011 6:40 PM o 1 To: Regg, James B (DOA) Cc: NSK Prod Engr & Optimization Supv; NSK Fieldwide Operations Supt Subject: RE: 1C ESP well testing Jim — thanks for your reply, yes 1C -109 was treated the same as 1C -102 d tested the same day, (7/14/11) and is covered in the MISC report. Thanks, pt. -, , 1 °, . Darrell s From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, August 05, 2011 1:46 PM To: NSK Prod Engr Specialist Cc: Crisp, John H (DOA); Brooks, Phoebe L (DOA) Subject: RE: 1C ESP well testing This is an exception we will allow because of 1C-102 being an ESP well and opportunity to involve Centrilift personnel in monitoring. Normally the well should be retested with the pad test. Miscellaneous test report is correct. Was 1C -109 treated like 1C -102 or retested with pad test ?; your note is a little confusing in this regard. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Crisp, John H (DOA) Sent: Friday, August 05, 2011 11:23 AM To: 'NSK Prod Engr Specialist' Cc: Regg, James B (DOA) Subject: RE: 1C ESP well testing We had just tested 8 ESP wells on 1J Pad & the KRU State testers had a good procedure going & it was my opinion that it would be beneficial for State of Alaska to take advantage of Centralift & witness at least the 2 ESP wells on 1C Pad. I did not know at the time if an Inspector would be available to witness the entire 1C Pad for this month. After the 1C well tests we then finished the 1J Pad test. don't think the well will need to retested. My Supervisor will make that decision. These tests were not intended to cause confusion but just taking advantage of personnel available. Thanks From: NSK Prod Engr Specialist [mailto:n1139 @conocophillips.com] Sent: Friday, August 05, 2011 10:16 AM To: DOA AOGCC Prudhoe Bay Cc: NSK Prod Engr & Optimization Supv Subject: 1C ESP well testing 8/8/2011 Page 2 of 2 John- per our earlier phone conversation to let me know if you concur with the state�nt below. On 7/14 a 1J pad test was scheduled which included the testing of some ESP wells. This was coordinated with Centrilift as they had a short window of availability due to ongoing pump replacement activities, it was decided to test the ESP's on 1C pad also, (1 C -102 and 109 ). This was done to take advantage of Centralift's current availability to monitor the pumps. A separate MISC report has been completed for this activity. The 1C pad test occurred on 7/20 and 1C -102 was not tested during that time as it had been previously tested. Through our conversation it was determined that it was not necessary to go back and retest 1 C -102 as it was previously tested on 7/14. Please respond with your acceptance or changes to this explanation. Thanks, Darrell Humphrey / Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659 -7535 NSK -69 Pager (907) 659 -7000 (924) 8/8/2011 ~, ~~~ PROACTIVE DIncN05TIC SERVICES INC. i li~/ELL Lt7[a T14ANSfTTAL To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~ w ; E,~ ~.~ ~ ~j"~ 130 West International Airport Road ~°'~~ ~'~ ~~^~"' `~' ~ ` Suite C Anchorage, AK 99518 Fax: (907J 245-8952 1 J MTf Report 29-Ma}F10 1 G102 2J • 1 Report 50-029-23037-00 !~~ a~a:~F ~., ,: -~ Print Name: Da i ~ „, PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-MAIL : pdsarachorapeCcanaerseoryl~p.coan WEBSITE : tre~,vw.rftemorVlop.cssrn C:\Docutnents and Settings\Diazte Williams\Desk[op\Transmit_Conoco.docx • • Memory Magnetic Thickness Toal Lag Results Summary. Company: ConocaPhillips Alaska, Inc. Well: 1C-102 Log Date: May 29, 2010 Field: West Sak Log No.: 7409 State: Alaska Run No.: 1 API No.: 50-029-23037-00 Pipet Desc.: 4.5" 12.61b, L-80 NSCT Top Log Intvt1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 242 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib. L-80 BTC-MOD Top Log Intvl1.: Surface Pipet Use: Surtace Casing Bot. Log intvl1.: 242 Ft. (MD) Pipe3 Desc.: 16" 62.50 Ib. H-40 Welded Top Log Intvl1.: Surface Pipe3 Use: Conductor Bot. Log lntvl1.: 161 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This HTT data is tied into the Handle/ Hanger @ 0' Depth. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT}. The MTT responds to the total metal thickness of the 4.5" tubing and 7.625" casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 15 fpm, with 5Hz and 8Hz passes selected for analysis in this report. ^ INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surface to 242'. Changes in metal volume are relative to the calibration points at 78' and 198', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 4.5" tubing, 7.625" casing and 16" conductor pipe. ' A log plot overlay of the average overall metal thickness recorded by the 5Hz and 8Hz passes is included in this report. This plot indicates an area of up to 8°k relative metal loss over the interval (3' - 29') from the 5Hz pass, and up to 7% relative metal loss from the 8Hz pass. Since the lower frequency magnetic signals are more capable of permeating metal further from the tool than the higher frequency signals, the response from the 5Hz pass is considered to be more representative of the relative overall metal loss ftom the outer concentric string(s) in this interval. Several short intervals indicating up to 5% metal loss are indicated in the interval logged below 63', but the general instability in the data holding a firm baseline makes these intervals ' somewhat speculative in regard to representing a significant metal loss event. A log plot of the entire 5Hz pass is included in this report. Notable isolated metal loss events are indicated over the interval (113' to 116') and (214' to 242'). An expanded log plot of the 5Hz pass from 212' to 242' is included in this report to ' show the detail of the isolated metal loss events in tubing joint 8. A maximum ^~8% circumferential metal loss is indicated in the interval between 3' - 29' in the 5Hz pass. ' The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 4.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. ' Field Engineer: Wm. McCrossan Analyst: HY. Yang/J. Burton (MTT) Witness: R. Ober ProActive Diagnostic Services, Inc. / P.Q. Box 1369, Stafford, TX 77497 Phone: {281) or {888) 555-9085 Fax: {281) 565-1369 E-mail: PDSra?memorylag.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: {907) 659-2314 t 1 ~b~ - ~~~ A o`~"` ~E"s Shand 8Hz Passes Delta Meta~hickness overlay -r ~ F~'~ F~ ~ 1 C-102 May 29, 2010 Prt°Ac'rivE UinyNOSric Scavices Database File: d:\warrioridatal1c-1021overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Mon May 31 11:37:40 2010 Charted by: Depth in Feet scaled 1:150 Delta Metal Thickness 2010 (8Hz) (%) Delta Metal Thickness 2010 (5Hz} (%) 0 Delta Metal Thickness 2010 20 40 Metal Thickness 2010 60 50 80 • 120 140 160 Conductor Metal Thickness 2010 180 200 220 s o`~"' ~E"s R~rded Magnetic Thickness ~ Data - 5Hz Pass a~' AFB; 1 C-102 May 29, 2010 Pn°Acrivt Dinynosrit SERYICCS Database File: d:lwarrior\data\1c-10215hzpass.db Dataset Pathname: SHzDn Presentation Format: 2 scale Dataset Creation' Mon May 31 10:41:36 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness {%) 50 2 MTTP01 (rad) 12 0 Line Speed (ft/min) 200 -6.8 MTTP12 (rad} 3.2 Tree langer 5" Collar S Metal Tubing Jt. 1 20 Metal Loss 5" Collar +--; ~--~- i I ~ 40 ng Jt. 2 ' Collar 60 5" Collar ~ ~ ng Jt. 3 so 625" Collar 625" 5" Collar 7.625" Collar 5' 5" 7.625" Collar Tubing Jt. 4 of 16" Conductor ~~~ Tubing Jt. 5 140 Tubing Jt. 6 180 Tubing Jt. 7 200 Tubing Jt. 8 M (212' - 242') , • 1 C-102 May 29 10 P'R°ACTiVE DlaytwSTIC SERVICES Database File: d:lwarriorldatal1c-10215hzpass(212'-242').db Dataset Pathname: SHzDn Presentation Format: 2 scale Dataset Creation: Mon May 31 10:41:36 2010 Charted by: Depth in Feet scaled 1:20 -50 Delta Metal Thickness (%) 50 2 MTTP01 (rad) 12 0 Line Speed (ftimin) 200 -6.8 MTTP12 (rad) 3.2 Tubing Jt. 7 4.5" Delta Metal Thickness Isolated Metal Loss 220 r f I T ubing Jt. 8 230 r ~ } i 4 S ~ r ( , r Iso late d M etal Los s ; t I 1 ,~ 240 I Delt a M etal Thi ckness Is olat ed r Meta l Lo ss Line Sp eed ~ ' ~ ~ '_, c -50 Delta Metal Thickness {%) 50 2 MTTP01 (rad) 12 0 Line Speed (ft/min} 200 -6.8 MTTP12 (rad) 3.2 ~ j ~~~ KUP ConocoPhillips ~ w~l~A~tiw`~ ry~N __ __ i 500292303740 WEST "-"9G HANGER, 25 TUBMIG, 2T CONDUCTOR, aa3s~ Heffi Trgce, 26 ESP MPNDREL, 5 863 PUMP, 5 803 IMAKE. 5 840 ESP SEAL, 5,650 MOTOR. S.E64 GAUGE, 5 B7E Ceritrafi:er. 5 883 i 1 1 ' TD (1 G1021, 10,510 1 C-102 ~~ ConocoPhiilips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 14, 2007 ~~ NOV ~ ~ 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 ~ ~ f Anchorage, AK 99501 ~~ i Dear Mr. Maunder: • REDEIVED O C T 1 7 2007 Alaska Oil & Gas Cons. Corrurrissio~ ~nchora~e -Enclosed please find a~ spreadsheet =with a list of•~vellsfrom the Kuparuk field (KRLJ).' Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor,. engineered to prevent water from entering the annular space.. As per previous agreement with the AOGCC, this .letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on August 21 & September 28, 2007 and the corrosion inhibitor/sealant was pumped on. September 28 & 29, 2007. The attached spreadsheet presents the well name, top' of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions Sincerely, Perry Kl ConocoPhillips Well Integrity Projects Supervisor r ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field r1afP_ enuw innn~ ell Name TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor ..... Corrosion inhibitor/ sealant date ft bbls ft al 1 L-28 199-098 15' 6" 2 4" 8/29/2007 1 9/28/2007 1C-102 201-161 29' 8 24" 9/21/2009 11.5 9/29/2007 1 D-10 198-049 sf n/a sf n/a 4 9/29/2007 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc )3 N~if ~""1!~) DATA SUBMITTAL COMPLIANCE REPORT 1 0/22/2003 Permit to Drill 2011610 Well Name/No. KUPARUK RIV U WSAK 1C-102 Operator CONOCOPHILLIPS ALASKA INC S{ll~ ¿ (g ~ Å-\"Y ( API No. 50-029-23037-00-00 MD 10570 ./ TVD 3753 ./ Completion Date 1 0/13/2001 ~ Completion Status 1-01L Current Status SOlED UIC N ----"--- -- --- - -- - - -- .- REQUIRED INFORMATION Mud Log No Samples No Directional Survey No - ----- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Typ~ Med/Frmt Num.-ger C ¿;tf263 (data taken from Logs Portion of Master Well Data Maínt) .--"" Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments ---- - - - - 1 5800 10570 Case 11/1/2002 Digital Data: Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity 1 241 10517 Open 217/2002 25 1 0 5622 Case 4/14/2003 25 Blu 1 0 5622 Case 4/14/2003 RST-C / SIGMA MODE 25 Blu 1 0 5622 Case 4/14/2003 RST-C / SIGMA MODE 25 Blu 1 0 5622 Case 4/14/2003 RST-C / SIGMA MODE 25 1 0 5622 Case 4/14/2003 RST-C / SIGMA MODE 25 1 0 5622 Case 4/14/2003 RST -C / SIGMA MODE 25 1 0 5622 Case 4/14/2003 RST-C / SIGMA MODE - j ~-- Name í i i I I I-- I .Pf\ 0 .~~ C Lis ~ Reservoir Saturation ]i"" og Temperature og Pressure ~D C Pds ~/12082 Reservoir Saturation 1ED C Pd. '¡ZO82 Temperature / ED C Pds 1..12082 Pressure Well Cores/Samples Information: 0-0010 LIS Verification .....+2082 LIS Verification Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ...- '( ¡ f';I -- Daily History Received? ~N WN Formation Tops Analysis Received? ~ ---- _n- - . - Comments: DATA SUBMITTAL COMPLIANCE REPORT 1 0/22/2003 Permit to Drill 2011610 Well Name/No. KUPARUK RIV U WSAK 1C-102 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23037-00-00 MD 10570 TVD 3753 Completion Date 10/13/2001 Completion Status 1-01L Current Status SOlED UIC N Compliance Reviewed By: ~ ------ Date: ~fV' ~ if ~ ----- -- -----~ -- ,---- 04/03/03 Schlumbel'ger NO. 2731 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk -~~. Well Job# Log Description Date BL Color CD "-- ./ 3S-16 ?Xf) -')-rv) +1/ --- INJECTION PROFILE 03/15/03 1 1A-13 \ '9\ J -, C( r:; ¿ ./.=,. LEAK DETECTION LOG 03/16/03 1 1C-102 fi-nJ -) l'n T /22067 RST 01/16/02 1 f J :::JOe "} SIGNE;~~)\ \--\.. )\¡\~~ \.. () Ö:..:~ ~~ DATE: RECEIVED Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. APR 1 4 2003 II I ~ O.:¡.o A', 1"'",- f'¡ '. ~.aBfi.a. . f¡ 0; {j8.S VVi is. ,,;omm~n AnÑ1nr.......- ~ l' ~DJ-llo/ 1/ ~I.t> :5 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 1 00 Anchorage, Alaska 99501 November 01, 2002 RE: MWD Formation Evaluation Logs: 1 C-1 02, AK-MM-l1144 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AI( 99518 lC-lO2: Digital Log Images: 50-029-23037-00 1 CD ROlll ~~ RECEIVED NOV 0 1 2002 Alaska ai & Gas Cons. Commisejon Anchorage "I ( .' ( -~"'~;~il,I--,.,4jr_:::" ( 1:¡l1li~~i~.l~ ',,"" WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Lisa W eepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 05, 2001 RE: MWD Formation Evaluation Logs 1 C-l 02, AK-MM-11144 1 LDWG formatted Disc with verification listing. API#: 50-029-23037-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 ~bvec Si~ ú.,..Q~ FEB 0 7 2002 Alaska Oil & Gas Cons. Commission Anchorage (" (' PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage,AJaska 9951~60 C. Mallary Phone(907)265~4 Fax: (907) 265-6224 December 17, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Reports for 1C-I02 and lC-102Ll (201-161/ 301-275 and 201-172) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Reports for the drilling operations on the multilateral wells lC-102 and 1C-102Ll. If you have any questions regarding this matter, please contact Steve McKeever at 265-6826. Sincere ~ ~ ¿(~. C. Mallary Drilling Engineering Supervisor PAl Drilling ~ fl% /Ia,y CM/skad RECEIVED DEC 1 8 2001 Alaska on & Gas Cons. Commission Anchorage ~,.) ",-", ' \ #'"'" I' f.\," ! ",f,i;, ~", ")' \"" \: \,\ " {'I , -" """I ", 1\ J, J. , , ! ¡' ('"'1 t,i t \ .. ~.^,_./ ;: ;, ~\!'i ,'~ ~-.." ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Oil 0 Gas D 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surlace Suspended D Service D Abandoned D ,"-'--""""", .",- 1420'FNL,600'FWL,Sec.12,T11N,R10E,UM(ASP:561606,5968814).: '. .:' ":""'; At T~P Producing ,Interval " .1t2~'(§:~Q-' i' 175 FNL, 2416 FEL, Sec. 11, T11N, R1OE, UM (ASP: 558580, 5970034), . :.: ¡:: :,\: At Total Depth , .--~~;f15,~-- [ 934' FSL, 2391' FEL, Sec. 11, T11N, R10E, UM (ASP: 558642, 5965864) " I.',"""""""'" 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 41 feet ADL 25649 ALK 467 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. August 18, 2001 August 31,2001 October 13, 2001 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 10570' MD 1 3753' TVD N/A YES 0 No D 22. Type Electric or Other Logs Run GR/Res 23. Classification of Service Well LOCA~ 7.PennitNumber Vfi1F11Ð 201-161/301-275 St:~ ,~'Y\ 8. API Number .» .~..., 5Q..029-23037-00 :..-....:...:............,.\~9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1C-102 11. Field and Pool Kuparuk River Field West Sak Oil Pool 15. Water Depth, if offshore N/A feel MSL 20. Depth where SSSV set N/A feel MD 16. No. of Completions 1 21. Thickness of Pennafrost 2025' GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 158' Surface 6518' 5936' 10566' 6042' 10550' CASING SIZE 16" HOLE SIZE CEMENTING RECORD 24" 432sxASI 9.875" 660 sx ASLite, 275 sx Class G WT. PER FT. 62.5# 29.7# 9.5# 9.5# 6" 6" 7.625" 4" X 4.5" 4" X 4.5" 24. Perlorations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE No perfs - Pre-pack screens in horizontal laterals AMOUNT PULLED screen screen 4.5" TUBING RECORD DEPTH SET (MD) 5894' PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10405'-6523' 3.2 bbls HCr acid per screen 27. Date First Production November 22, 2001 Date otTest Hours Tested 11/29/2001 4.0 Flow Tubing Casing Pressure Press. 368 psi not available 28. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing - shares production with 1C-102L 1 Production for OIL-BBL GAS-MCF Test Period> 1029 95 Calculated Oll-BBl GAS-MCF 24-Hour Rate> 171.5 16 CORE DATA WATER-BBL 67 W A TER-BBL 11 CHOKE SIZE GAS-Oil RATIO 100 92 OIL GRAVITY - API (corr) not available Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ('""' ! ; Ü ~ ,. ~ ':. ," ~"" ¡ /""\ ¡ 'II ' ¡, 1 """, 'I I ~I' ; :', ;",..", I, RECE IVED DEC 1 8 200i . Alaska Oil & Gas Cons. Commissicm Anchorage _. Submit in duplicate 1\ " .lA. l~BDMS 8Ft DEC 2 820m c.,P 29. (' GEOLOGIC MARKERS 30. FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME Top West Sak So/'d West Sak B ./ Base West Sak Sand 6130' 6396' 10570' 3743' 3795' 3753' Annulus left open - freeze protected with diesel. RECEIVED DEe 1 8 2001 Alaska Oil & Gas Cons. Commission Anch " 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I her.,ZY certify' hat the following is true éI corre~t to the best of my knowledge. ~~ . ìi ÞiN~ Signed ~ ~.::f¿ Title Drillinq Enaineerina Supervisor Chuck Ma/lary ¿;::? Questions? Call Steve McKeever 265.6826 Dale ß- / -;j¡ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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 (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Fonn 10-407 ,""""'~r""\I¡,i""~\¡:¡'\,! {I\'", L, ~ l" )' , , l) 1--\ ¡ lJ [i \ \1 i~\ ' ( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 1 C-1 02 a 01-1(0/ Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 0.00' MD Window / Kickoff Survey , MD Projected Survey: 10,570.00' MD (if applicable) ( 07-Nov-01 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED Nov 1 J 2001 Alaska Oil ,£ G " as Cons c. . Ar (:;kt)rag~ ommBs:,~iof) ~ DEFINITIVE "-.- Kuparuk River Unit North Slope, Alaska Kuparuk 1C, Slot 1C-102 - 1C-102 Job No. AKMM11144, Surveyed: 1 SeptemberJl2oo1 .--" SURVEY REPORT 7 November, 2001 Your Ref: 500292303700 Surface Coordinates: 5968813.50 N, 561606.18 E (70" 19' 31.2102" N, 149" 30' 01.5791" W) Surface Coordinates relative to Project H Reference: 968813.50 NJI 61606.18 E (Grid) Surface Coordinates relative to Stucture Referance: 297.32 N, 763.45 W (True) Kelly Bushing: 101.85ft above Mean Sea Level '1 sper'r'v-sul1 DRILLING SeRViCes A Halliburton Company Survey Ref: svy9621 Sperry-Sun Drilling Services DEFINIT'~ Survey Report for 1C-102 Your Ref: 500292303700 Job No. AKMM11144, Surveyed: 1 September, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) eft) eft) (ft) eft) (°/1 OOft) . 0.00 0.000 0.000 -101.85 0.00 O.OON 0.00 E 5968813.50 N 561606.18 E 0.00 MWD Magnetic 158.00 0.000 0.000 56.15 158.00 O.OON O.OOE 5968813.50 N 561606.18 E 0.000 0.00 200.07 1.320 330.260 98.22 200.07 0.42N 0.24W 5968813.92 N 561605.94 E 3.138 -0.42 .~--.,. '...:.--' 288.07 0.970 261.360 186.20 288.05 1.19 N 1.48W 5968814.68 N 561604.69 E 1.508 -1.19 380.07 4.130 223.040 278.10 379.95 1.355 4.51 W 5968812.11 N 561601.68 E 3.720 1.35 '--- 470.56 8.440 225.500 368.03 469.88 8.395 11.48 W 5968805.02 N 561594.77 E 4.771 8.39 562.56 11.160 229.010 458.68 . 560.53 18.96 S 23.01 W 5968794.35 N 561583.32 E 3.026 18.96 653.53 11.600 248.340 547.89 649.74 28.12 5 38.16 W 5968785.07 N 561568.25 E 4.201 28.12 749.06 12.650 266.270 641.32 743.17 32.34 5 57.54 W 5968780.68 N 561548.91 E 4.074 32.34 840.01 14.850 280.690 729.69 831.54 30.83 5 78.94 W 5968782.02 N 561527.50 E 4.460 30.83 933.17 14.950 283.150 819.72 921.57 25.88 S 102.37 W 5968786.78 N 561504.03 E 0.687 25.88 1027.19 17.750 286.310 909.93 1011.78 19.10 5 127.94 W 5968793.35 N 561478.40 E 3.124 19.10 1120.36 25.310 296.860 996.56 1098.41 6.095 159.39 W 5968806.11 N 561446.84 E 9.086 6.09 1214.96 27.680 . 305.300 1081.25 1183.10 15.76 N 195.38 W 5968827.65 N 561410.67 E 4.697 -15.76 1308.08 28.380 307.760 1163.45 1265.30 41.81 N 230.53 W 5968853.42 N 561375.31 E 1.451 -41.81 1403.69 30.410 311.620 1246.76 1348.61 71.80 N 266.59 W 5968883.11 N 561339.01 E 2.903 - 71.80 1497.62 35.330 311.620 1325.63 1427.48 105.65 N 304~69 W 5968916.65 N 561300.63 E 5.238 -105.65 1593.15 38.840 311.980 1401.82 1503.67 144.05 N 347.62 W 5968954.69 N 561257.39 E 3.681 -144.05 1687.49 43.240 314.440 1472.96 1574.81 186.48 N 392.71 W 5968996.75 N 561211.95 E 4.968 -186.48 1782.19 47.020 315.840 1539.77 1641.62 234.06 N 440.02 W 5969043.94 N 561164.25 E 4.127 -234.06 ~ ) 1875.15 52.290 317.600 1599.93 1701.78 285.65 N 488.54 W 5969095.13 N 561115.31 E 5.849 -285.65 1970.48 57.910 318.660 1654.45 1756.30 343.86 N 540.69 W 5969152.91 N 561062.69 E 5.965 -343.86 2064.69 58.090 317.600 1704.37 1806.22 403.36 N 594.01 W 5969211.96 N 561008.88 E 0.973 -403.36 2159.77 66.180 321.120 1748.79 1850.64 467.13 N 648.63 W 5969275.29 N 560953.74 E 9.115 -467.13 2254.76 65.470 322.870 1787.69 1889.54 535.41 N .701.98 W 5969343.13 N 560899.82 E 1.839 -535.41 2348.76 64.950 322.870 1827.10 1928.95 6O3.45N 753.50 W 5969410.74 N 560847.75 E 0.553 -603.45 2443.19 64.510 322.870 1867.42 1969.27 671.53 N 805.04 W 5969478.40 N 560795.65 E 0.466 -671.53 2536.98 64.070 322.870 1908.10 2009.95 738.90 N 856.05 W 5969545.35 N 560744.09 E 0.469 - 738.90 2632.06. 63.720 322.520 1949.94 2051.79 806.82 N 907.80 W 5969612.84 N 560691.79 E 0.495 -806.82 2727:26 63.800 322.870 1992.03 2093.88 874.74 N 959.55 W 5969680.33 N 560639.48 E 0.340 -874.74 -- ---- 7 November, 2001 - 12:15 Page 2 of 8 DrllfOuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 1C-102 Your Ref: 500292303700 Job No. AKMM11144, Surveyed: 1 September, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 2822.36 65.210 322.170 2032.96 2134.81 942.85 N 1011.78 W 5969748.01 N 560586.69 E 1.625 -942.85 2916.21 65.830 322.870 2071.85 2173.70 1010.63 N 1063.75 W 5969815.37 N 560534.17 E 0.947 -1010.63 3010.80 65.910 322.520 2110.52 2212.37 1079.30 N 1116.07 W 5969883.60 N 560481.29 E 0.348 -1079.30 -~ -- 3107.47 65.740 322.870 2150.11 2251.96 1149.45 N 1169.52 W 5969953.31 N 560427.26 E 0.374 -1149.45 3202.11 65.830 322.520 2188.93 2290.78 1218.10N 1221.83 W 5970021.53 N 560374.39 E 0.350 -1218.10 " , "- 3296.91 65.120 322.520 2228.28 2330.13 1286.54 N 1274.31 W 5970089.54 N 560321.35 E 0.749 -1286.54 3391.71 65.030 323.580 2268.23 2370.08 1355.25 N 1325.99 W 5970157.81 N 560269.11 E 1.018 -1355.25 3486.20 64.950 323.930 2308.18 2410.03 1424.31 N 1376.61 W 5970226.46 N 560217.92 E 0.346 -1424.31 3581.23 64.680 323.580 2348.62 2450.47 1493.66 N 1427.46 W 5970295.39 N 560166.51 E 0.438 -1493.66 3675.61 64.770 323.580 2388.92 2490.77 1562.34 N 1478.13 W 5970363.65 N 560115.28 E 0.095 -1562.34 3765.72 64.510 322.170 2427.51 2529.36 1627.26 N - 1527.27 W 5970428.17 N 560065.60 E 1.443 -1627.26 3863.86 64.330 323.930 2469.89 2571.74 -1698.00 N 1580.48 W 5970498.46 N 560011.81 E 1.628 -1698.00 3959.05 63;890 324.280 2511.45 2613.30 1767.37 N 1630.69 W 5970567.42 N 559961.04 E 0.568 -1767.37 4054.93 62.570 323.930 2554.64 2656.49 1836.72 N 1680.88 W 5970636.35 N 559910.28 E 1.415 -1836.72 4148.86 61.080 323.230 2598.99 2700.84 1903.34 N 1730.03 W 5970702.58 N 559860.58 E 1.717 -1903.34 4243.34 59.150 318.660 2646.08 2747.93 1966.95 N 1781.59 W 5970765.75 N 559808.50 E 4.664 -1966.95 4337.51 57.120 314.080 2695.81 2797.66 2024.83 N 1836.73 W 5970823.19 N 559752.89 E 4.659 -2024.83 4433.07 54.660 306.340 2749.45 2851.30 2075.90 N 1897.02 W 5970873.76 N 559692.18 E 7.181 -2075.90 4525.97 51.410 300.370 2805.34 2907.19 2116.75 N 1958.92 W 5970914.09 N 559629.95 E 6.211 -2116.75 4619.36 50.530 293.690 2864.19 2966.04 2149.71 N 2023.46 W 5970946.52 N 559565.14 E 5.634 -2149.71 ~ 4714.78 52.030 288.420 2923.90 3025.75 2176.40 N 2092.91 W 5970972.65 N 559495.47 E 4.586 -2176.40 4811.51 51 .500 278.580 2983.86 3085.71 2194.12N 2166.62 W 5970989.76 N 559421.62 E 8.005 -2194.12 4903.24 50.970 269.440 3041 .36 3143.21 2199.14N 2237.83 W 5970994.19 N 559350.37 E 7.787 -2199.14 4998.99 48.860 260.300 3103.09 3204.94 2192.69 N 2310.66 W 5970987.15 N 559277.60 E 7.624 -2192.69 5093.95 47.980 252.210 3166.17 3268.02 2175.87 N 2379.56 W 5970969.76 N 559208.84 E 6.437 -2175.87 5190.56 49.650 244.120 3229.85 3331.70 2148.81 N 2446.92 W 5970942.15 N 559141.70 E 6.532 -2148.81 5286.02 52.030 235.330 3290.20 3392.05 2111.48 N 2510.68 W 5970904.30 N 559078.25 E 7.558 -2111.48 5380.18 55.370 227.600 3345.99 3447.84 2064.19 N 2569.88 W 5970856.52 N 559019.44 E 7.503 -2064.19 5473.91 60.020 222.330 3396.09 3497.94 2008.11 N 2625.75 W 5970799.99 N 558964.03 E 6.868 -2008.11 5569.16 65.390 216.000 3439.79 3541.64 1942.49 N 2679.07 W 5970733.93 N 558911.26 E 8.161 -1942.49 .- . - ----------- .------- -._----- - 7 Novembel~ 2001 - 12:15 Page 3 of 8 DrlllQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 1C-102 Your Ref: 500292303700 Job No. AKMM11144, Surveyed: 1 September, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. . Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) . 5664.19 68.460 213.890 3477.03 3578.88 1870.83 N 2729.12 W 5970661.86 N 558861.79 E 3.822 -1870.83 5760.10 68.730 212.480 3512.04 3613.89 1796.10 N 2777.99 W 5970586.73 N 558813.54 E 1.397 -1796.10 5854.56 68.730 211.780 3546.30 3648.15 1721.55 N 2824.81 W 5970511.80 N 558767.33 E 0.691 -1721.55 --, '......~ 5948.05 68.550 212.840 3580.36 3682.21 1647.97 N 2871.34 W 5970437.84 N 558721.40 E '1.073 -1647.97 Tie On To BHI 6039.27 70.290 207.440 3612.44 3714.29 1574.14 N 2914.18 W 5970363.66 N 558679.17 E 5.861 -1574.14 6129.94 73.270 202.400 3640.80. 3742.65 1496.06 N 2950.42 W 5970285.29 N 558643.57 E 6.218 -1496.06 6226.91 76.080 197.890 3666.44 3768.29 1408.29 N 2982.60 W 5970197;25 N 558612.12 E 5.340 -1408.29 6320.95 81.290 190.950 . 3684.91 3786.76 1319.06 N 3005.49 W 5970107.84 N 558589.96 E 9.111 -1319.06 6416.24 86.490 184.460 3695.06 3796.91 1225.24 N 3018.15W 5970013.92 N 558578.07 E 8.695 -1225.24 6450.67 86.610 183.060 3697.13 3798.98 1190.95 N 3020.41 W 5969979.61 N 558576.10 E 4.074 -1190.95 6536.36 89.750 182.530 3699.85 3801.70 1105.42 N 3024.58 W 5969894.05 N 558572.62 E 3.716 -1105.42 6578.95 89.510 182.670 3700.13 3801.98 1062.87 N 3026.51 W 5969851.49 N 558571.04 E 0.652 -1062.87 6631.01 89.880 181.620 3700.40 3802.25 1010.85 N 3028.46 W 5969799.45 N 558569.52 E 2.138 -1010.05 6674.45 90.860 182.020 3700.12 3801.97 967.43 N 3029.84 W 5969756.02 N 558568.50 E 2.437 -967.43 6726.70 89.200 182.480 3700.10 3801.95 915.22 N 3031.89 W 5969703.80 N 558566.87 E 3.297 -915.22 6769.72 89.260 181.520 3700.67 3802.52 872.23 N 3033.39 W 5969660.80 N 558565.73 E 2.236 -872.23 6821.47 89.630 180.810 3701.18 3803.03 820.50 N 3034.45 W 5969609.06 N 558565.10 E 1.547 -820.50 6863.56 90.370 180.950 3701.18 3803.03 778.41 N 3035.09 W 5969566.97 N 558564.80 E 1.789 - 778.41 6916.10 91 .850 181.100 3700.16 3802.01 725.89 N 3036.03 W 5969514.44 N 558564.29 E 2.831 - 725.89 6952.31 92.400 181.040 3698.82 3800.67 689.71 N 3036.71 W 5969478.26 N 558563.91 E 1.528 -689.71 ~ 7009.87 92.830 180.670 3696.19 3798.04 632.22 N 3037.57 W 5969420.76 N 558563.53 E 0.985 -632.22 7048.27 91.970 180.380 3694.58 3796.43 593.86 N 3037.92 W 5969382.40 N 558563.49 E 2.363 -593.86 7105.11 92.090 180.280 3692.57 3794.42 537.05 N 3038.25 W 5969325.59 N 558563.63 E 0.275 -537.05 7148.65 92.580 180.000 3690.79 3792.64 493.55 N 3038.35 W 5969282.09 N 558563.88 E 1.296 -493.55 7199.82 93.450 180.600 3688.10 3789.95 442.45 N 3038.62 W 5969230.99 N 558564.03 E 2.064 -442.45 7243.11 92.280 179.900 3685.94 3787.79 399.22 N 3038.81 W 5969187.76 N 558564.20 E 3.148 -399.22 7295.25 91.040 179.400 3684.43 3786.28 347.10 N 3038.49 W 5969135.64 N 558564.94 E 2.564 -347.10 7338.00 90.800 178.900 3683.74 3785.59 304.36 N 3037.86 W 5969092.91 N 558565.93 E 1.297 -304.36 7390.61 . 91.850 179.260 3682.53 3784.38 251.77N 3037.01 W 5969040.33 N 558567.20 E 2.110 -251.77 7433.52 90.370 179.350 3681.69 3783.54 208.88 N 3036.49 W 5968997.44 N 558568.08 E 3.455 -208.88 .-__--__n. -O-_un._- -0_---- .---_0'_- 7 November, 2001 - 12:15 Page 4 of 8 DrlllOllest 2.00.09.003 Kuparuk River Unit Measured Depth (ft) --. 7484.88 7529.78 7579.72 7624.74 7674.51 7721.42 7769.26 7813.82 7864.02 7908.72 7958.31 8003.73 8053.40 8097.71 8148.09 8194.57 8240.73 8285.46 8337.59 8380.81 8431.59 8476.18 8526.78 8570.52 8622.07 8665.59 8716.92 8759.24 8811.54 8854.00 Inct 91.290 89.750 90.250 91.170 90.310 90.430 89.940 92.030 92.770 91.910 89.630 89.820 90.250 91.050 91.850 92.530 90.920 91 .350 90.060 90.370 90.980 90.860 91.290 92.220 93.080 90.800 90.620 88.770 89.690 90.180 Azlm. 179.630 180.260 180.750 181.380 181.450 181.120 181.440 181.260 180.800 181.250 179.920 180.070 179.480 179.690 179.270 179.360 178.490 178.350 178.860 178.190 180.060 179.040 178.740 177.300 176.730 176.370 177.530 177.500 178.010 177.500 7 November, 2001 - 12:15 Sub-Sea Depth (ft) 3680.95 3680.54 3680.54 3679.98 3679.34 3679.04 3678.88 3678.12 3676.02 3674.19 3673.52 3673.74 3673.71 3673.21 3671.93 3670.16 3668. 77 3667.88 3667.24 3667.08 3666.48 3665.77 3664.82 3663.48 3661.09 3659.62 3658.98 3659.21 3659.91 3659.96 Vertical Depth (ft) 3782.80 3782.39 3782.39 3781.83 3781.19 3780.89 3780.73 3779.97 3777.87 3776.04 3775.37 3775.59 3775.56 3775.06 3773.78 3772.01 3770.62 3769.73 3769.09 3768.93 3768.33 3767.62 3766.67 3765.33 3762.94 3761.47 3760.83 3761.06 3761.76 3761.81 Sperry-Sun Drilling Services Survey Report for 1C-102 Your Ref: 500292303700 Job No. AKMM11144, Surveyed: 1 September, 2001 Local Coordinates Northlngs Elatlngs (ft) (ft) 157.52 N 112.63 N 62.69 N I 17¡.68 N 32.07 S 78.97 S 121.7.9 S 17 .33 S 22 .48 S 266.135 315.71 5 361.135 410.805 455.11 5 505.475 551.91 5 598.04 5 642.745 694.85 5 738.065 788.83 5 833.41 5 883.99 5 927.68 5 979.11 5 1022.52 5 1073.77 S 1116.055 1168.30 5 1210.735 3036.03 W 3035.99 W 3036.43 W 3037.27 W 3038.50 W 3039.55 W 3040.62 W 3041.67 W 3042.57 W 3043.37 W 3043.87 W 3043.87 W 3043.67 W 3043.35 W 3042.90 W 3042.34 W 3041.47 W 3040.24 W 3038.97 W 3037.86 W 3037.08 W 3036.73 W 3035.75 W 3034.24 W 3031.56 W 3028.95 W 3026:21 W 3024.38 W 3022.33 W 3020.67 W Global Coordinates Northlngs EIstlngs (ft) (ft) 5968946.09 N 5968901.20 N 5968851.26 N 5968806.25 N 5968756.49 N 5968709.58 N 5968661.75 N 5968617.20 N 5968567.05 N 5968522.39 N 5968472.81 N 5968427.39 N 5968377.72 N 5968333.42 N 5968283.07 N 5968236.63 N 5968190.51 N 5968145.82 N 5968093.72 N 5968050.53 N 5967999.77 N 5967955.19 N 5967904.62 N 5967860.94 N 5967809.54 N 5967766.15 N 5967714.92 N 5967672.66 N 5967620.42 N 5967578.01 N 558568.96 E 558569.37 E 558569.34 E 558568.87 E 558568.05 E 558567.38 E 558566.71 E 558566.02 E 558565.53 E 558565.10 E 558565.00 E 558565.38 E 558565.98 E 558566.67 E 558567.54 E 558568.4 7 E 558569.72 E 558571.32 E 558573.01 E 558574.48 E 558575.67 E 558576.39 E 558577.79 E 558579.65 E 558582.76 E 558585.73 E 558588.88 E 558591.06 E 558593.54 E 558595.55 E -------- -------.- Page 5 of 8 Dogleg Rate (o/100ft) 1.872 3.706 1.402 2.477 1.734 0.749 1.223 4.708 1.735 2.171 5.323 0.533 1.470 1.867 1.793 1.476 3.964 1.011 2.661 1.708 3.873 2.303 1.036 3.918 2.001 5.304 2.287 4.372 2.011 1.666 Vertical Section -157.52 -112.63 -62.69 -17.68 32.07 78.97 126.79 171.33 221.48 266.13 315.71 361 . 13 410.80 455.11 505.47 551.91 598.04 642.74 694.85 738.06 788.83 833.41 883.99 927.68 979.11 1022.52 1073.77 1116.05 1168.30 1210.73 . North Slope, Alaska Kuparuk 1C Comment (' , ~ DrlllQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 1C-102 Your Ref: 500292303700 Job No. AKMM11144, Surveyed: 1 September, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. . Azlm. Depth Depth Northlngs . Eastlngs Northlrigs Eastlngs Rate Section Comment (ft) . (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) . 8902.41 90.060 177.010 3659~86 3761.71 1259.09 S 3018.35 W 5967529.68 N 558598.27 E 1.042 1259.09 8950.96 90.310 176.820 3659.70 3761.55 1307.56 S 3015.74 W. 5967481.22 N 558601.28 E 0.647 1307.56 9001.00 91.850 175.840 3658.76 3760.61 1357.498 3012.53 W 5967431.32 N 558604.89 E 3.648 1357.49 -c -. 9045.35 91.420 175.240 3657.49 3759.34 1401.698 3009.09 W 5967387.15 N 558608.70 E 1.664 1401.69 9095.29 90.430 173.960 . 3656.69 3758.54 1451.408 3004.39 W 5967337.48 N 558613.81 E 3.240 1451.40 ~ 9139.02 90.620 174.200 3656.29 3758.14 1494.89 8 2999.88 W 5967294.03 N 558618.68 E 0.700 1494.89 9190.14 90.430 174.420 3655.82 3757.67 1545.76 8 2994.81 W 5967243.21 N 558624.16 E 0.569 1545.76 9239.13 90.490 176.100 3655.42 3757.27 1594.58 8 2990.76 W 5967194.42 N 558628.61 E 3.431 1594.58 9284.98 92.090 178.590 3654.39 3756.24 1640.36 8 2988.64 W 5967148.66 N 558631.11 E 6.454 1640.36 9331 .37 93.080 181.120 3652.30 3754.15 1686.70 8 2988.52 W 5967102.32 N 558631.61 E 5.851 1686.70 9380.05 90.370. 183.000 3650.83 3752.68 1735.32 8 2990.27 W 5967053.69 N 558630.26 E 6.774 1735.32 9424.04 90.180 182.610 3650.62 3752.47 1779.268 2992.42W 5967009.73 N 558628.47 E 0.986 1779.26 9474.62 90.370 182.100 . 3650.38 3752.23 1829.798 2994.50 W 5966959.18 N 558626.80 E 1.076 1829.79 9511.88 90.860 181.950 3649.98 3751.83 1867.03 8 2995.82 W 5966921.94 N 558625.79 E 1.375 1867.03 9567.20 91.170 182.320 3649.00 3750.85 1922.30 8 2997.88 W 5966866.65 N 558624.18 E 0.872 1922.30 9614.78 90.250 182.220 3648.41 3750.26 1969.84 8 2999.76 W 5966819.10 N 558622.69 E 1.945 1969.84 9663.41 89.320 182.000 3648.59 3750.44 2018.44 8 3001.55 W 5966770.49 N 558621.30 E 1.965 2018.44 9711.03 88.710 180.850 3649.41 3751.26 2066.03 S 3002.74 W 5966722.88 N 558620.51 E 2.733 2066.03 9758.17 88.770 180.020 3650.45 3752.30 2113.168 3003.1 0 W 5966675.76 N 558620.53 E 1.765 2113.16 9801.37 88.650 179.980 3651.42 3753.27 2156.35 8 3003.10 W 5966632.57 N 558620.89 E 0.293 2156.35 -, 9853.78 88.950 180.130 3652.52 3754.37 2208.75 S 3003.15 W 5966580.17 N 558621.27 E 0.640 2208.75 9894.73 90.000 180.060 3652.89 3754.74 2249.70 S 3003.21 W 5966539.22 N 558621.54 E 2.570 2249.70 9948.90 90; 120 179.940 3652;84 3754.69 2303.86 S 3003.21 W 5966485.06 N 558621.98 E 0.313 2303.86 9989.51 90.180 179.570 3652.73 3754.58 2344.478 3OO3.04W 5966444.45 N 558622.49 E 0.923 2344.47 10043.37 90.250 179.310 3652.53 3754.38 2398.33 8 3002.51 W 5966390.60 N 558623.46 E 0.500 2398.33 10083.91 90.680 178.820 3652.20 3754.05 2438.86 S 3001.85 W 5966350.07 N 558624.45 E 1.608 2438.86 10137.79 90.740 179.310 3651.53 3753.38 2492.73 S 3000.97 W 5966296.21 N 558625.77 E 0.916 2492.73 10180.14 90.620 178.780 3651.03 3752.88 2535.07 S 3000.27 W 5966253.88 N 558626.83 E 1.283 2535.07 10232.69 90.800 179.010 3650.38 3752.23 2587.61 S 2999.25 W 5966201.35 N 558628.27 E 0.556 2587.61 10274.67 91.110 178.380 3649.68 3751.53 2629.57 S . 2998.30 W 5966159.40 N 558629.57 E 1.672 2629.57 n- _n. 7 November, 2001 - 12: 15 Page 6 of 8 DrlllQlIest 2.00.09.003 Kuparuk River Unit Measured Depth (It) Incl. Azlm. 1 0327.50 10369.48 10421.65 10463.78 10503.00 89.140 178.430 89.570 178.200 90.000 178.770 89.940 177.550 89.380 177.420 89.380 177.420 10570.00 Sperry-Sun Drilling Services Survey Report for 1C-102 Your Ref: 500292303700 Job No. AKMM11144, Surveyed: 1 September, 2001 Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate (It) (It) (It) (ft) (ft) (ft) (0/100ft) 3649.56 3751.41 2682.38 S 2996.83 W 5966106.61 N 558631 .48 E 3.730 3650.04 3751.89 2724.34 S 2995.59 W 5966064.66 N 558633.05 E 1.162 3650.23 3752.08 2776.49 S 2994.21 W 5966012.52 N 558634.86 E 1.369 3650.25 3752.10 2818.60 S 2992.86 W 5965970.43 N 558636.56 E 2.899 3650.49 3752.34 2857.78 S 2991.14 W 5965931.26 N 558638.60 E 1 .466 3651 .21 3753.06 2924.71 S 2988.12 W 5965864.36 N 558642.17 E 0.000 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 101.85' (MSL). Northings and Eastings are relative to 1420' FNl & 600' FWL. Magnetic Declination at Surface is 26.139° (30-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1420' FNL & 600' FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10570.00ft., The Bottom Hole Displacement is 4181.24ft., in the Direction of 225.614° (True). Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastlngs (It) (ft) (ft) Comment 5948.05 10570.00 3682.21 3753.06 ~-~ ----.---- 7 November, 2001 - 12:15 1647.97 N 2924.71 S 2871.34 W 2988.12 W. Tie On To BHI Projected Survey _____h- - -.---- ---- Page 7 of 8 Vertical Section 2682.38 2724.34 2776.49 2818.60 2857.78 2924.71 . North Slope, Alaska Kuparuk 1C Comment r\ Projected Survey ~ DrIllQuesI2.00.09.003 . Kuparuk River Unit Survey tool program for 1C-102 ----."- " From Measured Vertical Depth Depth (ft) (ft) 0.00 To Measured Vertical Depth Depth (ft) (ft) 0.00 10570.00 3753.06 Sperry-Sun Drilling Services Survey Report for 1C-102 Your Ref: 500292303700 Job No. AKMM11144, Surveyed: 1 September, 2001 Survey Tool Description MWD Magnetic 7 November, 2001 - 12:15 --------------- Page 8 of 8 . North Slope, Alaska Kuparuk 1 C ~ \-- ~ ì / ---"---""----- DrlllQuest 2.00.09.003 f (' PHILLIPS ALASKA INC.. . . Operations Summary Report . Legal Well Name: 1C-102 Common Well Name: 1 C-1 02 Event Name: ROT - DRILLING Contractor Name: Rig Name: Date From - To Hours Code. Sub Phase .. Code 8/17/2001 07:00 - 09:30 2.50 MOVE MOVE MOBMIR 09:30 - 11 :00 1.50 MOVE OTHR MOBMIR 11:00 -12:00 1.00 MOVE MOVE MOBMIR 12:00 - 14:00 2.00 MOVE MOVE MOBMIR 14:00 - 16:00 2.00 WELCTL NUND SURFAC 16:00 - 21:00 5.00 WELCTL NUND SURFAC 21 :00 - 22:30 22:30 - 23:00 23:00 - 00:00 1.50 RIGMNT RURD SURFAC 0.50 RIGMNT RSRV SURFAC 1.00 DRILL OTHR SURFAC 8/18/2001 00:00 - 02:00 2.00 DRILL OTHR SURFAC 0.50 DRILL OTHR SURFAC 8.50 DRILL PULD SURFAC 1.00 DRILL SFTY SURFAC 1.00 DRILL OTHR SURFAC 02:00 - 02:30 02:30 - 11 :00 11:00 -12:00 12:00 - 13:00 8/19/2001 13:00 - 17:00 4.00 DRILL OTHR SURFAC 17:00 - 22:00 5.00 DRILL PULD SURFAC 22:00 - 23:30 1.50 DRILL DRLG SURFAC 23:30 - 00:00 0.50 DRILL DRLG SURFAC 00:00 - 03:30 3.50 DRILL DRLG SURFAC 03:30 - 04:30 1.00 DRILL OTHR SURFAC 04:30 - 06:00 1.50 DRILL SURV SURFAC 06:00 - 06:30 0.50 DRILL TRIP SURFAC 06:30 - 08:30 2.00 DRILL SURV SURFAC 08:30 - 09:00 0.50 DRILL SURV SURFAC 09:00 - 09:30 0.50 DRILL SURV SURFAC , 09:30 - 10:00 0.50 DRILL CIRC SURFAC 10:00 - 13:30 3.50 RIGMNT RGRP SURFAC 13:30 - 14:00 0.50 RIGMNT RSRV SURFAC 14:00 - 00:00 10.00 DRILL DRLG SURFAC 00:00 - 08:30 8.50 DRILL DRLG SURFAC 8/20/2001 Page 1 of 15 Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: Description of Operations Raise Cellar box, prep rig and move f/1C-1 19 to 1C-102 (270' away fl CPM) Load casing on truck and move matting boar ds for move to 1 C-1 02 Set drill module over hole. Skid floor7" towards pipe shed. Mate utility module to drill module. Set CPM. NU diverter line and knife valve, mix spud m u d. PU 10' riser & NU 13 5/8" 5m stack. Raise ri g 8" by jacking off Lampson crawler to set B OP stack on riser. Welder cut wall out to fit choke and kill lines. Welder shorten length of slip joint on flow line riser. Slip and cut 93' of drilling line. Service rig and top drive. LD 3 1/2" jars & 2 joints of 3 1/2" HWDP. Lo ad 4" Weatherford rental drill pipe in pipe s hed and prep to pick up. Prepare weatherford 4" HT38 drill pipe, stra p and rabbit in pipe shed. ' Change top drive saver sub to 4 1/2" IF box x 4" HT 38 pin. PJSM. PU and stand back in derrick 4" DP, 4" HWDP, and drill collars. Pre spud meeting wI team members. Function test diverter system. Witness of f unction test waived by AOGCC inspector Jef f Jones. Dry test casing hanger with landing joint. OK. Lay down hanger and landing join t. MU wear bushing, run in & set in head. Trou 'ble working thru, BOP stack @ 13+ ft. MU BHA. Orient and program tools. Break circulation, clean ice out of conducto r from 85' to 158'. Drill 9 7/8" hole fl 158' to 181'. Drill 9 7/8" hole fl 181' to 257' (76') ADT. 25 hrs ASAT .25 hrs ' Flowline plugged off with gravel. Attempt survey. Tool failure. Circ hole clea n, blow down top drive. Trip out of hole to check MWD tools. Download MWD, LD pulsar. PU MWD, orient and program tools. Trip in hole Wash to 257". 40' fill. Change out and rebuild DISCFLOW pump to move cuttings to CPM. Service rig and top drive. Directional drill 9 7/8" hole fl 257' t01190'.( 933') ART 2 hrs. AST 6.4 hrs , Directional drill 9 7/8" hole fI 1190' to 1795 Printed: 11/30/2001 11:17:54 AM ( ( PHILLIPS ALASKA INC. . . . . . . Operations' Summary . Report Legal Well Name: 1 C-1 02 Common Well Name: 1C-102 Event Name: ROT - DRILLING Contractor Name: Rig Name: Date From - To Hours Code Sub Phase .. Code 8/20/2001 00:00 - 08:30 8.50 DRILL DRLG SURFAC 08:30 - 09:30 1.00 DRILL CIRC SURFAC 09:30 - 12:00 2.50 DRILL DRLG SURFAC 12:00 - 12:30 0.50 RIGMNT RSRV SURFAC 12:30 - 00:00 11.50 DRILL DRLG SURFAC 8/21/2001 00:00 - 04:30 4.50 DRILL DRLG SURFAC 04:30 - 05:00 0.50 DRILL CIRC SURFAC 05:00 - 08:30 3.50 DRILL TRIP SURFAC 8/22/2001 08:30 - 12:00 3.50 DRILL SURV SURFAC 12:00 - 12:30 0.50 DRILL TRIP SURFAC 12:30 - 13:00 0.50 RIGMNT RSRV SURFAC 13:00 - 16:00 3.00 DRILL TRIP SURFAC 16:00 - 16:30 0.50 DRILL RËAM SURFAC 16:30 - 00:00 7.50 DRILL DRLG SURFAC 00:00 - 12:00 12.00 DRILL DRLG SURFAC 12:00 - 12:30 0.50 RIGMNT RSRV SURFAC 12:30 - 00:00 11.50 DRILL DRLG SURFAC 00:00 - 01 :00 1.00 DRILL DRLG SURFAC 01:00 - 01:30 0.50 DRILL CIRC SURFAC 01 :30 - 06:30 5.00 DRILL DRLG SURFAC 06:30 - 07:00 0.50 DRILL SURV SURFAC 07:00 - 09:00 2.00 DRILL CIRC SURFAC 09:00 - 14:30 5.50 DRILL TRIP SURFAC 8/23/2001 14:30 - 19:00 4.50 DRILL PULD SURFAC 19:00 -19:30 0.50 DRILL TRIP SURFAC 19:30 - 20:30 1.00 DRILL SURV SURFAC 20:30 - 22:30 2.00 DRILL TRIP SURFAC 22:30 - 00:00 1.50 DRILL PULD SURFAC 8/24/2001 00:00 - 04:00 4.00 DRILL TRIP SURFAC Page 2 0115 Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: '(605') ART.3 hrs AST 6.1 hrs Stand back 1 stand of DP. Circ hole. Confir m with town that directional profile will be OK. Directional drill 97/88 hole fl 1795' to 1948 '(153') ART = 0 hrs AST =1.3 hrs Service rig and top drive. . Directional drill 9 7/88 hole from 1948' to 33 68' (1420') ART = 5.4 hrs. AST = .7 hrs TVD 2360' Directional drill 9 7/88 hole .fl 3368' to 3841 '. (473') ART = 2.6 hrs Circulate sweep and clean hole prior to trip. Monitor well. Pump dry job. Blow down top d rive. POOH. Monitor@ HWDP. Continue POO H. Tight spot @ 308'. Work through tight sp ot. Monitor well @, DC's. Continue POOH. Ch ange out bit. '. . . Download and program MWD tools. RIH to 1st HWDP. Test MWD.. Service rig and top drive.' RIH wI bit # 2. Precautionary ream 190' to bottom. Directional drill 9 7/8H hole fl 3841' to 4598 , (757') ART = 2.4 hrs AST = 2.4 hrs Directional drill 9 7/8" hole fl 4598' to 5168 , (570') ART = 1.3 hrs AST = 7.5 hrs. Service rig and top drive Directional drill 9 7/88 hole fl , (757') ART = 4.2 hrs AST Directional drill 9 7/88 hole fl '. (30') ART =.5 hrs. Circulate hole. Directional drill 9 7/88 hole f/ 5955' to 6091 , (36') ART = .6hrs. AST =2.8 hrs. Attempt to survey wI MWD. Failed. Mix and pump hi-density sweep prio.r to trip f/ MWD failure. Monitor well, pump dry job, blow down top d rive, POOH for MWD. Tight spot @ 5535', 25 k over. Work through, OK. Tight spot @ 721' , 25 k over. Work through, OK. . Download MWD. Change out tools, program a nd orient same. Run in hole to 1190'. Check MWD. Pulsar failed to operate. POOH for pulsar problem. Change out pu.lsar. RIH wI 9 7/88 bit. Check shot w./ MWD @ 302 , (OK), 1184' (OK), 2230' (OK). Continue RI H to 4225'. Lay down and change out joint 0 f 48 DP. 5168' to 5925 =3.7 hrs. 5925' to 5955 . Printed: 11/30/2001 11:17:54 AM f f Page 30115 PHILLIPS ALASKA INC. ... Operations Summary Report. Legal Well Name: 1 C-1 02 Common Well Name: 1C-102 Event Name: ROT - DRILLING Contractor Name: Rig Name: Date From- To. Hours Code Sub Phase Code 8/24/20.0.1 04:0.0. - 0.5:0.0. 1.0.0. DRILL CIRC SURFAC 0.5:0.0. - 0.7:0.0. 0.7:0.0. - 10.:0.0. 10.:0.0. - 10.:30. 10.:30 - 11 :0.0. 11 :0.0. - 12:0.0. 12:0.0. - 12:30. 12:30. -15:30. 15:30. - 16:0.0. 16:0.0. - 17:0.0. 17:0.0. - 18:30. 8/25/20.0.1 18:30. - 21:0.0. 21 :0.0. - 0.0.:0.0. 0.0.:0.0. - 0.5:30. 0.5:30. - 0.7:0.0. 0.7:0.0. -11:0.0. 11 :0.0. - 12:30. 12:30. - 0.0.:0.0. 2.0.0. DRILL 3.0.0. DRILL TRIP SURFAC CIRC SURFAC 0..50. DRILL TRIP SURFAC 0..50. DRILL DRLG SURFAC 1.0.0. DRILL CIRC SURFAC 0..50. DRILL CIRC SURFAC 3.0.0. DRILL TRIP SURFAC 0..50. DRILL SURV SURFAC 1.0.0. DRILL TRIP SURFAC 1.50. DRILL SURV SURFAC 2.50. DRILL RIRD SURFAC 3.0.0. DRILL RIRD SURFAC 5.50. DRILL RIRD SURFAC 1.50. DRILL PULD SURFAC 4.0.0. DRILL TRIP SURFAC 1.50. DRILL SURV SURFAC 11.50. DRILL DRLG SURFAC 8/26/20.0.1 0.0.:0.0. - 0.1 :30. 1.50. DRILL CIRC SURFAC 0.1 :30. - 0.6:0.0. 4.50. DRILL TRIP SURFAC 0.6:0.0. - 0.7:30. 1.50. DRILL PULD SURFAC 0.7:30. - 0.8:30. 1.0.0. DRILL PULD SURFAC 0.8:30. -11:30. 3.0.0. DRILL TRIP SURFAC 11:30. ~ 13:0.0. 1.50. DRILL REAM SURFAC 13:0.0. - 15:30. 2.50. DRILL CIRC SURFAC 15:30 - 16:0.0. 0..50. DRILL OBSV SURFAC Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: Description of Operations Circ and condition mud and hole. Check shot WI MWD @ 4183' (Weak signal, suspect wil I have future problems). . Continue trip in hole to 5519'. Circulate and pump hi-density sweep. Test MWD, not very strong of signal. Continue trip in hole f/ 5519' to 5961'. Prec autionary wash fl 5961' to 60.91' (130'). No Fill. Drill fl 60.91' to 610.0.' (9') ART = .25 hrs TV 0 =approx 3732'. Circulate and condition hole prior to tri pout fl MWD tools. Monitor well, pump dry job, blow down To.p d rive. POOH to HWDP @ 1100.'. Pump up survey. Blow down Top Drive. Continue POOH. Download Baker tools. Lay down MWD and m 0 to r. Rig down Baker Hughes Inteq equipment. Rig up Sperry Sun equipment. Rig up Sperry Sun surface equipment f/ MW D-LWD-PWD services. . PU BHA, orient and surface test. RIH wI bit # 3. Took weight @ 180.2,2053,2 0.57,3410.,3653,4127. Continue RIH to 580. 0.' . Measurement after Drilling (MAD pass) fl 58 0.0.' to 610.0.'. Tie in log for Sperry Sun. No te : Within 1'. Directional drill 97/8" hole fl 610.0.' to , (428') ART1.4 hrs. AST 5.9 hrs. 3800.'. Geologist picks: Top of west @ 6130.' MD = 3741'TVD Top of west @ 6270.' MD = 3774'TVD Top of west @ 6396' MD = 3796' TVD . Circulate @ TO of surface hole (6528'). Monitor well, pump dry job, POOH, monitor @ BHA. LID MWD & BHA. Clear rig floor. PU BHA #6 wI hole opener, stabilizers and X-O. Trip in hole wI 9 7/8" hole opener. Wash an d ream through dog legs @ 1120.',2159', an d 4433'. No problems. Continue. trip in to 52 35'. . Precautionary wash and ream f/6235' to.652 8' . Circulate and condition mud and hole fI casi ng. Pump hi vis-density sweep. Monitor well, pump dry job, blow down top d rive. 6528 TVD sak 0 sak C s ak B Printed: 11/30/2001 11 :17:54 AM (' .. PHILLIPS ALASKA INC.. .. . Operations Summary Repoi1. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 02 1 C-1 02 ROT - DRILLING Date. From':To Hours. Code. Sub Phase Code. 8/26/2001 16:00 - 19:30 3.50 DRILL TRIP SURFAC 19:30 - 20:30 1.00 DRILL PULD SURFAC 20:30 - 21 :30 1.00 DRILL OTHR SURFAC 21 :30 - 23:30 2.00 CASE RURD SURFAC 23:30 - 00:00 0.50 CASE SFTY SURFAC 8/27/2001 00:00 - 11 :00 11.00 CASE RUNC SURFAC 11 :00 - 16:30 5.50 CEMEN CIRC SURFAC 16:30 -20:30 4.00 CEMEN PUMP SURFAC 20:30 - 21 :30 1.00 CEMEN OTHR SURFAC 21:30 - 00:00 2.50 WELCTL NUND PROD 8/28/2001 1.00 WELCTL NUND PROD 2.50 WELCTL NUND PROD 00:00 - 01 :00 01 :00 - 03:30 03:30 - 07:00 3.50 WELCTL BOPE PROD 07:00 - 10:00 3.00 WELCTL OTHR PROD 10:00 - 11 :00 1.00 RIGMNT RSRV PROD 11 :00 - 12:00 1.00 WELCTL OTHR. PROD 12:00 - 12:30 0.50 RIGMNT RSRV PROD 12:30 - 13:00 0.50 DRILL RIRD PROD 13:00 - 16:00 3.00 DRILL TRIP PROD 16:00 - 21:00 5.00 DRILL TRIP PROD 21 :00 - 00:00 3.00 DRILL TRIP PROD 8/29/2001 00:00 - 01 :00 1.00 DRILL TRIP PROD 01 :00 - 02:00 1.00 DRILL CIRC PROD 02:00 - 03:30 1.50 DRILL DEaT PROD 03:30 - 06:00 2.50 CEMEN DSHO PROD 06:00 ~ 06:30 0.50 DRILL DRLG PROD 06:30 - 07:00 0.50 DRILL CIRC PROD . Page 4 of 15 Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: . Description of Operations POOH w/ 9 7/8" hole opener. Lay down BHA. Pull wear bushing. Change saver sub on top drive to 4 1/2" IF f or fill up tool, MU fill up tool, RU casing crew Hold pre job meeting w/ rig team members p rior to running 7 5/8" surface casing. Pre job safety meeting, run 7 5/8" casing to 6518' . Circulate and condition mudand hole while reciprocating casing. Circulated total of 125 2 bbls (12400 strokes). PU weight = 245 k SO weight = 120 k PJSM, Dowell/Schlumber test lines to 3500 psi. Cement per well plan. Bump p.lug @ 29 96 strokes, pressure up to 2500 psi. Check f loats. OK. Flush out stack. R/D. cement equipment.. L/ 0 landing joint. Install flange on diverter sp 00 I. PU Test joint and running tool. Set packoff. Change bottom pipe rams f/ 3 1/2" to variabl e rams 2 7/8" X 5". Test pack off to 5000 psi. Tighten rams doors. Remove knife valve & fl ange, 4" cement valves, Install 16", 5M Blin d flange. Rig up test equipment & test BOPE complete to 250 psi & 5000 psi. Annular to 250 psi & 3500 psi. Perform accumulator test. Witnes sing of test waived by AOGCC rep. Chuck Sc heve. Install wear bushing. Opening would not line up with wing valve. Pull wear bushing form odification. Cut Drilling line 86'. Install wear bushing after modification. Service Rig & Top Drive Change elevators, rig up floor for trippfng P/U BHA, Orient & program tools. S h a II 0 w t est M WOe qui p men t. AI H w / ex c e s s 0 P & L / Os a me. RIH wI Drilling Assy. SLM. RIH to 6432' MD Circ. bottoms up R/U and run casing test to 3000 psi for 30 m ins., held ok Drill out float equipment and cement to shoe @ 6518', clean out rat hole to.6528' Drill new formation F/6528' to 6548' ART hr s =.1 AST hrs = .2 . Circ. bottoms up Printed: 11/30/2001 11: 17:54 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8/29/2001 8/30/2001 8/31/2001 9/1/2001 9/2/2001 From -To' 07:00 - 10:30 10:30 - 11 :30 11 :30 - 12:00 12:00 - 13:00 13:00 - 23:00 23:00 - 00:00 1'" ( Page 50115 PHILLIPS ALASKA I NC. , , , , , , ' , , " ' Operations Summary Report. 1C-102 1 C-1 02 ROT - DRILLING Sub, Code Phase OTHR PROD CIRC PROD 3.50 DRILL 1.00 DRILL 0.50 DRILL OTHR PROD 1.00 DRILL FIT PROD 10.00 DRILL OTHR PROD 1.00 DRILL DRLG PROD 00:00 - 00:30 0.50 DRILL DRLG PROD 00:30 - 01 :00 0.50 DRILL RIRD PROD 01 :00 - 20:30 19.50 DRILL DRLG PROD 20:30 - 21 :30 1.00 DRILL CIRC PROD 21 :30 - 22:30 1.00 DRILL WIPR PROD 22:30 - 23:00 0.50 RIGMNT RSRV PROD 23:00 - 00:00 1.00 DRILL WIPR PROD 00:00 - 00:30 0.50 DRILL WIPR PROD 00:30 - 23:30 23.00 DRILL DRLG PROD 23:30 - 00:00 0.50 DRILL CIRC PROD 00:00 - 01 :00 1.00 DRILL CIRC PROD 01:00 - 01:30 0.50 DRILL SFTY PROD 01 :30 - 10:00 8.50 DRILL TRIP PROD 10:00 - 11 :00 1.00 DRILL PULD PROD 11 :00 - 12:00 1.00 DRILL PULD PROD 12:00 - 16:00 4.00 DRILL TRIP PROD 16:00 - 16:30 0.50 RIGMNT RSRV PROD 16:30 - 00:00 7.50 DRILL REAM PROD 00:00 - 08:30 08:30 . 15:30 15:30.18:30 8.50 DRILL REAM PROD 7.00 DRILL CIRC PROD 3.00 DRILL TRIP PROD Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: Description',of',Operations Clean mud pits and flush surface equipment Circ. Lo vis/High vis sweep, displace hole w ith 9.1 ppg. Baradrill;N mud, Continue to clean and flush surface mud cir culating system. Perform FIT test to 12 ppg. @ 600 psi Continue to clean and flush surface mud cir culating system Drill F/6548' to 6601' MD, 3802' TVD ART = .45 hrs. AST =.0 Circ. & survey = .55 hrs Drill from 6601' to 6651', shakers blinding 0 ff, losing mud Change shaker screens Drill from 6651' to 8495' MD, 3767' TVD AS T = 2.25 hrs. ART = 10.5 hrs. Circ., pump high vis low vis sweep, circ bott oms up , Wiper trip to the shoe, (6518'), had tight spo tat 7700', wiped once and it was gone. Service top drive TIH, currtently at 7900', hole in good shape TI H to, 8406', wash last stand to bottòm 849 5' Drill from 8495' to 10570' MD, 37653' TVD AST = 3,.75 hrs. ART = 10.25 hrs. Circ. and condo hole, pump high vis sweep Circ and cond hole Check for flow, pre-job safety meeting, pum p dry job POOH, no tight spots, check for flow at sho e, continue ou,t of hole. Down load MWD, L/D MWD and mud motor P/U 6 3/4" hole opener, reamer and stabilize, rs TIH to shoe, 6518' Service top drive Wash and Ream each stand down and up and washing down from 6518' to 8533', have se en no torque or drag. RPM 90 Pump 300 G PM , Wash and Ream to 10570, reaming each con nection once, had one tight spot at 9332', r earned thru once and didn't see again. ' Circ and cond hole, pump sweep and eire bo ttoms up', pump 30 bbls. M.I push pill, folio wed with 600 bbls. 8.9 kcl brine', followed b y 290 bbls HeC high vis brine. Clean fluid c oming in returns. POOH using trip tank to 7 5/8" casing shoe, losses show hole taking 10 bbls. per hr, plu s the pipe displacement, no tight spots or e -- Printed: 11/30/2001 11: 17:54 AM ( ( PHILLIPS ALASKA. INC. , " ' OperationsSulI1mary Report ' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-102 1C-102 ROT - DRILLING Date Sub From -To Hours Code Code Phase. 9/212001 15:30 -18:30 3.00 DRILL TRIP PROD 18:30 - 19:30 1.00 DRILL CIRC PROD 19:30 - 23:30 4.00 DRILL TRIP PROD 23:30 - 00:00 0.50 RIGMNT RURD PROD 00:00 - 01 :30 1.50 RIGMNT RURD PROD 01 :30 - 02:00 0.50 RIGMNT RSRV PROD 02:00 - 05:00 3.00 CMPL T PULD CMPL TN 05:00 - 08:00 3.00 CMPL T TRIP CMPL TN 08:00 - 09:00 CMPL TN 09:00 - 10:30 CMPL TN 9/3/2001 10:30 - 11 :00 11 :00 - 11 :30. 11:30 -15:30 CMPL TN CMPL TN CMPL TN 15:30 - 23:30 8.00 CMPL TN AWSH CMPL TN 23:30 - 00:00 0.50 CMPLTN TRIP CMPL TN 9/4/2001 00:00 -,05:00 5.00 CMPLTN TRIP CMPL TN 05:00 - 05:30 0.50 CMPL TN RURD CMPL TN 05:30 - 06:00 0.50 RIGMNT RSRV CMPL TN 06:00 - 06:30 0.50 CMPL T SFTY CMPL TN 06:30 - 17:30 11.00 CMPLT SCAN CMPL TN 17:30 - 18:30 1.00 CMPL T RURD CMPL TN 18:30 - 00:00 5.50CMPL T TRIP CMPL TN 9/5/2001 00:00 - 01 :00 1.00 CMPLT TRIP CMPL TN 01 :00 - 02:00 1.00 CMPL TN SOHO CMPL TN 02:00 ~02:30 0.50 CMPLT SFTY CMPLTN '02:30 - 10:30 8.00 CMPL T SCAN CMPL TN 10:30 -11:30 1.00 CMPL T SEaT CMPL TN 11:30 -13:00 1.50 CMPLTN PCKR CMPL TN 13:00 - 14:30 1.50 CMPLTN CIRC CMPLTN Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: Description, of, Operations " xcess drag coming out. Circ. high vis brine out of hole, continue to circ. until clean brine is at surface. POOH, LID stabilizers, reamers and hole op ener Slip and Cut drill line Finish slip and cutting drill line Service top drive P/U BHA, scrapers, 18 - 4 3/4" DC's, 30 - 4" HWDP and RIH TIH with 4" drill pipe to 6512' - strap going in h 0 I e Circ. clean brine Continue to circ, while waiting on caustic w ash, trucks were stuck behind rig move comi ng from BP side Pre-job safety meeting R/U to do caustic wash on DP and casing Pump 75 bbl,s caustic wash, displace with 8. 9 clean brine. Diverted caustic wash to vac. truck and circ. hole clean. Pump 500 gals 15% HCL acid to pickle Drill string. Displace down drill string at 1/2 BPM to bit. R'everse ,circ. acid back to surface, putting acid in open top tank, acid come bac k cl,ean, looking. Continue reverse circ. brin e until it cleaned up. Displace casing with H EC viscosified. brine. Check for flow. TOOH strapping pipe POOH strapping and drifting drill string, LID bit and scrapers R/U to run 4" liner Rig service Hold pre-job safety meeting and running pro cedure with rig employees and service comp any personal Run 4" liner and screens to 4500' R I U tor u n B a k e r cup a ss e m b I Y and 2 7 I 8" t u bin g , RIH inside 4" liner with2 7/8" tubing and Ba ker cup assembly to 3800' at report time. Finish RIH with 2 7/8" tubing, total 148 jts. Space out tubing and install liner hanger pa cker Hold pre-job safety meeting RIH W/4" liner and screens, set at 10551' M D Hold pre-job meeting, R/U and test lines to 4000 psi, Set liner hanger packer at 6042.45', staging pressure to 3500 psi. Test annulus to 1000 psi, release from packer. ' Blow ball seat and circ. 500 bbls filtered 8. Printed: 11/30/2001 11:17:54 AM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 02 1 C-1 02 ROT - DRILLING ... .. Sub Frorn- To . Hours Code Code Phase 9/5/2001 13:00 - 14:30 14:30 - 16:30 1.50 CMPLT CIRC CMPLTN 2.00 CMPL T CIRC CMPL TN 16:30 - 19:00 2.50 CMPLT AWSH CMPL TN 19:00 - 19:30 CMPL TN 19:30 - 21:00 1.50 CMPL T CMPL TN 21:00 - 21:30 0.50 CMPL T CIRC CMPL TN 21 :30 - 22:30 1.00 CMPL TN AWSH CMPL TN 22:30 - 23:30 1.00 CMPLTN CIRC CMPL TN 23:30 - 00:00 0.50 CMPL TN AWSH CMPL TN 9/6/2001 00:00 - 03:00 3.00 CMPL T TRIP CMPL TN 03:00 - 06:00 3.00 CMPLTN AWSH CMPLTN 06:00 - 08:30 2.50 CMPLTN CIRC CMPL TN 08:30 -11:30 3.00 CMPL T TRIP CMPL TN 11 :30 - 12:00 0.50 CMPL TN DEaT CMPL TN 12:00 - 13:30 1.50 CMPL TN TRIP CMPL TN 13:30 - 19:30 6.00 CMPL TN PULD CMPL TN 19:30 - 20:30 1.00 CMPL TN RURD CMPL TN 20:30 - 00:00 3.50 WELCTL BOPE PROD 9n/2001 00:00 - 01 :00 1.00 WELCTL BOPE PROD 01 :00 - 03:00 2.00 WELCTL NUND PROD 03:00 - 09:30 6.50 WINDO PULD PROD 09:30 - 11 :30 RIP PROD 11 :30 . 13:00 13:00.16:30 16:30 - 17:30 1.50 WIN DO OTHR PROD 3.50 WINDO RIP PROD 1.00 WINDO SETW PROD 17:30 - 19:00 19:00.21:00 Page70f 15 Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: Description of Operations.. 9 ppg brine Hold pre-job meeting, test Dowell lines to 2 500 psi, fill DP wI 83.5 bbls 10% HCL acid, followed with 10 bbls brine Pump 3.2 bbls acid into each screen from 10 405' to 8890' Load DP wI 54.5 bbls acid followed with 14. 9 bbls brine Pump 3.2 bbls acid into each screen from 88 27' to 7627' Load DP wI 42.5 bbls acid followed with 15. 5 bbls brine . Pump 3.2 bbls acid into each screen from 75 64' to 6807' Load DP wI 12 bbls acid followed with 32.8 bbls brine Pump 3.2 bbls acid into each screen from 67 44' to 6523' TIH with DP, to place 2 7/8" tubing on botto m, while waiting on 6 hr. acid soak Waiting on 6 hr. acid soak,R/U equipment to circ. out acid with clean brine Circ. out acid with 8.9# clean brine, started at 7.5 BPM at 1800 psi and ended 2 to 3 BP M at 1100 psi. Total fluid circ. was 550 bbls . Circulated to 2 vacumn trucks POOH to. 1475' Pressure test KOIV to 690 psi POOH with 4- HWDP and DC's POOH LID last 9 DC's and 148 jts. 2 7/8" tu bing R/U to test BOP's, Pull wear bushing Run test plug and test BOP's to 250 psi low and 5000 psi high, test annular to 3500 psi. Finish BOP test, 250 psi low and 5000 psi 10. w, hole taking 4 - 5 bbls fluid a hour RID test equip., pull test plug, set wear bus hing in well head. P/U BHA, whipstock and associated equip., mills and Sperry Sun MWD. Upload MWD and test, MWDfailed, LID tool and P/U differen t MWD an.d upload. Test MWD, everything ok . Hole taking 2 - 3 bbls. fluid a hour TIH WI DC's, shallow test MWD again, TIH t 0 1492' R/U and test KOIV to 690 psi, held ok TIH W I Baker whipstock assembly Orient whipstock and set in top.of liner .han ger Displace brine water out of hole and circ. dr illing mud in hole Mill out window from 5941' to 5945' MD, 368 0' TVD Printed: 11/30/2001 11 :17:54 AM ( (' PageS.of 15 PHilliPS ALASKA INC. . . . , . . . Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-102 1C-102 ROT - DRILLING Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: F.rom -To Hours Code Sub Phase Code. . 9f7/2001 21 :00 - 22:00 22:00 - 22:30 22:30 - 00:00 9/8/2001 00:00 - 02:00 02:00 - 04:30 04:30 - 05:30 05:30 - 06:30 06:30 - 07:30 07:30 - 10:30 10:30 - 11 :00 11:00 -15:00 15:00 - 22:30 22:30 - 00:00 9/9/2001 00:00 - 01 :00 01 :00 - 02:30 02:30 - 03:00 03:00 - 05:30 05:30 - 09:30 09:30 -10:30 10:30 - 12:00 12:00 - 14:00 14:00-15:00 15:00 - 17:30 17:30 - 18:00 1.00 WINDO CIRC PROD 0.50 RIGMNT RSRV PROD 1.50 WINDO RIP PROD 2.00 WINDO RIP PROD 2.50 WELCTL EaRP PROD 1.00 WELCTL TRIP PROD 1.00 WELCTL TRIP 1.00 WELCTL OBSV PROD PROD 3.00 WELCTL EaRP PROD 0.50 WELCTL SFTY PROD 4.00 WELCTL NUND PROD 7.50 WELCTL NUND PROD 1.50 WELCTL EaRP PROD 1.00 RIGMNT OTHR PROD 1.50 RIGMNT RURD PROD 0.50 RIGMNT RSRV PROD 2.50 WAlTON EQlP PROD 4.00 WELCTL NUND PROD 1.00 WELCTL BOPE PROD 1.50 WELCTL EaRP PROD 2.00 WELCTL TRIP PROD 1.00 WELCTL TRIP PROD 2.50 WINDO RIP PROD 0.50 WINDO STWP PROD Description of Operations' . . Circ. hale clean, we have magnets in the pa ssum belly and screens under the discharge .of the shaker screens ta catch the metal cu ttings Rig service, sevice tap drive TOOH ta change BHA's,( this is a twa run, n ew design Baker whipstack system) POOH far mill change, LID MWD . Pull wear bushing far Vetca Gray ta la.ok at why wear bushing will nat fit praperly in we I I head. Faund well head pack .off was n.ot se t in place, it's nat sealing .off between 7 5/8 . casing and 16"canductar RIH WI 9 - 4 3/4" DC's and19 stands .of 3 11 2" DP ta use as tail pipe bel .ow starm packer Wait an 7 5/8" starm packer ta be braught fr am Baker Oil Taals in Deadharse RIH WI starm packer and set at 273' fr.om su rface Attempt ta pull packaff aut .off well head, re cave red the tap piece .of packaff Hald pre-jab safety meeting, ta prepare far I ifting and setting back the BOP's N 10 BOP's N/D well head, remave packaff, had ta build taal ta recaver bottam part .of packaft. Redr ess hanger and N/U well head, install new p ackaff and canfirm it is in place. Test packa ff ta 5000 psi, held ok. Run wear bushing in ta wellhead and make sure everything lines up and sets praperly. Everything is as shaul d be. Waiting far new riser ta fit under BOP's, it was air lifted fram Ancharage taday and is' s uppase. ta be an lacatian tanight. The riser we presently have is ta lang, we have ta jac k rig up 8" ta install arremave BOP's Clean cellar area Slip and cut drill line Service tap drive . Waiting an riser far Nabors BOP stack. Curr ent riser was ta lang and rig has ta be jacke d up 8" ta install and remave BOP. N/U riser and BOP's Test breaks made an wellhead and BOP ta 2 50 psi law and 5000 psi high Pull test plug, set wear bushing RIH and latch .onto st.orm packer, POOH, LID packer TOOH with tail pipe used bel.ow packer TIH will new side track mill t.o 5940' Ream thru and clean up wind.ow fr.om 5941' t Printed: 11/30/2001 11:17:54AM I'" ( Page 9 0115 PH Illl PSALASKAINC. " . . . OperationsS'ummary Report: Legal Well Name: 1 C-1 02 Common Well Name: 1C-1 02 Event Name: ROT - DRILLING Contractor Name: Rig Name: Date From-To Hours Code 9/9/2001 17:30 - 18:00 0.50 WINDO 18:00 - 22:00 4.00 WINDO 22:00 - 23:00 1.00 WINDO 23:00 - 00:00 1.00 DRILL 9/10/2001 00:00 - 04:30 4.50 WINDO PROD 04:30 - 05:00 0.50 DRILL PULD PROD 05:00 - 10:30 5.50 DRILL PULD PROD 10:30 - 12:00 1.50 DRILL DEaT PROD. 12:00 - 14:00 2.00 DRILL TRIP PROD 14:00 - 19:30 5.50 DRILL PULD PROD 19:30 - 22:30 3.00 DRILL TRIP PROD 22:30 - 00:00 1.50 DRILL DRLG PROD 9/11/2001 00:00 - 08:30 8.50 DRILL DRLG PROD 08:30 - 09:00 0.50 DRILL CIRC PROD 09:00 - 09:30 0.50 DRILL TRIP PROD 09:30 - 15:00 5.50 WAlTON ORDR PROD 9/12/2001 15:00 - 15:30 0.50 DRILL TRIP PROD 15:30 - 00:00 8.50 DRILL DRLG PROD 00:00 - 15:30 15.50 DRILL DRLG PROD 15:30 - 16:00 0.50 DRILL CIRC PROD .16:00 - 00:00 8.00 DRILL DRLG PROD 00:00 - 00:30 0.50 DRILL CIRC PROD 00:30 - 11 :30 11.00 DRILL DRLG PROD 11:30 -13:00 1.50 DRILL CIRC PROD 13:00 - 13:30 0.50 DRILL CIRC PROD 13:30- 15:00 1.50 DRILL TRIP PROD 15:00 - 15:30 0.50 RIGMNT RSRV PROD 15:30 - 17:30 2.00 DRILL TRIP PROD 17:30 - 00:00 6.50 DRILL DRLG PROD 00:00 ;. 00:30 0.50 DRILL CIRC PROD 9/13/2001 9/14/2001 Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: Description of Operations 0 5945' Mill from 5945' to 5971', ream thru several t ¡mes to clean up Circ. sweep and bottoms up Perform FIT to 12 ppg., 505 psi at 3590' TV D with 9.3 ppg mud Pump dry job, POOH, L/D 4" HWDP & 4 3/4" DC's and milling assembly Change out saver sub and install corrosion r in g P/U BHA, MWD and PWD, upload MWD, TIH t 0 5000' Test MWD tool, failed and couldn't get it wo rking correctly. Pump dry job, POOH Attempt to repair MWD tool, but failed, L/D tool and PIU new tool, upload MWD, surface test tool, OK TIH to 5900', test MWD, everything working, Orient tool and RIH through window and to TD 5971', never seen a flicker on weight ind icator going through window. Drill ahead from 5971' to 5985' MD. 3690 TV D. ROP in this shale is 7 to 10 FPH. . Drill from 5985' to 6063' Circ. bottoms up, was called from town to s hut dow.n operations until further notice, be cause of safety issue. POOH 3 stands, to 5856', shut down waiting on orders from town. Shut down drilling operations because of fli ght shut downs, leaving us with no medivac . if somebody.should get injured Orient tool face to go through window, TIH t. 0 bottom. Drilling from 6063' to 6155' MD, 3747 TVD. ROP = 10.8 fph Drilling from 6155' to 6400' MD 2.00 hrs. A RT 9.75 hrs. AST Circ. for PWD base line Drilling from 6400' to 7127' MD, 3724' TVD 2.00 hrs..ART 4.75 hrs. AST Circulate bottoms up. Drill 6" hole f/ 7127' to 8313'(1186') (3708' TVD) AST =.75 hrs. ART = 4.5 hrs. Circulate bottoms up prior to wiper trip. Monitor well, pump dry job. . POOH to 5900'. Service rig and top drive. RIH Drill. 6" hole f/ 8313' to 9072' (759') (3697' TVD) AST = .75 hrs. ART = 4.6 hrs.. CBU prior to trip for ABI failure. Printed: 11/30/2001 11:17:54 AM """ r ( , Page'10 of 15 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 1C-1 02 Common Well Name: 1C-1 02 Event Name: ROT - DRILLING Contractor Name: Rig Name: Date From -To Hours Code Sub Phase Code 9/14/2001 00:30 - 06:30 6.00 DRILL TRIP PROD 06:30 - 10:00 3.50 DRILL TRIP PROD 10:00 - 12:00 2.00 WELCTL BOPE PROD 12:00 - 17:30 5.50 WELCTL BOPE PROD 17:30 - 19:00 1.50 WELCTL BOPE PROD 19:00 - 22:00 3.00 DRILL OTHR PROD 22:00 - 00:00 2.00 DRILL TRIP PROD 9/15/2001 ,00:00 - 03:00 3.00 DRILL TRIP PROD 03:00 - 12:00 9.00 DRILL DRLG PROD 12:00 - 19:30 7.50 DRILL DRLG PROD 19:30 - 00:00 4.50 DRILL CIRC PROD 9/16/2001 00:00 - 12:00 12.00 DRILL TRIP PROD 12:00 - 13:00 1.00 DRILL TRIP PROD 13:00 - 13:30 0.50 DRILL OTHR PROD 13:30 - 14:30 1.00 DRILL TRIP PROD 14:30 - 17:00 2.50 DRILL TRIP PROD 17:00 - 19:00 2.00 RIGMNT RURD PROD 19:00.. 19:30 0.50 DRILL TRIP PROD 19:30 - 20:30 1.00 RIGMNT RSRV PROÒ 20:30 - 00:00 3.50 DRILL SFTY PROD 9/17/2001 00:00 - 17:30 17.50 DRILL SFTY PROD 17:30 - 18:30 1.00 RIGMNT RSRV PROD Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: Description of Operations' POOH wet. Hole in good condition. ABI faulty. Download MWD. L/D motor. PU m otor. Check ABI (O'K). L/D hang off sub. Sta nd back motor, MWD and float sub. Pull wear bushing. RU for BOPE weekly test. Waived by AOGCC inspector Jeff Jones. Te st Annular to 250 psi low and 3500 psi high. Test upper pipe rams(31/2' x 6" VBR), cho ke line valves, 1,2,3 kill and HCR valves, u pper IBOP to 250 psi low and 5000 psi high. Test 4-16, HCR & manual kill line valve, low er top drive valve, 4M floor safety valve, 3 1 /2" IF floor safety valve, 4M IBOP, 3 1/2" IF IBOP to 250 low and 5000 psi high. Tested I ower pipe rams(2 7/8M x 5" VBR) to 250 and 5000 psi with 3 1/2" and 4". Upper ramss (3 112M x 6" VBA) were tested with both 3 1/2" and 4" also. RID test equipment. Run wearbushing. Blowd own choke manifold. MU BHA. Change stabilizer on motor. Adjust angle on motor to 1.5 deg. Orient motor wi th MWD. Program Sperry tools., , RIH wI 6M bit and BHA # 13. Shallow test OK . RIH to +1- 5900'. Trip in hole to window. Orient for entrance. Continue to RIH. Precautionary ream 90' to bottom. Drill 6" hole from 9072' to 10017'(945') (TV 0= 3693') ART = .3 hrs. AST = 1.5 hrs. Drill 6" hole from 10017' to 10600' (583') (T VD= 3688') Circulate and condition mud and hole. Chan ge out mud system. POOH, SLM, wet, tight 11 6326' to window. P ump fl 6232' to 5985'. Continue POOH, down load MWD. LID pulsar & hangoff sub. LID BHA ' Retreive corrosion ring fl saver sub on top d r i v e. , MU 6M Hole opener assembly. 'RIH to casing window.. Slip and cut drilling line. Service rig and to p drive. Start to continue and go out window. Notice d keeper out of grabs. ' Change out grab heads on top drive. Floorha nd injured both hands. ' Injury while changing die blocks. Safety sta nd down. Safety stand down. Injury while changing gr abs on top drive. Finish replacement of grabs on top drive. Printed: 11/30/2001 11 :17:54 AM .'" , ( . . . PHilliPS ALASKA INC." . . . . ." Operations SummarY Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 02 1 C-1 02 ROT - DRILLING Page 11 of 15 Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: Description of Operations Date. From-To Hours Code. Sub Code 9/17/2001 18:30 - 19:00 0.50 DRILL REAM PROD 19:00 - 00:00 5.00 DRILL REAM PROD 9/18/2001 00:00 - 09:00 9.00 DRILL REAM PROD 09:00 - 11 :30 2.50 DRILL CIRC PROD 11 :30 - 15:30 4.00 DRILL TRIP PROD 15:30 -16:00 0.50 RIGMNT RSRV PROD 16:00 -18:30 2.50 DRILL TRIP PROD 18:30 - 23:00 4.50 DRILL CIRC PROD 23:00 - 00:00 1.00 DRILL CIRC PROD 9/19/2001 00:00 - 03:00 3.00 DRILL PROD CIRC 03:00 - 10:00 7.00 DRILL TRIP PROD 10:00 - 10:30 0.50 DRILL CIRC PROD 10:30 -16:00 5.50 DRILL TRIP PROD 16:00 - 00:00 8.00 DRILL TRIP PROD 9/20/2001 00:00 - 02:30 2.50 CMPLTN TRIP PROD 02:30 - 03:30 1.00 CMPLTN CIRC PROD 03:30 - 05:00 1.50 CMPLTN CIRC PROD 05:00 - 07:00 2.00 CMPL TN CIRC PROD 07:00 - 08:30 1.50 CMPLTN AWSH PROD 08:30 - 10:00 1.50 CMPL T CIRC PROD 10:00 - 17:00 7.00 CMPL T TRIP PROD 17:00 - 17:30 0.50 CMPL TN TRIP PROD 17:30- 18:00 0.50 RIGMNT RSRV PROD 18:00 - 20:30 2.50 CMPL T TRIP PROD 20:30 - 21 :00 0.50 RIGMNT OTHR PROD 21 :00 - 00:00 3.00 CMPL TN TRIP PROD 9/21/2001 00:00 - 01 :00 1.00 CMPL T TRIP PROD Circulate out through window to 6000'. Ream 6" upper lateral hole, with hole open er assembly. Ream each stand down and up, then circulate each stand down. Ream f/ 8023' to 10600' with 6" hole opener assembly. Circulate and condition mud. Short trip to casing window @ 5941'. Hole in good shape.A little excess drag @ 6250'-6 450' area of hole. Service rig and top drive. RIH. Precautionary ream f/ 6250' to 6450'. D id not see any problems. Continue to TO. Circulate sweep and condition hole. . Pump 30 bbl push pill. Flush surface lines w / water (1,2,3 pumps- choke manifold- kill I ine- cement standpipe- 3 sections of hose 0 n floor) . Circulate 600 bbls filtered brine @ 8.9 ppg while displaceing mud from hole. Follow wit h 290 bbls viscosified brine, displaced with 41 bbls f.iltered brine, leaving viscosified br ine in open hole. . PJSM. Monitor well. Blow down top drive. P OOH to 4753'. Work through tight spots @ 6 323',6097' and 5944'. Max 10 k overpull. Circulate viscosified brine out of hole (Clea ning up drill pipe). PJSM, monitor well, blow down top drive. L/ D 3 1/2" dril.1 pipe & BHA. MU BHA with dual 7 5/8. casing scrapers. RI H wI 3 1/2" DP, HWDP, and 4 3/4. drill colla rs. PU 3 /2. HWDP and 4 3/4" DC's to run dual scrapers. . CBU, check ntu's of filtered brine. RU, PJSM, Pump caustic wash taking return s f/ well head to vac truck for disposal of c austic wash. . . Circulate, checking ntu's. Came down to 22 ntu's. RU, PJSM, Pump acid wash w/ Dowell, takin g returns to outside open top slop tank. RU, pump brine, check ntu's. Pump 215 bbls viscosified brine. Drop rabbit, monitor well, POOH wet. L/D BHA Safety meeting, Service top drive. MU BHA to fetch whipstock. Adjsut kicker cylinder clamps on bales for t op drive. RIH to retreive whipstock. Trip in hole to 5947' with whipstock retrieva Printed: 11/30/2001 11:17:54 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/21/2001 9/22/2001 00:00 - 01 :00 01 :00 - 02:00 02:00 - 03:00 03:00 - 06:30 06:30 - 10:00 10:00 - 12:00 12:00 - 17:30 17:30 - 19:30 19:30 - 00:00 00:00 - 02:00 02:00 - 04:30 04:30 - 05:30 05:30 - 13:00 13:00 -16:30 "" ( PHilliPS ALASKA INC. , , - , , , Operations Summary Report 1 C-102 1C-102 ROT - DRILLING Sub Hours Code Code' Phase 1.00 CMPLT TRIP PROD 1.00 CMPLT OTHR PROD 1.00 CMPLT CIRC PROD 3.50 CMPLT TRIP PROD 3.50 CMPL T TRIP PROD 2.00 CMPL T RURD PROD 5.50 CMPL T RUNT PROD 2.00 CMPL TN RUNT PROD 4.50 CMPL T RUNT PROD 2.00 CMPL TN RUNT PROD 2.50 CMPL T RUNT PROD 1.00 CMPL TN OTHR PROD 7.50 CMPLTN RUNT PROD 3.50 CMPL T RUNT PROD 16:30 - 00:00 7.50 CMPL TN TRIP PROD 9/23/2001 00:00 - 03:30 3.50 CMPL TN TRIP PROD 03:30 - 10:30 7.00 CMPLT TRIP PROD 10:30 - 11 :30 1.00 RIGMNT RSRV PROD 11 :30 - 13:00 13:00 -18:30 18:30 .. 20:00 20:00 - 20:30 1.50 WELCTL OTHR PROD 5.50 WELCTL BOPE PROD 1.50 WELCTL OTHR PROD 0.50 RIGMNT RSRV PROD Page 120f 15 Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: Description. of Operations I to 0 I, Workover and engage whipstock. Pull free w ith 52k overpull. CBU Monitor well. Blow down TD. POOH -(slow/w e t) LID MWD, BHA, Whipstock, subs & x-o's. CI ear rig floor. PJSM. RU casing tools and equipment to run 4. screens and blanks for upper lateral. Safety meeting. Run 4" screens and blanks. Run 4061.91') , Change elevators. Run 4 1/2. blanks and 2- ECP's . Total length of 539.42') Run 2 7/8. inner circulating string inside lin er. 110 jts in hole (3282.27') Run 2 7/8" inner circulating string (152 join ts run + 0.8'). Tagged packoff @ 4562.26'. B ottom out @ 4575.46'.(152 jts + 14') , Space out with 2 7/8" pups and MWD collar & x-o's. Ran 151 its 2 7/8" + 7.87 pup' + 7.8 6' pup+ collars and x-o's(19.90) to leave bo ttom of slick stick @ 4569.58' (approx 7 1/2' into packoff bushing). Ch,ange saver sub on TD from 41/2" IF box by 4. HT38 to 41/2" IF box by3 1/2" IF pin so if needed to circ. Trip in hole with 4. liner. Fill every stand. Determine actual up and down weight every 5 stands while running. Orient & set flanged hook hanger in window. Drop 1-1/2" ball, pump down & pressure to 2700 psi & release running tool. Pressure to 3700 psi to blow ball seat. LID all 3 1/2. IF work string. L/D3 1/2" HWDP and 31/2" drill pipe after setting flange hook in casing window. Monitor well. PJSM, RU & lay down MWD co I jar and 2- 7/8" inner circulating string. Change top drive saver sub from 4 1/2"'IF t 0 3 1/2" IF ~o 4 1/2" IF to, 4" HT38 for, 4" dri II pi pe. , Pull wear bushing, Rig up for weekly BOPE t est. Verbal extension was given byAOGCC in sp. Chuck Sheve to test after liner was in h ole. ' Weekly BOPE test. Test witnessed by AOGC C rep. John Spaulding. Test annular @ 250 psi low and 3500 psi high. Test all other pie ces @ 250 psi low and 5000 psi high. RID test equipment. Blow down lines. Install wear bushing. ' Service top drive and rig. Printed: 11/30/2001 11 :17:54 AM ( ( Page' 1301 15 PHILLIPS ALASKA INC. , ' Operations Summary, Report 1C-102 1C-102 ROT - DRILLING Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Spud Date: 8/18/2001 End: 9/28/2001 Group: Start: 8/16/2001 Rig Release: Rig Number: Sub Code Description of Operations, PU and MU running tool & diverter to get int a top lateral. RIH total of 33 stands 4" drill pipe @ midni ght. Run @ 2 min per stand. RIH wI 4" drill pipe and diverter to TOL @ 5 936'. Set Diverter 2' into TOL @ 5938'. Set diverter. PU wt 140 k. SO wt 110 K Monitor well. Blow down TD. POOH. LID runn ing tools. PJSM. RU tbg tools to PU 18 joints of 2 7/8" tbg. and assembly to cement upper and low er ECP's. ' RIH wI cement inflation tools to inflate uppe r and lower external casing packers. ' Drop ball and pump to seat @ 6430'. Pressu re test cups to 1500 psi fl 10 min. OK. Pres sure to 3100 psi to blow seat. PJSM. RUcement equipment. Test, Dowell to 5000 psi. Load string, wI cement,cement low er external casing packer. Took 3/8 bbls ce ment in packer = 7" open hole. POOH ,to 6043', RU to inflate upper external casing packer. Put 1 3/4 bbls cement in pa cker=11" open hole. ' PU to 5927'. Reverse out excess cement. Pooh, wI 4" dp and 18 joints of 2 7/8" tbg an d inflation tools. ' PJSM. RU to make up screen washing assem bly. PU 2 7/8" tbg on assembly and RIH wI 2 7/8". . P/U 153 jts. of 2 7/8" Tubing and RIH - RID Tubing handling equipment 'RIH WI 4" DP to 10524' Displace hole with 8.9 ppg filtered ,brine, 60 0 bbbis. R/U Dowell Schlumberger for acid wash Hold pre-job safety meeting, test lines to 50 00 psi Pump 82 bbls 10% Hcl acid into work string, displace 10 bbls of acid out into open hole with 8.9 brine. Attempt to rig down Dowell Ii nes from work string, well was U-tubing up work string, with acid close to surface. Rig back Dowell lines. Check acid weight coming out of transport and found it to be on the I ' ight side of 8.8 ppg and the brine is a 8.9+. Reverse acid back out of work string into 0 pen top tank. , ' POOH 42 stands, above where our last wash will be pumped and place a float in string. TIH at 2 mins per std., fill every 10 stands Pump 82 bbls 10% Hcl acid, displace 10 bbl s of acid into open hole, start acid wash on 9/23/2001 20:30 - 21 :30 PROD PROD 21 :30 - 00:00 PROD 9/24/2001 00:00 - 02:30 1.00 CMPL T OTHR PROD 2.50 CMPL T TRIP PROD 02:30 - 03:30 03:30 - 06:00 PROD 06:00 - 08:00 PROD 08:00 - 11 :30 11 :30 - 13:00 2.00 CEMEN PUMP PROD 13:00 - 15:00 1.00 CEMEN PUMP PROD 15:00 - 16:00 1.00 CEMEN OTHR PROD 4.00 CEMEN TRIP PROD 16:00 - 17:00 17:00 - 21 :00 3.00 CMPL TN TRIP PROD 21 :00 - 00:00 9/25/2001 00:00 - 04:00 4.00 CMPLTN TRIP PROD 04:00 - 09:00 5.00 CMPL TN TRIP PROD 09:00 - 11 :00 2.00 CMPLTN CIRC PROD 11 :00 - 12:00 1.00 CMPL TN RURD PROD 12:00 - 12:30 0.50 CMPL TN SFTY PROD 12:30 - 15:30 3.00 CMPLTN AWSH PROD 2.00 CMPLT TRIP PROD 15:30 - 17:30 4.00 CMPL T TRIP PROD 2.50 CMPL T AWSH PROD 17:30 - 21 :30 21 :30 - 00:00 Printed: 11/30/2001 11:17:54AM ( Page 14of 15 PHILLIPS ALASKA INC. Operations Summary Report. Legal Well Name: 1C-102 Common Well Name: 1C-102 Event Name: ROT - DRILLING Contractor Name: Rig Name: From~To Hours Code. Sub Code 9/25/2001 21 :30 - 00:00 2.50 CMPL T AWSH PROD Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: Description of Operations. 9/26/2001 00:00 - 05:00 5.00 CMPL T AWSH PROD 05:00 - 07:00 07:00 - 08:30 08:30 - 11 :00 2.00 CMPL TN TRIP PROD 1.50 RIGMNT RURD PROD 2.50 CMPL TN RURD PROD 11 :00 - 13:00 2.00 CMPL T CIRC PROD 13:00 - 16:30 3.50 CMPL TN TRIP PROD 16:30 - 22:00 5.50 CMPLTN TRIP PROD 22:00 - 22:30 0.50 CMPL TN RURD PROD 22:30 - 00:00 1.50 CMPLTN TRIP PROD 9/27/2001 00:00 - 01 :00 1.00 CMPLTN TRIP PROD 01 :00 - 02:00 1.00 CMPL TN TRIP PROD 02:00 - 06:30 4.50 CMPLTN TRIP PROD 06:30 - 07:30 1.00 CMPL TN RURD PROD 07:30 - 08:30 1.00 CMPL TN RURD PROD 08:30 - 16:00 7.50 CMPLTNTRIP PROD 16:00 - 21:30 5.50 CMPL TN RURD PROD screens from 10443' to 9357'. At report time 17 screens had been washed with 3.8 bbls acid per screen . Acid wash screens F/9357' to 8853',6 - scre ens., Pump 69 bbls 10% Hcl in work string, displace to end of tubing, acid wash screens F/8853' to 7541',19 screens., Pump 52 bbl s 10% Hcl in work string, displace to end of tubing, acid wash F/7541' to 6535',15 scre ens. Displace +- 3.8 bbls acid per screen at 3 bbl per min. Pull float out of string. TIH to 10524, wait on acid soak Hold pre-job meeting, slip and cut drill line Assemble and test to 5000 psi the 2 piece V etco Gray tubing hanger, redress hanger wit h new outer seals. Hold pre-job for displaci ng acid out of hole Displace acid out of hole. with 8.9 ppg ed brine. Displaced to vacumn trucks. pumped 650 bbls. at rates from8 bbls in to 3 bbls per min. POOH W/4" DP Hold pre-job for R/U and pulling of 2 7/8" tu bing Change handling tools to 2 7/8". tubing POOH LID 153jts of 2 7/8" tubing Hold pre-job, change handling equip. back t 0 4" P/U spear and TIH to latch onto diverter ass embly New crew held pre-job meeting, TIH with spe ar Latch onto diverter, took several try's, but c . aught it by circ. into it, took20K overpull t 0 pull loose. . . Held pre-job meeting, TOOH w/diverter, rele ase spear from diverter and LID Held pre-job meeting, pull wear bushing, ha d trouble getting it through Hydril annular R/U to run 4 1/2" kill string, hold pre-job m e e ti n g TIH with 4 1/2" kill string Held pre-jb meeting, attempt to hang off tub ing hanger, couldn't get it through the top 0 ff 13 5/8" annular, after several attempts it was decided to pull bel. I nipple and look.for the problem, held pre-job meeting, pull bell nipple, fo.und that the wear ring on top of an nular rubber was smaller than the Vetco Gra y hanger, hanger OD is 13.450" and annular wear ring should have been 13.625". held pr e-job meeting, made proper safety precautio ns and ground the wear ring to the proper si ze filter Total perm Printed: 11/30/2001 11:17:54 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/28/2001 23:00 - 00:00 00:00 - 03:00 03:00 - 06:00 06:00 - 09:00 09:00 - 10:00 f (' PHilliPS ALASKA INC~ . " . Operations Summary Report .. 1C-102 1C-102 ROT - DRILLING 1.00 CMPL TN NUND PROD 3.00 CMPL T NUND PROD 3.00 CMPL TN NUND PROD 3.00 CMPL T FRZP PROD 1.00 CMPL TN RURD PROD Start: 8/16/2001 Rig Release: Rig Number: Spud Date: 8/18/2001 End: 9/28/2001 Group: Date From- To Hours Code Sub Phase. . Code . . 9/27/2001 21 :30 - 23:00 1.S0 CMPL T RURD PROD Description of Operations. Run tubing hanger through BOP's and land i n wellhead with no problems, test hanger to SOOO psi., LID landing jt., set BPV. Ran a total of 190 jts of 4 1/2- 12.6# L-80 NSCT tubing with a 4 1/2"x2- swage, w ith a 1.S" ID on bottom, plus a tubing hang er with a 30' 4 1/2" hanger jt baker locked 0 n it. Kill string is set at S84S' RKB Held pre-job meeting, N/D BOP's N/D BOP's and layout drilling spool N/U Vetco Gray tree and test to SOOO psi Freeze protect well by pumping 110 bbls die sel down annulus and letting it u-tube back through tree. Had 1S0 psi on both tubing an d annulus when complete. Rig up lubricator on tree and set BPV, Rig d own lubricator. Release rig at 10:00 hrs. 9/2 8/01. Finish rig down to move to 1c-131 Printed: 11/30/2001 11:17:54AM Re: 1 C-1 02 Sundry - Change in proœaure /t"'"., ,. ~ Subject: Re: 1 C-1 02 Sundry - Change in Procedure Date:.Wed, 10 Oct 2001 18:18:13 -0800 From: "Steve McKeever" <smckeev@ppco.com> To: tom_maunder@admin.state.ak.us CC: "Sharon Allsup-Drake" <sallsup@ppco.com>, "Todd J Mushovic" <tmushov@ppco.com> " Tom: ~()\- \fe.\ ~t)\-\"-;). Nordic Rig 3 has moved onto 1C-102/1C-102L 1 late last night, and is in the process of running the ESP completion as was originally permitted. Steve McKeever Drilling Engineer Phillips Alaska, Inc. 907.265.6826 office 907.265.1535 fax 907.275.0369 pager smckeev@ppco.com "It is better to keep your mouth shut and appear stupid than to open it and remove all doubt." - Mark Twain ---- Forwarded by Steve McKeever/PPCO on 10/10/01 06:22 PM ----- Tom Maunder <tom_maunder@admin.state.ak.us> 09/20/01 05:04 AM To: Steve McKeever/PPCO@Phillips cc: Subject: Re: 1 C-1 02 Sundry - Change in Procedure Steve, Your program looks acceptable and you have approval to proceed. You are correct a sundry . will be necessary. Thanks for providing an estimate of when the rig would move back. When operations resume, please send us an emaH. giving notice. Tom Maunder, PE Sr. Petroleum Engineer Steve McKeever wrote: > Hi Tom: > > re: West Sak Multilateral We1/1C-102 / 1C-102L 1, Permits # 201-161, > 201-172 > 1of3 10/11/01 12:22 PM Re: 1 C-1 02 ~unary - l,;nange 10 t-'roceaure .~, - '" > Due to a delivery problem with a down hole sensor we would like > authorization for a completion procedure other than the one permitted for > the above weJJ. > We had planned to run the ESP completion at the usual time, at the end of > the drilling phase, before the rig moves off. We are hoping that the AOGCC > will authorize us to suspend our operations on this we/J, move off, then > move back on in late November to run the ESP. > > The attached file details the proposed changes in procedure, with a > schematic showing the well as it would be "suspended". > > If this alternative procedure is acceptable to the Commission, can you > please provide authorization via e-mail? Should you provide such > authorization we will fol/ow up with a formal Application for Sundry > Approval, should you require it. > > We are expecting to move off of this well sometime early next week. > > (See attached file: 1C-102L 1 Sundry Procedure change.pdt) > > Steve McKeever > > > > > > > > > "It is better to keep your mouth shut and appear stupid than to open it and > > remove aI/ doubt. ., > - Mark Twain > > '- Drilling Engineer Phillips Alaska, Inc. 907.265.6826 office 907.265. 1535 fax 907.275.0369 pager smckeev@ppco. com ---~---------------------------------------------------------------~---- > Procedure change.pdt > 1C-102L 1 Sundry Procedure change.pdf ( appliGation/pdf) > Encodmg:base64 (See attached file: tom_maunder.vct) Name: 1C-102L 1 Sundry Type: Acrobat '" Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2of3 10/11/0112:22 PM . ( ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Chuck Mallary Phone (907) 265-6434 Fax: (907) 265-1535 September 21, 2001 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry Approvals, West Sak Multilateral WelllC-102 . Permit to Drill # 201-139 (lC-I02) and # 201-172 (lC-I02l1) API # 50-029-23034 (lC-I02) and 50-029-23034-60 (lC-I02l1) Dear Commissioner Taylor: Further to a change in drilling procedure authorized by Tom Maunder on September 20, 2001, Phillips Alaska, Inc. hereby requests a Sundry Approval for a well in the West Sak Oil Pool, designated #1C-102. Please find attached for the review of the Commission Form 10-403, and two attachments: . a copy of the e-mail from Tom Maunder, authorizing the change in procedure. . the Proposed Drilling Program which was submitted with the Application for Permit to Drill, showing the changes proposed. If you have any questions or require any further information, please contact Steve McKeever at 265- 6826. èœ;¿ ~ Chuck Mallary ~ GKA Drilling Engineering Supervisor p.""'o.:"&",,,", ,\".. Þ)' ,!"'"\\ ,"""'~ . )1' '\:""'"'< () k!."" iJ'V\\ /l~.~';,)".;"-<>o- n-;"""i. -""'.~"""'Ii!.,- t' """"k I~ ~._" ,a .,""" t.-.ß Cf'. ,),~p 2 ~¿ 2001 Alaska Oil & G" , C ' as on.'), C(ìr '".'. /, ')C~I' 0 ~' nrr/l,)SIUiì l".( r C1ge OR\G\NAL (,' (' , ^ \< It:. 'J tt- ,~: ., ;)\.. '¥~ íí)\C:) \0, --D\ ~ c/- -J' o~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon- Suspend- Alter casing - Repairwell- Change approved program X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1420' FNL, 600' FWL, Sec. 12, T11N, R10E, UM At top of productive interval At effective depth At total depth 4344' FNL, 2390' FEL, Sec. 11, T11 N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length Size 117' 16" 6477' 7.625" 4509' 4" 4639' 411 Casing L1 Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth No tubing Packers & SSSV (type & measured depth) Baker 'SCR-1' pkr @ 6042' No SSSV 13. Attachments Description summary of proposal J 14. Estimated date for commencing operation September 20, 2001 16. If proposal was verbally approv~4vI\ V 20-Sep-01 Name of approver Tom Maunder 17. I hereby certify th e foregoing is tr Signed /J c~ (fa Operational shutdown - Plugging - Pull tubing 5. Type of Well: Development _X Exploratory - Stratigraphic - Servlce- (asp's 561606,5968813) (asp's 558642, 5965864) 1 0570 feet 3753 feet NI A feet feet Plugs (measured) Junk (measured) Cemented 432 sx AS 1 660 sx ASlite, 275 sx Class G screen screen Re-enter suspended well - Time extension - Stimulate - Variance Perforate 6. Datum elevation (DF or KB feet) RKB 41 feet 7. Unit or Property name Other Kuparuk River Unit 8. Well number 1 C-1 021 1 C-1 02L 1 9. Permit number 1 approval number 201-161/201-172 10. API number 50-029-23037 1 50-029-23037-60 11. Field 1 Pool Kuparuk River Field 1 West Sak Oil Pool Measured Depth 158' 6518' 6042'-10551 ' 5941 '-1 0580' True vertical Depth 158' 3800' 3802' 3687' ~.t::J.) Ii;,::: ~ý"""\T~ ;~,::~,'" ¡I; .~\ .,/7 ~l,:'~"."" I¡""'~"I' ,\1 ,> i~ "I . , 'I' I.""",, L:1T ,/ ~,~"""u ",~,~~ L""", l~ J R..~, l SEP 2 4 2001 1~laska Oil & Gas Cons. Commission ,'~nchorage Detailed operations program 15. Status of well classification as: Oil_X Date approved orrect to the best of my knowledge. Service FOR COMMISSION USE ONLY Conditions of approval: Notify Commission 0 r resentative may witness Approval no. Plug integrity - BOP Test :i. Location clearance -- - Mechanical Integrity Test- Subsequent fonn required 10-~~~(.D~,"""t:.,c~~~~~ ~~,\~~~ O~ ~~~~\-~ Original Signed By . A roved b order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 . Title: Drilling Engineering Supervisor BOP sketch Gas- Suspended - Que&lons? c:~:ve ~i~:7;T Pre ared b Sharon A/lsu Drake 263-4612 ORIGINAL SUBMIT IN TRIPLICATE ( ( v/ Steve, Your program looks acceptable and you have approval to proceed. correct a sundry will be necessary. move back. When operations resume, please send us an email giving notice. Tom Maunder, PE ~ Sr. Petroleum Engineer You are Thanks for providing an estimate of when the rig would Steve McKeever wrote: > Hi Tom: > > re: West Sak Multilateral Well 1C-102 / 1C-102L1, Permits # 201-161, > 201-172 > > Due to a delivery problem with a down hole sensor we would like > authorization for a completion procedure other than the one permitted for > the above well. > We had planned to run the ESP completion at the usual time, at the end of > the drilling phase, before the rig moves off. We are hoping that the AOGCC > will authorize us to suspend our operations on this well, move off, then > move back on in late November to run the ESP. > > The attached file details the proposed changes in procedure, with a > schematic showing the well as it would be "suspended". > > > > > > > We are expecting to move off of this well sometime early next week. > > (See attached file: 1C-102L1 Sundry Procedure change.pdf) > > Steve McKeever > > If this alternative procedure is acceptable to the Commission, can you please provide authorization via e-mail? Should you provide such authorization we will follow up with a formal Application for Sundry Approval, should you require it. > > > > Drilling Engineer Phillips Alaska, Inc. 907.265.6826 office 907.265.1535 fax 907.275.0369 pager smckeev@ppco.com > > > "It is better to keep your mouth shut and appear stupid than to open it and > > remove all doubt." > - Mark Twain > > ------------------------------------------------------------------------ > Name: 1C-102L1 Sundry Procedure change.pdf > 1C-102L1 Sundry Procedure change.pdf Type: Acrobat (application/pdf) > Encoding: base64 1m tom_maunder. vcf ~. ( Permitted Procedure for lC-l02 1. Excavate cellar, install cellar box, set and cement 16" conductor to +1- 161' RKB. Weld landing ring on conductor. Install wellhead. 2. Move in / rig up Nabors 245e. Install Diverter I BOPE and function test same. 3. Spud and directionally drill 9-7/8" hole to casing point at +/- 6410' MD I 3794' TVD as per directional plan. Run MWD, LWD and PWD tools as required for directional monitoring and data gathering. 4. Run and cement 7-5/8", 29.7#, L-80, BTC Mod casing to sulface. Displace cement with mud and perform stage job or top job if required. 5. Note: Port collar to be run @ +/- 1000' MD. 6. Nipple down diverter, NU and test BOP's. Notify AOGCC 24 hrs before test. 7. PU 6-3/4" PDC Bit and directional BHA. RIH, clean out cement to top of float equipment, pressure test casing to 3000 psi for 30 minutes and record results. 8. Drill out cement and between 20' and 50' of new hole. Perform FIT not to exceed 12.0 ppg EMW and record results (ECDls estimated not to exceed 11.5 ppg) 9. Directionally drill 6-3/4" hole to TD at +1- 10585' MD I 3,744' TVD as per directional plan. 10. POOH and lay down MWD, LWD and PWD tools. 11. RIH with 6-3/4" hole opener and ream entire open hole. 12. Circulate and condition hole to run liner. Displace mud with clean filtered kill weight brine and spot viscosified brine across open hole. 13. RIH with casing seaper assembly to 7-5/8" shoe. Perform casing and drill pipe clean-up including Caustic SL Wash and Acid Pickle. Displace casing with kill weight viscosified brine. 14. PU and run 4" Liner with excluder screen (run liner with 2-7/8" inner wash string). 15. Land liner, set liner top packer @ +/- 5944' MD I 3681' TVD and displace viscosified brine with clean filtered brine. Spot 8% Formic Acid through the screens and allow acid to soak 6 hours. Displace acid with clean filtered brine. 16. POOH to liner top and displace well, above liner top packer, with clean filtered brine. Continue POOH and lay down 2- 7/8" inner wash string assembly. Permitted Procedure for lC-l02Ll (with proposed changes in blue) 1. Run and set Baker WindowMasterTM whipstock, 30 degrees to left of high side. 2. Mill starting window in K-13 shale above the D-sand. POOH. 3. Polish and complete window with finishing mill and 2 watermelon mills. 4. Pick up 6" drilling assembly, RIH, and drill 20-50 feet of new hole. 5. Perform Formation Integrity Test to 12.0 ppg EMW. 6. Drill through shale to the D Sand heel. Change over to BaraDril'N drilling mud. 7. Continue to directionally drill to TD of D sand lateral at 10,571' MD I 3,691' TVD. POOH. 8. POOH and lay down MWD, LWD and PWD tools. 9. RIH with 6" hole opener and ream entire open hole. 10. Circulate and condition hole to run liner. Displace mud with clean filtered kill weight brine and spot viscosified brine across open hole. POOH and lay down hole opener assembly. 11. RIH with whipstock retrieval tool and easing scaper assembly to whipstock. Perform casing and drill pipe clean-up including Caustic SL Wash and Acid Pickle. Displace casing with kill weight brine. Retrieve whipstock and POOH. 12. PU 4" Liner with flanged hook hanger, ECP's and excluder screen and 2-7/8" inner wash string. 13. RIH, until Hook Hanger is just above window. Run gyro tools to orient hook hanger to window and land hanger. (" ( 14. Release hanger running tool and place cup tool across each ECP and inflate with cement. Reverse out excess cement and POOH. 15. Pick up lateral diverter tool and RIH and set in hook hanger. 16. RIH with cup tool assembly and spot 8% Formic Acid through the screens and allow acid to soak 6 hours. Displace acid with clean filtered brine. POOH, laying down Drill pipe as needed. 17. ~4akc up latcral divcrtcr retricving tool ~nd RIH on '1 1/2" completion tubing. Oncc ~t divcrtcr, run dummy ESP through tubing string on wirclinc. Retrieve diverter, and POOH, standing b~ck tubing. 17. Make up lateral diverter retrieving tool on drill pipe. Retrieve diverter and POOH. 18. IUH with 4-1/2'~ 12.6#, L-8o NSCT tubing to a depth of +/- 5880' MD. 19. Land Tubing, Lay down landing joint and set BPv. 20. Nipple down BOP£, Nipple up and test tree. 21. Rig up and freeze protect well by displaceing tubing and annulus to diesel to a depth of 2000' TVO.. 22. Shut in well Set BPv. ROMO Nabors 245e. 23. Rig up wireline and run Centrilift dummy ESP (3.833 00) through tubing. Tag up at the minimum IO in the crossover at the bottom of the tubing string. 24. Move in and rig up Nabors 245e. 25. Pull BPv. 26. Rig up to circulate out freeze protection fluid with 8.9 ppg 3% KCI brine. 27. Install BPv. Nipple down tree and tree adapter flange. Nipple up 13-5/8" 5K BOP and test. 28. Screw in landing joint, back out lock down screws and pull hanger to floor. Ensure well is dead. 29. POOH standing back tubing in stands 30. Make up ESP and components as required and RIH. Run heat trace on tubing through permafrost zone. 31. Land tubing with ESP +/- 60 feet above window. Install BPV, nipple down stack, nipple up and test tree. Pull BPV. Freeze protect well with diesel by pumping into annulus, taking returns from tubing and allowing to equalize. 32. Set BPV and move off. ¡. ( Well # 1 C-1 02, AFE #AK0202 West Sak Multilateral Well ( Planned Completion Schematic Status at Rig Move Details PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Tree Assembly, Vetco Gray Gen II, API 13-5/8 - 5000 psi Flange Down x 4- 1/16" 5000 Studded Top, with Penetrators Tubing Hanger, 4-1/2", Vetco Gray w/ 4.909" MCA Top Connection, 4-1/2" L-80 NSCT Pup Joint Down Penetrator Holes blanked off Back Pressure Valve installed Nabors Rig 245 RKB @ 0' Eastings: 561,606.18 Northings: 5,968,813.50 Elevation: 101.8' AMSL Tubing Head Assembly, Vetco Gray (1) Joint Tubing 16" Conductor: +/- 158' MD (x) Joints Tubing Tubing String: 4-1/2", 12.6#, L-80, NSCT Port Collar: +/- 1000' MD / 988' TVD (1) Cross over, 4-1/2, 12.6#, NSCT Box x 2" Line Pipe pin (481-4950) Set at +/- 5880' MD / +/- 3657' TVD Top of Window: +/- 5,941' MD /3,680' TVD Top of Lower Lateral Liner: +/- 6,045' MD / 3,716' TVD ------------ ------------ ------------ ------------ ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------ ------------ ------------ D-Sand Lateral 6" Open Hole TD: +/- 10,600' MD /3,691' TVD 7-5/8" Shoe: +/- 6,518' MD / 3,800' TVD ------------ ------------ ----------- ----------- ------------ ----------- ------------ ------------ ------------ ------------ ----------- ----------- ----------- ----------- B-Sand Lateral 6-3/4" Open Hole TD: 10,570' MD / 3,753' TVD 1C-102 Planned Completion Schematic Status at Rig Move Details prepared by Steve McKeever September 18, 2001 Ke: 1l,;-1 UZ ~unary - l,;nange In ~roœaure . ( (' Subject: Re: 1C-102 Sundry - Change in Procedure Date: Thu, 20 Sep 2001 05:04:29 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Steve McKeever <smckeev@ppco.com> Steve, Your program looks acceptable and you have approval to proceed. You are correct a sundry will be necessary. Thanks for providing an estimate of when the rig would move back. When operations resume, please send us an email giving notice. Tom Maunder, PE Sr. Petroleum Engineer Steve McKeever wrote: > Hi Tom: > > re: West Sak Multilateral We1l1C-102 / 1C-102L 1, Permits # 201-161, > 201-172 > > Due to a delivery problem with a down hole sensor we would like > authorization for a completion procedure other than the one permitted for > the above well. > We had planned to run the ESP completion at the usual time, at the end of > the drilling phase, before the rig moves off. We are hoping that the AOGCC > will authorize us to suspend our operations on this well, move o~ then > move back on in late November to run the ESP. > > The attached file details the proposed changes in procedure, with a > schematic showing the well as it would be "suspended". > > If this alternative procedure is acceptable to the Commission, can you > please provide authorization via e~mail? Should you provide such > authorization we will follow up with a formal Application for Sundry > Approval, should you require it. > > We are expecting to move off of this well sometime early next week. > > (See attached file: 1C-102L 1 Sundry Procedure change.pdt) > > Steve McKeever > > > > > > > > Drilling Engineer Phillips Alaska, Inc. 907.265.6826 office 907.265.1535 fax 907.275.0369 pager smckeev@ppco.com > "It is better to keep your mouth shut and appear stupid than to open it and > > remove all doubt. " > - Mark Twain > :> ------~-----------------------------------------------------~----------- 1of2 9/20/01 5:44 AM Ke: 1 (;-1 02 ~un(1ry - c.;nange In t-'roceaure . > > > ( Name: 1 C-1 02L 1 Sundry Procedure change.pdf 1C-102L 1 Sundry Procedure change.pdf Type: Acrobat (application/pdf) Encoding: base64 ( ¡ I i Tom Maunder <tom maunder@admin.state.ak.us> I Sf. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of2 9/20/01 5:44 AM 1 l;- 1 02 ~UncJry - L;nange In t-'roceaure , , ( t Subject: 1 C-1 02 Sundry - Change in Procedure Date: Wed, 19 Sep 2001 16:34:41 -0800 From: IISteve McKeever' <smckeev@ppco.com> To: tom_maunder@admin.state.ak.us CC: IISharon Allsup-Drake" <sallsup@ppco.com> Hi Tom: re: West Sak Multilateral Well 1 C-1 02 /1 C-1 02L 1, Permits # 201-161, 201-172 Due to a delivery problem with a down hole sensor we would like authorization for a completion procedure other than the one permitted for the above well. We had planned to run the ESP completion at the usual time, at the end of the drilling phase, before the rig moves off. We are hoping that the AOGCC will authorize us to suspend our operations on this well, move off, then move back on in Jate November to run the ESP. The attached file details the proposed changes in procedure, with a schematic showing the well as it would be "suspended". If this alternative procedure is acceptable to the Commission, can you please provide authorization via e-mail? Should you provide such authorization we will follow up with a formal Application for Sundry Approval, should you require it. We are expecting to move off of this well sometime early next week. (See attached file: 1 C-1 02L 1 Sundry Procedure change.pdt) Steve McKeever Drilling Engineer Phillips Alaska, Inc. 907.265.6826 office 907.265.1535 fax 907.275.0369 pager smckeev@ppco.com lilt is better to keep your mouth shut and appear stupid than to open it and remove all doubtll - Mark Twain I... . Name: 1 C-1 02L 1 Sundry Procedure change.pdf I ~1C-102L 1 Sundry Procedure chanQe.pdf Type: Acrobat (application/pdt) . Encoding: base64 10f2 9/20/01 4:59 AM t (' Permitted Procedure for lC-l02 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 161' RKB. Weld landing ring on conductor. Install wellhead. 2. Move in / rig up Nabors 245e. Install Diverter I BOPE and function test same. 3. Spud and direction ally drill 9-7/8" hole to casing point at +/- 6410' MD I 3794' TVD as per directional plan. Run MWD, LWD and PWD tools as required for directional monitoring and data gathering. 4. Run and cement 7-5/8",29.7#, L-80, BTC Mod casing to surface. Displace cement with mud and perform stage job or top job if required. 5. Note: Port collar to be run @ +/- 1000' MD. 6. Nipple down diverter, NU and test BOP's. Notify AOGCC 24 hrs before test. 7. PU 6-3/4" PDC Bit and directional BHA. RIH, clean out cement to top of float equipment, pressure test casing to 3000 psi for 30 minutes and record results. . 8. Drill out cement and between 20' and 50' of new hole. Perform FIT not to exceed 12.0 ppg EMW and record results (ECD's estimated not to exceed 11.5 ppg) 9. Directionally drill 6-3/4" hole to TD at +/- 10585' MD / 3,744' TVD as per directional plan. 10. POOH and lay down MWD, LWD and PWD tools. 11. RIH with 6-3/4" hole opener and ream entire open hole. 12. Circulate and condition hole to run liner. Displace mud with clean filtered kill weight brine and spot viscosified brine across open hole. 13. RIH with casing scaper assembly to 7-5/8" shoe. Perfonn caSing and drill pipe clean..up including Caustic Sl Wash and Acid Pickle. Displace casing with kill weight viscosified brine. 14. PU and run 4" liner with excluder screen (run liner with 2-7/8" inner wash string). 15. Land liner, set liner top packer @ +/- 5944' MD /3681' TVD and displace viscosified brine with clean filtered brine. Spot 8% Formic Acid through the screens and allow acid to soak 6 hours. Displace acid with clean filtered brine. 16. POOH to liner top and displace well, above liner top packer, with clean filtered brin~. Continue POOH and lay down 2- 7/8" inner wash string assembly. Permitted Procedure for IC-IO2LI (with proposed changes in blue) 1. Run and set Baker WindowMasterTM whipstock, 30 degrees to left of high side. 2. Mill starting window in K-13 shale above the D-sand. POOH. 3. Polish and complete window with finishing mill and 2 watennelon mills. 4. Pick up 6" drilling assembly, RIH, and drill 20-50 feet of new hole. 5. Perform Formation Integrity Test to 12.0 ppg EMW. 6. Drill through shale to the D Sand heel. Change over to BaraDril'N drilling mud. 7. Continue to directionally drill to TD of D sand lateral at 10,571' MD / 3,691' TVD. POOH. 8. POOH and lay down MWD, lWD and PWD tools. 9. RIH with 6" hole opener and ream entire open hole. 10. Circulate and condition hole to run liner. Displace mud with clean filtered kill weight brine and spot viscosified brine across open hole. POOH and lay down hole opener assembly. 11. RIH with whipstock retrieval tool and casing scaper assembly to whipstock. Perform casing and drill pipe clean-up including Caustic SL Wash and Acid Pickle. Displace casing with kill weight brine. Retrieve whipstock and POOH. 12. PU 4" Liner with flanged hook hanger, ECP's and excluder screen and 2-7/8" inner wash string. 13. RIH, until Hook Hanger is just above window. Run gyro tools to orient hook hanger to window and land hanger. ( { 14. Release hanger running tool and place cup tool across each ECP and inflate with cement. Reverse out excess cement and POOH. 15. Pick up lateral diverter tool and RIH and set in hook hanger. 16. RIH with cup tool assembly and spot 8% Formic Acid through the screens and allow acid to soak 6 hours. Displace acid with clean filtered brine. POOH, laying down Drill pipe as needed. 17. Make up latcral divcrtcr rctric',ing tool and RIH on 1 1/2" complction tubing. Once at divcrtcr, run dummy ESP through tubing string on wirclinc. Retrieve di'¡ertcr, and roOH, stmding back tubing. 17. Make up lateral diverter retrieving tool on drill pipe. Retrieve diverter and POOH. 18. RIH with 4-1/2n, 12.6#, L-80 NSCT tubing to a depth of + /- 5880' MO. 19. Land Tubing, Lay down landing joint and set BPv. 20. Nipple down BOPE, Nipple up and test tree. 21. Rig up and freeze protect well by displaceing tubing and annulus to diesel to a depth of 2000' WOn 22. Shut in well. Set BPv. ROMO Nabors 245e. 23. Rig up wireline and run Centrilift dummy ESP (3.833 00) through tubing. Tag up at the minimum IO in the crossover at the bottom of the tubing string. 24. Move in and rig up Nabors 245e. 25. Pull BPv. 26. Rig up to circulate out freeze protection fluid with 8.9 ppg 3% KCI brine. 27. Install BPv. Nipple down tree and tree adapter flange. Nipple up 13-5/8" 5K BOP and test. 28. Screw in landing joint, back out lock down screws and pull hanger to floor. Ensure well is dead. 29. POOH standing back tubing in stands 30. Make u~ ESP and components as required and RIH. Run heat trace on tubing through permafrost zone. 31. Land tubing with ESP +/.60 feet above window. Install BPV, nipple down stack, nipple up and test tree. Pull BPV. Freeze protect well with diesel by pumping into annulus, taking returns from tubing and allowing to equalize. 32. Set BPV and move off. (' ( Well # 1C-102, AFE #AKO202 West Sat Multilateral Well Planned Completion Schematic Status at Rig lIove Details 8 f,t'I!:~J~I~~~'; T.-- .'UI..mbIy, vetco GIay Gen II. API 13-518 - 5000 psi Flange Down x 4- 1/1&- 5000 Studded Top, wiIh Pel ... db'!; Tubing Hanger, 4-1 fz", v etm Gray wi 4.9O!r MCA Top eor..dio.., 4-1fZ" L-80 NSCT Pup Joint Down Per ... db Holes blallIœd off Back PnIssa88 VahNt installed Nabors Rig 245 RKB @ 0" E-otir.g:.: 561,606.18 NorIhÎIIQ&: 5,968,813-50 EIevaIion: 1 011r AMSl Tubing Høad humbly, Vek;o Gray (1) Joint Tubing 16- Conductor. +I- 158" _0 (x) Joints Tœing Tubing SIring: 4-1/r,12.8I, L-80, NSCT Port Collar: +1- 100Ø' lID I 988" TVD (1) Crass CMII', "'1J2, 12.-' NSCT Box x r Une Pipe pin (481..t950) Set at +1- 588Cr lID I +1- 36ST 1VD Top of Lower LaI8raIUner: +1- 6,045" .0 I 3,716" TVD ------------ - - -- ------------ ------------ ----------- ----------- ----------- ----------- ----------- .=-.=-.=-.=-.=-.=-.::::::-.=-.=-.=-.=- Top of Window: +1- 5,941. .0 I 3,680" TVD 0-5and Lateral 6- Open Hole TO: +1- 10'-' _0 I 3,181' 1W 7-518- Shoe: +1- 6,518" lID I 3,8Ø' TVD ------------ ------------ ------------ ------------ ------------ ------------ ------------ ----------- ----------- ----------- ----------- ----------- ----------- ----------- ß.Sand I..aIøraI 6-314- 0p8n Hole TO: 10,57Ø' MD I 3,753" 1VD 1C-102 Planned Completion SchemaIic Status aI. Rig AIowe DeIaíIs prepared by Stew! JkKeeIIer September 18. 2001 I ( ( ~lJ~lJŒ (ID~ ~~~~[K\~ ALAS IiA 0 IL AlVD GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas Brockway Interin Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit I C-I 02 Phillips Alaska, Inc. Permit No: 201-161 Sur Loc: 1420' FNL, 600, FWL, SEC. 12, TlIN, RI0N, UM Btmhole Loc. 912' FSL, 2747' FEL, SEC. II, TIIN, RIOE, UM Dear Mr. Brockway: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparok River Unit 1 C-I02. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on 1 C pad 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 longer than one year. 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 by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~ D~l T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this/ ¿/71Iay of August, 2001 . jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. !t '\ k~ ~ ( mq ~1 ~) STATE OF ALASKA (J',:A l;t L ALASKA Oil AND GAS CONSERVATION COMMISSION îl \ PERMIT TO DRILL 20 MC 25.005 1 a. Type of work: Drill [t] Redlill 0 1b. Type of well. Exploratory 0 Stratigraphic Test 0 Development Oil [t] Re-entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone [t] Multiple Zone 0 2. Name of Operator 5. Datum elevation (OF or KB) 10..:zld and Pool 'f/ ~ / Phillips Alaska, Inc. RKB 41 feet V-' L, .s:A:' a &Þd -. 3. Address 6. Property Designation Kuparuk River Field ~c:: P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25649 ALK 467 Kw :fartll( n¡'tðl Oit F' ~61 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1420' FNL, 600' FWL, Sec. 12, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval B. Well number Number 182' FSL, 2365' FEL, Sec. 2, T11 N, R10E, UM 1C-102 #59-52-180 At total depth 9. Approximate spud date Amount 912' FSL, 2747' FEL, Sec. 11, T11N, R10E, UM August 10, 2001 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres In property 15. Proposed depth (MD and TVD) 912 @ TD feet feet 2560 10585' MD /3744' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 MC 25.035 (e)(2)) Kickoff depth: 250' MD Maximum hole angle 91 0 Maximum surface 1328 psig At total depth (TVD) 1745 psig 1 B. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 120' 41' 41' 161' 161' 225cfAS 1 9.875" 7.625" 29.7# L-80 BTCM 6369' 41' 41' 6410' 3794' 650 sx AS Lite & 240 sx Class G 6.75" 4" 9.5# L-80 HSLHT 4641' ~ X 10585' 3744' screen ::>'í.\.\,-\ ~CaCX\ II ~AN.A 19. To be completed for Redrlll, Re-entry, and Deepen Operations. 1-diJ.' "l91 \. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Intermediate RECEIVED Production Liner JUL 27 2001 Perforation depth: measured Alaska Oil & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee [t] I?P~rty Plat 0 BOP Sketch [t] Diverter Sketch 0 Drilling program [t] Drilling fluid program /7 [t] Time vs depth ot ;DRefraCtion analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I hereby ~fO~Þ4 the best of my ImOWledge. . . .. . Questions? Call Mark Chambers 265-131~ 7/2¿ /0 / Signed ~~ .,"" ~ Title. Inteflm Of/Illng Engmeerlng SupeN/sor Date Tom Brockway - hv" AII.<:/Jn-nr::Jl<~ Commission Use Onl\ Permit Number API number Approval ~ IJ ,/j See cover letter '20/- /6"/ 50- 02. 9-.2. 30'57 r'D (\ I for other requirements Conditions of approval Samples required 0 Yes J8J No Mud log requl~ed 0 Yes J8I No Hydrogen sulfide measures 0 Yes 181 No Directional survey required ::§ Yes 0 No Required working pressure for BOPE D2M; ~ 3M; 0 5M; 0 10M;D 0 Other: by order of '«110/0 J Approved by ORIGINAL SIGNED By Commissioner the commission Date 0 Ta lor Seamount ' Form 10-401 Rev. 12/1/85. y OR I GI NAL Submit in triplicate (' PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY ( Post Office Box 100360 Anchorage, Alaska 99510-0360 Thomas A. Brockway Phone (907) 263-4135 Fax: (907) 265-1535 Email: tbrockw@ppco.com July 24, 2001 Cammy Oechsli Taylor Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, West Sak Multilateral Well lC-102. Dear Commissioner Taylor: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore multilateral development well to the West Sak interval from lC Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak Sands in the vicinity of lC Pad, with two horizontal penetrations. This application is for the Permit to Drill the main well bore from surface to total depth of the horizontal penetration of the lower West Sak "B" Sand. Another application will be forthcoming for the Permit to Drill the upper lateral, designated lC-102 L1, a horizontal penetration of the West Sak "D" Sand. The well is designated as a horizontal producer using a 7-5/8"N::. tapered casing string. A 4-1/2" x 4" Production Liner will be run and the well will be completed with 4-1/2" tubing and ESP. The well will be drilled and completed using Nabors Rig 245e. The expected spud date is August 10, 2001. Please find attached for the review of the Commission Form 10-401 and the information required by 20 ACC 25.005. If you have any questions or require any further information, please contact me at 263-4135 or Mark Chambers at 265-1319. ( ~' Jation for Permit to Drill, Well 1 C-1 02 Revision No.1 Saved: 26-Jul-01 Permit It - West Sak Well #1 C-1 02 Application for Permit to Drill Document MoximizE W~II Vglu~ Table of Contents 1. Well Name................................... ................ ....... ........................... ........... .............. ... 2 Requirements of 20 AAC 25.005 (f)........................................................................................................2 2. Location Sum mary .............................. .................................................. .... ..... .......... 2 Requirements of 20 AAC 25. 005( c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b)........................................................................................................3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ...................................................................................................3 4. Dri II i ng Hazards Information .............. ...................................................... ............... 3 Requirements of 20 AAC 25.005 (c)( 4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ..................................................................................................3 6. Casing and Cementing Program .............................................................................4 Requirements of 20 AAC 25. 005( c)(6) ................ m................................................ ................ ................ 4 7. Diverter System Information .............. ..... .............................................. .................. 4 Requirements of 20 AAC 25.005(c)(7) ...................................................................................................4 8. Dri II i ng FI u id Program ................................................................... ........ .................. 4 Requirements of 20 AAC 25. 005( c)(B) .......................................................................................... .........4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ................................................................. ........................... ......5 10. Seism ic Analysis..................................... ... .............................................................. 5 Requirements of 20 AAC 25.005 (c)(10) ......................................................,.........................................5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................5 12. Evidence of Bond i ng................................................................................ ................ 5 Requirements of 20 AAC 25.005 (c)(12) ......".................. ......................................................................5 1 C-1 02 PERMIT IT ver. 1 Page 1 of 7 Printed: 26-Jul-O1 ( 1 ~ation for Permit to Drill, Well 1 C-1 02 Revision No.1 Saved: 26-Jul-01 13. Proposed Dri Iii ng Program......... ... ... ..... ....... ...... .......... .............. ... ....... .... ....... ........5 Requirements of 20 AAC 25.005 (c)(13) """""""""""""""""""""""""""""""..................................5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................6 15. Attachments.......... ........ ...... ....... .............. ..... ...... ...... .... ................. ........ ... ... ............ 7 Attachment 1 Directional Plan (10 pages) """""""""""""""""""""""""""""""".............................7 Attachment 2 Diagram and Description of 11" 5,000 psi Blowout Prevention Equipment (1 page)Error! Bookmark not defined. Attachment 3 Drilling Hazards Summary (1 page) ................................................................................ 7 Attachment 4 Cement Loads and CemCADE Summary (1 page)......................................................... 7 Attachment 5 Well Schematic (3 pages)................................................................................................7 1. Well Name Requirements of 20 AAC 25.005 (f) Eaäl well mu:..7: be identified by a unique name designated by the operator and a unique API number a.s:.c,igned by the commis.sion lmder 20 AAC 25:040(b). For a well with multiple well brandJe!J~ each branch mustsimilady be identitled by a unique name and APi number by adding a sìJffìx to the name designated fòr the well by the operator and to the number a!J-signed to the well by the commis-sion The well for which this Application is submitted will be designated as 1C-102. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the fOllowing item~ except for an item already on file wIth the commission and Identified in the application: (2) a plat Identifying the property and t/7e property's owners and s/1Owing (A)the coordinates of the proposed location of the well at the surface" at the top of each objective formationl and at total depth referenced to govemmental section line5: (B) the coordinates olthe proposed location orthe well at the surface" referenced to the state plane Gvordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmo!Jphelic Administration; (C) tile proposed depth of the well at the top of' each objective formation and at total depth; Location at Surface I 1420' FNL, 600' FWL, Section 12, T11N, R10E, UM NGS Coordinates RKB Elevation 102.0' AMSL Northings: 5,968,813.187 Eastings: 561,605.104 Pad Elevation 60.8' AMSL Location at Top of Productive Interval West Sak "8" Sand NGS Coordinates Northings: 5,970,173 182' FSL, 2365' FEL, Section 2, T11N, R10E, UM Eastings: 558,561 6252 3786 3684 Location at Total De th NGS Coordinates Northings: 5,965,842 Eastings: 558,585 UM 10585 3744 3642 1 C-1 02 PERMIT IT ver. 1 Page 2 of 7 Printed: 26-Jul-O1 ( l .ation for Permit to Drill, We1l1C-1O2 Revision No.1 Saved: 26-Jul-O1 and (0) ot/ler information required by 20 MC 25.0S0(b); Requirements of 20 AAC 25. 050 (b) If a well is to be intentionally deviated, the application for a Perrmt to Dr/II (Form 10-401) must (1) include a plaf; drawn to a sUItable scale, showing the path of the proposed wellbore, including all adjacent well bores within 200 feet of any pot1ion of the proposed welt. Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public record~ and show that eacl7 named operator has been furnished a copy of the application by certified mai~' or (B) state ttJat the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (3) a diagram and description olthe blowout prevention equipment (BOPE) as reqwì-ed by 20 MC 2S.03.'i, 20 MC 25.03~ or 20 MC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete well lC-l02. Please see "Diagram and Description of the Blowout Prevention Equipment for Nabors Rig 245e", placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application fÖr a Permit to Drill must be accompanied by each of the following item~~ except for an item already Of} l7Ie with the commission and identified in the application: (4) information on dril/íng hazard!>; including (A) the maximum downhole pr-essure that may be encountered, critetia used to determine if; and maximum potential surfàce pre..'isure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the lC pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight). These are pressures obtained from actual well test data from the nearby WS1-01 well. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the West Sak formation is 1328 psi, calculated thusly: MPSP =(3794 ft)(0.46 - 0.11 psi/ft) = 1328 psi (B) data on potential gas zones..,. The well bore is not expected to penetrate any gas zones. and (C) data concermì7g potential causes of hole problems :.,ì.lch as abnormally geo-pressured strata, lost circulation zone!:>; and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a PermIt to 01711 must be accompanied by each ot' the following Items, except lor an item already 0/7 file with the commi'ision and identified in the application: (5) a description of the procedure f'Or conducting formation integrity tests, as required under 20 AA C 25: 030(f); 1 C-1 02 PERMIT IT ver. 1 Page 3 of 7 Printed: 26-Jul-O1 ( J ,ation for Permit to Drill, Well 1 C-1 02 Revision No.1 Saved: 26-Jul-01 lC-l02 will be completed with 7-5/8" surface casing landed in the West Sak B-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that Phillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: . (6) a complete proposed casing and cementing program as required by 20 AAC 2s.03~ and a description of any slotted liner" pre- perforated liner" or screen to be installed/ Casing and Cementing Program Hole Top atm Csg/Tbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) (lblft) Grade Connection (tV (ft) (ft) Cement Proaram 16 24 62.5 H-40 Welded 120 41/41 161 / 161 Cemented to surface with 225 cf ArcticSet 1 7-5/8 9-7/8 29.7 L-80 BTCM 6369 41/41 6410 / 3794 Cemented to Surface with 650 sx ASLite Lead, 240 sx Class G Tail 4 6-3/4" 9.5 L-80 HSLHT 4641 5944/ 3681 10585 / 3744 Screens - no screen Lower cement Lateral 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application lor a Permit to Olill mlJ!it be accompanied by each of the following item~~ except for an item already on file with the commis~ion and identified in the application: (7) a diagram and dt'l$cription of'tl1e diverter system as required by 20 AAC 25.035" unless t/7is requirement is waived by the commission under 20 MC 2.'i.035(I1)(2); Please see "Diagram And Description of the Diverter System For Nabors Rig 245e", placed on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Dnll must be accompanied by each of the I'dlowing item~ except lor an item already on file with tfle commis_"ion and identitìed in tlie application: (8) a dlilling fluid program! including a diagram and descTiptiol7 of't!7e drilling flUId system! as required by 20 MC 25.033/' Drilling will be done with a bentonite slurry having the following properties over the listed intervals: Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value Density (ppg) 8.5 < 9.4 < 9.4* < 9.4* Funnel Viscosity 150-200 150-200 150 75 (seconds) Yield Point 30-60 30-60 20-40 18-30 (cP) Plastic Viscostiy 8-15 11- 22 15-30 15-30 Obl100 st) 10 second Gel 10-30 10-25 10-25 10-25 Strength (/b1100 sf) 1 C-1 02 PERMIT IT ver. 1 Page 4 of 7 Printed: 26-Jul-O1 ( ) ,ation for Permit to Drill, Well 1 C-1 02 Revision No.1 Saved: 26-Jul-01 10 minute Gel 25-55 25-55 20-40 20-40 Strength (lb1100 sf) pH 8-9 8-9 8-9 8-9 API Filtrate(cc) 8-15 6 5-6 5-6 Solids (%) 5-8 5-8 5-8 6-11 *9.8 ppg if hydrates are encountered Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. This drilling fluid system of Nabors Rig 245e consists of: (3) Continental Emsco FB-1600 Mud Pumps, Steel Mud pits with 1100 barrel capacity, Pill Pit, Trip Tank, (3) Derrick Flo-line Shale Shakers (rated at 600 gpm), Brandt Model SRS-2 Desander, Derrick Model 58S Mud Cleaner, (2) Alpha-Laval Model 418-VT- 5 Centrifuges, Degassers, PVT System with visual and audio alarms, Trip Tank, Flow Sensor, and Fluid Agitators. Please see "Diagram of Mud System, Nabors Rig 245e", placed on file with the Commission. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items¡. except for an item already 017 file with the commission and Identified in the application: (9) for an exploratory or stratigraphic test wel¿ a tabulation setting out the depth", of predicted abnormally geo-pressured 5'trata as required by 2{) MC25:033(f)/ Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Pel7l71t to Onll must be accompanied by each of the following Item5; exæpt for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigrtlphic test wel¿ a seismic retraction or reflection analysi..r:; as required by 20 MC 25. 061 (a),: Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items" except for an item already on file with the commi5:"iof] and identified in the application: , (1.1) for a well efrílled ti-om an olf<:...:f1ore platfvrrn mobile bottom-founded !:J1.ruäure)' jack-up lig/ or floatinq drilling vesse¿ an analysis of"seabed mncf¡tiol7s as required by 20 MC 25,O6J(b)/ Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill mast be accompanied by ead, of" the following item~ except for an item already on me wIth the commi!;,-sion and Identified in the application: (12) evIdence showing that the requirements of 20 MC 25.02.5 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit: to Drill must be accompanied by each of" the following items, except for an item already 0/7 file with the cvmmission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 161' RKB. Weld landing ring on conductor. Install wellhead. 1 C-1 02 PERMIT IT ver. 1 Page 5 of 7 Printed: 26-Jul-O1 ~ ) , ,ation for Permit to Drill, Well 1 C-1 02 Revision No.1 Saved: 26-Jul-01 2. Move in / rig up Nabors 245e. Install Diverter / BOPE and function test same. 3. Spud and directionally drill 9-7/8" hole to casing point at +/- 6410' MD / 3794' TVD as per directional plan. Run MWD, LWD and PWD tools as required for directional monitoring and data gathering. 4. Run and cement 7-5/8", 29.7#, L-80, BTC Mod casing to surface. Displace cement with mud and perform stage job or top job if required. Note: Port collar to be run @ +/- 1000' MD. 5. Nipple down diverter, NU and test BOP's. Notify AOGCC 24 hrs before test. 6. PU 6-3/4" PDC Bit and directional BHA. RIH, clean out cement to top of float equipment, pressure test casing to 3000 psi for 30 minutes and record results. 7. Drill out cement and between 20' and 50' of new hole. Perform FIT not to exceed 12.0 ppg EMW and record results (ECD's estimated not to exceed 11.5 ppg) 8. Directionally drill 6-3/4" hole to TD at +/- 10585' MD / 3,744' TVD as per directional plan. 9. POOH and lay down MWD, LWD and PWD tools. 10. RIH with 6-3/4" hole opener and ream entire open hole. 11. Circulate and condition hole to run liner. Displace mud with clean filtered kill weight brine and spot viscosified brine across open hole. 12. RIH with casing scaper assembly to 7-5/8" shoe. Perform casing and drill pipe clean-up including Caustic SL Wash and Acid Pickle. Displace casing with kill weight viscosified brine. 13. PU and run 4" Liner with excluder screen (run liner with 2-7/8" inner wash string). 14. Land liner, set liner top packer @ +/- 5944' MD / 3681' TVD and displace viscosified brine with clean filtered brine. Spot 8% Formic Acid through the screens and allow acid to soak 6 hours. Displace acid with clean filtered brine. 15. POOH to liner top and displace well, above liner top packer, with clean filtered brine. 16. Continue POOH and lay down 2-7/8" inner wash string assembly. Note: Remaining operations will be covered under the 1C-102 L1 Application for Permit to Drill. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a PermIt to Drill mustc be accompanied IJy each of the followti7g items¡ except for an Hem already on file with the COmmiS'fJ70n and Identified in the application: (14) a general description of how the operator plans to dispose of dnllin{l mud and cuttin{ls' and a statement of whether the operator 1¡7tends' to request authorization under 20 AAC 25,080 tor an annular disposal operation in the well,; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1C Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1C Pad or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 1C-102 PERMIT ITver.1 Page 6 of 7 Printed: 26-Jul-O1 ( J~ Jation for Permit to Drill, Well 1 C-1 02 Revision No.1 Saved: 26-Jul-O1 Phillips Alaska does not intend to request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 Well Schematic 1 C-1 02 PERMIT IT veT. 1 Page 7 of 7 Printed: 26-Jul-O1 200 I 0 200 400 600 800 1000 1200 ..---- -I- ( ) 1400 ( ) ...... '-"" ..c 1600 -I- Q.. ( ) 0 1800 0 () -I- 2000 L ( ) > ( ) 2200 :J L I- I 2400 V 2600 2800 ( ~. ; Plîilli pS i\lasl~a, II1C. Structure: Pad 1 C Well: 102(B) Field: Kuparuk River Unit Location: North Slope, Alaska """",,"""'-"""""" KOP 3.00 DLS: 3.00 deg per 100 ft 6.00 -' ---.- - --'- .-..------ -'-'--'--- C"ol,o b, ,,",h Fa ": S McKeever' ~o" ploU.d , 17-J"'-:001 Piol RrI..."" oS '0: 6 Lot ,.:. Coo'O,"ot.. O" ," r." "'m"" slot' 10:. .1"" V..t"ol O'p'h, ... "fm".. .KB 10:' (N-2.5E) : Wl;:¡:'\Çi: BAKîR"'~ HUGHE 5 LNT/,;O ..... """"""""""""""""""""""""""'" 10.68 12.58 290.00 AZIMUTH 3283' (TO 7 5/8" CSG PT) 60.13 57.46 55.13 53.18 51.66 50.61 "-, 50.06 . ~ . 50.04 -'-"------------'--------------.--------------- T op -U~-~~--C----:-----~_..._...- ---SŒ5'5---------'--'------'---- "'. 51.56 " 53.05 . Top Ugnu B 54.97 Top Ugnu A 57.27 EOC 59.92 K-13 62.84 Begin Turn/Build Top W Sak D C B Begin Turn/Build 9.36 ...Plane of Proposal'" DLS: 3.00 deg per 100 ft 14.84 17.32 20.51 Beg 6/100 Bid 25.54 30.90 DLS: 6.00 deg per 100 It 36.45 42.10 47.83 53.60 59.40 EOC Base Permafrost TANGENT ANGLE 62.14 DEG TopK-15 Beg Turn/Build DLS: 6.00 deg per 100 It 3000 ..-- ----- ---..- ...... - .--..---..---.---- -.----.. ---- 3200 3400 TARGET ANGLE 91.26 DEG 3600 3800 t:{'- (;,:>0, " ,,<:> \'? /",è.' :-... ," 4000 0 200 1400 2200 1600 1800 2000 400 600 800 1000 1200 "V:J :-..'" "r:" ,~,. 65.64 75.16 '/' e. ¿.C) . ,,0, Iv.,' 6' I (;0 0(.° " <? V:J \<ç¡ ",Co 'Î 2400 3400 2600 2800 3000 3200 Vertical Section (feet) -> Azimuth 290.00 with reference 0.00 N, 0.00 E from slot #102 2760 r---.. -+- Q) 2990 Q) 4- '---"" ...c 3220 -+- 0... Q) 0 3450 - 0 0 -+- 3680 I..... Q) > Q) 3910 :J I..... I- I 4140 V 4370 :> C, c:-.:) . ~Oj i< oQ ,.~ ¡ " vjJ ! \ ~~:;" 'ò i D LATERAL ~. 'J~.:,\ .:) '?- c,e e! HORI , <!.~ ,," 0" ,.,0.ò,00'"1 ZONT AL AN G LE . oQ ~Oj ,OC'IQy.:)¿j- <;)oQ ; C, . <..: oQ C, "'~ c:-I,-.o :-\ ¡ ,0 90 71 D 0' "',' ,,° ,'^'é""~~~1:'b""'! )" . EG ,;- q,'1' -":> +: I< ò;C:- ~~" (}- ¡ .:)(c:- '<~ C>¡' Ix "'. /,oQ}'o",ßS1\' Cj ¡ <..: <;) V) :¡'?'. '<1+:0 ~~'P c, !ët / '0' ~ ~<'..oQ").'....",'.o. "".e.. (". +:" \x .' 'P v v¡<..:" 'O'?'? è!- <;) <()'c, ,.. .~... m. .om_" ... - .nnn .. ...... e;,° '?: <Q~! t ,"" '\ Oc, .1 c:-o, ~'? . ~ ~' '\\ ,0' ",I ~Oi ," \~ -<-ß \'ò ' ",. ~ <Q 'J\ ! ,c:- <..: ~:'\ i ~ ,,'" . ~- - - - - _n - _. n __n._n__._.- -.. - --.- n. .Phillips Alasl{a '._!?~.! Structure: Pad 1 C Well: 102(8) Field: Kuparuk River Unit Location: North Slope, Alaska: __nn"-..m.-. .n_n".._n..n....n , rnCteOleò by finch _n.. For: S'-McKeev'~'t Dote plotl.ò : 1J-Ju'-2001 .. Plol Refetence is 102 B Lal v.2. i ¡ ¡ Coon ;nales ute ;n feel reference 5101 6102. i ¡ !T",e Vetlieul o"plhs ore reference RKB 102' (N-24~).: j ir~ir¡¡¡¡! : ~"iR.i...'" I ¡ ..u~- I ; J..n! ! INTÕ£Q /.Ä ~/ I i ,,'- ¡ iJ ! .,0 I QO( ! bOo, ! 00 '0' C;. <;)v i B LATERAL T1\RGET ANGLE ; 91.26 DEG 2300 690 230 920 1150 1380 230 460 690 460 0 2070 1840 1610 1380 ;1150 920 Vertical Section (feet) -> Azimuth 180.00 with reference 0.00 N, 0.00 E from slot # 102 1610 1840 2070 2300 ."--0 -'" ~,.. ü, (5' / ,(j s Q'-~ (.;,°, . <' ~;.) 2530 27GO 2990 7', .J. c..o<.o o. '"" For: S McKee\'er Do" plo...., 1;-Jul-:ODI ~Iol ".r"."," ,. 10: C lol , : '0.'.".'" ." ;" 1.., "I","" ,101 /1,,: ."u' V"';'.' C.pln, .'. ,.1"".00 .'B 10:' (N-:<SE) rt:i8 BAKER HU~S TNT!:Q . ..................... ...... 3500 3:50 Top W Sok D ( \ ( Structure: Pod 1 G P 11 i II ips LL\ I a s l( 8- , I 11 C . .--.-... ..-. -. -.... ........... '-"-"'--""'-" -.... _.... -'.....--..-...-... ........ ......n...... ...... ""'" -.-..- .-.. ..u- .......... .........- --.-.. -'-'.. Well: 102(0) Field: Kuparuk River Unit 3000 :75,0 :500 :25.0 Top Ugnu 6 Top Ugnu A EOG ~'r ~ !'J K-13 '1) Kl- Begin Turn/Build ':;0 ."T' "Wh' t I F 'V I. op IpS oc" ace . Bose Whipstock Face ¡ "OP /Mill Bury Depth Top W Sak D EOG ....Tc.p Ugnu C .. +' C B Begin Turn TGT B Heel/EOG j. TGT - D Heel/EOC 7 5/8 Casing ¡ B LATERAL TOP W SAK D LOCATION: 182' FSL. 2365' FEL SEC, 2. TllN, R10E B SAND LOCATION: 36' FNL, 243.3' FEL SEC. 11,TllN,Rl0E In\. Tgt #5 ~ B LATERAL HEEL TARGET LOCATION: 193' FNL, 2447' FEL SEC, 11, T11N, Rl0E -------...--..............-.-.--. . D LATERAL TOP W SAK D LOCATION: 152' FSL, 2374' FEL SEC.2,T11N.R10E N ...: 1"- 0:> O'Õ 1"- .... D LATERAL HEEL TARGET LOCATION: 19.3' FNL, 2422' FEL SEC,11,T111~,Rl0E In\. Tgt #8 ~ . "-""""""""'-"'-"""""""""'-"""-"""-"""'-""----""'-n_._..--..... B LATERAL TD LOCATION: 912' FSL, 2747' FEL SEC. 11.TllN,Rl0E TO - C5g Pt D LATERAL TD LOCATION: 912' FSL, 2422' FEL SEC. 11, T11N, R10E Location: North Slope. Alaska <- West (feet) :000 1"'SO 1500 1250 1000 ". Beg Turn/Build + Top 1<-15 " "\ .~ ~ o'{'ó' '1. 't'" 7S0 500 250 \ \ \ "'\ Base Permafrost .. EOC "'. Beg 6/100 Bid' """""'# KOP Begin Turn/Build ~'\.o 'I-~~ SURFACE LOCATlor~: 1420' FNL, 600' FWL SEC, 12, T11N, Rl0E 290.00 AZIMUTH 3283' (TO 7 5/8" CSG PT) ".Plane of Proposal". TRUE .. """---"""-"""-"--'-""""""""""" 0 250 ...--....--...--..-------....-....---.....----...-....., ....-...-.........-....-... " c£ ~ 2250 2000 1750 1500 1250 1000 750 500 ~50 (j') 0 C - ::J ...-.... -+- <D 500 <D - .........., I 750 V 1000 1250 1500 1750 2000 2250 2500 2750 3000 0 250 .. -- ....-....-...... ....... f " (' P11illi ps Alasl(a, lllC. ""-'--'----"-'------"--'-------'- -..---.. -- ----.- -. --- - --.- ---- -- --.-.-- ---..-- .-.- ---- -.--.---.. ------.- - -.--- , "'°1.. b, ';n<" For: S McKeever Structure: Pod 1 C Well: 102(8) 0°" plolt.d , I7-Jul-:O~1 FIOI R.I...n" ;, 10: e Lo' ,:. Field: Kuporuk River Unit Location: North Slope, Alasko '",,'dinol.. 01' in ,.., """ne< ,101 plv: -------.----.-----------. .-. '-.------.. ----,-,----_._--- ---.- ----..- .TM v,ni,ol 0..'"0 0.. "'".n" RK6 10:- ("-¡'~E). . ì";;ížli BAkER HUGHES INTH) 240 200 <- West (feet) 120 100 80 60 40 180 160 140 20 0 20 40 60 300 1900 ~ 280 260 , + 800 240 220 300 ~ ~ ~ " '-'<\ 1 ìOO " 280 " B_.._;~~~.__....._.., ................, " " ... 1200 " 260 2-~~~-~""""""'" " , """"'"",,- " ."".".........,.....~..,... ""'" ~ 1600 2100 '~.. """"", "... 1 200 "-':'....~.,~-?OO " '-""" \ 240 I I ~ ìOO ! i """"", I . """""', ""... '-, + 600 1900 """'..-, \ 500 , ':',"';'~;O...,..J 300 ÆJ "', ~OO 30;~:':', ~. '. 220 " , 200 , " '- 180 "".1100 , \ \ 1500 , , , , 160 '..¡... 11 00 ~ ~\ , \ -- , , , ^ I , .. " " 't 1100 " 140 , , , "*,1000 " , " " " r---. +- Q) Q) 'I- '-../ " \ ' 120 \¡.1(100 \ \ \ \ " \ \ , , \. ..,,1300 \ " .. 1100 " \ " \, \ \ '. '", 900 J: +- .... 0 Z 100 \ , 80 '. '* 1200 '. \. \ .... 1000 " " 60 ~ " ,.. 1300 ....1100 '.. 1000 \ 1300', . '" 800 5300 @J..,... ' , ..",i4600'., " -------------~ 3 0 02'9'6Ó~~:;~;~o""~:'":':"'¿\9ío~---~~\-:--"----~ ---4 0'- '. ... ~... 1200 , " '-. "" , ". --.--- ---..-..:.......----,------_..__.-----,___",,_9_0.~~.~- 40 " '..' \, '. " .,. 1 000 , " , 20 "" 1200 '. . ",.. 800 ' e "'" ""...~OO ,,>1+300 """.,...~,,800 5Q.o.."'" '400 600 ìOO ""'"",--"--"-+""",,,,,~,,:;"'~':_:..- > . *. .. 600 700 -$-300 ,~ 300 \ 600 20 ~ ; ~ .¡. 500 0 ~ 400 ~300 20 " " " 0 '" '.. .. "" !,1O0 ". , ", 1 000 ,,'+ 500 *.. " " "'" 900' ""',....,..,800 ,.,"'600 ., ..;¡;.., "".. ", ~ 700 20 10S.. 1100 "',... " .., 40 1000 '.. "" ..... ", '.. """ , 1&300 900 '.. "'", ... .. '. 800 ... ...;¡,.. . .iI" , 500 700 .jo " ,.. ."......",. "," 600 Q&" '.. '.. "'... 60 " , , 'Qz;; 240 220 160 40 140 120 100 80 60 <- West (feet) 0 20 200 180 40 20 220 200 a 180 160 ^ 140 I Z 0 .., 120 -+- ::r ~ r---. -+, 100 (1) (1) -+- '-../ 80 60 ...------"-""""" 40 60 60 ---_.._"--------,-",,-,,-----,, C,eo,eo b" "'OK For: S McKeever Dot. 0""'0 : "-Jol-"OOI PIC' P.'...nce ,. '°" E Lol -,c, CO"d'nc'.. 0" ,. ",' "'"cn" "°1 ., 0: ;1,oe Yc"òcol o.OIKo ..C "'m.ee PKE '°"' (N-:'~(i" , lPlitl! BAKER HUGHES INTH) no ~) ". -:, \ 680 ' 640 600 560 ~ ", 520 480 , , \ \ , \ , \ \ \ \ , \ \ , .' 1800 .,..' , : , , , \ \ \ \ \ \ , \ 500 ï50 ï20 r( (, ~ "",,1500 , "".. : : P 11 i 11 i 1) s .AJ Et s l{ .a, I I1 C . '-----,--..-.. ---.., - - ,- - '------'---'-" ---.. ---, - _._, '..'----- --- -- -,,_.., - --.. -...., -,-_.., .-- ,-, , Structure: Pad 1 C Well: 102(8) Field: Kuparuk River Unit Location North Slope. Alaska 580 <- West (feet) 550 520 460 440 400 ~ \ ~~ 2400', , 540 600 350 320 280 240 200 ~ ,l' 1800 ~.' 3200 ,¡,' r>" ~... '\ "¡',1400 \ \ \ , " 1 500 " + 2300 '-.', ' 4000 "",,--", ' .. .. " , , , 3300./' .. ?OOO , , \ \ \ , , '", 2200 ... " \ .. ',3900 3400 f , \ '\ 1900 1700 , <~\ " , 'j , '~ 2100 '\, , "~~?ó' , .- , ,Ú' , 'I, -t,,1400 , "" " , , , , , 2000"', , " CD...,... 30ò'Ô~"""""/""'" "',;' 350Ò"""""" ......."" 2900 ...."......, " .. ----_.._------;~.;- -_..._-..:- ._.._--~._".--~-----------_...__._- ---------'-"--------'------~"'~---'-----'------150~\\.~~1~OO-~--'~~~----'--'-"'--' --;~~-" -" ".-. " " '" " ... .. "~,, 'ríõ? ", 1500""" ~ '. 440 ^ I 400 ,-., - Q) Q) 360 '+- '---'" J: - \... 320 0 Z 280 240 ~J',. 150 " [!J 120 80 40 ~. " ; ~" 3600 , " ..,,1800 " " " " ". '. " 0 800 ï50 ï20 " \ , , , .., '", .. 1700 1400 '. ,,'. '", 1800 ' \ .. 1600 .. , , , , ", \ \ , , , .-' , , '" --';oõ~::::..:' ',¿b, .......-....,...,..~, " , \ , , , , , \ '.".170b, 1500 ", \ , '/." """"":":"::"'....",.. ' 2600 ",-.." 1300 ';::""":'" 2500 ;'-"'\""""""""" '\, """"""....,....2400 \ " """"""" 1600 \if, \.. f4DQ """""....; <.-,~~.OO \ '. ' '" '. 1300'</> ~ \ 1600 *'" \ , '-' ".'. ";;,1200 , , , " ... 1 400 1200 ill; \ .. , , , , \ , , \ , , "*', 'I 300 .. , 1100' , " Q) 1000',¡. ~ ", " ";',,1400 \, " \, .... 1400 ' " " " "" -",1700 '. '. -., '. ~., , , , '; - 1300 ' ";' ~, ,1300 40 1200"', ""roJ 0 280 240 200 150 580 , '. '.. , " .. "" " '" "' " ". C(& '. 'Œ§E 560 520 480 440 400 350 320 <- West (feet) 640 600 160 no ~ 580 540 600 550 520 480 440 ^ 400 I z 0 ., 360 -+ ::J ,-., - 320 CD CD -+ '---'" 280 8 240 ..--,-.. .....,....-.... 160 120 80 \ ( Plîilli ps Alasl~a , 111C. -'----"-'---"-'------'-'- ----..-..--- C..o,.d b, "n" For: S McKeever -----. .--... --.. ----.- -- -- - .--- ---- '----. .-- .---- --- --------- -...-.--- Structure: Pad 1 C Well: 102(8) eo,. ol.I\.d , 17-Jul-:001 bTot Ro""'" ;, 1O: B Lol .: Field: Kuparuk River Unit Location: North Slope, Alaska Coo,.;n".. .10 in ..., 10'0""" ~ol ; 10: .r,U, V.rti,., IkOlhO ... "r...n" RKe 1O:' ("-:.~E-" ¡;;~¡¡;'!Jl BAKER ~ tRJ GtŒ 5 ^ I r-... -I- Q) Q) '-I- '--"' ..r::. -I- !.... 0 Z ------ -..--.. INTn) <- West (feet) .3600 2400 .3400 .3200 .3000 2800 2600 2400 2200 2000 1BOO 1600 1400 1200 1000 800 600 \j 400 2400 Q( ~ ~~ 't,~,J-< 6400 2200 C2¿¿:> 32?0..... -""" ,,' 6')00 ~>'+- ,~400 340~.," 3000" " ,'" '.t, 2400 3000" " ' , '" "- 2000 ' , , ' '", ,3200 2800 ' .. 6000 , ~>4200 "',:",,3600 2800 . " ',', 3000;' " "~~ -6800 "'::,./ ,,~,,2200 'i." 2600"', .. '3.~og600 ~ .. "'~,,2600 " '>," ~" ~ " , '~ ""'",,5000 1 -",," '. \' '. 5400" 1 800' ", t ~- ""'\ .. """ I: 2800'~<, "'3ÒÖO '. (;:::;-"., """'. I: 2400 " '. \ -.;2000\ ~, 4800 ""'!.' ":':~'" 2400 '\ ,"".. 5200 1400 """" I,""""', ',...28QO, \2200 " I : "..,,~600 , '. ',' ", 5-000 "" I, "'" 2600"'".", \' ,\II, 3000 """,,1~374- """",,4400' "",,2200 ", ' .. (\ 3794 '1'"".) """, " ... 26110 "~ 4800 V 1200 ::2;~O"" """".",,4200' 2200','. ".\1800160~, " "", ,....".,- "..240b, " "\,'-..4600 I , """" ",' ",,2000 ,~2000\..' I, 260'0"" 4000""""" , ?400\ "-'.' ~ 1000 " "" """" - , " '..4400~ I """"'" \ '.\ r>::. (' """ 3800"""'"""., "" "~:800 2000 "", \.... 22'b.o'¡600~V I I 2400 """'~,,2200, " 3'QÒO.'~ 800 I' ,,3600""" " " ,*~ I, '.. ""'~"" "". "3200/H~,OO I I 2200 """ . -":,';,..,,3400 ", 1600 ", \ '2'O'OOc;.;", II "" "'" '" ',lit ~ I, .. ", ""","".""',"""", 3.2ÒO.' .J80.Ò":34G~'.«¿" 600 II 2000"" "'" ";.', -' " "" 2000 ", """""," '0 " ' ,; ""'" "3¿Òò".i" ',,' '" I ! 1800"" ,; """",::;:~ , °" II " : 2800 ", t [D2] "", i 3600 3000 I ,*" '" """'*'... 1 800 119""""""".."..,....:":,~80,?o,,..,.., 2600 400~""-"""""""';;oò""""""""""""", 1600 '-:i"":",,, ::'..,'.......,... """, 2400 ;'600"""""",,; 140Ò"~ I ' .. ", .., «.. ".. .. 'o, 2200 """""" ¡ " Ie; I' """ """" .. .. """"'/""""" 2200 éI '" "'... "'" 2000 ! """'"""""'", :: """""""""" I 2000'117 :: "",'soò";"""..,..,....(jJ] 200 . ,- .__...~~J------------- 6~"'" ...m""""""~w;::~=='~~~4:2¡)Ù~:::~:_~':'.~'~'=~i8~Q_Q::~::'~f38Ö_~:::~:~~f:_n .. ...'--, - ,..-. I; \'2\ 400 : : ~ .............,",."...... II 189.9...,.."'" : :..."...-,;;;-;""" """"""2Ö;~<'-"- , (, ..,..........,....., I ;"""~'24ÕÖ :, ....,..........,.........,............. "....,....."""' 2600 """"","",: ,.,..""'2800 I! 1200 @"""" ~;- L!JOO , "... :2000 \" .3600 \ 2600 . 2200 1800 \<400 \,3200 2000 \ 2400 1800 1600 .. .. \", 3000 1600 " 2800 1400 1200 1000 800 ^ I Z 0 ") -+- ::J 600 400 400 ~ -+, <D <D -+- '---" ~ 200 200 0 0 200 400 600 600 800 1000 800 1000 "" /b & 1400 3600 3209...-'1"8'00. ,;:' . ,/ -. 2400 3(9.,....""'- && f @ 1400 400 1200 .3200 3400 .3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 <- West (feet) \ ( Plìilli P s _.. -.-- .-. - -.. --.-....- ..-.. - --_.. -...-...-- - -'----... - ,""'... .-..-...-.. - _... - '-...-........-...... --... -...... ..-- TrlC. c"".O 0) ,,",>- Fol": S Mcl\ee\'er c-". Clcllc.: '~-Jur-"o:' Structure: Pad 1 C PIC! R.f.,,"," i, 'O~ S Lcl ,-: Field: Kuparuk River Unit Coc'",",'" c" i" '.., ,.,.,.n:. sic' ~ ,~"- i"u. Vc..i,cI c..." cr. ,.fc"n,. RK6 'O"' (N-:'5E)' W.:';¡¡jiï;i BAKER HUGHES 1400 1600 ~ -I- Q) Q) 1800 '+- "-" ....c -I- 2000 :J 0 U1 I 2200 V 2400 2600 INTEC) Alétsl<a, Well: 102(8) Location: North Slope, Alaska- 3600 3400 2400 <- West (feet) 1000 3200 3000 2800 2600 376W [!J I I I, I I- I' Ii II I, I- II I I, : ' ~",--"""-,,,,-"""""""'~'2"4;';""""" I,.........."'" 2600 ....,,~......"."...:': ..,..."., 2800 II 1200 >10"""" I @ 3000 I ; 200 400 600 800 1000 2200 2000 1800 1600 1400 1200 o'" 6600 4800 """"""""""""" ...~..."".."...... 800 4200 3800.........).~,QQ"'K 4 ,.....->,.,............... .."..."""........"..' t 3800 § \'2\ "...."" ~'--'-"'-'-'---'-""-""2õ~~........'8..0~""_:""--" 600 ...., 2200 : ~'J 800 : .,ÇiJ,;,-",1' j ,,""',,' , " 3000 ...."':',,';+2200 3200 ,...,....,.A" . <~ ' ,/~/ 1800,. ')I<240d 3400 ."...,., , ,. ! " " ' 3600,""""'" , ""~; ;600 ....................... ..."..,"" 3800 ....,....., ..",.", 4000 ...........'. ....... 4200 ,.....,.."..,' ",..w'.," 48~,9.....'" 5000 ,......' .""" 5200 "...' óY"" , / / , " , ,.. /2600 , , , , , .- " , 2000 ",' ',/ " '" 2800 , ",,' .' " ' 3000 2200 ,'"Ii> 3200 .- "," 3400 .' . ," 3600 r;--;;-;-¡" 4000 , 'L!EJ 2400 , /2200 " " 600 200 400 1000 !J; 1200 I! II I ¡ II , ¡ I! I! II II 4400 ".."..", 3747*, ,...".".";¡'-'" I ¡ ..."'" "" ",,'f'r'" 4600 I ¡ Ii I! I; II I! Ii Ii I! II II II I' fl I; I! I; Ii" I L""2800 ,1' -.___.......28.0,0.....__.,...,.....,..,," I! .._.._-_._~ I' .' I: ..' 37ti-.J..; 3691 3000 )",' ' ~'~ , " '" 2400 2600 1400 1600 U1 0 1800 C -+ :::; ,..---..., 2000 -+. <D <D -+ '----'" 2200 I V 2400 2600 ._..__._..._---_._--------_.~-_..._._.._,_....._...,_._-_.....",..--...--..-.-;.-,-...... ..,.---..,-,--..._,_..2Q.Q()......-.. 3000 ,/ ~ 3000 3200' &' 3400 3600 3800 3600 3400 2400 < - West (f eet) 3200 3000 2800 2600 2800 , , 3200 3400 ," , 3600 ,/ 3800 .- 4000 ,/ [ill[ 2200 2000 1800 1600 1400 1200 1000 800 3000 3200 3400 3600 3800 600 ==== .----- Point ----- KOP Begin Turn/Build Beg 6/100 Bid EOC Bose Pel-mafrost Top K-15 Beg Turn/Build Top Ugnu C Top Ugnu B Top Ugnu A EOC 1<-13 IBegin Turn/Build ITop W Sak D IC iB 17 5/8 Casing pt \TGT B Heel/EOC ¡lilt. Tgt #5 lint. Tgt #8 l.lDnn=unnç$gnJ?t 6410.27 i Phillips Alask:a, II1C. Structure: Pad 1 C Well: 102(8) . . . . . . L_!~eld~pa~_R~er _~~n~~~~ : Nort~--=~o~~~I~sk~j Inc 0.00 9.00 19.20 62.14 62.14 62.14 62.14 50.25 57.95 59.59 63.54 63.54 63.54 71.08 78.22 82.95 91.26 91.26 "B" Lateral u..u.. .. nu n'" ",uu,','.n . ...nuuu. nnu unu... . ..nuuO.. .u n un ¡Created by I;nch For: S McKebver : ¡ Dote planed : t7-Jut-2DO1 l : : PlatReference;slD2BLatv.2. : : Coord;no!.. are ;n feel reference 5101 1/1. 2. ¡ ¡True Verlkal Depths are reference RKB 102' (~-245E).¡ : ~~ߧ ¡ ! B~ÏŒ§ ; : : INTEO I ...nn.__. .n__.__.__n.__.__._-_.'-.__._._---_.__u_.__.nn_..___~----------.---.1 . !PROFILE I ! I MD I I 1250.00 I 1550.00 I 11072.00 i i 11847.08 i ~081.55 d299.15 I 1130.78 4954.54 I ~426.70 9488.41 i $622.65 ! 5779.79 I -185 'I .95 i ~017.08 ~ 160.44 I 6252.09 i I 6410.26 I .--_uu_---.----_uu.uu,..__.nn___,,--uu'-n" ._n..... .n.. .. COMMENT DATA Dir TVD North ECI st 236.00 250.00 0.00 0.00 236.00 548.77 -13. '15 -19.49 290.00 1056.19 -6.58 -134.72 321 .85 1635.43 324.83 -485.61 321 .85 1745.00 487.84 -613.67 321 .85 2314.00 1334.35 -1278.66 321 .85 2702.63 1 91 2.53 -1732.85 263.00 3189.00 2176.88 -2308.26 229.10 3471.00 2020.55 -2646.59 225.22 3503.00 1984.67 -2685.26 217.23 3566.98 1895.91 -2762.84 217.23 3637.00 178.3.90 -2847.96 217.23 3669.15 1732.47 -2887.04 205.19 3733.00 1602.34 -2965.37 195.63 3771.00 1472.96 -3013.30 189.80 3786.00 '1384.82 -3033.15 1 79.97 3794.00 1227.75 -3046.52 1 79.97 3794.00 1227.74 -3046.52 7r899.72 90.82 '179.~)7 3767.00 -261.46 -3045.62 I I ~399.06 90.71 179.97 3747.00 -1760.66 -3044.81 ! 10585.23 89.58 179.99 3744.00 -2946.82 -3044.45 .n .unn_- . un___u_nn..n..n__u.__uu_u. n~o_n~uT .__nuunn_u__u__u___n___Un___nU____nu_----_nnuu.--u_----u_n____._n___-u- .un__--_____n_-__m_"_----- _n" --.-..-. ..nn -----_.u.. . _n .n.. '00-"'" u _n ..... ..-..... I ==== -- V. Sect De~J/¡ 00 0.00 0.00 13.82 3.00 124,,34 3.00 r=r747 6.00 ._1 J . - 743.5'1 0.00 -1657.92 0.00 2282.47 0.00 291.3.59 6.00 3178.05 6.00 3 ? 0 ') 1 °) 6.00 ~ ~. L : -- ,3244.C6 (3.00 3286..3.3 0.00: 3~)05.47 0.00: 7774 r=7 e.! 3: ~I..J~) ....J 373C:: 7C:: 8.1.3 ...J ...J. ...J.:J 3327 OF ô.13 . ,_I.U J 3282.70 E:.13 3282.70 8.13 2772.52 0.03 2259.00 0.01 lnt:29° 0.10 0,,) .' U { :( Phillips Alaska, Inc. Pad 1C 102(B) slot #102 Kuparuk River Unit North Slope, Alaska PRO PO SA L LIS TIN G by Baker Hughes INTEQ Your ref: 102 BLat v.2 Our ref: prop2487 License: Date printed: 17-Jul-2001 Date created: 7-Nov-1997 Last revised: 17-Jul-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 31.207,w149 30 1.61+ Slot Grid coordinates are N 5968813.187, E 561605.104 Slot local coordinates are 1420.00 S 600.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ---------------.- ---------.-----.----------------------- .._-- (' ~' Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 1C,102(B) Your ref : 102 BLat v.2 Kuparuk River Unit,North Slope. Alaska Last revised : 17-Jul-2001 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect 0.00 0.00 236.00 0.00 0.00 N 0.00 E 0.00 0.00 250.00 0.00 236.00 250.00 0.00 N 0.00 E 0.00 0.00 KOP 350.00 3.00 236.00 349.95 1. 46 S 2.17 W 3.00 1. 54 450.00 6.00 236.00 449.63 5.85 S 8.67 W 3.00 6.15 550.00 9.00 236.00 548.77 13.15 S 19.49 W 3.00 13.82 Begin Turn/Build 600.00 9.36 245.13 598.13 17.05 S 26.42 W 3.00 19.00 700.00 10.68 260.67 696.62 21. 97 S 42.94 W 3.00 32.84 800.00 12.58 272.21 794.58 23.05 S 62.97 W 3.00 51. 29 900.00 14.84 280.53 891.73 20.29 S 86.45 W 3.00 74.30 1000.00 17.32 286.60 987.82 13.69 S 113.32 W 3.00 101.80 1072 . 00 19.20 290.00 1056.19 6.58 S 134.72 W 3.00 124.34 Beg 6/100 BId 1100.00 20.51 293.08 1082.53 3.08 S 143.56 W 6.00 133.84 1200.00 25.54 301. 50 1174.55 15.07 N 178.09 W 6.00 172.50 1300.00 30.90 307.22 1262.65 41. 89 N 216.96 W 6.00 218.20 1400.00 36.45 311.38 1345.84 77.09 N 259.74 W 6.00 270.44 1500.00 42.10 314.56 1423.23 120.29 N 305.95 W 6.00 328.64 1600.00 47.83 317.11 1493.96 171. 01 N 355.10 W 6.00 392.17 1700.00 53.60 319.23 1557.27 228.69 N 406.64 W 6.00 460.34 1800.00 59.40 321. 06 1612.44 292.70 N 460.02 W 6.00 532.38 1847.08 62.14 321. 85 1635.43 324.83 N 485.61 W 6.00 567.42 EOC 2000.00 62.14 321. 85 1706.89 431.15 N 569.13 W 0.00 682.27 2081. 55 62.14 321. 85 1745.00 487.84 N 613.67 W 0.00 743.51 Base Permafrost 2500.00 62.14 321. 85 1940.55 778.76 N 842.20 W 0.00 1057.76 3000.00 62.14 321. 85 2174.20 1126.38 N 1115.28 W 0.00 1433.26 3299.15 62.14 321. 85 2314.00 1334.35 N 1278.66 W 0.00 1657.92 Top K-15 3500.00 62.14 321. 85 2407.86 1473.99 N 1388.35 W 0.00 1808.76 4000.00 62.14 321. 85 2641.52 1821.60 N 1661. 42 W 0.00 2184.25 4130.78 62.14 321. 85 2702.63 1912.53 N 1732.85 W 0.00 2282.47 Beg Turn/Build 4200.00 60.13 317.70 2736.06 1958.81 N 1771.97 W 6.00 2335.06 4300.00 57.46 311.41 2787.90 2018.81 N 1832.82 W 6.00 2412.76 4400.00 55.13 304.76 2843.43 2070.13 N 1898.19 W 6.00 2491.74 4500.00 53.18 297.76 2902.04 2112.20N 1967.37 W 6.00 2571.14 4600.00 51.66 290.44 2963.08 2144.57 N 2039.60 W 6.00 2650.08 4700.00 50.61 282.85 3025.89 2166.88 N 2114.09 W 6.00 2727.71 4800.00 50.06 275.08 3089.78 2178.87 N 2190.02 W 6.00 2803.16 4900.00 50.04 267.25 3154.04 2180.44 N 2266.56 W 6.00 2875.62 4954.54 50.25 263.00 3189.00 2176.88 N 2308.26 W 6.00 2913.59 Top Ugnu C 5000.00 50.55 259.48 3217.98 2171.54 N 2342.87 W 6.00 2944.29 5100.00 51. 56 251.87 3280.90 2152.29 N 2418.11 W 6.00 3008.41 5200.00 53.05 244.52 3342.10 2122.89 N 2491. 47 W 6.00 3067.29 5300.00 54.97 237.50 3400.91 2083.67 N 2562.13 W 6.00 3120.28 5400.00 57.27 230.82 3456.70 2035.05 N 2629.33 W 6.00 3166.79 5426.70 57.95 229.10 3471.00 2020.55 N 2646.59 W 6.00 3178.05 Top Ugnu B 5488.41 59.59 225.22 3503.00 1984.67 N 2685.26 W 6.00 3202.12 Top Ugnu A 5500.00 59.92 224.51 3508.84 1977.57 N 2692.32 W 6.00 3206.33 --5-6-f)(}-;-(} (}------6.z--;-84 -. --.z-1-8-;-54---------3-5-5- 6-;-7!:J----..---191-1-;-8 -6--- N---- -_._-- --2~-S- 0~--4 -2--W - -----.---6-;{)-0----3-2-3-8 -..4-5 -- ---- --.-- -- ------_.-- -______n.___._-. 5622.65 63.54 217.23 3566.98 1895.91 N 2762.84 W 6.00 3244.66 EOC 5779.79 63.54 217.23 3637.00 1783.90 N 2847.96 W 0.00 3286.33 K-13 5851.95 63.54 217.23 3669.15 1732.47 N 2887.04 W 0.00 3305.47 Begin Turn/Build 5900.00 65.64 213.59 3689.78 1697.10 N 2912.18 W 8.13 3316.99 Coordinates from slot Bottom hole All data is in feet unless otherwise stated. #102 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea distance is 4237.03 on azimuth 225.93 degrees from wellhead. Total Dogleg for wellpath is 207.71 degrees. section is from N 0.00 E 0.00 on azimuth 290.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . Vertical ~, Phillips Alaska, Inc. Pad 1C,102(B) Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 6000.00 6017.08 6100.00 6160.44 6200.00 6252.09 6300.00 6400.00 6410.26 6410.27 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 7600.00 7700.00 7800.00 7899.72 7900.00 8000.00 8100.00 8200.00 8300.00 8400.00 8500.00 8600.00 8700.00 8800.00 8900.00 9000.00 9100.00 9200.00 9300.00 9399.06 9400.00 9500.00 9600.00 9700.00 70.26 71.08 75.16 78.22 80.25 82.95 85.46 90.72 91.26 91.26 91. 23 91. 20 91.17 91.14 91.11 91. 08 91. 05 91. 03 91. 00 90.97 90.94 90.91 90.88 90.85 90.82 90.82 90.81 90.80 90.80 90.79 90.78 90.78 90.77 90.76 90.75 90.75 90.74 90.73 90.72 90.72 --9800 --:OÕ------go,'3-j- . 9900.00 90.23 10000.00 90.14 10100.00 90.04 10200.00 89.95 206.38 205.19 199.58 195.63 193.09 189.80 186.80 180.60 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 179.97 90.71 90.71 90.61 90.52 90.42 179.97 179.97 179.97 179.98 179.98 3727.35 3733.00 3757.08 3771. 00 3778.39 3786.00 3790.84 3794.18 3794.00 3794.00 3792.05 3789.92 3787.85 3785.83 3783.86 3781. 94 3780.07 3778.26 3776.49 3774.78 3773.12 3771.51 3769.96 3768.45 3767.00 3767.00 3765.57 3764.16 3762.77 3761.38 3760.01 3758.65 3757.31 3755.97 3754.65 3753.34 3752.05 3750.76 3749.49 3748.23 3747.00 3746.99 3745.83 3744.84 . 3744.02 R E C TAN G U LA R COO R DIN ATE S 1616.86 N 1602.34 N 1529.01 N 1472.96 N 1435.31 N 1384.82 N 1337.66 N 1238.01 N 1227.75 N 1227.74 N 1138.03 N 1038.05 N 938.08 N 838.10 N 738.12 N 638.13 N 538.15 N 438.17 N 338.18 N 238.20 N 138.21 N 38.23 N 61.76 S 161. 75 S 261.46 S 261. 74 S 361. 73 S 461.72 S 561. 71 S 661. 70 S 761. 69 S 861. 68 S 961. 67 S 1061.66 S 1161. 66 S 1261.65 S 1361.64 S 1461. 63 S 1561.62 S 1661.61 S 1760.66 S 1761.61 S 1861.60 S 1961.59 S 2061.59 S 2958.36 W 2965.37 W 2995.53 W 3013.30 W 3022.93 W 3033.15 W 3040.03 W 3046.47 W 3046.52 W 3046.52 W 3046.46 W 3046.40 W 3046.34 W 3046.29 W 3046.23 W 3046.17 W 3046.11 W 3046.05 W 3045.99 W 3045.93 W 3045.87 W 3045.80 W 3045.74 W 3045.68 W 3045.62 W 3045.62 W 3045.56 W 3045.50 W 3045.44 W 3045.39 W 3045.33 W 3045.27 W 3045.22 W 3045.16 W 3045.11 W 3045.06 W 3045.01 W 3044.96 W 3044.91 W 3044.86 W 3044.81 W 3044.81 W 3044.76 W 3044.72 W 3044.68 W Dogleg Deg/100ft ( PROPOSAL LISTING Page 2 Your ref: 102 BLat v.2 Last revised: 17-Jul-2001 Vert Sect 8.13 8.13 8.13 8.13 8.13 3332.94 3334.57 Top W Sak D 3337.82 3335.35 C 3331. 53 8.13 8.13 8.13 8.13 8.13 3323.86 B 3314.20 3286.17 3282.70 7 5/8 Casing pt 3282.70 WS 1C G3 B-HEEL(5-DEC-00) 0.03 0.03 0.03 0.03 0.03 3251.97 3217.72 3183.47 3149.22 3114.97 0.03 0.03 0.03 0.03 0.03 3080.71 3046.46 3012.21 2977.96 2943.70 0.03 0.03 0.03 0.03 0.03 2909.45 2875.19 2840.94 2806.68 2772.52 102B T#5 10-Ju1-01 0.01 0.01 0.01 0.01 0.01 2772.43 2738.17 2703.92 2669.66 2635.41 0.01 0.01 0.01 0.01 0.01 2601.16 2566.91 2532.66 2498.41 2464.16 0.01 0.01 0.01 0.01 0.01 2429.91 2395.66 2361. 42 2327.17 2292.92 0.01 0.10 0.10 0.10 0.10 102B T#8 10-Jul-01 2259.00 2258.68 2224.44 2190.20 2155.96 -'"ï 7 9--:9ã'-3;iÜ-~31---.-'-~6'1~--Š-9--S'-'-'---'jõ-4T:64-W-------0-:TO""'-'Z12r:72---'--"-. -----... . 179.98 3742.88 2261.59 S 3044.61 W 0.10 2087.49 179.98 3742.55 2361,59 S 3044.58 W 0.10 2053.26 179.98 3742.40 2461.59 S 3044.55 W 0.10 2019.03 179.99 3742.41 2561.59 S 3044.52 W 0.10 1984.80 ..'.--_--'__.0.--_....'..--- .. All data is in feet unless otherwise stated. #102 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea distance is 4237.03 on azimuth 225.93 degrees from wellhead. Total Dogleg for wellpath is 207.71 degrees. section is from N 0.00 E 0.00 on azimuth 290.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Coordinates from slot Bottom hole Vertical level) . ( ( Phillips Alaska, Inc. Pad 1C,102(B) Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C TAN G U L A R Depth Degrees Degrees Depth COO R D I N ATE S 10300.00 89.85 179.99 3742.58 2661.59 S 3044.50 W 10400.00 89.76 179.99 3742.93 2761.59 S 3044.48 W 10500.00 89.66 179.99 3743.43 2861.59 S 3044.46 W 10585.23 89.58 179.99 3744.00 2946.82 S 3044.45 W PROPOSAL LISTING Page 3 Your ref: 102 BLat v.2 Last revised: 17-Jul-2001 Dogleg Deg/100ft Vert Sect 0.10 0.10 0.10 0.10 1950.58 1916.36 1882.14 1852.98 WS 1C G3 B-TOE(5-DEC-00) Coordinates from slot Bottom hole All data is in feet unless otherwise stated. #102 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea distance is 4237.03 on azimuth 225.93 degrees from wellhead. Total Dogleg for wellpath is 207.71 degrees. section is from N 0.00 E 0.00 on azimuth 290.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . Vertical Phillips Alaska, Inc. Pad 1C,102(B) Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 4 Your ref: 102 BLat v.2 Last revised: l7-Jul-2001 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 250.00 250.00 0.00 N 0.00 E KOP 550.00 548.77 13.15 S 19.49 W Begin Turn/Build 1072.00 1056.19 6.58 S 134.72 W Beg 6/100 BId 1847.08 1635.43 324.83 N 485.61 W EOC 2081.55 1745.00 487.84 N 613.67 W Base Permafrost 3299.15 2314.00 1334.35 N 1278.66 W Top K-15 4130.78 2702.63 1912.53 N 1732.85 W Beg Turn/Build 4954.54 3189.00 2176.88 N 2308.26 W Top Ugnu C 5426.70 3471.00 2020.55 N 2646.59 W Top Ugnu B 5488.41 3503.00 1984.67 N 2685.26 W Top Ugnu A 5622.65 3566.98 1895.91 N 2762.84 W EOC 5779.79 3637.00 1783.90 N 2847.96 W K-13 5851.95 3669.15 1732.47 N 2887.04 W Begin Turn/Build 6017.08 3733.00 1602.34 N 2965.37 W Top W Sak D 6160.44 3771.00 1472.96 N 3013.30 W C 6252.09 3786.00 1384.82 N 3033.15 W B 6410.26 3794.00 1227.75 N 3046.52 W 7 5/8 Casing pt 6410.27 3794.00 1227.74 N 3046.52 W WS 1C G3 B-HEEL(5-DEC-00) 7899.72 3767.00 261.46 S 3045.62 W 102B T#5 10-Jul-01 9399.06 3747.00 1760.66 S 3044.81 W 102B T#8 10-Jul-01 --1-05-8-5-.2-3--3-9 -4-4-.0 0----294-6-;--8-2- 8-------3-Ð-4-4-;-4-5--W---W 8-1e-G3- B -T0Et5 -DEe-O 0) --- _____h - - _n"_____"-------------------------------------______n_------------ --- Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 6410.27 3794.00 1227.74N 3046.52W 7 5/8" Casing Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- W8 1C G3 B-HEEL(5-DE 558549.000,5970016.000,0.0000 102B T#5 10-Jul-01 558562.000,5968527.000,0.0000 102B T#8 10-Jul-Ol 558575.000,5967028.000,0.0000 W8 1C G3 B-TOE(5-DEC 558585.000,5965842.000,0.0000 3794.00 3767.00 3747.00 3744.00 1227.74N 261. 46S 1760.668 2946.828 3046.52W 3045.62W 3044.81W 3044.45W 8-Jan-2001 14-0ct-1996 10-Feb-1993 8-Jan-2001 ~ ~. " lC-l02 Drilling Hazards Summary (SEE WELL PLAN FOR DETAILED DISCUSSION OF THESE RISKS) 9-7/8" OIHID Hole / 7-5/8" Casing In~erva~ Hazard Broach of Conductor Gas Hydrates Running Sands and Gravels Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Hazard Abnormal Reservoir Pressure Stuck Pipe Lost Circulation Hole Swabbing on Trips Risk Level Low Low Moderate Low Low Moderate Miti ation Strate Monitor cellar continuously during interval. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Maintain planned mud parameters, Increase mud weight, use weighted swee s, run ravel isolation strin . Diverter drills, increased mud weight. 4" Liner Interval Risk Level Low Low Low Moderate Miti ation Strate Stripping drills, Shut-in drills, Increased mud wei ht. Good hole cleaning, PWD Tools, Hole 0 ener Decreased mud wei ht Reduced um rates, Mud rheolo , LCM Trip speeds, Proper hole filling (use of trip sheets, Pum in out 1 C-1 02 Drilling Hazards Summary prepared by Mark Chambers 07/24/01 ( ( Scbl. Dlber DIP West Sak 1 C-1 02 Multi-Lateral Well, Cement Loads and CemCADE Summary. 350/0 Excess Below permafrost, 2500/0 Above permafrost with 50 bbls to surface. 9-7/8" Openhole. TD @ 6410' MD. 7-5/8", 29.7# Casing. Base of permafrost @ 2082' MD. Port collar for no cement to surface contingency. Port Collar @ 1000' MD. Previous Casing 16", 62.6# @ 120' MD Tail Slurry TOC @ 5517' MD. (500' above D Sand). Revised on 7-23-2001 Volume Cales: Pump 70 bbls CW preflush, 50 bbls MudPUSH XL @ 10.2 ppg. Cement from TD to 5517' MD with Class G + adds @ 15.8 ppg, and from 5517' to surface with ASLite @ 10.7 ppg. Lead Slurry Reauirements: ASLite @ 10.7 ppg, Class G + 50% 0124, 3.5% D44, 0.4% 046, 30% D53, 1.5% S1, 1.5% D79 - 4.44 ft3/sk (5517' - 2082') x 0.2148 ft3/ft x 1.35 (35% excess) (2082'-120') x 0.2148 x 3.5 (250% excess) 120' x 0.9513 x 1.0 (no excess) 50 bbls to surface Total 2866.02 ft3/4.44 ft3/sk = 996.08 ft3 = 1475.03 ft3 = 114.15 ft3 = 280.75 ft3 = 2866.02 ft3 = 645.5 sks Round upto 650 sks BHST: 80 of (Temp gradient: 2.4°F/100 ft below permafrost) Tail Slurry Reauirements: BATCH MIX for 60 min. prior to pumpina. Expanding Cement @ 15.8 ppg, Class G + 0.450/0 D65, 0.3% M117, 2.0 gps D600, 0.1 % D35, 0.2% 047, 3.0% D174 -1.20 ft3/sk (6410' - 5517') x 0.2148 ft3/ft x 1.35 (35% excess) 80' (shoe joints) x 0.2578 ft3/ft Total 279.57 ft3/1.20 ft3/sk = 258.95 ft3 = 20.62 ft3 = 279.57 ft3 = 232.97 sks Round upto 240 sks CemCADE* Summary: Fluid sequence: Establish circulation using FW. 70 bbl CW100 preflush, Drop Bottom Plug, 50 bbls 10.2 ppg MudPUSH XL spacer, 650 sks (514 bbls) AS Lite Lead, 240 sks (51 bbls) Class G + adds, Drop Top Plug. Displacement is approximately 290 bbls. Circu lation: Circulation and cementing at or less than 6 bpm is within safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug as well as maintaining returns. Estimated maximum surface pressure during the job is 600 psi. Run dye marker in the spacer to provide insight into the decision to open port collar or performing a top job. Recommended Conditioned Mud Properties: 9.4 ppg, PV < 12, Ty < 12, as thin and light as possible for effective mud removal. 07 -23-2001 KVT ( West Sak 1 C-1 02 ML Producer It: Multi lateral wI Excluder Screen Planned Completion - Phase 1 16" Conductor @ 120' J L 7-5/S" 29.7# L-SO BTC Mod Casing as required from Port Collar to Surface. TAM 7 -5/S" Port Collar BTC Mod Box x Pin set @ +/- 1000' TVD 7-5/S" 29.7# L-SO BTC Mod Casing as required from Float Collar to Port Collar. Float Collar 7-5/S" 29.7# L-SO BTC Box x Pin. @Ji'idd@IWddilUdlllldli¡ Production Casing 7-5/S" 29.7# L-SO BTC Mod ij .' i !i ...... :' Ii ~; ':..... 2 Joints 7-5/S" 29.7# L-80 BTC Mod Casing. Float Shoe 7-5/8" 29.7# L-80 BTC Box Up. TD @ 6,410' MD /3,794' TVD MAC 07/24/01 ( West Sak 1C-102 ML Producer ( 16" Conductor @ 120' Liner Top Packer Set @ +/- 5,944' MD / 3,681' TVD Production Casing 7-5/8" 29.7# L-80 BTC Mod Set @ 6,410' MD / 3,794' TVD Multi Lateral wi Excluder Screen Planned Completion - Phase 2 J ~ L TAM 7-5/8" Port Collar BTC Mod Box x Pin set @ +/- 1000' TVD Lower Lateral Completion (Run wI 2-7/8" Hvd 511 Inner Wash Strinq) Baker 'SC1-R' Liner Top Packer (76B2-40) 7-5/8" 24-29.7# w/ 5-1/2" SLHT Box Down Baker 3' Mill Out Extension w/ 5-1/2" SLHT Pin x Pin Crossover Sub w/ 5-1/2" SLHT Box x 4-1/2" IBT Pin Baker Model 'C' KOIV w/ 4-1/2" IBT Box x Pin Crossover Sub w/ 4-1/2" IBT Box x 4-1/2" SLHT Pin 4-1/2" 12.6# L-80 Blank Pipe w/ SLHT Connections as required to locate top of SC1-R packer +/- 80 feet below setting depth of Whipstock Bottom Trip Anchor. Baker 4-1/2" Model 'CMD' Sliding Sleeve Assembly w/ 3.43" ID and 4-1/2" SLHT Box x Pin 1 Joint 4-1/2" 12.6# L-80 Blank Pipe w/ SLHT Connections. Crossover Sub w/ 4-1/2" SLHT Box x 4" SLHT Pin. 1 Joint 4" 9.5# L-80 Blank Pipe w/ SLHT Connections. 4" Baker Excluder 2000 Screen w/ SLHT Connections (37' Joints) as required from 'GPV' Set Shoe Assembly to Model 'CMD' Sliding Sleeve. 4" 9.5# L-80 Blank Pipe w/ SLHT Connections (30' Joints) as required from 'GPV' Set Shoe Assembly to Model 'CMD' Sliding Sleeve. Plan to alternate Excluder Screen and Blank Pipe throuqh production interval. 2 Joints 4" 9.5# L-80 Blank Pipe w/ SLHT Connections. Baker Model 'GPV' Set Shoe Assembly (5.560" Max OD). Assembly Includes Shoe, 5" Blank Pipe Above Shoe (18' Pup Joint) and Crossover Back to 4" Blank Pipe. ------------- ------------- ------------- ------------- ------------- ------------ ------------ ------------ ------------ ------------ B-Sand Lateral (Planned 6-3/4" Open Hole) TD @ 10,585' MD /3,744' TVD MAC 07/24/01 ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL v (If api number last two (2) digits are between 60-69) DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORATION ANNUL?\,. ~POSAL NO INJECTION WELL ANNULAR DISPOSAL <--> YES INJECTION WELL REDRILL ANNULAR DISPOSAL THIS WELL \ c.. - \0 d.- "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS / LYØ' YES + SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved 'subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. ' ~a.Q,\ '\.:-,~ý"C-ÇL ~ ~~ ,,~\ Templates are located m drive\jody\templates (' ( 11 ;, , . ,/ ., .. American Express. Cash Advance Draft 155 PAY TO THE ORDER OF DATE 27 JIA. ~ Z¿V / $11 VC). c/o 82-4011 021 ...J DOLLARS '"I Issued by Inœ,rated Payment System. Inc. Englewood. Colorado Payable at Norwest Bank of Grand junction - Downtown. NA Grand junction. Colorado PERIOD ENDING I: ~ 0 2 ~ 0 0 ... 0 0 I: ~ 5 II' 0 ~ r 5 0 0 0 5 :¡ b 118 0 ~ 5 5 '" , WELL PERMIT CHECKLIST COMPANY WELL NAMEt,(ú Jé- /0'2. PROGRAM: exp - dev -K redrll FIELD & POOL 'I1t? Iso INITCLASS fJ~ /-o,¡ï GEOLAREA Ç? 76 ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y 4.Welllocatedinadefinedpool.................. Y 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . Y N 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N 14. Conductor string provided. . . . . . . . . . . . . . . . . . . {i N 15. Surface casing protects all known USDWs. . .'. . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y N ~þ... ,.~~c::..:.Cè:.. <D-~\~C~\'1 18. CMTwill cover all known productive horizons. . . . . . . . . . . Y <ID ~~Iil~, ~~Ç>\~~~?,\ 19. Casing designs adequate for C, T, B & permafrost. . . . . . . ~ N "- 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . <3? N <k.~~~ ~ ~......o ~ ~\\.. 21. If a re-drill, has a 10-403 for abandonment been approved. . . ~y No \...)~ ~ :> . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . Y N 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . '.' . . . . ~. . . . N 26. BOPE press rating appropriate; test to ~ tpsig. N ~ (L~\--Q \~d-%{>~~' 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N ~~: ~~~~~~~~~~r~~h;: ~~:~:~~; ~~u~d~~n: : : : : .. : : : : : Y @ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . Á , /J 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . . . / Vi t:L~ APPR D"T9I- . 33. Seabed condition survey (If off-shore). . . . . . . . . . . . . , ~ 34. Contact name/phone for weekly progress reports (exploratory ani ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate. freshwater; or cause drilling waste. .. 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 G~ ENGINEERING: UIC/Annular COMMISSION: ~~ +~W WM 9gs serv wellbore seg _ann, disposal para req - /; .í1: ON/OFF SHORE oÞ() UNIT# ~R ~~} ENGINEERING 3Ç)O~~, .'\~ \'~~ ~~ ~~ . . ~ GEOLOGY APPR DATE ò.~t"\~\o..,~,>~. ' \ t-.O-\--~~~'\b \e O".:~~> Wit t \ \? . ,~~~ "-..)">fC Y N c.J..\>\'~~~ o-'N"..\,.)\.....;)"-:> Cr"'- \ <:(. O\~'c..~~ ¡r~\, Y N Comments/lnstructions: J 6}07 " . ': \ ' 1,li t ir \I 11Jnll/On) 0 0 Z 0 -I ~ ;0 (' - -f m - Z -t :I: - ( ) » ::0 m » ( (' (' Well History File APPENDIX Information of detailed nature that is not. , particularly germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, information of this . . nature is accumulated at the end of the file under APPE~DIX. No special' effort has been made to chronologically, . organize this category of information. (' ( ~'" ",<" '" , "'" I", ',~"Ij~)¡¡" ""',>C"". Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Feb 05 12:56:08 2002 Reel Header Service name............ .LISTPE Date.....................02/02/05 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.....................02/02/05 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 1C-102 500292303700 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 05-FEB-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MM-11144 M. HANIK D. WESTER MWDRUN 2 AK-MM-11144 M. HANIK F. HERBERT # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 11N 10E 1420 600 MSL 0) 101.85 60.60 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 158.0 6.750 7.625 6518.0 ( ( \ 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 AND 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 1 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD) i MWD RUN 2 INCLUDED AT BIT INCLINATION (ABI). AN UPPER LATERAL WAS DRILLED FROM A WHIPSTOCK SET AT 5941'MD (TOP). THESE DATA ARE PRESENTED SEPARATELY. 4. MWD DATA ARE CONSIDERED PDC PER E-MAIL DATED 1/04/02 FROM D. SCHWARTZ, PHILLIPS ALASKA, INC., QUOTING AUTHORIZATION FROM GKA GEOSCIENCE GROUP. 5. UPHOLE BHI ROP, RESISTIVITY, AND GAMMA RAY DATA WERE RECEIVED FROM C. WORLEY (PHILLIPS ALASKA) ON 1/31/02. THESE DATA WERE CORRECTED/SHIFTED TO SSDS DATA AND MERGED WITH SSDS MWD RUN 1 DATA. NO BHI FORMATION EXPOSURE TIME DATA WERE IDENTIFIED. NO BHI HEADER DATA ARE INCLUDED. 6. MWD RUNS 1 AND 2 REPRESENT WELL 1C-102 WITH API#: 50-029-23037-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10570'MD/3753'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...... .02/02/05 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD 1 (" (, Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE RPD RPM RPS RPX GR ROP FET $ clipped curves; all bit runs merged. .5000 START DEPTH 234.0 234.0 234.0 234.0 241.0 286.5 6050.5 STOP DEPTH 10524.5 10524.5 10524.5 10524.5 10517.5 10569.5 10524.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 MERGE TOP 234.0 6528.0 MERGE BASE 6528.0 10569.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT 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 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 234 10569.5 5401.75 20672 234 10569.5 ROP MWD FT/H 1 1031.92 173.303 20165 286.5 10569.5 GR MWD API 13.533 138.215 68.0028 20554 241 10517.5 RPX MWD OHMM 0.379 1563.01 37.8687 20582 234 10524.5 RPS MWD OHMM 0.95 1563.36 45.281 20582 234 10524.5 RPM MWD OHMM 0.06 2000 51.5528 20582 234 10524.5 RPD MWD OHMM 0.618 2000 58.2745 20582 234 10524.5 FET MWD HOUR 0.2 95.71 1.74285 8949 6050.5 10524.5 ( ( First Reading For Entire File......... .234 Last Reading For Entire File.......... .10569.5 File Trailer Service name............ .STSLIB.OOI Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/05 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...... .02/02/05 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.OOI Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPD RPS RPM GR ROP FET $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 234.0 234.0 234.0 234.0 241.0 286.5 6050.5 STOP DEPTH 6477.5 6477.5 6477.5 6477.5 6485.0 6528.0 6477.5 # 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: 25-AUG-Ol Insite 66.16 Memory 6528.0 5800.0 6528.0 70.3 86.6 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02031HWRG6 PB02031HWRG6 # ( BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O ( 9.875 SPUD 9.60 90.0 9.4 200 4.8 4.500 4.130 4.750 3.500 68.0 74.7 62.0 66.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 234 6528 3381 12589 234 6528 ROP MWD010 FT/H 1.36 1031.92 160.082 12082 286.5 6528 GR MWD010 API 13.533 138.215 71.3188 12489 241 6485 RPX MWD010 OHMM 0.379 587.324 43.6117 12488 234 6477.5 RPS MWD010 OHMM 0.95 853.492 47.9154 12488 234 6477.5 RPM MWD010 OHMM 0.653 893.602 49.5413 12488 234 6477.5 RPD MWD010 OHMM 0.618 940.883 53.8346 12488 234 6477.5 FET MWD010 HOUR 0.27 3.29 1.31634 855 6050.5 6477.5 First Reading For Entire File......... .234 { ( Last Reading For Entire File.......... .6528 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/05 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...... .02/02/05 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 6478.0 6478.0 6478.0 6478.0 6478.0 6485.5 6528.5 # 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 VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 10524.5 10524.5 10524.5 10524.5 10524.5 10517.5 10569.5 31-AUG-01 Insite 66.16 Memory 10570.0 6528.0 10570.0 88.7 93.4 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02106HAGR4 PB02106HAGR4 # BOREHOLE AND CASING DATA (' OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O (' 6.750 3%KCL/POLY 9.30 45.0 9.0 14500 5.2 .280 .200 .240 .730 65.0 95.0 65.0 65.0 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 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6478 10569.5 8523.75 8184 6478 10569.5 ROP MWD020 FT/H 1 509.56 193.066 8083 6528.5 10569.5 GR MWD020 API 28.13 91.27 62.868 8065 6485.5 10517.5 RPX MWD020 OHMM 0.76 1563.01 29.0081 8094 6478 10524.5 RPS MWD020 OHMM 1.03 1563.36 41.2166 8094 6478 10524.5 RPM MWD020 OHMM 0.06 2000 54.6562 8094 6478 10524.5 RPD MWD020 OHMM 3.03 2000 65.1247 8094 6478 10524.5 FET MWD020 HOUR 0.2 95.71 1.78791 8094 6478 10524.5 First Reading For Entire File......... .6478 Last Reading For Entire File.......... .10569.5 ( File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/05 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................02/02/05 Origin...................STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Reel Trailer Service name............ .LISTPE Date.....................02/02/05 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File ( Scientific Technical Services Scientific Technical Services
