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202-061
Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760 fax Delivered to: n .� P# AOGCC ATTN: Natural Resources Technician II { Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 +yy Anchorage, AK 99501 20'1 3111_2 TRM- DATE 20 -Au -19 TRANSMITTAL N 20Au 19-JW02 SERVICE ORDER WELL NAME API q q SERVICE FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE Color DATE LOGGED Prints CD's --_--_-� �� Rel M \'1"•1 �1---- ' A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X xJ l package have been verified to match the media noted above. Pr t Sig atu Date The specific content of the CDs and/or hardco / py prints mayor may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy to Sch umberger and CPAI. point. Schlumberger -Private STATE OF ALAS ALA.OIL AND GAS CON ERVATION COMMIOON RECEIVED REPORT OF SUNDRY WELL OPERATIONS NOV 0 g 201 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operationsp� shutdown ElElPerformed: Suspend ❑ Perforate ❑ Other Stimulate Alter Casing❑ AMPc�lfcvp�Program ❑ Plug for Redrill El .erforate New Pool I=1 Repair Well IIIRe-enterSusp Well I=1 Other: d (rr++9h Packer ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development p Exploratory ❑ 202-061 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic Service ❑ 6.API Number: 99510 50-029-23076-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1 C-104 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 11,560 feet Plugs measured None feet true vertical 3,688 feet Junk measured None feet Effective Depth measured 11,560 feet Packer measured 2438, 7208 feet true vertical 3,688 feet true vertical 1772, 3718 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 113 feet 16 " 158'MD 158 TVD SURFACE 7,354 feet 7 5/8 " 7,395'MD 3741 TVD LINER B-SAND 4,342 feet 4"X 4.5" 11,550'MD 3689 TVD Perforation depth Measured depth 7446-11395 feet True Vertical depth 3746-3692 feet Tubing(size,grade,measured and true vertical depth) 4.5" L-80 6,268' MD 3, 451'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-VIKING FEED THROUGH PACKER 2,438' MD 1,772'TVD PACKER-BAKER MODEL SCR-1 PACKER 7,208 MD 3,718 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): None DEi 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 0 0 Subsequent to operation: Shut-in Shut-in Shut-in 20 225 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I] Exploratory ❑ Development 0 Service ❑ Stratigraphic El Copies of Logs and Surveys Run El 16.Well Status after work: Oil 0 Gas El WDSPL ❑ Printed and Electronic Fracture Stimulation Data El GSTOR ❑ WINJ ❑ WAG ❑ GINJ El 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: N/A Contact Name: Sara Heskin Authorized Name: Sara Heskin Contact Email: Sara.Heskin@cop.com Authorized Title: Assoc.Wells Engineer 9S / M 1 ) / I I Contact Phone: (907)265-1027 Authorized Signature: A- l 14-/ Date: I k7-1.— !7-/7//3 Form 10-404Revised 4/2017 (2./747 RBDIIS u_ NOV - _? 2017 Submit Original Only • • Operations Summary (with Timelog Depths) �� a 1C-104 t'hillip 'U 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(ftKE) 9/28/2017 9/28/2017 1.50 MIRU MOVE RURD P Remove bell nipple from BOPE.. Move 0.0 0.0 06:00 07:30 beaver slide to rig move position. Prep to skid rig floor. 9/28/2017 9/28/2017 0.50 MIRU MOVE RURD P PJSM-Skid rig floor to move position. 0.0 0.0 07:30 08:00 9/28/2017 9/28/2017 1.50 MIRU MOVE MOB P PJSM-Pull rig off 1J-137 and spot on 0.0 0.0 08:00 09:30 pad. 9/28/2017 9/28/2017 1.50 MIRU MOVE RURD P PJSM-Install BOPE on travel cradle. 0.0 0.0 09:30 11:00 Retract cuttings tank conveyer. 9/28/2017 9/28/2017 1.00 MIRU MOVE RURD P Install rear booster tires.Continue to 0.0 0.0 11:00 12:00 retract cuttings tank conveyer 9/28/2017 9/28/2017 1.00 MIRU MOVE RURD P Transport BOPE and rig equipment to 0.0 0.0 12:00 13:00 1D pad.Continue to retract cuttings tank conveyer 9/28/2017 9/28/2017 2.50 MIRU MOVE MOB P Move rig 1.3 miles down 1J access 0.0 0.0 13:00 15:30 road on single stack mats. 9/28/2017 9/28/2017 1.50 MIRU MOVE WAIT P Pick up and double stack mats behind 0.0 0.0 15:30 17:00 rig. 9/28/2017 9/28/2017 1.00 MIRU MOVE MOB P Move rig back onto double stack mats. 0.0 0.0 17:00 18:00 9/28/2017 9/28/2017 3.50 MIRU MOVE WAIT P Pick up and single stack mats in front 0.0 0.0 18:00 21:30 of rig. 9/28/2017 9/28/2017 1.50 MIRU MOVE MOB P Move rig.2 miles foward on single 0.0 0.0 21:30 23:00 stack mats. 9/28/2017 9/29/2017 1.00 MIRU MOVE WAIT P Pick up and double stack mats behind 0.0 0.0 23:00 00:00 rig. 11.0 hrs moving and shuffling mats 9/29/2017 9/29/2017 1.50 MIRU MOVE WAIT P Pick up and double stack mats behind 0.0 0.0 00:00 01:30 rig. 9/29/2017 9/29/2017 0.75 MIRU MOVE MOB P Move rig back onto double stack mats. 0.0 0.0 01:30 02:15 9/29/2017 9/29/2017 3.25 MIRU MOVE WAIT P Pick up and single stack mats in front 0.0 0.0 02:15 05:30 of rig. 9/29/2017 9/29/2017 1.00 MIRU MOVE MOB P Move rig.2 miles foward on single 0.0 0.0 05:30 06:30 stack mats on 1J access road. 9/29/2017 9/29/2017 1.75 MIRU MOVE WAIT P Pick up and double stack mats behind 0.0 0.0 06:30 08:15 rig.Made.8 miles from 15:30 hrs.on 9 -28-17 till 07:00hrs.on 9-29-17 9/29/2017 9/29/2017 0.75 MIRU MOVE MOB P Move rig back onto double stack mats. 0.0 0.0 08:15 09:00 9/29/2017 9/29/2017 2.25 MIRU MOVE WAIT P Pick up and single stack mats in front 0.0 0.0 09:00 11:15 of rig. 9/29/2017 9/29/2017 1.00 MIRU MOVE MOB P Move rig.2 miles foward on single 0.0 0.0 11:15 12:15 stack mats on 1J access road. 9/29/2017 9/29/2017 1.75 MIRU MOVE WAIT P Pick up and double stack mats behind 0.0 0.0 12:15 14:00 rig. 9/29/2017 9/29/2017 0.75 MIRU MOVE MOB P Move rig back onto double stack mats. 0.0 0.0 14:00 14:45 9/29/2017 9/29/2017 2.00 MIRU MOVE WAIT P Pick up and single stack mats in front 0.0 0.0 14:45 16:45 of rig. 9/29/2017 9/29/2017 1.00 MIRU MOVE MOB P Move rig.2 miles foward on single 0.0 0.0 16:45 17:45 stack mats on 1J access road. 9/29/2017 9/29/2017 2.50 MIRU MOVE WAIT P Pick up and double stack mats behind 0.0 0.0 17:45 20:15 rig. 9/29/2017 9/29/2017 0.50 MIRU MOVE MOB P Move rig back onto double stack mats. 0.0 0.0 20:15 20:45 Page 1/14 Report Printed: 11/1/2017 i • 01 Operations Summary (with Timelog Depths) 1C-104 ConocoPhiliips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time; End Time Dir(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftKE); 9/29/2017 9/30/2017 3.25 MIRU MOVE WAIT P Pick up and single stack mats in front 0.0 0.0 20:45 00:00 of rig. 24.0 hrs moving and shuffling mats/ 35 hrs Accum. 9/30/2017 9/30/2017 0.25 MIRU MOVE WAIT P Pick up and single stack mats in front 0.0 0.0 00:00 00:15 of rig. 9/30/2017 9/30/2017 0.75 MIRU MOVE MOB P Move rig.2 miles foward on single 0.0 0.0 00:15 01:00 stack mats on 1J access road. 9/30/2017 9/30/2017 2.50 MIRU MOVE WAIT P Pick up and double stack mats behind 0.0 0.0 01:00 03:30 rig. 9/30/2017 9/30/2017 0.50 MIRU MOVE MOB P Move rig back onto double stack mats. 0.0 0.0 03:30 04:00 9/30/2017 9/30/2017 3.50 MIRU MOVE WAIT P Pick up and single stack mats in front 0.0 0.0 04:00 07:30 of rig. 9/30/2017 9/30/2017 0.75 MIRU MOVE MOB P Move rig.2 miles foward on single 0.0 0.0 07:30 08:15 stack mats on 1J access road to 10 pad. 9/30/2017 9/30/2017 3.25 MIRU MOVE WAIT P Pick up and move mats from behind 0.0 0.0 08:15 11:30 rig and lay in front of rig.Sim- ops/Remove rear covers on mud pumps for gear end inspection. 9/30/2017 9/30/2017 0.50 MIRU MOVE MOB P Move rig .2 miles foward on single 0.0 0.0 11:30 12:00 stack mats on 1J access road to intersection of Spine road. 12.0 hrs moving and shuffling mats/ 47 hrs Accum. 9/30/2017 9/30/2017 3.00 MIRU MOVE MOB P Move rig 2.6 miles down Spine road to 0.0 0.0 12:00 15:00 KCC pad.Turn rig around at KCC pad. 12.0 hrs moving and shuffling mats/ 47 hrs Accum.for 3.2 miles 9/30/2017 9/30/2017 7.50 MIRU MOVE WAIT P Lay mats on KIC and 1C access 0.0 0.0 15:00 22:30 roads.. 12.0 hrs moving and shuffling mats/ 47 hrs Accum.for 3.2 miles Standby with rig while setting mats= 7.5 hrs 9/30/2017 10/1/2017 1.50 MIRU MOVE MOB P Move rig.8 miles from KCC pad to 1C 0.0 22:30 00:00 access road. 10/1/2017 10/1/2017 3.00 MIRU MOVE MOB P Move rig 1.6 miles down 1C access 0.0 0.0 00:00 03:00 road to 1C pad. 10/1/2017 10/1/2017 0.75 MIRU MOVE RURD P Remove rear booster wheels. 0.0 0.0 03:00 03:45 10/1/2017 10/1/2017 1.00 MIRU MOVE RURD P Set BOPE in cellar and install on 0.0 0.0 03:45 04:45 stump. 10/1/2017 10/1/2017 2.00 MIRU MOVE RURD P Remove front boosters and mounts. 0.0 0.0 04:45 06:45 Install stairs to boiler room. 10/1/2017 10/1/2017 0.50 MIRU MOVE MOB P Move rig off staging area mats and lay 0.0 0.0 06:45 07:15 mats for spotting over well. 10/1/2017 10/1/2017 1.50 MIRU MOVE MOB P Spot rig over 1C-104.Level and shim 0.0 0.0 07:15 08:45 rig. 10/1/2017 10/1/2017 1.00 MIRU MOVE RURD P PJSM-Skid rig floor to drilling position. 0.0 0.0 08:45 09:45 10/1/2017 10/1/2017 1.25 MIRU MOVE RURD P Rig up floor equipment.Hook up gas 0.0 0.0 09:45 11:00 buster line,choke line,air,water and steam lines below rig floor. Page 2/14 Report Printed: 11/1/2017 • • Operations Summary (with Timelog Depths) 1C-104 ConcooPhillips 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(ftKO)< 10/1/2017 10/1/2017 7.00 MIRU MOVE RURD P Rig up in cellar.Extend cuttings tank 0.0 0.0 11:00 18:00 drag chain.Prep pits to take on fluids/begin taking on 3%KCL 140° filtered fresh water.Assemble mud pumps after performing annual inspection. 10/1/2017 10/1/2017 1.00 MIRU MOVE SVRG P Fill mud pump#1 with oil.Rig up 0.0 0.0 18:00 19:00 hardline to flow back tanks. Accept rig at 19:00 hrs 10-1-17 10/1/2017 10/1/2017 1.50 MIRU WELCTL RURD P Take on 8.5 ppg 3%KCL 140°fresh 0.0 0.0 19:00 20:30 water. 10/1/2017 10/1/2017 1.00 MIRU WELCTL MPSP P Rig up lubricator and test to 2500 psi. 0.0 0.0 20:30 21:30 Pull BPV. Lay down lubricator. Tbg=200 psi. IA=220 psi. 10/1/2017 10/1/2017 0.75 MIRU WELCTL SEQP P PJSM-Test circ lines and hardline to 0.0 0.0 21:30 22:15 3000 psi. 10/1/2017 10/1/2017 1.25 MIRU WELCTL KLWL P Tbg=200 psi IA=220 psi.Bleed IA to 0.0 0.0 22:15 23:30 60 psi. NO gas back just clean diesel to flow back tanks.Bleed tbg down to 125 psi.Minimal gas mainly diesel to flow back tanks.Shut in and tbg pressure increased to 325 psi.and IA to 80 psi.Bleed IA from 80 psi to 50 psi.Tubing increased to 350 psi. Bleed tbg w/no change in pressure but IA increased to 200 psi getting diesel returns.Bleed total of 97 bbls diesel. 10/1/2017 10/2/2017 0.50 MIRU WELCTL OWFF P Monitor pressures.IA built to 210 psi 0.0 0.0 23:30 00:00 and tbg built to 375 psi.Consult with RWO engineer. 10/2/2017 10/2/2017 2.25 MIRU WELCTL KLWL P Reverse circulate 80 bbls of 8.5 ppg 0.0 0.0 00:00 02:15 140°F 3%KCL brine at 4 bpm at 500 FCP. Shut down pumps -TBG Psi= 200 and CSG Psi=40. Recovered 38 bbls of the 80 bbls pumped. Bull head 200 bbls down the TBG at 6 bpm at 1,150 psi,slow PR to 5 bpm at 940 psi. Shut down pump operation- Monitor SIP's 50 psi TBG fell to 20 psi and 60 psi CSG fell to 40 psi. Bleed back 5 bbls from TBG and pressure fell to zero and shut in-SITP gained 50 psi and SICP fell to 20 psi.in 15 minutes. Bleed back 9 bbls from TBG and shut in-SITP gained 80 psi and SICP stayed at 20 psi.in 15 minutes. 10/2/2017 10/2/2017 1.00 MIRU WELCTL OWFF P Monitor SIP's for 1 hr-SITP built to 0.0 0.0 02:15 03:15 100 psi,SICP stayed at 20 psi. Notified Town Engr. 10/2/2017 10/2/2017 1.25 MIRU WELCTL OWFF T SITP gained 50 psi to 150 PSI,SICP 0.0 0.0 03:15 04:30 remained at 20 PSI. -Bled TBG pressure to kill tank-14 bbls of Diesel/Crude was recovered in Kill Tank. SWI for 10 minutes-SITP=50 PSI ,SICP=20 PSI; SITP increased to 80 PSI-bled TBG back to Kill Tank -recovered 5 bbls. SWI. Page 3/14 Report Printed: 11/1/2017 s� • • Operations Summary (with Timelog Depths) ry 1C-104 ConocoPhilllps A,l:msk.a Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)' 10/2/2017 10/2/2017 1.00 MIRU WELCTL KLWL T Reverse Circulate 80 BBLS of 8.5 ppg 0.0 0.0 04:30 05:30 140°3%KCL Brine at 4 bpm at 580 FCP-recovered 27 BBLs at kill tank. Bull head 115 bbls down TBG at 5 BPM at 930 FCP. IA Pressure increased to 500 PSI. 10/2/2017 10/2/2017 1.00 MIRU WELCTL OWFF T Monitor SIP's 0.0 0.0 05:30 06:30 10/2/2017 10/2/2017 1.00 MIRU WELCTL KLWL T Bullhead 65 bbls of 140°3%KCL 0.0 0.0 06:30 07:30 Brine down the IA at 2 bpm at 170 ICP and 310 FCP. Bullhead 88 bbls down the TBG at 4 bpm at 610 psi. 10/2/2017 10/2/2017 1.50 MIRU WELCTL OWFF T Monitor pressure build and Load pits 0.0 0.0 07:30 09:00 with 8.6 ppg 3%KCL Brine 10/2/2017 10/2/2017 0.50 MIRU WELCTL KLWL T Bull head 120 bbls of 8.6 3%KCL at 4 0.0 0.0 09:00 09:30 bpm at 640 ICP and 730 FCP. 10/2/2017 10/2/2017 1.00 MIRU WELCTL OWFF T Monitor pressure 0.0 0.0 09:30 10:30 10/2/2017 10/2/2017 0.50 MIRU WELCTL OWFF T Bleed off IA pressure to 50 psi.3 bbls 0.0 0.0 10:30 11:00 bled back.Tbg=50 psi.8.2 ppg returns. 10/2/2017 10/2/2017 0.50 MIRU WELCTL OWFF T Monitor pressures.IA built to 70 psi. 0.0 0.0 11:00 11:30 Tbg built to 150 psi. 10/2/2017 10/2/2017 0.50 MIRU WELCTL OWFF T Bleed tbg to 70 psi. 0.0 0.0 11:30 12:00 10/2/2017 10/2/2017 1.00 MIRU WELCTL OWFF T Monitor pressures.IA built to 90 psi. 0.0 0.0 12:00 13:00 Tbg built to 160 psi. 10/2/2017 10/2/2017 0.50 MIRU WELCTL OWFF T Bleed off tbg and IA to 10 psi. 0.0 0.0 13:00 13:30 10/2/2017 10/2/2017 0.50 MIRU WELCTL OWFF T Monitor pressures.IA built to 70 psi. 0.0 0.0 13:30 14:00 Tbg built to 140 psi. 10/2/2017 10/2/2017 4.00 MIRU WELCTL SLKL T Rig up slickline.Test lubricator to 0.0 0.0 14:00 18:00 2500 psi. Rlh w/kick over tool to 1400' WLM.Unable to pass 1400'. POOH w/slickline.Add weight/roller bars. 10/2/2017 10/2/2017 1.00 MIRU WELCTL KLWL T Pump 171 bbls 8.6 ppg 3%KCL 0.0 0.0 18:00 19:00 seawater down IA taking returns to flow back tank.5 bpm,880 psi FCP. 50 bbls returned to tank. 10/2/2017 10/2/2017 1.25 MIRU WELCTL SLKL T Test lubricator to 2500 psi.RIH 0.0 0.0 19:00 20:15 w/kickover tool loaded with a DV to 2176'WLM.Sim-ops/Weight up surface volume to 8.9 ppg. 10/2/2017 10/2/2017 0.50 MIRU WELCTL COND T Continue to weight up surface volume 0.0 0.0 20:15 20:45 to 8.9 ppg.Tbg=80 psi IA=60 psi. 10/2/2017 10/2/2017 0.75 MIRU WELCTL KLWL T Bullhead 40 bbls 8.9 ppg 3%KCL 0.0 0.0 20:45 21:30 seawater down tbg at 1 bpm.Starting pressures tbg=80 psi IA=90 psi. Ending pressures tbg=100 psi IA=100 psi. 10/2/2017 10/2/2017 0.25 MIRU WELCTL KLWL T Bullhead 65 bbls 8.9 ppg 3%KCL 0.0 0.0 21:30 21:45 seawater down IA at 4 bpm.Starting pressure tbg/IA=100 psi.Ending pressure tbg=320 psi IA=390 psi. Shut down pump.Pressure stabilized at 200 psi on tbg and IA. Page 4/14 Report Printed: 11/1/2017 . . = Operations Summary (with Timelog Depths) 1C-104 rhiffips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(Er) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ttKS), 10/2/2017 10/2/2017 0.25 MIRU WELCTL SLKL T RIH w/slickline.Bullhead 28 bbls 8.9 0.0 0.0 21:45 22:00 ppg 3%KCL seawater down tbg at 2 bpm to assist slickline.Start pressures tbg=100 psi IA=90 psi.Ending pressures tbg=195 IA=150 psi 10/2/2017 10/2/2017 1.00 MIRU WELCTL SLKL T Locate GLM w/slickline.Attempt to set 0.0 0.0 22:00 23:00 DV in GLM at 2314'MD.Unable to set DV.POOH with slickline.Tbg=80 psi IA=40 psi. 10/2/2017 10/2/2017 0.50 MIRU WELCTL SLKL T Add knuckle joint and weight/roller 0.0 0.0 23:00 23:30 bar to toolstring.Test lubricator to 2500 psi. 10/2/2017 10/2/2017 0.25 MIRU WELCTL OWFF T Check for flow at wellhead.IA static. 0.0 0.0 23:30 23:45 Tbg flowed slight gas cap then crude oil. 10/2/2017 10/3/2017 0.25 MIRU WELCTL SLKL T RIH with slickline to 500'WLM. 0.0 0.0 23:45 00:00 10/3/2017 10/3/2017 1.75 MIRU WELCTL SLKL T RIH w/slickline from 500'to GLM at 0.0 0.0 00:00 01:45 2318'WLM.Attempt to locate on GLM.Unable to locate.Bullhead 96 bbls 8.9 ppg brine down tubing at 2-4 bpm to clean up DV profile.Starting pressures tbg=50 psi IA=0 psi.Ending pressure tbg=320 psi IA=275 psi. Unable to locate DV profile.POOH with slickline. 10/3/2017 10/3/2017 2.50 MIRU WELCTL SLKL T Change out long barrel kick over tool 0.0 0.0 01:45 04:15 to short barrel kick over tool.Test lubricator to 2500 psi.RIH w/slickline to GLM at 2318'WLM.Attempt to set DV.Bullhead 73 bbls 8.9 ppg brine down tbg to assist slickline.4 bpm. Starting pressure tbg=25 psi IA=20 psi.Ending pressure tbg=375 psi IA=325 psi..Pump 3 bbls 8.9 ppg brine down IA to check if DV is set.75 psi on tbg and 100 psi on IA.Continue to try to set DV. Pump 2 bbls 8.9 ppg brine down IA to check if DV is set.90 psi on tbg and 30 psi on IA.POOH w/slickline.DV still on kick over tool. 10/3/2017 10/3/2017 0.25 MIRU WELCTL OWFF T Bleed IA to flow back tank.3 bbls 8.8 0.0 0.0 04:15 04:30 ppg brine/crude mix.bled back. 10/3/2017 10/3/2017 0.75 MIRU WELCTL KLWL T Reverse circ 60 bbls 8.9 ppg 3%KCL 0.0 0.0 04:30 05:15 brine.4 bpm,200 psi.32 bbls returned to flow back tank.Bullhead 119 bbls 8.9 ppg 3%KCL brine down tbg at 7 bpm.tbg=740 psi IA=690 psi. 10/3/2017 10/3/2017 1.50 MIRU WELCTL OWFF T Monitor shut in pressures.Tbg=575 0.0 0.0' 05:15 06:45 psi IA=500 psi.Tbg bled to 100 psi and IA bled to 50 psi. 10/3/2017 10/3/2017 0.25 MIRU WELCTL SLKL T Make up and test lubricator to 2500 0.0 0.0 06:45 07:00 psi. 10/3/2017 10/3/2017 1.25 MIRU WELCTL OWFF T Monitor pressures.Tbg=75 psi IA=0 0.0 0.0 07:00 08:15 psi.Wait on LRS. 10/3/2017 10/3/2017 0.75 MIRU WELCTL RURD T Rig up LRS.Test lines to 2500 psi. 0.0 0.0 08:15 09:00 Page 5/14 Report Printed: 11/1/2017 .,., • • Operations Summary (with Timelog Depths) 0 1C-104 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depen Start Time End Time Our(hr) Phase Op Code Activity Code' Time P-T-X Operation (ftKB) End Depth MKS) 10/3/2017 10/3/2017 0.50 MIRU WELCTL SLKL T Bullhead 36 bbls diesel down tubing at 0.0 0.0 09:00 09:30 2 bpm while RIH w/slickline.Tbg=300 psi IA=125 psi.Set DV in GLM at 2315'WLM.Pressure up on IA to 800 psi tor verify DV set.Release from running tool and bleed pressur off IA to flow back tank. 10/3/2017 10/3/2017 0.25 MIRU WELCTL SLKL T POOH w/slickline while bullheading 14 0.0 0.0 09:30 09:45 bbls diesel down tbg at 2 bpm. Tbg=400 psi IA=0 psi. 10/3/2017 10/3/2017 1.00 MIRU WELCTL SLKL T Change out kick over tools.Test 0.0 0.0 09:45 10:45 lubricator to 2500 psi. RIH w/slickline to GLM at 2547'MD.Pull OV.POOH w/slickline.Tbg=275 psi IA=0 psi 10/3/2017 10/3/2017 2.50 MIRU WELCTL SLKL T Change out kick over tools.Test 0.0 0.0 10:45 13:15 lubricator to 2500 psi.RIH w/slickline to GLM at 2547'MD.Set DV.POOH w/slickline.Rig down slickline. Tbg=210 psi IA=0 psi 10/3/2017 10/3/2017 1.00 MIRU WELCTL OWFF T Bleed off tbg pressure in 5 min 0.0 0.0 13:15 14:15 increments monitoring for any pressure increase.At 150 psi pressure climbed to 160 psi. 10/3/2017 10/3/2017 0.50 MIRU WELCTL KLWL T Bullhead 115 bbls 8.9 ppg 3%KCL 0.0 0.0 14:15 14:45 brine down tbg at 5 bpm.Tbg=375 500 psi IA=0-125 psi. Pumps off/tbg=300 psi IA=125 psi. 10/3/2017 10/3/2017 1.00 MIRU WELCTL OWFF T Monitor pressures.Pressure stabilized 0.0 0.0 14:45 15:45 at 100 psi on tbg and 0 psi on IA. 10/3/2017 10/3/2017 1.50 MIRU WELCTL OWFF T Bleed off tbg to flow back tank. 0.0 0.0 15:45 17:15 Flowing back 6.8 ppg diesel/crude mix.Bleed back rate slowly decreased to 0.31 bbls flowed back. 10/3/2017 10/3/2017 1.75 MIRU WELCTL OWFF P Monitor well.Tbg and IA static. 0.0 0.0 17:15 19:00 10/3/2017 10/3/2017 0.25 MIRU WHDBOP MPSP P Install Type H BPV. 0.0 0.0 19:00 19:15 10/3/2017 10/3/2017 0.75 MIRU WHDBOP OTHR P Blow down and rig down circulating 0.0 0.0 19:15 20:00 lines. 10/3/2017 10/3/2017 1.75 MIRU WHDBOP NUND P Bleed pressure from hanger void.ND 0.0 0.0 20:00 21:45 tree.Sim-ops/Check and tighten LLDS.Test casing packoff to 5000 psi/15 min.Witnessed by CoMan 10/3/2017 10/3/2017 0.25 MIRU WHDBOP NUND T Clean top of hanger.Inspect hanger 0.0 0.0 21:45 22:00 threads.Good. Dummy penetrator is loose.Pack plastic packing around all three penetrators. Install test plug.NU spacer spool and BOPE. 10/3/2017 10/4/2017 2.00 MIRU WHDBOP NUND P Install test plug.NU spacer spool and 0.0 0.0 22:00 00:00 BOPE. 10/4/2017 10/4/2017 2.50 MIRU WHDBOP NUND P NU BOPE. Install choke line, 0.0 0.0 00:00 02:30 turnbuckles and riser.Torque up bolts. Install koomey lines and mouse holes. 10/4/2017 10/4/2017 1.00 MIRU WHDBOP RURD P Rig up to test BOPE.Function test 0.0 0.0 02:30 03:30 rams and annular preventer. 10/4/2017 10/4/2017 0.25 MIRU WHDBOP BOPE P Perform body test against blind rams. 0.0 0.0 03:30 03:45 Unable to hold pressure. No surface leaks detected. Page 6/14 Report Printed: 11/1/2017 • • 0 0 Operations Summary (with Timelog Depths) 1C-104 conoocci'hilaps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB), 10/4/2017 10/4/2017 0.25 MIRU WHDBOP BOPE T Pick up 4 1/2"test joint.Perform body 0.0 0.0 03:45 04:00 test against lower VBR's.Unable to hold pressure.No surface leaks detected and no fluid coming out of annulus valve. 10/4/2017 10/4/2017 0.75 MIRU WHDBOP BOPE T Lay down 4 1/2"test joint.Make up 0.0 0.0 04:00 04:45 Vetco blanking plug pulling tool. 10/4/2017 10/4/2017 0.25 MIRU WHDBOP BOPE T Body test against blind rams.Fluid 0.0 0.0 04:45 05:00 flowing out production valve on wellhead indicating blanking plug leaking. 10/4/2017 10/4/2017 0.75 MIRU WHDBOP BOPE T Pull blanking plug.Clean and inspect 0.0 0.0 05:00 05:45 plug profile.Pull test poppet. Reset blanking plug. 10/4/2017 10/4/2017 0.25 MIRU WHDBOP BOPE T Body test against blind rams.Fluid 0.0 0.0 05:45 06:00 flowing out production valve on wellhead. 10/4/2017 10/4/2017 4.00 MIRU WHDBOP BOPE T Pull blanking plug.Clean,inspect and 0.0 0.0 06:00 10:00 apply teflon tape to plug.Set plug and attempt to pressure up.Flow out of production valve at 500 psi.Pull plug. Check poppet,reapply teflon tape. Tighten plug on setting tool.Run in and set plug.Attempt to pressure up. Unsuccessful. 10/4/2017 10/4/2017 0.50 MIRU WHDBOP BOPE T Pull Type H BPV and set Type HP 0.0 0.0 10:00 10:30 BPV w/test dart. Perform body test 250/2500 psi 10/4/2017 10/4/2017 3.50 MIRU WHDBOP BOPE P Perform initial BOPE test.All tests 250 0.0 0.0 10:30 14:00 psi low/2500 psi high for 5 min each with 4 1/2"test joint.Test#1-Upper 2 7/8"x 5"VBR,CV's 1, 12,13,14 and valve 20.Test#2-Kill and choke HCR's.Test#3-Manual choke and kill valves.Test#4-Lower 3 1/2"x 6" VBR,4 1/2"IBT FOSV.Test#5- Annular CV's 9,11.Test#6-Blind rams,CV's 5,8,10,upper IBOP.Test #7-CV's 4,6,7, Lower IBOP. 10/4/2017 10/4/2017 0.50 MIRU WHDBOP SFTY P Suspend test operations.De-ice 0.0 0.0 14:00 14:30 derrick. 10/4/2017 10/4/2017 1.00 MIRU WHDBOP BOPE P Continue to test BOPE.Test#8-Valve 0.0 0.0 14:30 15:30 2 and 4"dart valve.Test#9-Valve 9 and 4"TIW valve.Test#10-Manual and hydraulic chokes. Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3000 psi Accumulator Pressure After Closer= 1700 psi Pressure Gain of 200 psi=42 seconds Full System=190 Seconds Average N2(6 Bottles)=2000 psi Test PVT,flow show and gas alarms. Test witness waived by AOGCC inspector Guy Cook. 10/4/2017 10/4/2017 0.50 MIRU WHDBOP RURD P Blow down lines and rig down test 0.0 0.0 15:30 16:00 equipment. Page 7/14 Report Printed: 11/1/2017 • Operations Summary (with Timelog Depths) c4tAv „�'� :' 1C-104 ConocoPhitlips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code'. Time P-T X Operation (ftK ) End Depth(ftKD); 10/4/2017 10/4/2017 0.50 MIRU WHDBOP MPSP P Pull BPV and set isolation sleeve. 0.0 0.0 16:00 16:30 10/4/2017 10/4/2017 0.50 COMPZN RPCOMP RURD P Make up landing joint.BOLDS. 0.0 6,041.0 16:30 17:00 10/4/2017 10/4/2017 0.50 COMPZN RPCOMP PULL P Close annular preventer.Unseat 6,041.0 6,036.0 17:00 17:30 hanger at 195K.Pull up and release packer at 145K. 10/4/2017 10/4/2017 2.25 COMPZN RPCOMP CIRC P Rig up to circulate to flow back tank. 6,036.0 6,036.0 17:30 19:45 Circulate 300 bbls 8.9 ppg 3%KCL brine down tubing taking returns to flow back tank. 8 bpm at 310 psi for 150 bbls,5 bpm at 210 psi for final 150 bbls. 133 bbls returned to tank 10/4/2017 10/4/2017 1.50 COMPZN RPCOMP OWFF P Monitor pressures.Tbg=90 psi IA=80 6,036.0 6,036.0 19:45 21:15 psi. Bleed 10 bbls from IA to flow back tank.Shut in IA.Bleed tbg to 0 psi/3 bbls.Shut in tbg. Bleed 9 bbls from IA to flow back tank to 0 psi. 10/4/2017 10/4/2017 0.50 COMPZN RPCOMP OWFF P Open annular preventer.Monitor well. 6,036.0 6,036.0 21:15 21:45 Fluid level slowly dropping in annulus w/gas breaking out. 10/4/2017 10/4/2017 0.25 COMPZN RPCOMP CIRC T Close annular preventer Circulate 40 6,036.0 6,036.0 21:45 22:00 bbls 8.9 ppg brine down tubing taking returns to flow back tank.22 bbls returned. 10/4/2017 10/4/2017 1.00 COMPZN RPCOMP OWFF T Monitor well at flow back tank.Slight 6,036.0 6,036.0 22:00 23:00 returns decreasing to none.Open annular. Fill hole.Monitor well.Slowly dropping.9 bph static loss rate. Blow down lines in cellar. 10/4/2017 10/5/2017 1.00 COMPZN RPCOMP RURD P Blow down choke and kill lines.Rig up 6,036.0 6,036.0 23:00 00:00 ESP sheave elephant trunk.String rope through trunk. 10/5/2017 10/5/2017 0.75 COMPZN RPCOMP PULL P Pull hanger to rig floor. PU=107K 6,036.0 6,011.0 00:00 00:45 50=72K.Remove ESP cable from penetrator and test.Remove dummy penetrators and ESP penetrator from hanger. 10/5/2017 10/5/2017 0.75 COMPZN RPCOMP PULL P Break out landing joint.Hanger to 6,011.0 6,011.0 00:45 01:30 tubing connection broke.Mobilize 8”x 11 1/4"tong heads to rig floor to back up hanger.Back out landing joint and lay down hanger. 10/5/2017 10/5/2017 0.75 COMPZN RPCOMP RURD P Send landing joint to pipe shed.Turn 6,011.0 6,011.0 01:30 02:15 around and pick up landing joint upside down.Break out 5'DP pup joint and x-o with power tongs.Lay down landing joint. 10/5/2017 10/5/2017 4.50 COMPZN RPCOMP PULL P POOH laying down 4 1/2"ESP 6,011.0 4,490.0 02:15 06:45 completion from 6011'MD to 4490' MD..Pump 5 bbls 8.9 ppg 3%KCL brine in hole every 1/2 hr. 10/5/2017 10/5/2017 1.00 COMPZN RPCOMP CIRC P Attempt to rock out oil cap.Pump 5 4,490.0 4,490.0 06:45 07:45 bbls 8.9 ppg brine down IA at 1.5 bpm. Pressured up to 650 psi.Unable to pump.Circulate 15 bbls 809 ppg brine down tubing taking returns to flow back tank. 10/5/2017 10/5/2017 0.50 COMPZN RPCOMP PULL P POOH laying down 4 1/2"ESP 4,490.0 4,000.0 07:45 08:15 completion from 4490'MD to 4000' MD..Pump 5 bbls 8.9 ppg 3%KCL brine in hole every 1/2 hr. Page 8/14 Report Printed: 11/1/2017 • Operations Summary (with Timelog Depths) 1C-104 CcoricK0Phillips ,. 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(itKB); 10/5/2017 10/5/2017 0.50 COMPZN RPCOMP SFTY P De-ice derrick. 4,000.0 4,000.0 08:15 08:45 10/5/2017 10/5/2017 0.25 COMPZN RPCOMP PULL P POOH laying down 4 1/2"ESP 4,000.0 3,608.0 08:45 09:00 completion from 4000'MD to 3608' MD..Pump 5 bbls 8.9 ppg 3%KCL brine in hole every 1/2 hr. 10/5/2017 10/5/2017 0.75 COMPZN RPCOMP PULL P Lay down packer and splice ESP 3,608.0 3,608.0 09:00 09:45 cable. 10/5/2017 10/5/2017 6.75 COMPZN RPCOMP PULL P POOH laying down 4 1/2"ESP 3,608.0 110.0 09:45 16:30 completion from 3608'MD to 110'MD. Lay down discharge pressure sub, Pump 5 bbls 8.9 ppg 3%KCL brine in hole every 1/2 hr. 10/5/2017 10/5/2017 2.75 COMPZN RPCOMP ALFT P Lay down lower completion(seals and 110.0 0.0 16:30 19:15 motor and gauge assy). Pump 5 bbls 8.9 ppg 3%KCL brine in hole every 1/2 hr. Recover 107 Cannon clamps and 13 SS bands. 10/5/2017 10/5/2017 2.00 COMPZN RPCOMP RURD P Rig down Centrilift sheave and 0.0 0.0 19:15 21:15 elephant trunk.Rig up Access sheave and string motor lead through sheave. 10/5/2017 10/6/2017 2.75 COMPZN RPCOMP ALFT P Perform motor lead splice.Sim- 0.0 0.0 21:15 00:00 ops/Clear floor of old Cannon clamps, mobilize new clamps and TEC wire spooler to rig floor. 10/6/2017 10/6/20171.25 COMPZN RPCOMP PUTB P PU,MUtally and RIHnular with ESP completion 0.0 156.0 per 00:00 01:15 to anconnection port. 10/6/2017 10/6/2017 1.00 COMPZN RPCOMP ALFT P MU the motor lead to the annular 156.0 156.0 01:15 02:15 connection port. Perform electrical checks on the ESP cable and motor lead(good test on both). 10/6/2017 10/6/2017 2.00 COMPZN RPCOMP ALFT P Continue to RIH with ESP completion 156.0 256.0 02:15 04:15 per tally to the gauge carrier.MU the SureSENS gauge to the gauge mandrel. Perform electrical checks on the Tec wire(good test). 10/6/2017 10/6/2017 1.75 COMPZN RPCOMP PUTB P RIH picking up 1/2"12.6#L-80 256.0 1,001.0 04:15 06:00 IBTM ESP comp4letion from 256'MD to 1001'MD.Install dual channel Grippy clamps each connection.Pump 5 bbls 8.9 ppg brine in hole every 1/2 hr. 10/6/2017 10/6/2017 1.75 COMPZN RPCOMP ALFT P PJSM-Rig up slickline. 1,001.0 1,001.0 06:00 07:45 10/6/2017 10/6/2017 1.00 COMPZN RPCOMP ALFT P RIH w/3.83 drift on slickline.Could not 1,001.0 1,001.0 07:45 08:45 drift past 675'WLM.Rig down slickline.Pump 5 bbls 8.9 ppg brine in hole every 1/2 hr. 10/6/2017 10/6/2017 0.25 COMPZN RPCOMP RURD T Rig up power tongs. 1,001.0 1,001.0 08:45 09:00 10/6/2017 10/6/2017 1.00 COMPZN RPCOMP PULL T POOH laying down tubing from 1001" 1,001.0 377.0 09:00 10:00 MD to 377'MD.Pump 5 bbls 8.9 ppg brine in hole every 1/2 hr. 10/6/2017 10/6/2017 1.00 COMPZN RPCOMP ALFT T Rig up slickline and run 3.83"drift to 377.0 377.0 10:00 11:00 no-go.POOH and make up brush. RIH and brush to no-go. Page 9/14 Report Printed: 11/1/2017 • • , Operations Summary (with Timelog Depths) AN 1 C-104 hiHi Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Gude Activity Dade Tim*P-T-X Operation (MKS) End Depth(ftK6) 10/6/2017 10/6/2017 2.75 COMPZN RPCOMP ALFT T Pick up motor assy w/slickline and 377.0 377.0 11:00 13:45 RIH.Unable to pass 40'WLM.No success getting motor assy past GLM. POOH and rig down slickline. 10/6/2017 10/6/2017 0.50 COMPZN RPCOMP PULL T Rig up and lay down joint#4 and 377.0 308.0 13:45 14:15 GLM. 10/6/2017 10/6/2017 0.75 COMPZN RPCOMP ALFT T Rig up slickline.Pick up motor assy 308.0 308.0 14:15 15:00 w/slickline and RIH.Unable to pass 8' WLM.Plug arm assy hanging up. POOH w/slickline. 10/6/2017 10/6/2017 1.00 COMPZN RPCOMP ALFT T Trouble shoot motor plug arm assy. 308.0 308.0 15:00 16:00 10/6/2017 10/6/2017 1.00 COMPZN RPCOMP ALFT T Drain oil from seals. Lay down motor 308.0 308.0 16:00 17:00 and seal assy. 10/6/2017 10/6/2017 4.50 COMPZN RPCOMP WAIT T Prepare back up motor to RIH. 308.0 308.0 17:00 21:30 Mobilize KBG-2 GLM's from Deadhorse.Pump 5 bbls 8.9 ppg brine in hole every 1/2 hr.Perform housekeeping throughout rig. 10/6/2017 10/6/2017 0.50 COMPZN RPCOMP RURD T Rig down slickline.Load and strap 308.0 308.0 21:30 22:00 GLM's in pipeshed. 10/6/2017 10/6/2017 1.00 COMPZN RPCOMP PUTB T RIH picking up 4 1/2"12.6#L-80 308.0 751.0 22:00 23:00 IBTM ESP completion from 308'MD to 751'MD. Install dual channel Grippy clamps each connection. Pump 5 bbls 8.9 ppg brine in hole every 1/2 hr. 10/6/2017 10/6/2017 0.50 COMPZN RPCOMP RURD T Rig power surging spooling unit and 751.0 751.0 23:00 23:30 tripping out VFD.Swap spooler to gen power. 10/6/2017 10/7/2017 0.50 COMPZN RPCOMP PUTB T RIH picking up 4 1/2"12.6#L-80 751.0 1,001.0 23:30 00:00 IBTM ESP completion from 751'MD to 1001'MD. Install dual channel Grippy clamps each connection.Pump 5 bbls 8.9 ppg brine in hole every 1/2 hr. 10/7/2017 10/7/2017 1.00 COMPZN RPCOMP ALFT T Rig up slickline. 1,001.0 1,001.0 00:00 01:00 10/7/2017 10/7/2017 1.00 COMPZN RPCOMP ALFT T RIH w/3.83 drift on slickline.Could not 1,001.0 1,001.0 01:00 02:00 drift past 675'WLM.POOH w/slickline. Pump 5 bbls 8.9 ppg brine in hole every 1/2 hr. 10/7/2017 10/7/2017 0.50 COMPZN RPCOMP SLKL T Lay down 3.83"drift.Change out 1,001.0 1,001.0 02:00 02:30 toolstring to 3.84"swage.RIH w/slickline through GLM to 725'WLM. Work swage through GLM.POOH w/slickline. 10/7/2017 10/7/2017 0.75 COMPZN RPCOMP ALFT P RIH w/3.83 drift on slickline to no-go at 1,001.0 1,001.0 02:30 03:15 939'WLM.Bobble observed while passing through GLM.POOH w/slickline. Pump 5 bbls 8.9 ppg brine in hole every 1/2 hr. 10/7/2017 10/7/2017 2.00 COMPZN RPCOMP ALFT P Pick up motor/seal assy.Service seal 1,001.0 1,001.0 03:15 05:15 assy.Upon inspection threads in drain plug port in lower seal section were damaged. 10/7/2017 10/7/2017 1.25 COMPZN RPCOMP ALFT T Lay down motor/seal assy to pipe 1,001.0 1,001.0 05:15 06:30 shed.Change out lower seal section. 10/7/2017 10/7/2017 1.00 COMPZN RPCOMP ALFT T PJSM-Pick up motor/seal assy. 1,001.0 1,001.0 06:30 07:30 Service seals. Page 10/14 Report Printed: 11/1/2017 • • Operations Summary (with Timelog Depths) 1C-104 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(itKS) 10/7/2017 10/7/2017 2.00 COMPZN RPCOMP ALFT P Rig up slickline.Make up to motor/seal 1,001.0 1,001.0 07:30 09:30 assy.RIH w/motor/seal assy on slickline to no-go.Set motor/seal assy as per Access rep. 10/7/2017 10/7/2017 0.50 COMPZN RPCOMP ALFT T Attempt to release from motor/seal 1,001.0 1,001.0 09:30 10:00 assy.Pump 4 bpm down tubing to assist release of GS tool. .Unable to release from motor/seal assy.POOH w/motor/seal assy on slickline. 10/7/2017 10/7/2017 0.50 COMPZN RPCOMP ALFT T Rebuild GS tool.Add 5'weight bar 1,001.0 1,001.0 10:00 10:30 and change out steel shear pin for brass pin.Sim-ops/Redress motor plug arm. 10/7/2017 10/7/2017 0.50 COMPZN RPCOMP ALFT T RIH with motor/seal assemble to no- 1,001.0 1,001.0 10:30 11:00 go. Deploy the wet connect and engage the wet connect onto the annular connection port(good electrical readings). Shear off and POOH. 10/7/2017 10/7/2017 1.25 COMPZN RPCOMP ALFT P PU and MU the pump assembly. 1,001.0 1,001.0 11:00 12:15 Lower into the well and connect the GS running tool. 10/7/2017 10/7/2017 1.25 COMPZN RPCOMP ALFT P RIH with the pump,set the pump and 1,001.0 1,001.0 12:15 13:30 POOH. 10/7/2017 10/7/2017 0.50 COMPZN RPCOMP ALFT P PU,MU and RIH with pack off 1,001.0 1,001.0 13:30 14:00 assembly. Set the pack off and POOH. 10/7/2017 10/7/2017 0.50 COMPZN RPCOMP PRTS P RU pressure testing equipment. PT 1,001.0 1,001.0 14:00 14:30 the pack off to 1500 psi for 10 minutes (good test). RD pressure testing equipment. 10/7/2017 10/7/2017 0.50 COMPZN RPCOMP ALFT P PU,MU and RIH with the tubing stop. 1,001.0 1,001.0 14:30 15:00 Install the tubing stop on top of the pack off. POOH. Rig down slickline. 10/7/2017 10/7/2017 1.50 COMPZN RPCOMP PUTB P RIH w/4-1/2", 12.6#,L-80 IBTM,ESP 1,001.0 2,032.0 15:00 16:30 completion from 1001'MD to 2032' MD..Install dual channel Grippy clamps each connection. Filling hole at 10 bph-Test ESP andTec wire every 1,000-ft. 10/7/2017 10/7/2017 1.00 COMPZN RPCOMP ALFT P RU Slick line and RIH w/3.830"OD x 2,032.0 2,032.0 16:30 17:30 6"Drift on bottom of 3.80"OD x 10-ft Drift bar to 1100'WLM POOH and lay down Slickline.Test ESP cable and TEC wire. 10/7/2017 10/7/2017 2.00 COMPZN RPCOMP PUTB P RIH w/4-1/2", 12.6#,L-80 IBTM,ESP 2,032.0 3,039.0 17:30 19:30 completion from 2032'MD to 3039' MD. Install dual channel Grippy clamps each connection. Filling hole at 10 bph-Test ESP andTec wire every 1,000-ft. 10/7/2017 10/7/2017 1.00 COMPZN RPCOMP ALFT P RU Slick line and RIH w/3.830"OD x 3,039.0 3,039.0 19:30 20:30 6"Drift on bottom of 3.80"OD x 10-ft Drift bar to 1100'WLM POOH and lay down Slickline.Test ESP cable and TEC wire. Page 11/14 Report Printed: 11/1/2017 • • Operations Summary (with Timelog Depths) Pta_ 1C-104 itc Conocceh ititps 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(ftKD)'. 10/7/2017 10/7/2017 1.50 COMPZN RPCOMP PUTB P RIH w/4-1/2", 12.6#,L-80 IBTM,ESP 3,039.0 3,777.0 20:30 22:00 completion from 3039'MD to 3777' MD. Install dual channel Grippy clamps each connection. Filling hole at 10 bph-Test ESP andTec wire every 1,000-ft. 10/7/2017 10/7/2017 1.00 COMPZN RPCOMP ALFT P RU Slick line and RIH w/3.830"OD x 3,777.0 3,777.0 22:00 23:00 6"Drift on bottom of 3.80"OD x 10-ft Drift bar to 850'WLM POOH and lay down Slickline.Test ESP cable and TEC wire. 10/7/2017 10/7/2017 0.25 COMPZN RPCOMP PUTB P Pick up joints#86 w/pre-installed 3,777.0 3,897.0 23:00 23:15 WRP,#87 and#88 from 3777'MD to 3897'MD. 10/7/2017 10/7/2017 0.50 COMPZN RPCOMP MPSP P Rig up and test WRP to 4200 psi/10 3,897.0 3,897.0 23:15 23:45 mins.Rig down test equipment. 10/7/2017 10/8/2017 0.25 COMPZN RPCOMP PULL P POOH laying down joints#88 and#87 3,897.0 3,819.0 23:45 00:00 from 3897'MD to 3819'MD. 10/8/2017 10/8/2017 0.50 COMPZN RPCOMP ALFT P Make up Viking Feedthrough Packer. 3,819.0 3,819.0 00:00 00:30 Packer installed w/5 shear screws at 843 psi each for a setting pressure of 4215 psi and 19 pull to release shear pins at 3187K each for a pull release of 60,553K 10/8/2017 10/8/2017 4.50 COMPZN RPCOMP ALFT P Perform through hanger splice on ESP 3,819.0 3,819.0 00:30 05:00 cable and TEC wire. 10/8/2017 10/8/2017 0.50 COMPZN RPCOMP ALFT P Test ESP cable and TEC wire.Sim- 3,819.0 3,819.0 05:00 05:30 ops/Rig up slickline and set junk catcher on top of WRP.Rig down slickline. 10/8/2017 10/8/2017 1.75 COMPZN RPCOMP PUTB P RIH w/4-1/2", 12.6#,L-80 IBTM,ESP 3,819.0 4,885.0 05:30 07:15 completion from 3819'MD to 4885' MD. Install dual channel Grippy clamps each connection. Filling hole at 10 bph-Test ESP andTec wire every 1,000-ft. 10/8/2017 10/8/2017 0.75 COMPZN RPCOMP ALFT P RU Slick line and RIH w/3.830"OD x 4,885.0 4,885.0 07:15 08:00 6"Drift on bottom of 3.80"OD x 10-ft Drift bar to 1100'WLM POOH and lay down Slickline.Test ESP cable and TEC wire. 10/8/2017 10/8/2017 2.25 COMPZN RPCOMP PUTB P RIH w/4-1/2", 12.6#,L-80 IBTM, ESP 4,885.0 6,202.0 08:00 10:15 completion from 4885'MD to 6202' MD.Install single channel Grippy clamps each connection. Filling hole at 10 bph-Test ESP andTec wire every 1,000-ft. 10/8/2017 10/8/2017 1.50 COMPZN RPCOMP ALFT P RU Slick line and RIH w/3.830"OD x 6,202.0 6,202.0 10:15 11:45 6"Drift on bottom of 3.80"OD x 10-ft Drift bar.Could not drift past 233' WLM.POOH and make up 3.85" gauge ring. RIH w/gauge ring to 1500' WLM.POOH and make up 3.83"drift assy.RIH and drift to 1500'WLM.Lay down slickline.Test ESP cable and TEC wire. 10/8/2017 10/8/2017 0.75 COMPZN RPCOMP THGR P PJSM-Pick up tubing hanger and 6,202.0 6,232.0 11:45 12:30 landing joint.PU=105K SO=62K Ran 120 dual channel Grippy clamps and 41 single channel Grippy clamps. No remakes,no rejects. Page 12/14 Report Printed: 11/1/2017 II r Operations Summary (with Timelog Depths) 1C-104 tylv ConocoPhitlips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth MKS) 10/8/2017 10/8/2017 3.00 COMPZN RPCOMP ALFT P Install penetrator in hanger. Perform 6,232.0 6,232.0 12:30 15:30 hanger splice on ESP cable and terminate TEC wire.Perform electrical integrity checks on ESP cable and TEC wire. 10/8/2017 10/8/2017 0.50 COMPZN RPCOMP THGR P Land hanger.RILDS.Sim-ops/Rig up 6,232.0 6,268.0 15:30 16:00 slickline.RIH w/3.830"OD x 6"Drift on bottom of 3.80"OD x 10-ft Drift bar to 100'WLM. 10/8/2017 10/8/2017 0.50 COMPZN RPCOMP RURD P Lay down landing joint.Rig down 6,268.0 0.0 16:00 16:30 slickline. 10/8/2017 10/8/2017 0.50 COMPZN WHDBOP MPSP P Set TWC.Sim-ops/Lay down ESP line 0.0 0.0 16:30 17:00 over windwall. 10/8/2017 10/8/2017 1.00 COMPZN WHDBOP NUND P Pull mousehole and riser.Nipple down 0.0 0.0 17:00 18:00 BOPE and secure on pedestal. 10/8/2017 10/8/2017 2.00 COMPZN WHDBOP NUND P Clean up wellhead.Prep hanger and 0.0 0.0 18:00 20:00 TEC wire.Nipple up tree.Sim- ops/Clear rig floor tools/equipment. Remove ESP and TEC wire sheaves from derrick.Clean containment in front of spooling unit.Clean pits. 10/8/2017 10/8/2017 1.00 COMPZN WHDBOP ALFT P Centrilift/Access perform final 0.0 0.0 20:00 21:00 electrical integrity tests on ESP line. Baker terminate and test TEC wire line. 10/8/2017 10/8/2017 1.00 COMPZN WHDBOP PRTS P Test hanger void and seals to 0.0 0.0 21:00 22:00 250/5000 psi. 15 min's each. Witnessed by Co Man.Sim-ops/Rig up circ lines in cellar. 10/8/2017 10/8/2017 1.50 COMPZN WHDBOP PRTS P Rig up and test tree w/diesel to 0.0 0.0 22:00 23:30 250/5000 psi.5 min's each.Rig down test equipment. 10/8/2017 10/9/2017 0.50 COMPZN WHDBOP CRIH P Continue to rig up circ lines in cellar. 0.0 0.0 23:30 00:00 10/9/2017 10/9/2017 1.50 COMPZN WHDBOP SEQP P PJSM with LRS-PT lines fluid pack 0.0 0.0 00:00 01:30 lines to the kill tank to 2,500 psi- Good test,suck back lines and blow down. 10/9/2017 10/9/2017 0.50 COMPZN WHDBOP MPSP P Pull TWC,Zero pressure on the TBG 0.0 0.0 01:30 02:00 10/9/2017 10/9/2017 1.00 COMPZN WHDBOP FRZP P Load TBG with 37 bbls of diesel while 0.0 0.0 02:00 03:00 allowing to escape to the kill tank while pumping at.625 bpm at 100 psi. 10/9/2017 10/9/2017 1.50 COMPZN WHDBOP CIRC P Pressure test mud lines to 1,000 psi- 0.0 0.0 03:00 04:30 Good test. Line up and pump 100 bbls of 3 micron filtered CI 3%KCL 8.9 ppg brine down the IA at 2 bpm at 50 psi. 10/9/2017 10/9/2017 1.00 COMPZN WHDBOP CIRC P RU LRS to the IA. Pump 64 bbls of 0.0 0.0 04:30 05:30 diesel FP down the IA at 2 bpm at 100 psi,after 10 bbls the pressure increased to 180 psi,after 33 bbls pressure increased to 250 psi-slowed PR to 1.5 bpm and at 41 bbls away pressure increased to 281 psi-slowed PR to 1 bpm at 280 psi. Shut down pump and RD LRS after pumping a total for 64 bbls. Page 13/14 Report Printed: 11/1/2017 S • Operations Summary (with Timelog Depths) 04. tir 1C-104 ConacciPhillips 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 (ftK8) End Depth(ftK6)> 10/9/2017 10/9/2017 1.50 COMPZN WHDBOP PACK P RU LRS to the TBG and PT lines to 0.0 0.0 05:30 07:00 4,500 psi-Begin setting packer,pop off tripped,reset and continue to set packer by pressuring up to 4,500 psi with 2 bbls pumped against WRP set at 2,466-ft-hold for 15 minutes. Bleed off to Zero. 10/9/2017 10/9/2017 3.00 COMPZN WHDBOP PRTS P Pressure test TBG to 4,000 psi-seen 0.0 0.0 07:00 10:00 WRP move down hole while pressuring up on the TBG,then regained pressure increase to 4,400 psi-Shut down and close in to the sensor and monitor the TBG pressure via the chart recorder-TBG pressure slowly bled off from 4,400 psi to 4,000 psi in 18 minutes,4,000 to 3,800 psi in 30 minutes and 3,800 psi to 3,680 psi±in 30 minutes. Bleed TBG pressure to 2,000 psi and Pressure up on the is-Note-seen TBG pressure increase 200 psi prior to pressuring up on the IA -(200 psi increase was the psi differential below plug resurfacing). Continue to pressure up on the IA to 2,000 psi and shut in LRS,TBG pressure increased to 2,700 psi and held steady IA showed to have air in system,bumped pressure back up and finished Integrity test-all good, dump TBG and shear out SOV. Allow TBG to continue to bleed off plug differential-recovered 1.8 bbls. 10/9/2017 10/9/2017 0.50 COMPZN WHDBOP MPSP P Install Type H BPV via dry rod. 0.0 0.0 10:00 10:30 10/9/2017 10/9/2017 0.50 DEMOB MOVE RURD P Dress tree and Secure well 0.0 10:30 11:00 Release Doyon 14 at 11:00 hrs on 10- 9-17 Page 14/14 Report Printed: 11/1/2017 0 KUP PROD • 1C-104 ConocoPhillips a'< Well Attributes Max Angle&MD TD Alaska inc. ellbore API/UWI Field Name Wellbore Status n ) MD MKS) Act atm(ftKB) 5 `may„� ' 500292307600 WEST SAK PROD Jcl(`94.81 7,654.89 11,560.0 --- Comment Comment N2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-104,1072017 11,06 30 AM SSSV:NONE 10 2/4/2016 Last WO: 10/9/2017 45.16 7/29/2002 Vertical schemaVc(aclu90 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 6,055.0 11/8/2013 Rev Reason'WORKOVER-Rigless ESP pproven 11/7/2017 w/Feedthrough,PULL Catcher+WRP 8 GLV C/O ,IANGER:35.1- 4%4 ;1 Casing Strings Casing Descrlptlon 00(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I..Grade Top Thread CONDUCTOR 16 15.062 45.2 158.0 1580 62.50 H-40 WELDED Casing Description OD(In) ID(In) Top(ft(B) Set Depth(ftKB) Set Depth(TVD).. Wt/Len(I..Grade Top Thread SURFACE 75/8 6.875 41.3 7,395.1 3,740.7 29.70 L-80 BTCM ... , :. ....,, .. , ..Casing Deecrlptlen OD(In) ID(in) Top MKS) Set Depth(ft88) Set Depth(TVD)...WRLen(I...Grade Top Thread III • WINDOW L1 65/8 6.000 7,014.0 7.044.0 3,681.2 to 1C-104L1 Casing Description OD(In) ID(in) Top(ftKB) Set Depth(1tK8) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;45 2-158.0 '' LINER B-SAN) 4 1)2 4.000 7,208.3 11,550.0 3,688.5 12.60 L-80 SLHT Liner Details li Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) item Des Com (In) 7,208.3 3.718.4 79.34 PACKER BAKER MODEL'SCR-1'PACKER 3.958 GAS LIFT'.2,369.9 7,213.1 3,719.3 79.59.MILLOUT EXT BAKER MILLOUT EXTENSION 3.958 7215.9' 3,719.8 79.73-VALVE BAKER KOIV MODEL'C' 4.276 7,256.1 3,725.9 82.86 SLEEVE BAKER MODEL CMD SLIDING SLEEVE 4.540 PACKER,2437.0 ,- 7.289.5 3.729,6 84.03 SCREEN EXCLUDER 2000 SCREEN 4.000 I Tubing Strings Tubing Description String Ma...ID(in) Top(1003) Set Depth(ft...Set Depth(TVD)(...Wt(ISM Grade Top Connection 201/RWO-Rigless 41/2 3.958 35.1 6,268.5 3,4514 12.60 L-80 IBT-M ESP Completion GAS LIFT;2,544.3 Completion Details I I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (In) 35.1 35.1 0.03 HANGER Tubing Hanger,Vetco-Gtay MB222A 10 314 x 4 12 3.900 GAS LIFT',5 913 5 l... w/false bowl,Vetco Gray Gen 11 TBG Hanger was modified to MB222A-Excepts 4.909'MCA Landing Jt w/ I long nose-ONLY 2,437.8 1,772.1 61.76 PACKER Viking Feed Through Packer SN:VCT-P0-17-331-1 TVD 3.902 I -1774-ft 6,011.5 3,350.7 66.44 Gauge/Pump Baker SureSENS Gauge TVD-3352-ft 3.938 Gauge/Pump Sensor,8,011.5 Sensor 6,079.2 3,377,4 66.90 Sliding Sleeve Gas Venting Sliding Sleeve CMD,3.875"X Profile. 3.900 -CMD Access(Cloned) 6,101.6 3,386.2 66.94 Sliding Sleeve Gas Venting Sliding Sleeve CMU,3.875"X Profile. 3.900 -CMU Access(Open)TVD-3387-ft 6,112.1 3,390.3 66.96 Motor Motor Shroud/Centralizer,Access,5-7/2"FJL Pin x 5- 4,900 Stang Sleeve-CMD,6.0792 MI Shroud/Centra 1/7 FJL Pin !tzar 6,148.3 3,404.4 67.03 Annular Annular Connection Port,Access,5-1/2"FJL Box 4-1/7' 3.840 slang sleeve-cmu s,tots - Connection yam Top Pin Port XO Enlarg,ng(Tubing),9.109.1 +i Motor ShrousCenlretzer; 6,185.2- 3,418.9 66.99 Profile Sub 8-Profile Sub,Access,4-1/7.12.6#.L-80.IBT Boxx Box 3.956 6,112.1 i-_; ) Annular Connection Pot 8,148.3 'dm, 6,205.6 3,426.8 66.98 No-Go 3.80" No-Go 3.80"Sub,Access,4-1/2,12.611,L-80,TXP Box 3.800 Sub Pin Profile Sub,9,1852 ir Perforations&Slots I Shot Dens Ne-Go 3.80"Sub:6205.6 Top(TVD) 81m(TVD) (shots/f I Top(NKK) atm MKS) ' (ftKB) (ftKB) Zone Date t) Type Com 7.446.0 11.395.0 3,745.7 3,691.6 WS B,1C-104 7/282002 50.0 SLOTS Peds thru 37'screens every 31'alternating with Mule Shoe Pup Joint,62587 -/ solid liner-CMT SQZ'd • 9994-11381 on 7/28/2013 w/WORKOVER LINER 19-SAND;7,099.2- 11.3800 11.381.0 3,692.1 3,692.0 WS B,1C-104 7/25/2011 6.0 IPERF CMT SOZ'd 7/28/2013 17.514.2 WANORKOVER WINDOW L1;7,014.07.044.0 i Cement Squeezes Top(TVD) atm(TVD) Top(MB) Btm(ROB) (ORB) (SOB) Des Start Date Corn 9,994.0 11,514.0 3.702.5- 3,688.9 CMT SOZ 7/28/2011 PERFS SQZ'd w/2011 WORKOVER Mandrel Inserts 1 St all On Top(TVO) Valve Latch Pon Size TRO Run N Top(ftKB) (RKB) Make Model OD(In) Sera Type (In) (psi) Run Date Com 1 2,369.9 1,741.0 CAMCO KBG2 1 GAS LIFT OMY BEK 0.000 0.0 10/14/2017 49 2 2,544.3 1,822.2 CAMCO KBG2 1 GAS LIFT OV BK 0.250 0.0 10/14/2017- 3 5,943.5 3,323.1 CAMCO KBG2 1 GAS LIFT SOV BK 0.000 0.0 10/14/2017 20170# TBG Notes:General&Safety End Date Annotation 9/10/2005 NOTE:WORKOVER SURFACE,4167,395.1 10/25/2007 NOTE:WORKOVER _.. 7292008 NOTE:MULTI-LATERAL WELL:B-SAND(1C-104),D-SAND(1C-104L1) SLOTS:7,x46.&11,385.0 S 10/11/2008 NOTE:View Schematic w/Alaska Schematic9.0 CMT SQZ:9,99x.0060 iti' IJ, ' ,:',- 7/3/2011 NOTE:WORKOVER !PERF;11,3808-11.381.0 3( rt 727/2011 NOTE:CEMENT FROM 9994'TO 11493' Y 1/22/2014 NOTE.WORKOVER L :; 10/92017 NOTE:WORKOVER-Rigless ESP w/Feedthrough Packer ie hi 3 3 LINER&SAND',7.208.3- , �l 11,550.0 C9 • v O 6' S > Cv r x a O O - p > O CJ WCW N _C O 1 _ I CO 5 Z tap ,--' M > cz CO N J @ O C �- V U N Y > la-�Y U a a r- O Y v 0 E Lu YC -6 a co C o aQ u+ r r r r Y U E o a m Q J . l-7 - - - , p n Q C C C C Y L o Z Q •-•Z a Q v v c v LO C H • v . rG O C v L L''' 0000 OA C V 0 W W W W N N 'C 0 Q J J J J a .0 > c v co H Q Q Q Q a� v C 0O co CZ Z Z Z Z _E N O N cc G t• Q no p �. U Cr' Z - p u 0 - Q co V C > U a, Y Z. O 'G a c m a o 0 _ u z co Q v a y c a co L./ a -, > �, ;.W y LL rn S c . 0 Q a 0 E m 4 41 u °A m U a 1- fn • N G J Vw 0fx N 4 .., J w-, V CU Lu diltirf a °' OP wuJww W W W W Ce Ce W v1 M Y Y Y Y Dnnn O W d' d' Wv T Q Q Q Q ` a a a a Y o ® Y• Y Y Y co r'• 7 u w V °� Q, N N M •••••• [ ' CC o 0 0 o U) v 0 O O O q 0 V co co 00 oho C K.4 m v `) 0 LU 0 0 0 0 C Z Hco LU -, Q CE W o00 . � � co r- r cf N h- Ln i O N O M M O U N a N N N N Q co O) M O) a) h N N O N L o 0 0 o 3 � 0 N 4 C in in L ua+) 0. u co• W of vcO v Z �1 E u LW 1,c 122 ^ cc 0 c 9 �� U d Qj �-i 4. o W N a+ v a+ IN a z 4, b0 ^ Z T- o r F+ E y r 4 = a N 2 6, o N Y ra ro d G a Q O N : _1 N N Z W .G = 1 'i ^ ` i - v ca Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cQ O¿ - 0 10 L Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~scan Needed 1I11II1111111111111 RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA ~iskettes, No. Ll- D Other, NolType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: Scanning Preparation !þ x 30 = 0 D~::q, j~ ~b~llllil/lll~f Date: q dq (Jtf 151 V1fP j , J d-D + I{ = TOTAL PAGES J {~I (count;!ç...ot not !';.þude cover Shf1~ . ¡() Date: ~-I B-Of/ ólf 151 vvvr , 1111111111111111111 NOTES: BY: Helen ~- Project Proofing BY: Helen ~ BY: Helen C:Mari~) Production Scanning Stage 1 Page Count from Scanned File: J 3~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES Helen B Dateq/c9q fð'f If NO in stage 1 page(s) discrepancies were found: YES NO BY: NO 151 ÿijf Stage 1 BY: Helen Maria Date: Isl Scanning is complete at this point unless rescanning is required. ReScanned 111I I III BY: Helen Maria Date: Isl Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc • • WELL LOG c.... ..a.s TRANSMITTAL Ia. PrtoAcIivE DIAGNOSTIC SERVICES, INC_ To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 L p4 AUG % _x 7-01' [907) 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 attention of : RECE!VED ProActive Diagnostic Services, Inc. Attn: Robert A. Richey JUL ' 5 2011 130 West International Airport Road Suite C ON & Gas Cons. Curt • Anchorage, AK 99518 t Anchorage a Fax: (907) 245 -8952 1) Caliper Report 18- Jul -11 1D-34 1 Report / CD 50- 029 - 22975 -00 2) Caliper Report 14-Jul-11 1C-104 1--Report/ CD ✓ 50- 029 - 23076 -00 ('/ 1 Signed : ILLC)ibv•---k Date : �0 11 9 Print Name: C`� v 4,_ �`�'� PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -8952 E-MAIL : PDSANCHORAGE(d MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution \TransmittalSheets \ConocoPh llips_Transmit.docx A 6 2.. 6 61 1 • • i 1.1 Multi- Finger Caliper Log Results Summary C ompany: ConocoPhillips Alaska, Inc. Well: 1C -104 Log Date: July 14, 2011 Field: Kuparuk (West Sak) I Log No.: 6855 State: Alaska Run No.: 4 API No.: 50- 029 - 23076 -00 Pipet Desc.: 7.625" 29.71b. L -80 Top Log Intvll.: 110 Ft. (MD) Pipet Use: Surface Casing Bot. Log Intvll.: 6,480 Ft. (MD) 1 Inspection Type : Buckling and Restriction Inspection COMMENTS : 1 This log is correlated to the Schlumberger RST Log dated December 9, 2005. This log was run to assess the condition of the 7.625" surface casing with respect to corrosive and 1 mechanical damage, as well as to identify areas of buckling or ID restriction due to subsidence. The caliper recordings indicate areas of ovality due to buckling from — 2,045' to — 2,160', restricting the I.D. to 6.64" at 2,070'. Heavy Deposits are recorded from 2,376' to 2,378', 6,124' to 6,126', and 6,255' to 6,260', I restricting the I.D. to 4.79" at 2,377', 5.16" at 6,255', and 6.00" at 6,125'. No other significant areas of buckling or I.D. restrictions are recorded throughout the surface casing logged. A graph illustrating minimum recorded diameters on a joint-by-joint basis as well as a 3 -D log plot overlay of the centered and off - center caliper recordings across the areas of buckling are included in this report. I The caliper recordings indicate the 7.625" surface casing logged appears to be in good to fair condition with respect to corrosive damage, with a maximum recorded wall penetration of 29% in joint 143 (6,161'). I Recorded damage appears as general corrosion and line corrosion. No significant areas of cross - sectional wall loss are recorded throughout the surface casing logged. This is the fourth time a PDS caliper has been run in this well and the first time the 7.625" surface casing has 1 been logged. MAXIMUM RECORDED WALL PENETRATIONS: I Line Corrosion (29 %) (26 %) Jt. 143 @ 6,067 Ft. (MD) Line Corrosion Jt. 144 @ 7,206 Ft. (MD) Corrosion (23 %) Jt. 145 @ 8,087 Ft. (MD) Line Corrosion (20 %) Jt. 149 @ 8,154 Ft. (MD) I Line Corrosion (20 %) Jt. 142 @ 7,954 Ft. (MD) MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: 1 No significant areas of cross - sectional wall loss (> 8 %) are recorded throughout the surface casing logged. MAXIMUM RECORDED ID RESTRICTIONS: I Heavy Deposits Heavy Deposits Minimum I.D. = 4.79" Jt. 55 @ 2,377 Ft. (MD) Minimum I.D. = 5.16" Jt. 145 @ 6,255 Ft. (MD) Heavy Deposits Minimum I.D. = 6.00" Jt. 142 @ 6,125 Ft. (MD) Ovality due to Buckling Minimum I.D. = 6.64" Jt. 47 @ 2,070 Ft. (MD) 1 Ovality due to Buckling Minimum I.D. = 6.65" Jt. 49 @ 2,143 Ft. (MD) Field Engineer: N. Kesseru & J. Conrad & P. Juday Analyst: C. Waldrop Witness: D. Rowell 1 ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 C 1 • III PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk (West Sak) Well : 1C - 104 Date : July 14, 2011 I Description : Overlay of Centered and Off - Center Caliper Recordings Across Buckled 7.625" Casing. Maximum I.D. 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II iiiiii,;ui',+ Iit iy "Pt; ' ti ;" la' '1ii. i . I ' i . l'i= I , , 1 1 , p I • • ■tll■ I .. ■1 �■ ■■■ _ w • ■■iv�r�i ■■ - `. ■ ■t1l ■ ■ ■■ 2000 :: : - ■ ■ t ' 1 . ; . - ■11M■■■ MIN FAMI N■ 11111i111111111111111111 i'411.1.. ■ Iltgl.■ ■ ■■ 2050 = - _- I «� ■ ■ ■■ lirlittiiiiIIIII . up , . ___ la 11 MIKIIMPNEMEI ■M■EM■ ■■ 2100 At .4H IIMM ■ ■■ - I 7 ri 1 2150 ■L��' ■ ■■ Jl^ . . IBIEMMINNI ' ■■a■ ■ ■■ !I" . I MEANIE.. 2200 _- I 0 II ' i ■ � . � 2250 (. MI ■ ■I1■ ■ ■■ _ I in - 2300 - - ■ii■■■■ .t I ■ ■i 1 ■ ■ ■■ 2350 - :1 - . 1 ■f11■■■■ 1• - ; -- ■ri1 ■■ ■■ • - i r M.. .--- ■iRl■■■■ ■ tiI1 ■ ■■■ 1 _— . � ` M 1 2400 - j -'' 1 n — I 1,� _ 2450 j, . - - Eno .. ■ ■ui ■■ ■■ — � «MI■■■ 11 Nominal I.D. 6 inches 8 I Minimum I.D. --i 6 inches 8 Maximum I.D. Depth 3 -D Log (Off - Center) Image Map (Off - Center) 3-0 Log (Centered) Image Map (Centered) - 1 — 1ft:800ft I I - I , Z>I 1 I 6 inches 8 319° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° ■ 111 ■ I • • I Minimum Diameter Profile I Well: 1C -104 Survey Date: July 14, 2011 Field: Kuparuk (West Sak) Tool: UW MFC XR 40 No. 213120 I Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches Country: USA Tubing ID.: 6.875 inches Minimum Measured Diameters (In.) 2.75 3.25 3.75 42 4.75 5.25 5.75 6.25 6.75 II 3 7 7 11 15 � . I 19 22 _ . 26 1 ' I 30 34 38 I I 42 46 50 54 I I 58 62 i i 2 70 66 L. E 7 74 • r 78 L I •a 82 86 90 , 94 I • • 98 102 106 I, I 110 I 114 ■ 118 l ; I 122 ■ 126 130 ! 134 1 138 142 l 146 I Iy 1501 I I 1 • • Correlation of Recorded Damage to Borehole Profile I • Pipe 1 7.625 in (141.6' - 6474.2') Well: 1C-104 Field: Kuparuk (West Sak) I Company: Co nocoPhiiipsAlaska, Inc Country: USA Survey Date: July 14, 2011 I I ■ Approx. Tool Deviation ■ Approx. Borehole Profile 111 10 442 20 � 876 1 30 1 1 1298 I 40 1 1729 50 J 1 I 2159 60 2589 0 I il 1 70 3015 L E _ 80 — 3438 Q I I CS 90 3 3864 1 "I 100 ii ` 4291 I 110 4718 120 • 5142 •1 130 5570 1 140 6001 l 150 \ 6430 151 6474 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 151 I I I • • I C-� PDS Report Overview :. Body Region Analysis I Well: 1C -104 Survey Date: July 14, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC XR 40 No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 7.625 ins 29.7 ppf L-80 BTC -M Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 7.625 ins 29.7 ppf L -80 BTC -M 6.875 ins 7.625 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) I 150 • Penetration body Metal loss body 0 50 100 3 I 100 I 50 Mk 0 s I 0 to 20 to 40 to over 20% 40% 85% 85% 53 Number of joints analysed (total = 149) I 143 6 0 0 I Damage Configuration ( body ) 20 I 15 103 10 I 5 0 � I Isolated General Line Other Hole / Pitting Corroion Corrosion Damage Pos. Hole I 0 uu - • • _ .,ii...* •. = • 3 13 0 0 Bottom of Survey = 151 I I I I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.62 5 in 29.7 ppf LSO BTC M Well: 1C-104 Body Wall: 0.375 in Field: Kuparuk (West Sak) Upset Wall: 0.375 in Company: ConocoPhillips Alaska, Inc I Nominal I.D.: 6.875 in Country: USA Survey Date: July 14, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 3 142 0 0.04 9 2 6.76 4 185 0 0.03 7 2 6.80 5 228 0 0.03 7 1 6.81 6 271 0 0.03 7 2 6.79 7 314 0 0.03 8 3 6.82 I 8 357 0 0.03 7 2 6.79 9 401 0 0.03 7 2 6.78 10 442 O 0.03 8 2 6.77 11 485 0 0.03 9 3 6.81 I 12 529 0 0.02 5 1 6.82 13 572 0 0.03 9 2 6.78 14 615 0 0.02 5 2 6.80 15 659 0 0.02 6 2 6.78 I 16 702 0 0.02 6 2 6.79 17 746 0.05 0.05 14 3 6.79 ■ 18 789 0 0.04 11 2 6.79 19 833 0 0.02 6 2 6.81 I 20 21 876 0 0.03 8 2 6.77 917 0 0.03 9 2 6.75 22 959 0 0.03 7 2 6.78 22.1 1002 0 0 0 0 6.55 Tam Port Collar 23 1005 0 0.03 9 2 6.75 I 24 1048 0 0.04 11 2 6.79 ■I 25 1087 0 0.03 8 2 6.80 �i 26 1129 0 0.04 10 2 6.78 27 1170 0 0.03 9 2 6.81 I 28 1214 0 0.04 12 3 6.77 29 1255 0 0.03 9 3 6.80 30 1298 0 0.04 9 2 6.82 ■ 31 1342 0 0.03 9 2 6.78 I 32 1382 0 0.03 8 3 6.76 33 1426 0 0.03 8 2 6.83 34 1469 0 0.03 9 2 6.80 35 1513 0 0.03 9 3 6.82 I ] 36 1556 O 0.04 10 4 6.80 ■ I 37 1599 0 0.04 9 2 6.77 38 1643 0 0.03 7 3 6.78 39 1686 0 0.04 12 4 6.79 40 172 9 0 0.03 9 5 6.82 I 41 1772 0 0.04 11 3 6.82 42 1816 0 0.03 8 4 6.81 43 1859 0 0.03 9 4 6.78 44 1903 0 0.03 9 4 6.81 I 45 1946 0 0.03 8 3 6.84 46 1986 0 0.04 10 5 6.81 II 47 2029 0 0.04 10 6 6.64 Ovalitv due to Buckling. II 48 2072 0.07 0.03 9 5 6.67 Ovality due to Buckling. 49 2116 0.10 0.04 9 9 6.65 Ovality due to Buckling. 1 I 50 2159 0.05 0.04 9 4 6.71 Ovality due to Buckling. • 51 2201 0 0.04 10 2 6.78 dy I Metal Loss Penetration Body Page 1 I I • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 7.625 in 29.7 ppf L-80 BTC M Well: 1C-104 Body Wall: 0.375 in Field: Kuparuk (West Sak) I Upset Wall: 0.375 in Company: ConocoPhillips Alaska, Inc Nominal I.D.: 6.875 in Country: USA Survey Date: July 14, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (` wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 52 2244 0.05 0.04 10 3 6.78 • 53 2288 0 0.04 10 3 6.81 IN 54 2331 0 0.03 9 2 6.79 ■ 55 2372 0 0.04 9 2 4.79 ■ 56 2414 0 0.04 9 3 6.69 I il 57 2458 0 0.03 8 2 6.77 58 2501 0 0.03 9 2 6.75 ■ 59 2545 0 0.04 11 3 6.78 • 60 2589 0 0.04 10 3 6.75 I 61 2631 0 0.03 9 3 6.77 62 2673 0 0.04 10 4 6.78 ■ 63 2717 0 0.04 11 2 6.74 ■ 64 2760 0 0.04 10 2 6.81 I 65 2804 0 0.03 9 3 6.74 66 2847 0 0.03 8 2 6.83 67 2890 0 0.04 11 2 6.79 ■I 68 2931 0 0.03 9 2 6.76 ■� 69 2975 0 0.03 9 3 6.79 • I 70 3015 0 0.04 10 3 6.75 ■ 71 3059 0 0.04 10 2 6.80 s 72 3102 0 0.03 9 2 6.82 73 3145 0 0.04 11 3 6.79 ■ I 74 3189 0 0.04 11 2 6.79 ■ 75 3232 0 0.04 10 2 6.75 s 76 3274 0 0.03 9 3 6.77 77 3313 0 0.03 8 3 6.76 I 78 3353 0 0.04 11 2 6.76 • 79 3396 0 0.04 10 2 6.75 80 3438 0 0.03 7 2 6.76 81 3480 0 0.04 10 4 6.76 ■ I 82 3523 0 0.04 11 2 6.74 ■ 83 3566 0 0.04 10 2 6.79 NI 84 3608 0 0.04 10 2 6.75 ■ 85 3651 0 0.04 10 2 6.76 86 3692 0 0.03 9 2 6.78 I 87 3736 0 0.04 10 3 6.78 is 88 3779 0 0.04 10 3 6.73 ■ 89 3821 0 0.04 11 2 6.77 90 3864 0 0.03 7 3 6.80 1 91 3908 0 0.03 8 2 6.75 92 3946 0 0.03 7 2 6.80 93 3990 0 0.04 10 2 6.80 • 94 4033 0 0.04 11 2 6.78 • I 95 4077 0 0.04 10 2 6.75 96 4119 0 0.03 8 3 6.74 97 4162 0 0.04 9 2 6.78 • 98 4205 0 0.04 10 3 6.77 99 4248 0 0.03 9 2 6.75 I 100 4291 0 0.03 9 2 6.74 101 4333 0 0.04 10 3 6.79 I tiody y I Meta Penetra l Loss n Bod Page 2 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.62 5 in 29.7 ppf LSO BTC M Well: 1C-104 Body Wall: 0.375 in Field: Kuparuk (West Sak) I Upset Wall: 0.375 in Company: ConocoPhillips Alaska, Inc Nominal I.D.: 6.875 in Country: USA Survey Date: July 14, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 102 4376 0 0.03 9 6.81 103 4420 0 0.03 9 3 6.78 104 4464 0 0.03 9 3 6.76 105 4506 0 0.03 8 2 6.79 106 4550 0 0.03 8 2 6.71 I 107 4592 0 0.04 10 2 6.80 108 4635 0 0.03 8 2 6.76 3 109 4679 0 0.03 8 2 6.79 110 4718 0 0.04 11 2 6.78 • 111 4762 0 0.04 11 2 6.73 ■ 112 4804 0 0.04 10 2 6.78 ■ 113 4847 0 0.04 9 2 6.76 ■ 114 4890 0 0.04 10 2 6.77 ■ I 115 4932 0 0.03 9 3 6.76 116 4974 0 0.03 8 2 6.77 117 5017 0 0.03 8 2 6.76 3 118 5060 0 0.04 10 3 6.74 ■ I 119 5101 0 0.04 10 3 6.76 ■ 120 5142 0 0.03 9 2 6.80 ■ 121 5185 0 0.04 10 5 6.66 ■ 122 5228 0 0.04 10 3 6.81 ■ 123 5271 0 0.04 11 3 6.79 ■ I 124 5314 0 0.04 12 2 6.77 125 5356 0 0.03 9 2 6.77 126 5399 0 0.04 11 3 6.78 ■ 127 5443 0 0.04 11 2 6.81 I 128 5486 0 0.03 9 4 6.79 129 552 7 0 0.03 7 3 6.82 130 5570 _ 0 0.03 8 3 6.80 I ] 131 5614 0 0.03 9 3 6.81 ■ I 132 5657 0 0.04 10 2 6.79 ■ 133 5701 0 0.03 9 2 6.81 ■ 134 5744 0 0.04 9 2 6.79 ■ 135 5787 0 0.04 11 2 6.75 ■ 136 5831 0 0.05 14 2 6.78 Shallow Corrosion. Lt. Deposits. ■ I 137 5875 0 0.05 13 4 6.80 Shallow Corrosion. Lt. Deposits. • 138 5918 0 0.05 14 3 6.77 Shallow Line Corrosion. Lt. Deposits. ■ 139 5960 0 0.06 15 3 6.73 Shallow Line Corrosion. Lt. Deposits. ■ 140 6001 0 0.06 17 3 6.74 Shallow Line Corrosion. Lt. Deposits. ■ I 141 6044 0 0.07 17 5 6.77 Shallow Line Corrosion. Lt. Deposits. ■ 142 6087 0.05 0.08 20 5 6.00 Line Corrosion. Heavy Deposits. ■■ 143 6130 0.06 0.11 29 7 6.79 Line Corrosion. Lt. Deposits. ii■ 144 6173 0.08 0.10 26 3 6.76 Line Corrosion. Lt. Deposits. ■■ I 145 621 7 0.07 0.09 23 1 5.16 Corrosion. Heavy Deposits. ■ � 146 6260 0 0.07 19 4 6.77 Shallow Line Corrosion. Lt. Deposits. ■ 147 6303 0 0.07 20 3 6.80 Shallow Line Corrosion. Lt. Deposits. ■ 148 6347 0.05 0.07 19 3 6.77 Shallow Line Corrosion. Lt. Deposits. ■: I 149 6389 0.07 0.08 20 3 6.76 Line Corrosion. Lt. Deposits. 150 6430 0 0.07 19 3 6.71 Shallow Line Corrosion. Lt. Deposits. •■ : 151 6474 0 0.07 19 2 6.77 Shallow Line Corrosion. Lt. Deposits. neion dy y Page Pe Metal trat Loss Bo Pae 3 I I • • I TP PDS Report Cross Sections I �„ Well: 1C -104 Survey Date: July 14, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC XR 40 No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 7.625 ins 29.7 ppf L -80 BTC -M Analyst: C. Waldrop I I Cross Section for Joint 143 at depth 6161.400 ft Tool speed = 50 Nominal ID = 6.875 I Nominal OD = 7.625 Remaining wall area = 95% Tool deviation = 66° I I i ' I I \I \ Z I \ I Finger = 11 Penetration = 0.107 ins Line Corrosion 0.11 ins = 29% Wall Penetration HIGH SIDE = UP I I I I I 1 • • 1 PDS Report Cross Sections I Well: 1C -104 Survey Date: July 14, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC XR 40 No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 7.625 ins 29.7 ppf L -80 BTC -M Analyst: C. Waldrop 1 1 Cross Section for Joint 144 at depth 6185.260 ft Tool speed = 50 Nominal ID = 6.875 Nominal OD = 7.625 Remaining wall area = 99% Tool deviation = 67° \ 1 1 / „- 1 I . ,,,„ , ,N. 1 1 \ \ \ 1 /111\ I Finger = 13 Penetration = 0.099 ins Line Corrosion 0.10 ins = 26% Wall Penetration HIGH SIDE = UP 1 1 I 1 1 • • 1 PDS Report Cross Sections ti 1 ,. I Well: 1C -104 Survey Date: July 14, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC XR 40 No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 7.625 ins 29.7 ppf L -80 BTC -M Analyst: C. Waldrop 1 1 Cross Section for Joint 55 at depth 2376.840 ft Tool speed = 53 Nominal ID = 6.875 I Nominal OD = 7.625 Remaining wall area = 99% Tool deviation = 62° 1 1 1 1 1 /, I _ /// 1 1 Minimum I.D. = 4.787 ins Heavy Deposits Minimum I.D. = 4.79 ins HIGH SIDE = UP 1 I 1 1 1 1 • • 1 PDS Report Cross Sections I Well: 1C -104 Survey Date: July 14, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC XR 40 No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 7.625 ins 29.7 ppf 1 -80 BTC -M Analyst: C. Waldrop 1 1 Cross Section for Joint 145 at depth 6255.240 ft Tool speed = 50 Nominal ID = 6.875 I Nominal OD = 7.625 Remaining wall area = 92% " Tool deviation = 66° j 1 / \\ I 1 1 i 1 I V4141111111111111 I Minimum I.D. = 5.155 ins Heavy Deposits Minimum I.D. = 5.16 ins HIGH SIDE = UP 1 1 1 1 1 1 1 • • 1 PDS Report Cross Sections (tP__S„. I Well: 1C -104 Survey Date: July 14, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC XR 40 No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 7.625 ins 29.7 ppf L -80 BTC -M Analyst: C. Waldrop 1 1 Cross Section for Joint 47 at depth 2069.937 ft Tool speed = 53 Nominal ID = 6.875 I Nominal OD = 7.625 i •���� Remaining wall area = N/A Tool deviation = 71° 1 1 1 1 1 1 (l 1 Minimum I.D. = 6.640 ins Ovality due to Buckling Minimum I.D. = 6.64 ins HIGH SIDE = UP 1 1 1 1 1 1 • • 1 i-s, PDS Report Cross Sections I Well: 1C -104 Survey Date: July 14, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC XR 40 No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 7.625 ins 29.7 ppf L -80 BTC -M Analyst: C. Waldrop 1 1 Cross Section for Joint 49 at depth 2142.610 ft Tool speed = 53 Nominal ID = 6.875 I Nominal OD = 7.625 ��� _ Remaining wall area = N/A l Tool deviation = 67° \ 1 / \ 1 ' I 1 1 1 / 1 // \,—_________ 1 Minimum I.D. = 6.650 ins Ovality due to Buckling Minimum I.D. = 6.65 ins HIGH SIDE = UP 1 1 I 1 1 1 • • 1 PDS Report Cross Sections I Well: 1C -104 Survey Date: July 14, 2011 Field: Kuparuk (West yak) Tool Type: UW MFC XR 40 No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 7.625 ins 29.7 ppf L -80 BTC -M Analyst: C. Waldrop 1 1 Cross Section for Joint 48 at depth 2093.600 ft Tool speed = 53 Nominal ID = 6.875 ,� I Nominal OD = 7.625 - `` Remaining wall area = N/A � Tool deviation = 70° 1 1 1 1 1 1 Minimum I.D. = 6.665 ins Ovality due to Buckling Minimum I.D. = 6.67 ins HIGH SIDE = UP II I 1 1 1 1 � KUP C -104 ConocoPhillips 1 Attributes a MD r 1 o J - n4'9tlGn N' O 6PJ41 Reid Name 'Wei :btu. Edo) hal i•'i xDint 81 Edit Act frtK Edit twucdAerye 500292307600 WEST SAK PROD 94.81 7,654.8 11.560. --- camnlnt ILLa 112s i Cab Edit Ann ohtlon MC' Deb Edi E B°3Nrt1 019 0e1ee111 E[Ii[ i ••• SSSV: NONE 110 8!G!2 Last WO: 102 52(10 4 7292 Annotation Dap 10 trt0'. 0011 Le1(E Annotation La 1t rod B; end nab (Ed Last Tag. ' Rev Reason: PULL PACKER ASSY, GLV C/O ninam 711320 Casing Strings Ca ling le lOrlption string 00... sting ID. Top 1nkel Set Lbp01 it.. set op10 0901_. Snug Wt.. Siring_. String Top TWA CONDUCTOR 16 15.062 452 158.0 158.0 62.50 H-40 WELDE i N Mqt ••GEP.36 ' •-a•INDe tenpton Siring OD... Sting ID.. Top 111KBi set Depth it_- Nt Depth TVD(... String Wt.. String..- :9109 Top9E[1it SURFACE 7518 6.875 41.3 7,395.1 3,740.7 29.70 L B Cartg Dererp8on string M.. Steno ID... Top 111KB1 Set Depth it. set 0lpfi(TVDI... SINN M.. 8t99. . String T8 Edo WINDOW Lt 6518 6.000 7,014.0 7,044.0 3,681.2 10161 csong [4ialp41on string OD... Sting ID... Top (re 61 set Depth f1.. set 01pi1(TVDI... String M. string.- string TDB 11 1E[Iit LINER 8 -SAND 4 4.000 7,208.3 11,550.0 3,6985 12.60 L-80 SENT i I I i..®ler Details �Edrt Top Copal Top 7VDI Top hen 11K Nom I... i BI fttP: Bl f °'1 Aim G Comment .011811Pn Comment ID(101 coa /eC TOP . 1 7,208.3 3,718.3 78.86 PACKER BAKER MODEL'SCR- 1'PACKER 3.958 ' I I 7,213.1 3,7192 79.28 MILLOUTEXT BAKER MILLOUT EXTENSION 3.958 II EPT rPPCE. I 7,2152 3,719.7 79.49 05.565 4.9$0 7215.9 3,7198 79.53 ALVE BAKER Kith/ MODEL'C 4276 7,217.9 3,7202 79.70 O 564.5 4500 7,256.1 3,7262 84.18 SLEEVE BAKER MODEL CMD SLIDING SLEEVE 4.540 1P 1 o•EL.• 7,288.9 3,7295 84.03 X04.564 4.000 3a% Tubing Strings T lnlpi0n IStit11Q OD_ I rt 3.958 ... I 36.2 Set Ses�$$.. Nit 9D1... IStrtg� 'String Top 11jE(Gt Completion Details IEtlit, Top Olpih I Ia3P Top MD) Top 8oI Weil_ . • la.. seal. 6p13 ittli Eh ioo.n 1°1 MN De Knption �_Dm men! IDilnl 362 362 .041 HANGER VETCO GRAY TUBING HANGER 4.500 6,102.7 3,386.7 87.08 DISCHARGE PHOENIX DISCHARGE SUB 3.948 I. 6,183.9 3, 418.4 66.99 INTAKE TIC CROSSOVER V1PERFORATED INTAKE P. ^.TC N,6aL'. 6,194.6 3,422.5 66.98 SEAL TANDEM SEAL SECTION i eax•.e0E, 6.103 i. 6,208.4 3,427.0 66.91 MOTOR 6,225.1 3,434.4 66.95 GAUGE ESP MOTOR 130 HP KMN2415Vl4OA 1111, PHOENIX MDTXT GAUGE � _ ■ 6,226.9 3,4352 66.95 CENTRALIZ... MOTOR CENTRALIZER 1 Other In Hole (Wireline retrievable pllgs, valves, pimps, fish, etc.) Itdrt i 'Top (03) Top iTv'Dl Top hCl i1tk8, ILtk BI ° 1 Del00800 Comment Run Gib IDilni 360 36.0 -0.11 HEAT TRACE HEAT TRACE 10262007 0.000 _ 6024.0 3,355.6 66.57 PATCH SPACER PIPE,JJ STINGER, JJ TIE BACK(OAL =113') 12J312009 2.375 Perforations & Slots Edit our IITAKE,6.18° 0602 Bin Top (Tait BIN 1.1 Top M41.,6.195 ou,, 16 "� Top(11a B) 1140 13i Itt60) 111681 -one 010 1Mt.. Tp. Cnmm.nt 7,4460 11,395.0 3,746.8 3,6924 WS B. 1C-104 7282002 506 SLOTS Parts thru 37' screens every 31' '� aternating with solid filer aOT0e,6,3H ■ S I Notes: General & Safety Edit ic HTe!.ICEa, I Bb Data ArlW then wmaow` ,� / ?2921108 NOTE: MU LTI-LATE RALWELL: B -SAND (1C -104], Et-SAND (1C- 104L1) e1ai:�6E; 101112008 NOTE: VIEW SCHEMATIC w /Plaska Schematic9.0 111TJe 31.0�. 1 927,2009 NOTE LEAK DETECTED @ 6053' E LMD 1 1111E11 • I aciva, 'p Al1.S1♦ i 1 1 I cos 111 J 0JP I. ill 1 I Edit I Mandrel Details 0 Top Depth Fbrt Tap iT9Di Top 0(3 Latch slat 7P.0 Run Sin 11108, 4110 Bi hali °1 Mahe Model i 111 SW, 911 ve Tpe Type 00 (p111 Run Dab C m... LINER 1 3,895.6 2,405.0 63.90 CAM... K130 R t ESP DMY BK - 1 0.000 0.0 111'871007 6••e. � 11 `� � 2 6,0133 3,3513 66.46 CAM._ K130 1 ESP DM? BK 0000 0.0 62972011 TO.IC -100, 11560 1 STATE OF ALASKA ALASKA COAND GAS CONSERVATION COMMISSI110 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well Rug Perforations r Stimulate r Other r Alter Casing r Pull Tubing P Perforate New Pool r Waiver 1 """ Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 202 -061 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 — 50 029 - 23076 - 00 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25649 - 1C 9. Field /Pool(s): <. Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 11560 feet Plugs (measured) None true vertical 3688 feet Junk (measured) None Effective Depth measured 11550' feet Packer (measured) 2991, 7208 true vertical 3688 feet (true vertucal) 2018, 3718 Casing Length Size MD TVD Burst Collapse CONDUCTOR 113 16 158 158 SURFACE 7354 7.625 7395 3741 LINER B -SAND 4342 4" x 4.5" 11550 3689 Perforation depth: Measured depth: 7446'-11395' . : „ � � r1U `t 1 =„ `LU �� E E vED True Vertical Depth: 3747' - 3692' AUG 16 2011 Tubing (size, grade, MD, and TVD) 4.5, L - 80, 6116 MD, 3392 TVD Analftbee $IOR Packers & SSSV (type, MD, and TVD) PACKER - BAKER 'SCR -1' PACKER @ 7208 MD and 3718 TVD C-4--(' le PACKER - VIKING ESP FEED THRU PACKER @ 2991 MD and 2018 TVD, NO SSSV ox` 11. Stimulation or cement squeeze summary: cement squeeze toe abandonment from: 1- C Intervals treated (measured): 9995' - 11432' MD (I Treatment descriptions including volumes used and final pressure: 66 bbls 8.5# /gal ultra LiteCRETE, final squeeze pressure = 2085 psi 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development ]W , Service r Stratigraphic r 15. Well Status after work: , Oil Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer @ 265 -6845 Printed Name Brett Packer Title Wells Engineer Signature 7 `-"'+— -- Phone: 265 -6845 Date t F. / /sl j R8bMS AUG 16 2011 P . M. I( Form 10 -404 Revised 10/2010 G " S mit Original Only • KUP • 1C -104 COrK)COPhilli S K 3 II Attributes _ _. Max Angle & MD TD Al&Si;6. Wellbore APUUWI Feld Name Well Status Intl () MD (ftKB) Act Bat (ftKB) c,ari .a2tt•netf 500292307600 I WEST SAK _ PROD 9481 7 • 654.89 11 560 0 Cam ent H2S (ppm) Date [Annotation End Date I KB - Grd (ft) Rig Release Date "' SSSV: NONE 1 110 1 .. 8/6/2009 Last WO' � _... 10/25/2007 45.16 7/29/2002 SrAremg }ic. pCpigi Annotation Depth (ftKB) End Da Annotation Last Mod ._ End Date Last Ta : Rev Reason: WORKOVER ninam 1 8/15/2011 Casing Strings Casing Description String 0... String ID ... Top (HKB) Set Depth (t... Set Depth (TVD) ... String Wt... String String Top Thrd CONDUCTOR 16 15.062 45.2 158.0 158.0 62.50 H - 40 WELDED s Casing Desaription String 0... String ID ... Top (RIM) Set Depth (L.. Set Depth (TVD)... String Wt... String ... String Top Thrd - ii: ' - SURFACE . 75/8 6.875 41.3 7,395.1 3,740.7 2970 L - 80 BTCM r Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String WI... String ... String Top Thrd 5' < WINDOW L1 65/8 6.000 7,014.0 7,044.0 3,681.2 to 1C 104L1 ,- ;; Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String ... String Top Thrd 4 • ` ^! "'s ° -` LINER B -SAND 41/2 4.000 7,208.3 11,550.0 3,688.5 12.60 L -80 SLHT HANGER,36 ;Liner Details Top Depth CONDUCTOR, (ND) Top Intl Nomi... 65-158 Top(1KB) (MB) (°) Item Description Comment ID(in) 7,208.3 3,718.3 78.86 PACKER BAKER MODEL 'SCR-1' PACKER 3.958 3 7,213.1 3,719.2 79.28 MILLOUT EXT BAKER MILLOUT EXTENSION 3.958 7,215.2 3,719.7 79.46 XO 5.5x5 - -__ -- 4.950 GAS LIFT, 7,215.9 3, 719.8 79.53 VALVE BAKER KOIV MODEL 'C' 4.276 2.670 INT 7,217.9 3,720.2 79.70 XO 5x4.5 4.500 lir 7,256.1 3, 726.2 84 -18 SLEEVE BAKER MODEL CMD SLIDING SLEEVE 4.540 7,288.9, 3,729.5 84.03 X0 4.5x4 4.000 PACKER, 2ss1 - - -._ " - Tubing Strings "�` Tubing Description 500 0... Str g ID ... Top (HKB) Set Depth (f... Set Depth (TVD) .. !String Wt... String .. String Top Thrd TUBING WO , . 41/2 39581 36.2 1_ 6115.9 _3,39t8 __- 12.60 L-80 IBTM _ Completion Details Top Depth (TVD) Top Intl Nomi... G A S U , Top(ftKB) (�8) (1 Item Description Comment ID(in) ry -- 36.2 36.2 -0.11 HANGER Vetco CWCT 11 "X41/2" TUBING HANGER & HANGER JOINT 3.900 2,990.9 2,017.6 64.17 PACKER VICKING ESP FEED -THRU PACKER 3.878 5,933.2 3,318.8 65.64 GAUGE GUARDIAN DISCHARGE PRESSURE SUB 3.958 d 6,038.5 3,361.4 66.72 MOTOR UPPER MOTOR SHROUD 3.833 GAUGE, 5,933 _ -- 6,052.3 3,367.1 67.13 MOTOR LOWER MOTOR SHROUD 3.833 6,066.0 3,372.5 67.11 CONNECTOR PUMP CAN ASSEMBLY AND FIXED WET CONNECTOR SYSTEM 3.833 I ' 6,078.6 3,377.3 67.10 PIPE ASSY UPPER TAIL PIPE ASSEMBLY 3.833 6,105.1 3,387.6 67.07 COUPLING "B" PROFILE 3.833 6,106.6 3,388.2 67.07 PIPE ASSY LOWER TAIL PIPE ASSEMBLY 3.958 "� 6,114.1 3,391.1 67.06 PROFILE NO-GO ISOALTION SLEEVE ADAPTER 3.800 MOTOR, 6,039 MOTOR, 6,052 ' Perforations & Slots Shot CONNECTOR, If 1 Top (TVD) BtTVD) Dens 6,066 m (TVD) PIPE ASSY, b Top (HKB) 131m (ftKB ) _ (ftKB) MKS) Zone Nt. (s h... Type Comment 6,079 7,446 11,395 3,746.8 3,692.4 WS B, 1C -104 7/28/2002 50.0 SLOTS Perfs thru 37' screens every 31' COUPLING, - - ,. alternating with solid liner 6,105 PIPE ASSY,_ 6,107 Notes: General & Safety PROFILE, End Date Annotation 6.114 _ .. 7/29/2008 NOTE MULTI - LATERAL WELL B -SAND (1C -104), D -SAND (1C- 104L1) 10/11/2008 NOTE View Schematic w/ Alaska Schematic9.0 ' 9/27/2009 NOTE: LEAK DETECTED @ 6053' ELMD ' WINDOW Li, 7,014 -7,044 SURFACE, 41 -7,395 SLOTS, r 7,446-11,395 LINER D -SAND, 7,039 - 11,514 11 ;t !( # 1 Manc►ret Detax_ Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run ' ll 11 Ste Top (ftKB) MKS) (1 Make Model (in) Sery Type TYpa (in) (psi) Run Date Com... 1 2,870.2 1,963.5 62.87 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 7/312011 2 3,105.8 2,067.2 64.69 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 7/312011 LINER B -SAND, 7,208 - 11,550 \ TD(10 -104), es 11,560 ConocoPhillips • Time Log & Summary W'elNiew Web Reporting Report Well Name: 1C - 104 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 7/10/2011 1:30:00 AM Rig Release: 8/2/2011 8:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/08/2011 24 hr Summary Completed Well 1D-121. Released Rig. RDMO. Begin to move to 1C-Pad. 17:00 00:00 7.00 MIRU MOVE MOB P Continue to move Rig to 1C -Pad. 07/09/2011 Continue to mobilize Rig to 1C -Pad. Rig on Pad. 00:00 23:00 23.00 MIRU MOVE MOB P Mobilize Rig from 1D Pad, traveling to 1C -Pad. Rig on Pad at 22:30 hrs. 23:00 00:00 1.00 MIRU MOVE RURD P Set Rig over the 13 5/8" x 5K BOP components. Build same. 07/10/2011 Set 13 5/8" BOP Stack on the Stump. Move in and center Rig on 1C -104 Well Slot. Rig up Flow Back Tank and Filtration Farm. Take on filtered 8.6 lb/gal Sea Water w /3% KCL in Rig Pits. Test Lines. Pull BPV. Circulate and Kill Well. Install BPV. ND Tree. 00:00 01:30 1.50 MIRU MOVE RURD P Continue to build the 13 5/8" BOP Stack. Set on the Cellar Stump. 01:30 02:30 1.00 MIRU MOVE RURD P Move Rig over 1C -104 Well Slot. Level and berm up same. Accept Rig at 01:30 hrs 02:30 13:00 10.50 MIRU MOVE RURD P MIRU Flow back Tank and Lines. MIRU Filtration Farm. Spot Support Equipment. 13:00 13:15 0.25 COMPZ WELLPF SFTY P PJSM. Discuss Hazard with Pulling BPV. 13:15 14:00 0.75 COMPZ WELLPF KLWL P P/U Lubricator . Lubricate out BPV and L/D same. ITP= 100 psi IAP= 105 psi. 14:00 14:30 0.50 COMPZ WELLPF EQRP P Wait On High -Line personnel to finish hooking shore power. 14:30 15:15 0.75 COMPZ WELLPFOTHR P Crane Showed up to remove ESP spool from Rig floor. PJSM with crane operator,rigger and rig crew. Make lift to remove spool from rig floor and install another one. 15:15 15:30 0.25 COMPZ WELLPF SFTY P PJSM. Discuss hazard for killing the well. Page 1 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 17:30 2.00 COMPZ WELLPF KLWL P Fluid pack and PT lines 250/3000 psi. Start Pumping operation to kill, well. Lead with 100 bbls diesel down IA taking returns up the Tubing at 4 BPM. Initial Circulating psi down IA 160 psi / 60 psi on the tubing. Swap over to 8.6 ppg brine @ 4 BPM, 220 psi down IA, 80 psi on the Tubing. Pressure at 50 bbl away, IA =120 psi / 50 psi on tubing, 100 bbls away, 70 psi IA / 110 psi tubing, 150 bbl away,50 psi IA / 110 psi tubing,200 bbls away, 50 psi IA / 40 psi tubing, 269 bbls away, 70 psi IA / 10 psi tubing. Pressure after shutting down pump, 0 IA / 0 Tubing. 17:30 18:00 0.50 COMPZ WELLPF KLWL P Shut down after 369 bbl total of 8.6 ppg brine pumped. Check level in return tank, (292 bbl total returns). Back on line pumping 8.6 ppg brine at 4 bpm, 70 psi on IA / 10 psi on tubing, until 8.6 ppg brine is at surface. 18:00 19:30 1.50 COMPZ WELLPF OWFF P Pumped another 70 bbls of 8.6 ppg Brine down IA before seeing good 8.6 ppg Brine back at surface. Shut down pump and monitor well for flow for 15 mins and Bullhead another 50 bbls of brine down Tubing. Monitor Well on a slight vacuum. 19:30 20:30 1.00 COMPZ RPEQP1NUND P PJSM. Rig down Kill Lines. Nipple down Production Tree. 20:30 00:00 3.50 COMPZ WELCTL NUND P PJSM. Nipple up 13 5/8" x 5K BOP Stack. 37/11/2011 Nipple up 13 5/8" x 5K BOP Stack. Perform initial BOPE Test. Pull Tubing Hanger. Single down the 4 1/2" Completion with ESP /HT/TEC Cables. 00:00 05:00 5.00 COMPZ WELCTL NUND P Continue to Nipple up BOPE. Install 2 3/8" Pipe Rams (solids) in the Upper Gate. Verify that 2 7/8" x 5 1/2" VBPRs are installed in the Lower Gate. 05:00 05:30 0.50 COMPZ WELLPF SFTY P PJSM. Discuss Hazard and Duty for Testing BOPE. 05:30 12:30 7.00 COMPZ WELLPF BOPE P Perform Initial BOP test. bOe 12:30 14:00 1.50 COMPZ WELLPF EQRP T PJSM. Had to replace seals on Blind Rams. Rig testing equipment and (11/ test joint. Charge Up Hydraulic System. I Page 2 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 17:30 3.50 COMPZ WELLPF BOPE P Continue with BOP Test. Completed the initial BOPE Test per Conoco /Phillips and AOGCC requirements at 250/3,000 psi. Good. Perform Koomey draw -down test. Good. Pressure tests recorded on Chart. The State's right to witness the test was waived by B. Noble. Rig down Test Equipment. 17:30 18:00 0.50 COMPZ WHDBO MPSP P Pull Blanking Plug and BPV. 18:00 20:30 2.50 COMPZ WHDBO THGR P PJSM. Make -up Landing Joint. BOLDS. Attempted to pull the Tubing Hanger free. Worked up to 80% of the tubing tensile strength plus Top Drive weigh (210K). Continue to work to pull free. No -Joy. Call out Steam Unit from the Wash -Bay. 20:30 21:30 1.00 COMPZ WHDBO THGR P PJSM. with all. Discuss the hazards associated with working around steam. Wrap Wellhead and hook -up steam hose. Apply steam to Wellhead and pull 200K on Tubing Hanger. Hanger "popped free" after 15 minutes. Rig down Steam Unit and release. Tubing free with normal weight = 123K (includes Top Drive weight). 21:30 22:30 1.00 COMPZ RPCOM CIRC P Circulate and condition Well with 8.6 lb/gal, w /3% KCL at 4.0 bpm /90 psi. Total volume 275 bbls 22:30 00:00 1.50 6,227 6,196 COMPZ RPCOM THGR P Pull Tubing Hanger to floor. Disconnect TEC /HT /ESP cables from Hanger. Test and cut cable. Lay down Tubing Hanger and Landing Joint. 07/12/2011 Un -seat the Tubing Hanger and pull to the Floor. Circulate Well. RU to pull the 4 1/2" ESP /HT Completion. Single down 4 1/2" Tubing and spool ESP, HT, TEC Cables. Lay down ESP Assembly. Clean and Clear pipe shed. Test Annular with 2 3/8 test joint 250/3000. Set Wear Ring. PU MU Push Pipe and RIH to 217 -ft. 00:00 13:00 13.00 6,196 46 COMPZ RPCOM PULD P PJSM- Rig up to pull ESP /HT/TEC cables. POOH Single down 4 1/2 ESP completion to pipe shed. Number & Tally Tubing, Count Clamps. Page 3 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 15:00 2.00 46 0 COMPZ RPCOM PULD P At the tubing TTC crossover w /perforated intake, lay Down a total of 197 joints of 4 1/2" Tubing, joint 193 had a hole in the side of the tubing, 11 7" feet from the pin end, that was the only hole found, the rest of tubing showed signs of heavy scale. Lay down the tandem seal section, ESP motor, and Phoenix gauge with motor centrilizer. Fluid Sample was taken from ESP motor. Lost a total of (9) SS flat bands and (1) 5 -ft Flat guard in hole. (3) protectolizers (457) 5 -ft dual channel Cannon clamps (3) 4 -ft dual channel Cannon clamps (4) 3 -ft dual channel Cannon clamps (4) 2 -ft dual channel Cannon clamps (52) single cross coupling clamps (103) dual cross coupling clamps (1) heat trace shoe (1) 6 -ft flat guard (33) SS bands 15:00 19:30 4.50 0 0 COMPZ RPCOM PULD P Load and un -load storage containers for ESP equipment. Clean and clear rig floor of clamps. Continue to load and tally Drill Pipe & PH -6 work string. 19:30 21:00 1.50 0 0 COMPZ WELLPF BOPE P RU test equipment, Pressure Test Annular to 250/3000 with 2 3/8 PH -6 test joint, LD test equipment. 21:00 21:30 0.50 0 0 COMPZ WELLPF OTHR P RIH and Set Wear Ring. 21:30 23:00 1.50 0 0 COMPZ WELLPF OTHR P Continue Tally ID, OD, and Fishnecks of all Push Pipe. 23:00 00:00 1.00 0 217 COMPZ WELLPF PULD P PU MU Push Pipe and RIH to 217 -ft. 37/13/2011 Load and Tally Push Pipe and 2 3/8 PH -6 work string. PU and RIH with Push Pipe and HWDP, POOH and stand back. PU BHA# 1 and RIH picking up DP to 2,060 -ft and set down, attempt to work thru - no luck. POOH and standing back. Change Head from 6 3/4 to 6 1/8 and RIH w/ BHA #2 to 2,093 -ft. POOH and Drop CSG Scraper. RIH w/ BHA #3 to 6,970 -ft. 00:00 05:00 5.00 217 1,820 COMPZ WELLPF PULD P Continue RIH with Push Pipe from 217 -ft to 1376 -ft, PU 15 joints HWDP to 1820 -ft. 05:00 06:30 1.50 1,820 1,820 COMPZ WELLPF CIRC P Kelly Up and Reverse Ciruclate to Work string until clean. 06:30 07:00 0.50 1,820 0 COMPZ WELLPF PULD P PJSM. POOH F/1820 ft standing back HWDP, Up wt =82k. 07:00 07:30 0.50 0 0 COMPZ WELLPF PULD T PJSM. Load Needed tools to Rig floor to clean down to hook hanger. 07:30 09:00 1.50 0 355 COMPZ FISH PULD T PJSM. M/U BHA #1. Reverse Jet Basket, String magnet,2 Boot basket,Scraper,Bumper sub and jars, w /HWDP and Intensifier. Page 4 of 24 1 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 09:00 10:30 1.50 355 2,060 COMPZ FISH TRIP T Single In w/ Clean Out Assembly on 3 1/2" Drill Pipe. Set Down with Junk Basket at 2060 ft. Up Wt =65k, Dn Wt =58k. 10:30 11:00 0.50 2,060 2,060 COMPZ FISH OTHR T MU to TD and Try to rotate passed tight spot or junk. TD Torque 1650# at 30 RPM, 1 -2K WOB. Started to rotate down and stalled top drive. Seen 4 -5k over pull after stall. Attempt one time with same results. Call Town Engineer. Discuss Option. PUH, fluid pack tubing and drop 7/8" �" f ball and fluid pack to reverse circulate. 11:00 12:00 1.00 2,060 2,060 COMPZ FISH CIRC T PUH 30 ft and Fluid pack. Circulate at 8 bpm, 1410 psi, working DP up and Down while pumping and working junk basket, still seeing same tag depth at 2060 ft and seeing drag on tool string from 2045 ft down to tag depth. Tried rotating once at 5 rpm,with same results. 12:00 12:15 0.25 2,060 2,030 COMPZ FISH SFTY T PJSM. Discuss Hazard of TOOH. 12:15 13:15 1.00 2,030 355 COMPZ FISH TRIP T TOOH standing back DP to Inspect and Check junk and boot basket. 65k up weight. 13:15 13:30 0.25 355 0 COMPZ FISH PULD T Break Down BHA and Inspect BHA. Scraper look good with no marks, Boot basket were empty and junk basket was clean. Had metal from the housing of the ESP cable on the magnet. 13:30 14:30 1.00 0 0 COMPZ FISH OTHR T Wait on a smaller nose end for the junk basket. 14:30 15:00 0.50 0 355 COMPZ FISH PULD T PJSM. M/U BHA #2. Reverse Jet Basket, String magnet,2 Boot basket,Scraper,Bumper sub and jars, w /HWDP and Intensifier. 15:00 15:45 0.75 355 2,030 COMPZ FISH TRIP T TIH In w/ Clean Out Assembly on 3 1/2" Drill Pipe. 15:45 16:45 1.00 2,030 2,093 COMPZ FISH CIRC T Stop and Make -up to TD and Reverse Circulate down from 2,030 ft & stack out again at 2,060 ft with Junk Basket, able to work junk basket down to 2,093 ft while stacking 15k down weight. Continue in hole and sat down hard with scraper assembly at 2,060 ft. Ciruulate up and down with junk basket and POOH. 16:45 17:00 0.25 2,093 355 COMPZ FISH TRIP T POOH f/ 2,093 -ft to 355 -ft. 17:00 17:30 0.50 355 0 COMPZ FISH TRIP T POOH with BHA #2, dropping out CSG scraper, clean magnets and inspect RCJB. 17:30 18:00 0.50 0 351 COMPZ FISH TRIP T RIH w/ BHA #3 to 351 -ft. Page 5 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 23:30 5.50 351 6,882 COMPZ FISH TRIP T Continue to RIH w/ BHA #3 on 3 1/2 DP from 351 -ft to 2,000 -ft. KU (kelly Up) and wash through tight spot at 2,060 -ft. Continue to RIH picking 3 1/2 DP to 5,507 -ft. Ran 2 stds of 3 1/2 HWDP and 13 stds of Hybrid push pipe to 6,882 -ft. 23:30 00:00 0.50 6,882 6,970 COMPZ FISH WASH T Kelly Up and wash down from 6,882 -ft to 6,970 at 8 bpm at 3,700 psi Rotating at 30 rpms at 3,900 ft/Ibs free torque at 115k ROT wt. UP wt 155k DN wt 95k 07/14/2011 Continue to C/O from 6,970 -ft to 7,040 -ft. POOH and Inspect RCJB. ND Riser and NU 7" x 13 5/8 Shooting Flange. RU HES and PDS - RIH w/ 40 Arm Caliper tool to 6502 -ft and log back to 115 -ft where Wireline over pulled. 00:00 01:30 1.50 6,970 7,024 COMPZ FISH WASH T Continue to wash down from 6,970 -ft to 7,024 -ft. at 4 bpm at 780 psi. UP wt 155k DN wt 95k 01:30 07:00 5.50 7,024 351 COMPZ FISH TRIP T POOH f/ 7,024 -ft to 351 -ft 07:00 08:00 1.00 351 0 COMPZ FISH PULD T POOH, Lay down and inspect boot basket and junk basket. Had 2 small section of SS bands in the boot basket and 1 small peace inside junk basket and some armor from the ESP cable on the magnet. 08:00 11:00 3.00 0 0 COMPZ EVALWE NUND P Nipple Down Annular and Nipple Up Shooting Flange. Call Out E -line Crew. 11:00 12:00 1.00 0 0 COMPZ EVALWE OTHR T Wait On E -line Crew. Continue to Load PH -6 Tubing in Pipe Shed. 12:00 12:15 0.25 0 0 COMPZ EVALWESFTY P E -Line on Location. Hold PJSM with E -line crew and Rig crew. 12:15 15:15 3.00 0 0 COMPZ EVALWE ELOG P Spot E -line equipment and Load tools to Rig Floor. 15:15 17:00 1.75 0 0 COMPZ EVALWE ELOG T Had to Re -head E -Line Cable. 17:00 19:00 2.00 0 0 COMPZ EVALWE ELOG T RIH with PDS Caliper (4 centralizers) / GR / CCL to 2052 -ft, attempt to pass- POOH and remove 2 of 4 centralizers. 19:00 20:00 1.00 0 0 COMPZ EVALWE ELOG T RIH with PDS Caliper (2 centralizers) / GR / CCL to 2052 -ft, unable to pass- POOH and add more weight to toolstring (TS weight 285 Ibs) 20:00 22:00 2.00 0 6,502 COMPZ EVALWE ELOG P RIH with PDS Caliper / GR / CCL, work Tool string through tight spots 2052 -ft to 2059 -ft, Continue RIH to 6183 -ft, work past easily and sat down at 6480 -ft, unable to work past 6485 -ft (74 degrees) after E -line Gamma Ray correlation, found depth to be 6502 -ft ELM 22:00 00:00 2.00 6,502 115 COMPZ EVALWE ELOG P Log up from 6502 -ft to Over Pull at Page 6 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/15/2011 24 hr Summary Evaluate Over Pull and POOH with PDS Caliper /GR/CCL from 115 -ft to Surface. RIH with GYRO / GR/CCL to 6502 -ft and log back to Surface, RD E -line. ND Shooting Flange. NU Annular. PU MU and RIH with 7 5/8 Casing Scraper Assembly (BHA #4) to 6995 -ft with little or no drag. POOH with BHA #4 to 6150 -ft. Slip and Cut 84 -ft Drilling Line. Continue POOH with BHA #4 to 1879 -ft. 00:00 02:30 2.50 115 0 COMPZ EVALWE ELOG P Over Pulled (500#) at 115 -ft, stuck in Grease Head and unable to RBIH. Inspect line at Grease Head with no visible signs of damage. Work wire free and RIH to 200 -ft. Bring on Charge pump at 2 bpm and wash line while POOH and Over Pull at 115 -ft. Monitor well for flow. PU Lubricator 4 -ft and inspect 50 -ft of line below Grease Head, no visible signs of damage. MU lubricator and pull 1000# over and POOH to surface. Data sent for Interpretation. 02:30 04:00 1.50 0 0 COMPZ EVALWE ELOG T Cut 300' and rehead line. remove Grease Head and install Dual stripper pack off. 04:00 04:15 0.25 0 0 COMPZ EVALWE ELOG P Standby for GYRODATA Tool checks. 04:15 06:00 1.75 COMPZ EVALWE ELOG P Rig Up GYRO, RIH and log continuous GYRO down. Station Stops @ 50, 590, 690, 750. 06:00 10:00 4.00 2,092 6,504 COMPZ EVALWE ELOG P HES Crew Change. Continue RIH w/ Gyrodata tool string. Tools stop falling at 2092' try pass again, succeed, Log down for continuous GYRO survey making stops at 4250' and 6,504 feet. Log out for continuous Gyro Survey from 6504' to surface making stops at 4350', 2500', 750', 690', 590', to surface. 10:00 10:15 0.25 0 0 COMPZ EVALWESFTY P PJSM with E -Line and Rig Crew on Rigging down E -Line Tools. 10:15 11:00 0.75 0 0 COMPZ EVALWE PULD P Rig back and lay Gyrodata Tool string and E -line Tools and Equipment. 11:00 12:30 1.50 0 0 COMPZ EVALWE NUND P ND Shooting Flange and NU Annular. 12:30 13:30 1.00 0 45 COMPZ WELLPF PULD T PJSM with Baker Rep and Rig Crew. Load Tools to Rig Floor. MU 7 5/8" Scraper Assembly with 4 3/4" Bumper Sub on 3 1/2" Drill Pipe. 13:30 16:30 3.00 45 6,995 COMPZ WELLPF TRIP T Continue in hole with Scraper Assembly on 3 1/2" DP. Able to work 7 5/8" Scraper down to 6995.0 ft, leaving two foot of the Mule shoe passed the Hook hanger. PUH 10 feet. Up Wt =163k / Down Wt =90k 16:30 18:30 2.00 6,985 6,985 COMPZ WELLPF CIRC T Reverse Circulate 27 bbl High -Vis Sweep at 5 bpm and Circulate BU. ICP 140 psi FCP 210 psi. 18:30 19:30 1.00 6,985 6,110 COMPZ WELLPF TRIP T Blow Down Top Drive. Fill Trip Tank. POOH from 6985 -ft and stand back 10 stands of Push Pipe to 6110 -ft Page 7 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:30 2.00 6,110 6,110 COMPZ WELLPF SLPC T PJSM- Hang Blocks, Slip and Cut 84 -ft of 1 -1/8" Drill Line and service draw works. 21:30 00:00 2.50 6,110 1,879 COMPZ WELLPF TRIP T Continue to POOH from 6110 -ft standing back 5 stands of Push Pipe, 5 stands of HWDP and 34 stands of Drill Pipe to 1879 -ft. Up wt. 52k 07/16/2011 Continue POOH with BHA #4, LD KO. Load BHA #5. PU MU BHA #5 and change over floor equipment. PU MU and RIH with 4407 -ft of 2 3/8 PH -6 plus remainder of BHA #5. RIH with BHA #5 cleaning out from Top of Fill at 9748 -ft to 10180 -ft. 00:00 01:00 1.00 1,879 0 COMPZ WELLPF TRIP T Continue to POOH from 1879 -ft standing back remainder of DP and Scraper BHA, Lay Down same. 01:00 02:00 1.00 0 0 COMPZ WELLPF OTHR T Kick Out Scraper BHA #4 and load Clean Out BHA #5. Change over floor equipment. 02:00 08:00 6.00 0 4,407 COMPZ WELLPF TRIP P PJSM. M/U 2 3/8" Mule Shoe and Single in 2 3/8" PH 6 Tubing Down to 4,407 ft. Up Wt =52k. 08:00 09:00 1.00 4,407 4,780 COMPZ WELLPF PULD P PJSM, C/O Floor Equipment and Make Up BHA #5. String Magnet/Dual Boot Baskets /String Magnet/Bumper Sub /Jars // Pump Out Sub /9 jts. /HWDP /Intensifier and Drill Pipe 09:00 10:30 1.50 4,780 7,100 COMPZ WELLPF TRIP P Continue in hole with clean out assembly on 3 1/2" Drill Pipe. Set down at 7,038 ft ( bottom of hook hanger) able to work passed, continue down to 7,100 ft, stop and set top drive torque to 6k 10:30 11:00 0.50 7,100 7,261 COMPZ WELLPF CIRC P Continue down to 7,261 ft. Stop and circulated at 3 bpm, 900 psi to make sure Drill pipe is clear. 11:00 12:30 1.50 7,261 7,948 COMPZ WELLPF TRIP P Continue in hole with clean out assembly. Wt CK @ 7,680 ft, 105k up / 63k dn. Set down at 7,948 ft. 12:30 15:00 2.50 7,948 8,466 COMPZ WELLPF CIRC P Start Circulating at 4 bpm, 1700 psi, Rotating at 11 rpm, Torque at 2 -3k 15:00 18:00 3.00 8,466 9,350 COMPZ WELLPF CIRC P Continue to Circulate at 4 bpm, 1935 psi, rotating at 11 RPM, 2 -3k torque, cleaning blank section of 4" liner and slotted section 4" liner. Adding safe lube to the pit system to help with torque and drag, and circulating pressure. 18:00 00:00 6.00 9,350 10,180 COMPZ WELLPF CIRC P Continue to Circulate at 4 bpm at 2240 psi, 2 -3k torque at 10 rpm, Up 113k Down 63k, cleaning blank section of 4" liner and slotted section 4" liner. Adding safe lube to the pit system to help with torque and drag, and circulating pressure. Page 8 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/17/2011 24 hr Summary Pick up out of 4" liner f/ 10,270 -ft to 7196 -ft to rebuild surface volume. Continue RIH w/ Clean out BHA. Clean out lower 4" liner f/ 10,257 -ft to 11,400 -ft. Circulate 4 bpm until clean @ 2300 psi with average 50% loses, 3100 ft/lb Torque @ 11 rpm, Up / Dn= 135k / 87k. POOH standing back Push Pipe and DP. LD- KO Clean out BHA. Change over floors to 2 3/8 equipment. 00:00 01:00 1.00 10,180 10,270 COMPZ WELLPF CIRC P Continue to Circulate at 4 bpm at 2240 psi, 2 -3k torque at 10 rpm, Up wt 113k Down wt 63k, cleaning blank section of 4" liner and slotted section 4" liner 10,180 -ft to 10,270 -ft. Adding safe lube to the pit system to help with torque and drag, and circulating pressure. 01:00 03:30 2.50 10,270 7,193 COMPZ WELLPF CIRC T Pick Up out of 4" Liner f/ 10270 -ft to 7193 -ft to rebuild Surface Volume. Unable to filter fluid and transport fluid to the rig at the same time. 03:30 11:00 7.50 7,193 7,193 COMPZ WELLPF CIRC P Build Surface Volume in spare up -right tanks. RIH with clean out assembly f/ 7193 -ft. 11:00 15:00 4.00 7,193 10,257 COMPZ WELLPF CIRC P Back on bottom with clean out assembly. M/U to TD and Continue to clean out blank section and slotted section of 4" Liner. Pump Rate 4 bpm, 2080 psi, rotating at 11 rpm, 2 -2.5k torque. Up wt= 118k / Dn Wt= 75k, rotating wt =85k. Set down on Fill at 10,257 ft. 15:00 17:30 2.50 10,257 11,400 COMPZ WELLPF CIRC P Able to clean 4" Liner down to 11,400 ft, while pumping at 4 bpm, 2290 psi, Rotating at 11 rpm, 3000 ft/Ibs torque, average loses at 50 %, pumped high -vis sweep on every 1000 ft of liner clean, very little sand seen across shakers. Pumped another High -Vis sweep after reaching 11,400 ft and continue to circulate until clean. 17:30 22:00 4.50 11,400 4,780 COMPZ WELLPF TRIP P Blow Down Top Drive. POOH f/ 11,400 -ft, Up wt= 143k / Dn wt =90k standing back Push Pipe and Drill Pipe to 4780 -ft. 22:00 23:00 1.00 4,780 4,403 COMPZ WELLPF PULD P Lay down Intesifier / HWDP / Clean out BHA to 4403 -ft. Up wt =53k / Dn wt= 50k 23:00 00:00 1.00 4,403 4,403 COMPZ WELLPF SFTY P PJSM- Laying down 2 3/8 PH -6 Tubing. Table Top Man Down Drill. Change over floors to 2 3/8 equipment. 07/18/2011 Single out 2 3/8 PH -6. C/O Floors. PU -MU and RIH with 6 3/4 String Mill on Drill Pipe, will not pass 2078 -ft with 15k Dn wt. POOH & LD BHA #6. Weekly BOPE test performed, witnessed by Jeff Jones. PU -MU and RIH with 4 1/4 IBP on 3 1/2 Drill Pipe to 5143 -ft. 00:00 04:00 4.00 4,403 0 COMPZ WELLPF PULD P Single out 2 3/8 PH -6 Tubing to pipe shed. Changed out Joint 129 due to bad Tread in box end, strapped and entered into Master sheet. Page 9 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:00 1.00 0 0 COMPZ WELLPF PULD T PJSM. Change over floors. Load String Mill Assembly to floor. 05:00 05:45 0.75 0 455 COMPZ WELLPF PULD T PU MU Mule shoe / 6 3/4 String Mill / 1 std Hybrid DC / Dual 4 3/4 Boot Baskets / Bit Sub / String Magnet / Bumper Sub / Jars / Pump Out Sub / 9 jts HWDP / Intensifier followed by 3 1/2 DP. 05:45 06:30 0.75 455 2,078 COMPZ WELLPF TRIP T Continue In hole with String Mill assembly on Drill Pipe. Set down at 2,050 -ft, stacked 4k down and fell thru, continue in slow and set down at 2,078 -ft, stacked 17k down no -go, puh 5 feet and try to rotate at 5 rpm and torque up. POOH 06:30 07:15 0.75 2,078 455 COMPZ WELLPFTRIP T PJSM. POOH standing back Drill Pipe. 07:15 08:00 0.75 455 0 COMPZ WELLPF PULD T Lay Down 6 3/4" String Mill Assembly. 08:00 16:00 8.00 0 0 COMPZ WELLPF BOPE P Set Test Plug and Perform Weekly (O r BOP Test 250/3000 psi. Annular G{ 250/3000 ps i. witnessed by Jeff �( Jones. 16:00 17:00 1.00 0 0 COMPZ WELLPF BOPE T Inspect and Replace seals on the VPR's. 17:00 18:00 1.00 0 0 COMPZ WELLPF BOPE P Continue Testing BOPE, 250/3000 psi. 18:00 19:00 1.00 0 0 COMPZ WELLPF BOPE P Rig Down Test equipment. Pull Test Plug. Set Wear Ring. 19:00 00:00 5.00 0 5,143 COMPZ WELLPF PULD P PJSM. PU MU 4 1/4 IBP / Running Tool Assembly (BHA #7) and RIH on 3 1/2 Drill Pipe to 5143 -ft. Up wt= 93k / Down wt= 74k. X7/19/2011 POOH w/ IBP Running Tool. RIH w/ Retrieving head on DP to 6950 -ft. Dump 20 -ft sand on IBP. POOH with Retrieving head Assembly. P/T Casing 1500 psi. POOH f/ 6,980 -ft to 3,387 -ft. 00:00 01:30 1.50 5,143 6,974 COMPZ WELLPFTRIP P Continue RIH with 4 1/4 IBP on 3 1/2 Drill Pipe f/ 5143 -ft to 6974 -ft. Up w t= 137k, Down wt= 95k 01:30 01:45 0.25 6,974 6,947 COMPZ WELLPF PLUG P Kelly Up and pump pipe volume of 52 bbls at 3 bpm. ICP= 500 psi, FCP 570 psi, returns at 31 bbls. 01:45 02:15 0.50 6,974 7,000 COMPZ WELLPF PLUG P Drop 1/2" steel ball, add 1 joint HWDP and RIH 26' to 7000 -ft (bottom of IBP) bring pump on 1.5 bpm for 17 bbls and caught pressure. 02:15 03:15 1.00 7,000 6,970 COMPZ WELLPF PLUG P Pressure up IBP in 500 psi stages, 10 minutes each. Shear off IBP @ 2040 psi, Stack 5k down, Pick off clean to 6970 -ft. IBP set. 03:15 04:00 0.75 6,970 6,970 COMPZ WELLPF PRTS P Pressure Test against IBP tp 1450 psi, pressure bleeds back to 800 psi in 5 minutes then slows. Attempt same Pressure test with same results. 04:00 09:30 5.50 6,970 0 COMPZ WELLPFTRIP P POOH with IBP setting tool standing back DP. Page 10 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 10:30 1.00 0 0 COMPZ WELLPF PULD P Lay Down Setting tool BHA 10:30 13:30 3.00 0 6,980 COMPZ WELLPF TRIP P PU Retrieving Head and RIH on DP to 6,980 -ft 13:30 21:00 7.50 6,980 6,980 COMPZ WELLPF MPSP P Dump 400# 40 -20 river sand while pumping minimum rate. Pump 52 bbl pipe volume. Let sand settle above IBP for 1 hr. RIH to 6,980 -ft No tag. POOH to 6,534 -ft. and Reverse circulate 30 bbls at 2 bpm at 170 psi. RIH f/ 6,534 -ft to 6,980 -ft and Soft Tag Sand Top with 2k down. 21:00 21:30 0.50 6,980 6,980 COMPZ WELLPF PRTS T Pressure Test IBP in 7 5/8 Casing 1Q00psi a d1QP IeWose. 21:30 21:45 0.25 6,980 6,980 COMPZ WELLPF SFTY T Held PJSM on POOH with BHA #8 21:45 00:00 2.25 6,980 3,387 COMPZ WELLPF TRIP T POOH from 6,980 -ft to 3,387 -ft as of midnight. 73k up wt, 63k do wt. 07/20/2011 Continue to POOH f/ 3,387 -ft to surface. PU and MU 6.5" OD CSG swage and RIH to 2,995 -ft with no issues. POOH and Continue to swage out to 6 3/4" from 2,050 -ft to 2,136 -ft. Fell out and slide to 2,160 -ft. 00:00 02:00 2.00 3,387 0 COMPZ WELLPF TRIP T POOH from 3,387 -ft to Surface and lay down "L" retreiving head assy. 02:00 04:00 2.00 0 772 COMPZ FISH PULD T PU, MU and RIH with BHA #9 (6.5" OD CSG swage assy) to 772 -ft. 04:00 05:30 1.50 772 2,995 COMPZ FISH TRIP T RIH w/ BHA #9 on 3 1/2" DP from 772 -ft. to 2,995 -ft. No issues with swage assembly. 05:30 08:00 2.50 2,995 0 COMPZ FISH SWDG T TOOH w/ BHA# 9. LD BHA #9. Load 6 5/8" and 6 3/4" swages in pipe shed. 08:00 10:30 2.50 0 2,995 COMPZ FISH PULD T PJSM. MU BHA # 10 6 5/8" Swage assembly. RIH w/ Swage on 3 1/2" DP to 2,995 -ft. Took 2 -4K down weight from 2,077 -ft to 2,157 -ft, no other issues. 10:30 12:30 2.00 2,995 0 COMPZ FISH TRIP T TOOH w/ BHA# 10. LD BHA # 10. Page 1 1 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 00:00 11.50 0 2,160 COMPZ FISH PULD T PJSM. MU BHA # 11 6 3/4" Swage assembly. RIH w/ Swage on 3 1/2" DP to 6,800 -ft. Set down @ 2,050 -ft, start swaging on tight spots at 13:30. Continue to swedge thru to 2,057 -ft. - fell thru at 14:00 hrs. Pull back up above and slide thru with 15k down to Tag up at 2,074 -ft. Swedge thru to 2,078 -ft. Fell thru at 14:45 hrs and continue to RIH to 2,080 -ft and set down. At 15:45 hrs Conduct Top drive and derrick inspection. Begin swedging at 16:15 hrs from 2,080 -ft to 2,086 -ft and fell thru at 19:35 hrs to 2,108 -ft. Begin filling hole with 3% safe lube by vol. at 18:00 hrs at 15 bbl /hr rate and continue Swedge from 2,108 -ft to 2,112 -ft and fell thru at 22:00 hrs, slide down to 2,118 -ft at 23:00 hrs, work thru to 2,122 -ft and fell thru to 2,131 -ft. Work thru to 2,136 -ft and fell thru. RIH to 2,160 as of midnight. 07/21/2011 Continue RIH with 6 3/4 OD Casing Swage f/ 2,160 -ft to 3,061 -ft. Slip and Cut 1500 -ft Drill Line. PUH and work 6 3/4 OD Swage between 2,050 -ft and 2,136 -ft. POOH and check BHA and Joint tightness. Utilizing Daily Jars work 6 3/4 OD Casing Swage back and forth between tight areas 2,050 -ft and 2,083 -ft. Push 6 3/4 OD swage down through 2,083 -ft at 35k Down wt, Drag back up through 2,083 -ft at 30k. 00:00 02:00 2.00 2,160 3,061 COMPZ FISH SWDG T Continue RIH f/ 2,160 w/ 6 1/4 Casing Swage. Set down at 2,921 -ft, Drill string floating or pushing fill to 3,061 -ft. Pump down Annulus and string weight returns. PUH to 2,836 -ft at 01:30 clean. Set Slips. Maintain hourly hole fill. 02:00 05:30 3.50 2,836 28 COMPZ RIGMN1SLPC T Slip and Cut 1500 -ft Drill Line, Full Spool. Inspect Derrick prior to POOH. 05:30 07:00 1.50 2,836 2,050 COMPZ FISH SWDG T PUH f/ 2,836 -ft to 2,130 -ft and pulled 80k over string up wt of 90k. Jar thru after several jar hits. Continue to pull up to 2,050 -ft. Working 6 3/4" OD CSG swedge through tight areas. 07:00 11:00 4.00 2,050 2,108 COMPZ FISH SWDG T RIH and from 2,050 -ft through tight spot at 2,061 -ft with 10k down drag and tagged up 2,080 -ft. Swedge thru to 2,085 -ft and fell free. Pull back thru at 55k over string wt of 90k. Continue to swedge back and forth this area. Best drag seen was 35 to 40k over pull. RIH and set down at 2,108 -ft. 11:00 12:00 1.00 2,108 2,112 COMPZ FISH SWDG T Continue to swedge thru from 2,108 -ft to 2,112 -ft and fell thru. Continue to work this area, 60k over string wt of 90k was best seen. Page 12 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:45 2.75 2,112 2,112 COMPZ FISH OTHR T While swedging bolts broke at top drive and fell to rig floor. Suspend swedging operations and locate area that bolts fell from. Replace bolts and inspect equipment. 14:45 15:00 0.25 2,112 2,112 COMPZ FISH SFTY T Held PJSM on Tripping out of the hole and changing BHA. 15:00 16:30 1.50 2,112 0 COMPZ FISH TRIP T POOH with 6.75" OD CSG swedge from 2,112 -ft. to CSG swedge. 16:30 17:30 1.00 0 0 COMPZ FISH PULD T LD Intensifier and Fishing Jars. Inspect Casing Swage, small gouge down one side. PU fresh Intensifier and Daily Up /Down Jars. MU BHA #10- 6 3/4 OD Casing Swage. 17:30 18:30 1.00 0 795 COMPZ FISH TRIP T RIH with 6 3/4 OD Casing Swage Assembly checking all breaks on BHA to 795 -ft. 18:30 19:30 1.00 795 2,050 COMPZ FISH TRIP T Continue RIH adding Drill Pipe to BHA checking breaks on all stands to 2,050 -ft. Up wt= 70k, Dn wt= 60k 19:30 23:30 4.00 2,050 2,095 COMPZ FISH SWDG T Slid through 2,050 -ft with 10k down to 2,083 -ft. Swage down at 2,083 -ft total of 14 Daily Jar hits and fell thru at 2,089 -ft. PUH with 50k over pull. Swage thru same area 12 times improving each time until only 3 Daily Jars down to pass, PUH with 30k over pull through 2,083 -ft. 23:30 00:00 0.50 2,095 2,083 COMPZ FISH SWDG T MU to Top Drive. Attempt to push through 2,083 -ft. Remove 1 joint DP to reduce flex on surface pipe. MU to Top Drive. Push through tight area 35k down wt. PU through 2,083 -ft with 30k over pull as of midnight. X7/22/2011 Swag @ Down f/ 2,083 -ft through 2,136 -ft w/ 6 3/4 OD Casing Swage. POOH standing back DP, LD BHA #12. PU MU and RIH w/ 6.70" OD Drift on DP to 2,995 -ft with no issues. POOH standing back DP, LD BHA #13. PU MU and RIH w/ 6.43" max OD ALC Dummy Drift to 3,011 -ft with no issues. POOH with ALC Dummy Drift to 212 -ft as of midnight. 00:00 03:00 3.00 2,083 2,118 COMPZ FISH SWDG T Push 6 3/4 Casing Swage through 2,083 -ft using Top Drive at 35k down wt. Set down at 2,108 -ft. 14 Dailey Jars to pass through 2,108 -ft, PUH through 2,108 -ft at 55k over pull. Work back and forth until only 5 Daily Jars to pass 2,108 -ft, PUH 25k over pull to pass 2,108 -ft. Unable to push through with Top Drive. Work through to 2,118 -ft. 03:00 03:30 0.50 2,118 2,118 COMPZ FISH SWDG T Swage down through 2,118 -ft w/ 4 Dailey Jars down. PUH through 2,118 -ft w/ 40k over pull. work back and forth several times w/ same results Page 13 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:30 1.00 2,118 2,245 COMPZ FISH SWDG T RIH to 2,131 -ft and sit down. 1 Daily Jar and fell through, PUH with 20K over pull, repeat 3 times with same results. RIH to 2,245 -ft. Up wt= 70k, Down wt= 60k. 04:30 08:30 4.00 2,245 2,080 COMPZ FISH SWDG T POOH with 6 3/4 OD swage f/ 2,245 -ft. Over Pull 20 -30k through tight areas at 2,131 -ft, 2,118 -ft and 2,108 -ft. Over Pull 100k at 2,080 -ft. Swage thru tight area 10 to 12 cycles from 2,080 -ft to 2,086 -ft with 30k slide. Conduct derrick inspection. 08:30 09:00 0.50 2,080 795 COMPZ FISH TRIP T POOH from 2,080 -ft to 795 -ft. to BHA #11 09:00 10:00 1.00 795 0 COMPZ FISH PULD T POOH and lay down 6.75" OD CSG Swage. OD of Swage 6.75 ", minor scratches only. 10:00 10:30 0.50 0 0 COMPZ FISH OTHR T Bring in tools and off load BHA #10 10:30 10:45 0.25 0 0 COMPZ FISH SFTY T Held PJSM on PU and MU BHA #11 (6.70" OD CSG Swage assy) 10:45 13:00 2.25 0 2,995 COMPZ FISH TRIP T PU and RIH w/ BHA #11 to 2,995 -ft. Most drag seen through from 2,100 -ft to 2,122 -ft was 1k slack off. clean to 2,995-ft. 13:00 14:30 1.50 2,995 959 COMPZ FISH TRIP T POOH from 2,995 -ft to BHA at 959 -ft. No over pull seen. 14:30 15:45 1.25 959 0 COMPZ FISH PULD T POOH with BHA from 959 -ft laying down un- needed components to surface. No marks on 6.70 drift. 15:45 17:00 1.25 0 0 COMPZ FISH PULD T Send out Baker Tools and 3 DC's. Clean and change over floors to run 4 1/2 Tubing. Bring in ALC equipment. 17:00 20:00 3.00 0 212 COMPZ FISH PULD T PJSM w crews. PU MU and RIH 6.43" max OD ALC (BHA #12) Dummy as per ALC to 212 -ft. Change over floors to run 3 1/2 DP. 20:00 22:00 2.00 212 3,011 COMPZ FISH TRIP T RIH w/ ALC Dummy Drift Assembly on 3 1/2 DP. 18 stds down (1952 -ft) 58k do wt / 60k up wt. No Drag seen in tight area 2,050 -ft thru 2,136 -ft. No Drag seen to 3,011 -ft. 22:00 23:30 1.50 3,011 212 COMPZ FISH TRIP T PJSM. POOH from 3,011 -ft with ALC Dummy Drift to 212 -ft BHA #12. No Drag seen thru tight areas. 23:30 00:00 0.50 212 212 COMPZ FISH PULD T Change Over floor to LD 4 1/2 Tubing as of midnight. 07/23/2011 PU MU & RIH w/ "G" RBP- Test plug Assembly. Unable to pass 3,343 -ft, PUH and set RBP at 3,303 -ft. Test 7 5/8 Casing to 1500 psi, Passed and Charted. POOH w/ RBP assembly standing back DP, LD BHA #15. PU MU & RIH w/ IBP Retrieving Head Assembly to 7,186 -ft. Attempt to latch IBP unsuccessful. 00:00 02:30 2.50 212 0 COMPZ FISH PULD T POOH and LD 6.43" max OD BHA #12 Dummy Drift as per ALC. Send out ALC equipment. Clean & C/O floors. Load Baker tools. Page 14 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:30 1.00 0 123 COMPZ FISH PULD T PU MU Baker RBP, 1 std DP, Retrievamatic Test Plug Assembly to 123 -ft 03:30 09:45 6.25 123 3,343 COMPZ FISH TRIP T RIH w/ RBP BHA #13 on DP. Sat down at 3208 -ft. Kelly Up, Pump down 2 bpm and work down to 3,343 -ft. PU and set "G" plug at 3,303-ft. 09:45 10:45 1.00 3,303 3,303 COMPZ FISH PRTS P Pressure test 7 5/8" CSG from 3,303 -ft to surface at 1,500 psi for 15 minutes. Lost 50 psi in first 5 minutes and lost 0 psi in last 10 minutes. Bleed off pressure. Latch on to "G" plug and release same. Allow elements to relax. 10:45 11:15 0.50 3,303 3,303 COMPZ FISH SFTY P Held PSJM on POOH with integrity testing equipment. 11:15 13:30 2.25 3,303 0 COMPZ FISH TRIP P POOH from 3,303 -ft. to surface and laydown test packer and "G" plug. 13:30 14:00 0.50 0 0 COMPZ FISH SFTY P Held PJSM with Rig crew and Baker hand on changing out floor equipment and MU of BHA 14:00 15:00 1.00 0 0 COMPZ FISH OTHR T Change over to 2 3/8 TBG equipment and off load Test Packer assy. 15:00 15:45 0.75 0 231 COMPZ FISH PULD T PU and MU BHA #16 ( IBP retrieval tool ) to 231 -ft. 15:45 16:00 0.25 231 231 COMPZ FISH OTHR T Change over to 3 1/2 DP equipment 16:00 20:00 4.00 231 6,916 COMPZ FISH TRIP T RIH adding DP, Push Pipe and 3 stds HWDP to 6916 -ft. Up wt= 133k, Dn wt= 88k. Kelly Up, pump 2 bpm @ 120 psi, 3 bpm @ 320 psi, 4 bpm @ 650 psi, 5 bpm @ 970 psi. 20:00 23:00 3.00 6,916 7,186 COMPZ FISH TRIP T Continue RIH slowly adding last 2 stds HWDP, Spike in pump pressure @ 7,032 -ft, PUH but did not latch IBP continue RIH passing Hook Hanger at 7,040 -ft pumping 3 bpm. Sat down 5k @ 7186 -ft, pump pressure spike to 480 psi. Attempt to latch IBP multiple times pumping up to 5 bpm to not pumping, PUH and rotating 1/8 and 1/4 turns for new grapple orientation, RIH at different speeds, setting down up to 10k several times, unable to latch IBP. 23:00 23:30 0.50 7,186 7,186 COMPZ FISH SFTY P PJSM- Handleing Halliburton TCP guns and tools. Tripping out, LD BHA. 23:30 00:00 0.50 7,186 7,186 COMPZ FISH OTHR P Bring in Halliburton TCP guns and tools to pipe shed as of midnight 07/24/2011 Bring in HES TCP equipment. POOH f/ 7,186 -ft w/ IBP Retrieving Head Ass'y standing back DP- LD BHA #16. PU MU & RIH w/ IBP Retrieving Head (Short Catch) Ass'y to 7,185 -ft. POOH w/ failed 4 1/4 IBP standing back DP- LD BHA #17. PU MU & RIH w/ HES TCP Gun Ass'y to 3,342 -ft as of midnight. 00:00 00:30 0.50 7,186 7,186 COMPZ FISH OTHR P Bring in Halliburton TCP guns and tools to pipe shed as of midnight 00:30 01:00 0.50 3,342 COMPZ FISH OWFF P BDTD and monitor well, well on vac. Page 15 of 24 1 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 04:00 3.00 7,186 231 COMPZ FISH TRIP T POOH f/ 7,186 -ft with IBP Retrieving Head Ass'y standing back HWDP, Drill collars and Drill Pipe to BHA #13 at 231 -ft. 04:00 04:30 0.50 231 231 COMPZ FISH OTHR T Change floor over to 2 3/8 TBG equipment 04:30 05:00 0.50 231 0 COMPZ FISH PULD T POOH laying down BHA #16 - No fish, inspect IBP Overshot. No sign of trash inside OS. 05:00 05:30 0.50 0 231 COMPZ FISH PULD T PU Series 70 Over shot w/ 1.75" Grapple. RIH to 231 -ft 05:30 06:00 0.50 231 231 COMPZ FISH OTHR T Change floor over to 3 1/2 DP equipment 06:00 09:30 3.50 231 7,185 COMPZ FISH TRIP T RIH from 231 -ft to 7,185 -ft. 09:30 10:30 1.00 7,185 7,185 COMPZ FISH FISH T Attempt to engage fish, unable to see pressure increase. Munipulate overshot multiple times. 10:30 10:45 0.25 7,185 7,185 COMPZ FISH SFTY T Held PJSM on Blowing down Top drive and POOH w/ 3 1/2 DP. 10:45 15:00 4.25 7,185 231 COMPZ FISH TRIP T Blow down Top drive, POOH with 3 1/2 DP from 7,185 -ft. to 231 -ft. 15:00 15:30 0.50 231 231 COMPZ FISH OTHR T Change floor over to 2 3/8 TBG equipment 15:30 16:00 0.50 231 0 COMPZ FISH PULD T POOH laying down BHA #17 - Recovered fish, inspect IBP, showed damage on bottom - possibly. No sign of trash inside OS. 16:00 16:30 0.50 0 0 COMPZ FISH OTHR T Send out Baker tools 16:30 17:00 0.50 0 0 COMPZ PERF SFTY P PJSM w/ HES on assembling Perf Guns, Gun Safety. 17:00 19:30 2.50 0 924 COMPZ PERF TRIP P PU & assemble 2 3/4" 6spf Millennium Gun BHA #18 as per HES and RIH to 924 -ft. Up wt= 45k, Dn wt= 45k 19:30 00:00 4.50 924 3,342 COMPZ PERF TRIP P Single In 2 3/8 PH -6, L -80 Tubing f/ 924 -ft to 3,342 -ft filling every 5 stands. Up wt= 53k, Dn wt= 48k 07/25/2011 Continue to RIH w/ HES Gun Ass'y f/ 3,342 -ft to 11,380 -ft. Fire Guns @ 11,380 -ft. POOH from 11,380 -ft standing back DP to 8,850 -ft as of midnight. 00:00 01:30 1.50 3,342 4,405 COMPZ PERF TRIP P Single In 2 3/8 PH -6, L -80 Tubing f/ 3,342 -ft to 4,179 -ft, install 4.12" OD no -go, continue to single in 2 3/8 PH -6 to 4,405 -ft, install XO. 01:30 02:00 0.50 4,405 4,405 COMPZ PERF OTHR P Change Over Floors to run 3 1/2 Drill Pipe. 02:00 04:30 2.50 4,405 7,304 COMPZ PERF TRIP P Cintinue R11-1w/ HES TCP Guns adding 3 1/2 DP f/ 4,405 -ft to 7,304-ft. 04:30 05:30 1.00 7,304 7,304 COMPZ PERF SVRG P Service Rig,. 05:30 07:00 1.50 7,304 7,304 COMPZ RIGMNT RGRP T Change out Stuffing Box. Page 16 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 16:30 9.50 7,304 9,530 COMPZ PERF TRIP P Continue RIH w/ HES TCP Guns adding 3 1/2 DP f/ 7,304 -ft. to 7,445 -ft and set down. Rotate 1/4 turn coming up 10 -ft and run back thru with no problems. Continue to RIH and setdown at 7,542 -ft try work thru, no luck. Pump down DP till fluid at surface and shut in DP. Close annular and pump down IA at 5 bpm at 156 psi. for 30 bbls. RIH to 7,859 -ft and set down, flush annulus and continue to RIH having to wash by pert guns to 9,530 -ft and was able to work on in the with very little trouble to 16:30 19:30 3.00 9,530 11,369 COMPZ PERF TRIP P Continue RIH adding Hybrid DC and HWDP. Able to work on in with very little trouble to 11,362 -ft. Up wt= 152k, Dn wt =85k. Add working joint, sat down and Tagged lightly (5k do wt) at 11,378 -ft (15 -ft into working joint) Tagged same spot several times to confirm Tag. Get weight back (152k) at 11,374 -ft. PUH to 11,369 -ft (6 -ft into working joint) with 10 -ft RKB correction bottom Gun at 11,379 -ft. Pump pipe volume of 61 bbls, 2.3 bpm @ 1000 psi. 19:30 21:00 1.50 11,369 11,369 COMPZ PERF PERF P Mouse hole working joint and drop 5/8" steel ball at 21:10. Add working joint, Kelly up and position guns again at 11,369 -ft. 11,379 -ft with 10 -ft RKB correction. bring pumps on 3 bpm at 1400 psi. 21:00 21:45 0.75 11,369 11,369 COMPZ PERF PERF P 32 bbls away when 5/8" ball seats, continue pumping 3 bpm. Guns Fired at 3350 psi and pipe pressure immediatly falls back to 1400 psi at 3 bpm for another 8 bbls, good recirculation through firing head. 21:45 22:00 0.25 11,369 11,369 COMPZ PERF SFTY P PJSM- Tripping OOH standing back DP. monitor well for flow, well on vac. 22:00 00:00 2.00 11,369 8,850 COMPZ PERF TRIP P PJSM- POOH from 11,369 -ft standing back HWDP, DC and DP to 8850 -ft (Up wt= 110k) maintaining hole fill, well still on vac as of midnight. 07/26/2011 Continue to POOH from 8,850 -ft w /Drill Pipe. Single down the 2 3/8" PH -6 Pipe. Lay down 2 3/8" " DP Conveyed Perf Guns. Swap out ESP Spools w /Crane. RU Test Equipment. Begin Weekly BOPE Test. 00:00 02:30 2.50 8,850 4,405 COMPZ PERF TRIP P Continue POOH f/ 8,850 -ft standing back DP to 4,405 -ft maintaining hole fill. 02:30 03:00 0.50 4,405 4,405 COMPZ PERF SFTY P Kick while tripping drill. PJSM- Single Out 2 3/8 PH -6. 03:00 04:00 1.00 4,405 4,405 COMPZ PERF OTHR P PJSM. Change over floors to 2 3/8 equipment. Page 17 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 07:30 3.50 4,405 926 COMPZ PERF TRIP P Single out 2 3/8 PH -6 Tubing from 4,405 -ft to 926 -ft 07:30 09:30 2.00 926 0 COMPZ PERF PULD P POOH f/ 926 -ft breaking down 2 3/4" TCP guns as per HES and sending out. 09:30 12:00 2.50 0 0 COMPZ RPEQP1OTHR P Crane arrives on Location. PJSM. Spot Crane. Change of ESP Spools on Rig Floor. Change out TEC Wire Spools. 12:00 13:30 1.50 0 0 COMPZ RPEQP1BOPE P Clear and clean Floor. Pull Wear Bushing. Set Test Plug. Rig up Test Equipment. Vv,.11 13:30 00:00 10.50 0 0 COMPZ WELCTI BOPE P Begin BOPE Test per Conoco /Phillips and AOGCC requirements at 250/3,000 psi. �' �� 07/27/2011 Complete weekly BOPE Test. Pick -up Baker Inflatable Cement Retainer. Single in with 2 3/8" PH -6 Tbg, continue in w/3 1/2" DP, DC, and HWDP. Drop Ball and set ICR. Establish Injection rates. RU Cementers. Pump Cement as designed. POOH w/ Work String. 00:00 05:00 5.00 0 0 COMPZ WELCTL BOPE P Complete the weekly BOPE Test at 250/3,000 psi. Perform Koomey draw down test. Record all pressure tests on Chart. The State's right to witness the test was waived by C. Scheve. (Note: had to troubleshoot Choke Manifold and replace Choke Valve #2. Re - -test same). Pull Test Plug. Install Wear Bushing. Rig down Test Equipment. 05:00 05:30 0.50 0 0 COMPZ RIGMN1OTHR P Grease crown, blocks, and prep for BHA # 19 ICR 05:30 10:30 5.00 0 3,042 COMPZ CEMEN TRIP P PU /MU Baker Inflatable Cement Retainer on 2 3/8" PH -6 pipe. TIH on PH -6 to 3,042 -ft with no problems. 10:30 11:00 0.50 3,042 3,042 COMPZ CEMEN" PULD P Change out floor equipment for 3.5" DP 11:00 20:00 9.00 3,042 10,010 COMPZ CEMEN" TRIP P Continue in hole with Baker ICR to 9,994 -ft on 3.5" DP, 4 3/4" Drill collars, and 3 1/2" Heavy Weight Drill Pipe. 20:00 00:00 4.00 10,010 9,985 COMPZ CEMEN" PACK P Blow down top Drive. Space out with the center element of the ICR at l LIC 9,985 -ft. (Cementers on Location and begin to rig -up). Drop 1/2" steel Setting Ball. Bring Pump on line at 0.75 bpm /150 psi and attempt to pump ball on seat (48 bbls pumped). Attempt to surge ball to go on seat. No -Joy. Dropped a second lighter 1/2" Ball. Bring Pump on line at 0.9 bpm. After 44 bbls away ball went on seat at 550 psi. Allow Element to inflate. Bump pressure up to 800 psi. Continue to allow element to inflate. Repeat same at 1,400 psi, 1,800 psi, and again at 2,200 psi. Page 18 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/28/2011 24 hr Summary POOH and single down the DP String. Prep to PU the 4 1/2" Completion. RU S -Line to drift the 4 1/2" Tbg. Single in with 4 1/2" Tbg. Trip out and stand back the 4 1/2" Tbg in the Derrick. Prep to PU and service ALC and Centrilift Equip. 00:00 00:15 0.25 9,985 9,985 COMPZ CEMEN" PACK P With 2,200 psi on ball seat, set 5K down on the Inflatable Cement Retainer. Bring final pressure up and shear out ball seat at 2,750 psi. 00:15 00:30 0.25 9,985 9,985 COMPZ CEMEN" OTHR P Perform an injection test with 8.6 lb/gal Brine as follows: 1.0 bpm/300 psi, 2.0 bpm /1,050 psi, and at 3.0 bpm /2,200 psi. 00:30 01:00 0.50 9,985 9,985 COMPZ CEMEN" SFTY P PJSM and operational meeting with All. 01:00 03:30 2.50 9,985 9,985 COMPZ CEMEN" CMNT P B c h up 66 bb of 8.5 Ib /gal Ultra , LiteCRETE w/ 2 -3 lb/gal CemNet. Prime up with 5 bbls of Fresh Water. Pressure Test Line at 4,000 psi. .4, Begin 8.97 lb/gal Cement at 1.7 bpm /825 psi. Increase rate to 2.0 bpm. 25 bbls Cement away, 2.0 bpm /1,720 psi, density 8.99 lb /gal. 40 bbls Cement away, 2.0 bpm /1,940 psi, density 8.96 lb/gal. 50 bbls Cement away, 2.0 bpm /2,100 psi, density 8.96 lb/gal. Reduce rate to 1.5 bpm/1,925 psi. 56.5 bbls Cement to ICR, 1.5 bpm /2,100 psi, density 8.96 lb/gal. 60 bbls cement away, 1.4 bpm /2,250 psi, density 8.6 lb/gal. End Cement with 66.6 bbls pumped, 1.4 bbls /2,540 psi. Begin 8.6 lb/gal Brine displacement. 15 bbls displaced, 1.3 bpm /2,900 psi. 25 bbls displaced, 1.3 bpm/2,935 psi. Reduce rate to 1.0 bpm. 35 bbls displaced, 1.0 bpm /2,820 psi. 45 bbls displaced, 3,010 psi. End displacement with 56.5 bbls pumped, 0.7 bpm /2,085 psi. ISIP = 1,425 psi. Monitor final DP pressure at 1,230 psi and stable (bottom flapper closed). Bleed Drill Pipe pressure down to 500 psi. and monitor stable. Bottom Flapper is holding. Un -sting from the ICR at 170K. 03:30 06:00 2.50 9,985 8,166 COMPZ RPEQPITRIP P Lay down 1 Joint and the two space -out Pups. Pump 10 bbls down the Drill Pipe. POOH standing back the DC /HWDP Stands (will lay down later). 06:00 06:30 0.50 8,166 8,166 COMPZ RPEQPI OWFF P Monitor well for flow. Static losses 78 BPH. 06:30 08:00 1.50 8,166 6,747 COMPZ RPEQPITRIP P TOOH from 8,166 -ft to 6,747 -ft, just above leg.Up 90K Down 65K 08:00 10:00 2.00 6,747 6,747 COMPZ RPEQP1OTHR P Slip & Cut drill line. Page 19 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 14:00 4.00 6,747 4,150 COMPZ RPEQPI TRIP P Continue out of hole from 6,747 -ft to 4,150, started pulling back wet. Monitor well, circulate bottom ups, suspect cement stringer plugging up off, pressure up initially, dropped off. 14:00 15:00 1.00 4,150 3,042 COMPZ RPEQP1RURD P Continue out of hole from 4,150 -ft to 3,420 -ft to 2 3/8" PH -6. Change handling equipment. 15:00 18:00 3.00 3,042 0 COMPZ RPEQP1TRIP P Continue out of hole laying down 2 3/8" PH -6 Tubing. Lay down Baker ICR Stinger. 18:00 20:30 2.50 0 0 COMPZ RPEQPI RURD P Change floor equipment to handle Drill Collars and Heavy Weight Drill Plpe. Clear Pipe Shed of the 2 2/3" PH -6 tubing. Bring in first row of the 4 1/2" Completion Tubing. 20:30 22:00 1.50 0 1,739 COMPZ RPEQPITRIP PJSM. Trip in with the remaining Drill Collar /Heavy Weight Drill Collars stands left in the Derrick. 22:00 00:00 2.00 1,739 0 COMPZ RPEQPI PULD P Single down all remaining 4 3/4" Drill collars and the 3 1/2" Heavy Weight Drill Pipe. 37/29/2011 Load Pipe Shed with the 4 1/2" Completion Tbg. PU 4 1/2" Tbg. RU S -Line and drift same. POOH and stand back 4 1/2" Tbg. Make -up and service the Outer Completion BHA. Begin to RIH the WLESP w /Feed -thru Packer Completion on 4 1/2" Tbg. 00:00 04:30 4.50 0 0 COMPZ RPCOM PUTB P Load 4 1/2 ", 12.6 lb/ft, L -80, IBTM -SCC Tubing in the Pipe Shed. Drift and tally same. Rig up Floor to handle same. 04:30 05:30 1.00 0 0 COMPZ RPCOM RURD P Change out floor equipment. 05:30 12:00 6.50 0 5,873 COMPZ RPCOM PUTB P Single in hole with 4.5" IBTM Completion Tubing only to 5,873 -ft. 12:00 15:30 3.50 5,873 5,873 COMPZ RPCOM SLKL P PJSM. RU Slickline equipment. RIH w/ 12' X 3.80" Dummy drift to 1,062 -ft. Unable to work drift through doglegs between 700' - 1,100 -ft. POOH w/ Drift. RIH w/ 3.82" Centralizer, drift tubing to 5,873 -ft, no problems. POOH. RD Slickline. 15:30 20:30 5.00 5,873 0 COMPZ RPCOM TRIP P PJSM. TOOH w/ 4.5" Completion tubing standing back in derrick (63 stands). 20:30 21:00 0.50 0 0 COMPZ RPCOM TRIP P Pull Wear Bushing. Clear Floor. 21:00 22:00 1.00 0 0 COMPZ RPCOM RCST P Hang ESP Cable and TEC Wire Sheaves. 22:00 00:00 2.00 0 0 COMPZ RPCOM RCST P PJSM. Begin to pick -up the Outer Completion BHA per ALC Service Reps. 07/30/2011 Complete running the Outer Completion BHA. RU S -Line and Drift Tbg. MU and RIH with ALC, Centrilift, Motor /Seal Section on S -Line. Continue to Run the 4 1/2" WLESP Completion Tbg, ESP Cable and TEC Wire. Page 20 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:30 3.50 0 467 COMPZ RPCOM RCST P Complete making up the Outer Completion BHA. Run 1 Stand of 4 1/2" Tubing. Make -up the Guardian Discharge Pressure Sub. Attach the TEC Wire. Run 3 Stands of 4 1/2" Tubing. 03:30 04:30 1.00 467 467 COMPZ RPCOM SLKL P PJSM. Rig up S -Line. Drft Tubing w/3.80" Drift, down to the NO -GO Sleeve at 467 -ft. POOH. Stand back S -Line. 04:30 09:00 4.50 467 467 COMPZ RPCOM RCST P Assemble ESP assembly. 09:00 12:00 3.00 467 467 COMPZ RPCOM RCST P RIH w/ Motor assembly (39.9' TL) to 431 -ft. Verify engagement. Test motor, good test. 12:00 15:00 3.00 467 467 COMPZ RPCOM RCST P PU Pump assembly (33.15' TL) . RIH w/ pump assembly set @ 398 -ft, jar down twice, shear -off, POOH. RIH w/ Pack -off assembly with check valve (4.7' TL) set pack -off, POOH. RIH w/ Test test and set above pack -off, POOH. PT pack -off to 2,000 psi for 10 mins, good test, bleed off. RIH w/ pulling tool and pull test tool, POOH. RIH w/ 4.5" tubing stop to above pack -off, set stop, POOH. RD S/L equipment. 15:00 19:30 4.50 467 1,402 COMPZ RPCOM RCST P PJSM. Continue in hole with 4.5" completion tubing to 1,402 -ft. Rig up S -Line and drift the Tubing with a 3.80" x 12' Drift. The Drift sat down a 1,067 -ft (as expected). (Note: the 12 -ft long drift is unable to pass through at this depth due to a Wellbore Dog -Leg , not due to a tubing problem). Set Back S -Line. 19:30 22:00 2.50 1,402 2,338 COMPZ RPCOM RCST P Continue to run in with the 4 1/2" Completion Tubing, ESP Cable, and TEC Wire as designed to 2,338 -ft. Rig up s -Line and drift the Tubing with a 3 82" x 1' Drift down to 1,257 -ft, with no problems. Set back S -Line. 22:00 00:00 2.00 2,338 3,117 COMPZ RPCOM RCST P Continue to run in with the 4 1/2" Completion Tubing, ESP Cable, and TEC Wire. PU /MU the lower 4 1/2" x 1" GLM. PU /MU the Viking ESP Feed -Thru Packer. Make electrical checks. Good. Stop to splice ESP Cable and TEC Wire through the Packer. Up Weight = 75K. Down Weight = 60K. 07/31/2011 Complete running the 4 1/2" WLESP Completion as designed. MU Tbg Hanger. Splice in the ESP Cable and the TEC Wire. Perform electrical checks. Land Tbg Hanger. ND BOPE. NU Prod Tree. Test. 00:00 07:00 7.00 3,117 3,117 COMPZ RPCOM RCST P Splice ESP Cable and the TEC Wire through the Packer. Perform electrical checks. Good. Page 21 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 13:30 6.50 3,117 6,040 COMPZ RPCOM RCST P Continue in hole with 4.5" ESP completion from 3,117 to 6,040 -ft. Up /Down weight @ 6,040 -ft 113K / 67K. Make drift runs with 3,82" Centralizer every 1,000 -ft and make electrical integrity test, no problems. 13:30 14:30 1.00 6,040 6,040 COMPZ RPCOM RCST P PU /MU hanger assembly, drift with S/L to 3.82" centralizer, RD S/L equipment. 14:30 21:30 7.00 6,040 6,040 COMPZ RPCOM RCST P Install penetrator. Splice ESP/Tec wire to bottom of hanger. Perform electrical checks. Good. Up Weight = 113K. Down Weight = 67K. 95 ea Single Channel Clamps used. 97 ea Modified Single Channel Clamps used. 12 Stainless steel Bands used. 21:30 23:30 2.00 6,040 6,115 COMPZ RPEQP1THGR P PJSM. Land Tubing Hanger. RILDS. Test upper and lower Hanger Seals at 5,000 psi. Both good. Lay down Landing Joint. Pull Side Port Isolation Sleeve. Install BPV. 23:30 00:00 0.50 0 0 COMPZ WHDBO NUND P PJSM. Begin to nipple down the 13 _5/8" BOP Stack. 38/01/2011 NU Tbg Head and Tree. Test. Pull TWCV. RU S -Line. Set WRP. FP Annulus w /Gel Diesel. Set Pkr. Pull DV from Lower GLM and FP Tbg. Set DV back in lower GLM. RD S -Line. Set BPV. Perform final Elect Checks. 00:00 04:00 4.00 0 COMPZ WHDBO NUND P Complete nipple down BOP Stack. Prep for long -term storage. 04:00 11:00 7.00 COMPZ WHDBO NUND P Nipple up Tubing Head Adapter and Tree. Pressure test tubing hanger void 5000 -psi for 10+ minutes. ALC and Centrilift both perform electrical integrity checks: Centrilift final 1390 -psi and 61.3 -deg F. Set BPV /two -way- checks and line up to PT tree. DSO dropped by to check on tree alignment: all good. PT hanger void to 250/5,000 psi. PT tree 250/5,000 psi for 10 mins, RD test equipment.. 11:00 16:30 5.50 COMPZ WHDBO SLKL P PJSM. RU S/L equipment, lubricator assembly, test lub. to 1,000 psi. RIH w/ 4.5" OK -1 to 3,105' -ft, locate lower mandrel for depth control, flag wire, POOH. RIH w/ HES DPU setting tool and Weatherford 4.5" WRP to 3,138 -ft, wait 30 mins for DPU to activate and set WRP, lose weight on string, stack weight on plug, POOH. Stand back lubricator and install cap on BOP's. Test WRP to 1,000 psi. Page22of24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 18:15 1.75 COMPZ RPCOM PACK P PJSM. RU LRS to casing and PT lines to 4,500 psi. Pump 74 bbls of Gelled Diesel down the 7 5/8" x 4 1/2" Annulus (ordered 85 bbls but did not get what we ordered). Continue to pump down the IA with 12 more barrels of plain Diesel. 18:15 18:45 0.50 COMPZ RPCOM PACK P Swap Lil' Red over to the Tubing side. Pump diesel down the Tubing at 0.5 bpm and pressure up to 4,500 psi. Hold pressure for 5 minutes. Bleed pressure back to "0" psi. Packer set. Pressure up one more time to 4,500 psi and hold for 5 minutes. Bleed back to "0 ". 18:45 19:30 0.75 COMPZ RPCOM PRTS P Swap Lil' Red back to the Annulus. Pressure up to 1,500 psi x 30 minutes to test the Packer and Casing. Good. Record test on chart. (Lost —125 psi in 30 minutes). Bleed pressure down to 750 psi and begin the decompression bleed -off schedule. 19:30 22:00 2.50 COMPZ RPCOM SLKL P PJSM. Rig up S -Line. Run in and set a Catcher Sub at 3,142 -ft. (Note: found that the WRP had moved down hole from the middle of the joint that it was set in to the next collar below during the setting of the Packer) POOH. Run in and pulled the Dummy Valve from the lower GLM at 3,105 -ft. POOH. Re -dress Dummy Valve and stab back on Well. 22:00 23:30 1.50 COMPZ RPCOM FRZP P S -Line start run in with the Dummy Valve. Lil' Red on line at 2.0 bpm /550 psi down the tubing with Diesel to freeze protect the tubing. Total Diesel pumped 50 bbls. S -Line set Dummy Valve back in the lower GLM at 3,105 -ft. Lil' Red pressure up on Tubing to 500 psi. Monitor at 500 psi. Dummy Valve set. Rig down and release Lil' Red. S -Line POOH. Lay down Lubricator. Complete rig down and release S -Line. Perform final electrical checks. Good. Final Guardian Pressure Sub reading = 1,380 psi /62 degs F. 23:30 00:00 0.50 COMPZ Set BPV. 08/02/2011 Clean Pits. Clean and secure Cellar. Disconnect from Shore Power. Release Rig. Begin scheduled Summer Maintenance. Page 23 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 08:00 8.00 COMPZ RIGMNI RURD P Clean Pits. Blow down Lines. Rig down Kill Tank Line. Clean and secure Cellar. Disconnect from Shore Power. Release Rig for Scheduled Summer Rig Maintenance. Page 24 of 24 Page l of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, July 27, 2011 8:54 AM To: Schwartz, Guy L (DOA); Packer, J.Brett Cc: Regg, James B (DOA); Scheve, Charles M (DOA) Subject: RE: 1C-104 (PTD #202 -061) Update Brett, Make sure the BOP test report also includes an explanation of the circumstances when it is submitted... Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Monday, July 25, 2011 6:09 PM To: Packer, J.Brett Cc: Regg, James B (DOA); Scheve, Charles M (DOA) Subject: Re: 1C -104 (PTD #202 -061) Update tt Li I_ 2 8 MI Brett, As we discussed the BOP test extension is approved until the TCP guns are OOH. L, c- TcP �,. re rank 6 c- .k{,e.s -LC . Guy ® 7 z z • l/ Sent from my iPhone On Jul 25, 2011, at 11:05 AM, "Packer, J.Brett" <J. Brett. Packer @conocophillips.com> wrote: Guy, I'm writing to inform you of our current situation and keep you updated as to our progress. We are due for a BOP test today and have given Chuck Scheve 24 hour notice. Last night, we started running in the hole with our tubing - conveyed perforating guns to punch cement squeeze holes in the toe of the B- lateral for the MBE remediation. Originally, we figured this would be a quick trip to bottom since we have already done a cleanout to bottom, then we could perforate the liner and just pull out of the hole. This morning, we encountered some sand in the lateral and started slowing down. We are currently at 7,800' MD and moving ahead trying to push the sand ahead of us to a final depth of 11,400' MD. Chuck Scheve has been kept in the loop as to our progress. We mentioned to him this morning the possible need for an extension, if for some reason, this takes much longer than expected, and that once perforated, we could pull back into the mainbore, set a storm packer, and complete our weekly BOP test today. He gave a verbal one -day extension and said not to worry about the storm packer, and just pull out of the hole as planned. Seeing as this is a verbal extension, I just wanted to get you caught up and have it in writing. Background This well is incorporating the new Wireline ESP technology that we just installed in 1D-121 prior to this well. This is the second well of it's kind to be run in Alaska. This workover is slightly more complicated because as 1D-121 was a straight hole, 1C-104 is a highly deviated dual - lateral well. 7/27/2011 Page 2 of 2 1C -104 was chosen as a candidate because of the high deviation and the sand production, so that we can test the limits of this new WLESP system. This workover is also burdened with an MBE remediation to squeeze the toe of the B- lateral and attempt to isolate the matrix bypass we are seeing from injector 1C -125, which is suspected to be the primary cause of the high water and sand production. Despite difficulties early on when we encountered some tight spots around 2100' RKB, we are back on track to complete this workover. Based upon our gyro data we obtained during this workover, it appears that the tight spots are the result of doglegs from the original drilling, and that our BHA was too rigid to drift through these doglegs. We were finally able to drift the tight spots for our ESP completion, and have successfully pressure tested the 7%" casing. The well has been cooperating nicely and we have seen no gas to surface. A recent SBHP was run on 6/29/11 prior to the workover and measured 1288 psi at 3405' TVD, equivalent to 7.3 ppg. The MPSP is 947 psi based upon the current SBHP and a 0.1 psi /ft gradient. We are currently using 8.5 ppg seawater as our KWF. Current Plan Forward From here on out, the procedure involves perforating the toe of the B -later liner, cementing the last 1500' of the liner, and running the new WLESP completion. Attached is a proposed completion for this well. If you have any additional questions or comments, don't hesitate to give me a call. Thank You, 5 Brett Packer �Dri�ng BZ 'Wells Workover Engineer Work# (907) 265 -6845 Cell# (907) 230 -8377 <1C -104 Proposed Completion.pdf> 7/27/2011 • • STATE OF ALASKA ~ . , ~ -- ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~~~~~ i~ ~'~'~ ~°~ ~• Cofnmis~i~~l 1.Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ Other 0 Install Tubing After Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Patch Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Well Class Before Work: Permit to Drill Number: ConocoPhillips Alaska, Inc. Oesrelopment ^`~ Exploratory ^ 202-061 / 3. Address: Stratigraphic ^ Service ^ .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23076-00 . Property Designation (Lease Number): Well Name and Number: ADL 25649 1 C-104 9. Field/Pool(s) Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: \ 11560' Total Depth measured feet Plugs (measured) feet true vertical ~ 3688' feet Junk (measured) feet Effective Depth measured feet Packer (measured) feet true vertical feet Packer (true vertical) feet Casing Length Size MD TVD Burst Collapse - Structural CONDUCTOR 122' 16" 158' 158' 1640 630 SURFACE 7359' 7-5/8" 7395' 3741' 6890 4790 LINER B-SAND 4342' 4-1/2" 11550' 3689' •fi, ~~lY d/ ~ ,t~ ~t L~1{i Perforation depth: Measured depth: 7446' - 11395' true vertical depth: 3692' - 3747' Tubing (size, grade, measured and true vertical depth) 4-1/2", L-80, 6229' MD, 3436 TVD Weatherford ER Patch from 6021' - 6134' RKB Packers &SSSV (type, measured and true vertical depth) No Packer No SSSV 11. Stimulation or cement squeeze summary: Intervals treated (measured) not app>lcabte Treatment descriptions including volumes used and final pressure: 12, Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments .Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations X ~5. Well Status after work: Oil Q Gas ^ WDSPL ^ GSTOR^ WAG^ GINJ ^ WINJ ^ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: N/A Contact Martin Walters / Brent Rogers Printed Name Martin Walters Title: Problem Wells Supervisor Signature ,~G~~~~~GG~~~ ~ Phone: 659-7535 Date 6-Jan-2010 Form 10-404 Revised 7/2009 RBOMS ~a~ i 4 ~ Submit Original Oniy 1 C-104 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/31/2009 1/3/2010 1/5/2010 SET 4 1/2 D&D PACKOFF-STINGER ASSEMBLY (8.3' OAL) @ 6142' RKB. SET LOWER SECTION OF PATCH (52' 8" OAL) @ 6134' RKB. SET MIDDLE SECTION OF PATCH (52' 10" OAL) @ 6082' RKB. IN PROGRESS. DEPLOY CATCHER SUB, REPLACED DGLV @ 6013' RKB W/ 2000 PSI SOV. PULL CATCHER SUB @ 6040' RKB. JOB SUSPENDED DUE TO LENGTH OF UPPER PATCH ISSUE. SET 4 1/2 ER PACKER, SPACER PIPE, AND STINGER (20.33' OAL) @ 6044' RKB (TOP OF PACKER @ 6021' RKB) TESTED AGAINST CHECK IN PACKOFF @ 1000 PSI (GOOD TEST) COMPLETE Summary SET WEATHERFORD ER PATCH OVER TUBING LEAKS FROM 6021' - 6134' RKB WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 3, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 1C -104 Run Date: 9/27/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 IC-104 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 23076 -00 Aii.o++ t 1 V' Y PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating 1 Attn: Rafael Barreto �Q� O 6900 Arctic Blvd. Anchorage, Alaska 99518 /1593Q Office: 907 273 -3527 Fax: 907 273 -3535 J rafael.b arreto @halliburton, com Date: Signed: • • ~~: PeoAcrive D'wyn~sric SeRVicES, INC. II,~LL L ~"~4/~S~f~l'TAL To: ao~cc Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 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 BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Bhrd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 26-0ct-09 1 G104 2j Signed Print Name: ~-~~ ~~~~ ~ ~ ZQ~~ 1 Report / EDE 50-029-23076-00 Date : , PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL : _~ ~_-- `--- - _ ~ WEBSITE _~ .N C'~Documen~s and Settings\Diane Williams\Desktop\Transmit_BP.docx • • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1C-104 Log Date: October 26, 2009 Field: West Sak Log No.: 7370 S#ate: Alaska Run No.: 2 API No.: 50-029-23076-00 Pipet Desc.: 4.5" 12.6 Ib. L-80 tBTM Top Log Intvl1.: 27 Ft. (MD) Pipet Use: Tubing Bot. Log Intvl1.: 6,131 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the top of GLM 2 @ 6,093.29' (Tubing Tally dated 90-25-07). ' This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage particularly in the vicinity of a known tubing leak (+/- 6,055' MD) prior to patching operations. The caliper recordings indicate the 4.5" tubing logged is in good to poor condition, with a maximum recorded wall penetration of 80% recorded in a line of pits in joint 192 (6,051'). Wall penetrations ranging from 40% to 64% wall thickness are recorded in 92 of the 201 joints logged. Recorded damage appears as a line of pits and general corrosion throughout the tubing logged and isolated pitting. No significant areas of cross-sectional wall loss or L D. restrictions are recorded throughout the tubing logged. A 3-D log plot of the caliper recordings across a known tubing leak is included in this report. This is the second time a PDS caliper has been run in this well and the first time this 4.5" tubing has been logged. MAXIMUM RECORDED WALL PENETRATIONS: Line of pits { 80%) Jt. 192 @ 6,051 Ft. (MD) Line of pits (64%) Jt. 97 @ 3,034 Ft. (MD) Line of pits (61%) Jt. 190 @ 5,946 Ft. (MD) Line of pits (60%) Jt. 155 @ 4,866 Ft. (MD) Line of pits { 59%) Jt. 118 @ 3,693 Ft. {MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 10%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant LD. restrictions are recorded throughout the tubing logged. Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: C. Kennedy ProActive Diagnostic Services, Inc. f P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281} 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907) 659-2314 ~b~ro~ ( 1~ aS ~^ u PDS Multifinger Caliper 3D Log Plot L, .. Company : ConocoPhillips Alaska, Inc. Field : West Sak Well : 1C-104 Date : October 26, 2009 Description : Detail of Caliper Recordings Across Known Tubing Leak (+/- 6,055' MD). • • Correlation of Recorded Damage to Borehole Profile Pipe 1 4.5 in (27.5' - 6112.6') Well: 1 C-104 Field: West Sak Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: October 26, 2009 Approx. Tool Deviation ^ Approx. Borehole Profile I 27 780 1552 2326 j I i 3108 ~ c GLM 1 '~ 3909 4694 5471 GLM 2 194 6113 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 194 25 50 a °r. ~'~ 75 100 `w Z c 125 ' ~ o 150 175 • • PDS Report Overview t. ~,~ Body Region Analysis Well: 1 C-104 Survey Date: October 26, 2009 Field: West Sak Tool Type: UW MFC 40 No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 12.6 f L-80 IBTM 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~,; metal loss body 200 150 100 50 ;ti 0 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of 'Dints anal se d total = 201 pene. 0 0 8 loss 10 141 0 100 93 0 0 0 0 Damage Configuration (body ) 250 - 200 150 100 50 0 isolated general line ring hole / poss pittirg corrosion corrosion corrosion ible hole Number of 'Dints dama ed total = 201 201 0 0 0 0 Damage Profile (°~ wall) ~ penetration body ~~; ~ metal loss body 0 50 100 GLM 1 GLM 2 Bottom of Survey = 194 Analysis Overview page 2 • PDS REPORT JOINT TABUL ATION SHEET Pipe: 4.5 in 12.6 ppf L-80 IBTM Well: 1 C-104 Body Wall: 0.271 in Field: West Sak Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 26, 2009 Joint No. Jt. Depth (Ft) I'c~n. tJF~sc~t (Ins.) Pen. Body (Ins.) I'en. % M<~t,~l Loss °~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 27 0 0.04 14 1 3.92 Shallow ittin . 1.1 58 U 0.04 13 Z 3.93 PUP Shallow ittin . 2 61 U.US 0.06 23 I 3.92 Isolated ittin . 3 93 t? 0.04 15 Z 3.92 Shallow ittin . 4 124 n.U-~ 0.06 ' 1 1 3.91 Isolated ittin . 5 155 t) 0.08 3U .' 3.92 Isolated ittin . 6 187 O 0.09 (~ ? 3.92 Isolated ittin . 7 219 t? 0.05 c0 3.92 Shallow ittin . 8 250 0.O5 0.07 ~;' ~' 3.93 Line of its. Corrosion. 9 282 0.10 0.07 27 ~ 3.91 Line of its. Corrosion. 10 313 0.0<S 0.06 22 1 3.94 Line of its. Corrosion. 11 344 0 0.08 28 1 3.92 Line of its. Corrosion. 12 376 U 0.07 24 1 3.91 Line of its. Corrosion. 13 407 U 0.06 22 3 3.91 Line of its. Corrosion. 14 438 ~) 0.06 22 2 3.92 Line of its. Corrosion. 15 470 t) 0.07 Zi 1 3.92 Line of its. Corrosion. 16 501 0 0.06 ~4 ! 3.91 Line of its. Corrosion. 17 531 U.U(, 0.06 ?4 I 3.93 Line of its. Corrosion. 18 562 tt 0.08 31 3.90 ine of its. Corrosion. 19 93 O 0.06 :'' 7 3.93 Line of its. Corrosion. 20 622 (? 0.08 3U ! 3.91 Line of its. Corrosion. 21 654 n 0.08 30 1 3.92 Line of its. C rros'on. 22 685 t) 0.10 38 2 3.90 Line of its. Corrosion. 2 716 t).I I 0.10 3ti 3 3.90 Line f its. Corrosion. 24 748 t?.t)t> 0.10 i ~ 3.90 Line of its. Corrosion. 25 780 t_) 0.11 39 3.92 Line of its. Corrosion. 26 811 U.09 0.09 35 ~ 3.91 Line of its. Corrosion. 27 842 (?.06 0.11 39 s 3.87 Line of its. Corrosion. 28 873 i) 0.10 35 ~ 3.90 Line of its. Corrosion. 29 904 U.06 0.12 a; 3 3.89 Line of its. Corrosion. 30 935 O.U6 0.11 40 ~ 3.91 Line of its. Corrosion. 31 966 (t.U7 0.10 37 ~ 3.90 Line of its. Corrosion. 32 998 U.0 i 0.10 38 -1 3.91 Line of its. Corrosion. 33 1029 0 0.08 30 ~ 3.86 Line of its. Corrosion. 34 1058 tt 0.11 40 a 3.86 Line of its. Corro ion. 35 1089 t?.tt!, 0.11 39 ~ 3.91 Line of its. Corrosion. 36 1118 U 0.11 39 1 3.89 Line of its. Corrosion. 37 1149 0 0.09 tZ i 3.86 Line of its. Corrosion. 38 1180 t1 0.08 "1 '~ 3.90 Line of its. Corrosion. 39 1211 (1.Ob 0.09 31 •3 3.86 Line of its. Corrosion. 40 1242 0.(17 0.09 3~ 3.90 Line of its. Corrosion. 41 1273 (t 0.11 4~ -l 3.90 Line of its. Corrosion. 42 1304 U.U(3 0.10 35 a 3.90 Line of its. Corrosion. Lt. De osi 43 133 O.U7 0.10 3(3 -t 3.87 Line of i orrosion. 44 1366 UU5 0.09 3 ~ -1 3.86 Line of its. Corrosion. ~~: 45 139 U.Ob 0.10 >7 3.88 Line of its. Corrosio . 46 1428 0 0.10 i7 3.85 Line of its. Corrosion. 47 1459 t).(tt, 0.10 ~Ei ~4 3.90 Line of its. Corrosion. 48 1490 ~ i i?~? 0.12 46 i 3.89 Line of its. Corrosion. 49 1521 ~ ~ 0.11 39 =3 3.85 Li e of its. Corrosion. _ Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 IBTM Well: 1C-104 Body Wall: 0.271 in Field: West Sak Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 26, 2009 Joint No. Jt. Uepth (R.) I'~~n. Ulsc~t (lnti.) Pen. Body (Ins.) Pcn. `% ~lctal Ic~ss 9<~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 50 1552 U 0.08 31 ~ 3.86 Line of its. Corrosion. 51 1581 U 0.0 29 i 3.84 Line of its. Corrosion. Lt. De osits. 52 1612 U 0.13 46 4 3.90 Line of its. Corrosion 53 1643 U.t)~ 0.11 40 V 3.87 Line of its. Corrosion. 54 1674 0 0.1 aG (~ 3.88 Line of its. Corrosion. 55 1705 0 0.12 43 t~ 3.87 Line of its. Corrosion. 56 1737 U 0.12 43 b 3.83 Line of its. Corrosion. 57 1765 0 0.11 42 G 3.85 Line of its. Corrosion. 58 1796 U.US 0.11 39 V 3.87 Line of its. Corrosion. 59 1828 0 0. 7 27 5 3.87 Line of its. Corrosion. 60 1859 +LO8 0.12 4; 4 3.84 Line of its. Corrosion. 61 1888 0 0.11 41 5 3.85 Line of its. Corrosion. 62 1917 U 0.06 ?.3 4 3.89 Line of its. Corrosion. 63 1948 0 0.07 Z6 3 3.86 Line of its. Corrosion. 64 1980 U.O~) 0.08 i l ~l 3.89 Line of its. Corrosion. 65 2011 U 0.06 ~2 -1 3.89 Line of its. Corrosion. 66 2042 0 0.09 31 (~ 3.88 Line of its. Corrosion. 67 073 0 0.10 3i a 3.85 Line of its. Corrosion. 68 2105 O.US 0.08 28 5 3.87 Line of its. Corrosion. ~ :~ 69 2136 t) 0.09 3 3 4 3.88 Li e of its. Corrosion. 70 2168 i).0' 0.10 38 S 3.85 Line of its. Corrosion. 71 2199 ~'.0(i 0.11 ~1 ~ 3.84 Line of its. Corrosion. 72 2231 O.U_~ 0.09 33 3.89 Line of its. Co rosion. 73 2263 0 0.12 4-1 (; 3.88 Line of its. Corrosion. 74 2294 U 0.07 Z~ 4 3.88 Line of its. Corrosion. 75 2326 0.05 0.10 38 3.89 Line of its. Corrosion. 76 2358 U 0.12 d4 -4 3.87 Line of its. Corrosion. 77 2389 0.08 0.10 3? t 3.88 Line of its. Corrosion. 78 2421 0_U6 0.14 5 S 3.87 Line of its. Corrosion. 79 2453 O.U6 0.13 48 -i 3.88 Line of its. Corrosion. 80 2484 0 0.08 31 5 3.89 Line of its. Corrosion. 81 2516 0 0.10 38 (, 3.89 Line of its. Corrosion. 82 2547 0 0.10 38 5 3.88 Line of its. Corrosion. 83 2579 O.U8 0.09 34 t~ 3.87 Line of its. Corrosion. 84 2611 U. I0 0.08 30 1 3.89 Line of i .Corrosion. Lt. De osits. 85 2642 a 0.11 a 1 (~ 3.89 Line of its. Corrosion. 86 2673 U D.12 45 5 3.87 Line of its. Corrosion. t_t. De osits. 87 2705 O.U~ 0.14 i-? 5 3.81 Line of its. Corrosion. Lt De osits. 88 2736 U.07 0.11 39 4 3.87 Line of its. Corrosion 89 2765 U.U~) 0.13 48 (, 3.87 ine of its. Corrosion. 90 2797 O.U~ 0.12 d t ~~ 3.88 Line of its. Corrosion. 91 2829 t) 0.12 4 > > 3.85 Line of its. Corrosion. 92 2860 t ). 1 U 0.14 51 3.88 Line of its. Corrosion. 93 2892 U.U~ 0.11 3~) ~~ 3.89 ine of its. Corrosion. 94 2923 0.0h 0.10 ib ~ 3.88 Line of its. Corrosion. 5 2953 0.0~) 0.12 44 - 3.90 Line of its. Corrosion. 96 2985 U.05 0.15 5~k (, 3.88 Line of its. Corrosion. 97 3014 t).U' 0.17 64 7 3.88 Line of its. Corrosion. 98 3046 t).t))~ 0.13 47 - 3.86 Line of its. Corrosion. 99 3077 ~) t~(> 0.13 49 3.88 Line of its. Corrosion. _ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 IBTM Well: 1G104 Body Wall: 0.271 in Field: West Sak Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 26, 2009 Joint No. Jt. Depth (Ft.) Pen. Upsc I (Ins.) Pen. Body (Ins.) Pen. % Mc tal Loss `%~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 100 3108 l).Uh 0.15 i4 7 3.89 Line of its. Corrosion. 101 3139 1).l)tS 0.15 56 (i 3.87 Line of its. Corrosion. 102 3169 lt.lt) 0.15 55 ~ 3.87 Line of its. Corr Sion. 103 3200 O.li) 0.14 51 (~ 3.89 Line of its. Corrosion. 104 3231 a 0.14 51 - 3.84 Line of its. Corrosion. 105 3263 iLt); 0.11 ~t t~ 3.85 Line of its. Corrosion. 106 3295 t1 u7 0.14 53 (~ 3.88 Line of its. Corrosion. 107 3326 t?.i;t; 0.14 i) 7 3.87 Line of its. Corrosion. 108 3355 ! f 1 t) 0.13 4') - 3.86 Line of its. orrosion. 109 3384 U.O; 0.11 42 4 3.86 Line of its. Corrosion. I_t. De osits. 110 3416 U.U6 0.12 45 (~ 3.87 Line of its. Corrosion. 111 3447 U.1O 0.12 43 - 3.86 Line of i s. Corrosion. 112 3476 (1 0.16 59 E, 3.86 Line of its. Corrosion. 113 3508 U.U' 0.14 5O 6 3.88 ine of its. Corrosion. Lt. De osits. 114 3539 (LUI 0.12 45 3.85 Line of its. Corrosion. Lt. De osits. 115 3569 E).U6 0.12 46 '"i 3.89 Line of its. Corrosion. 116 3600 O.Ot3 0.12 46 b 3.86 Line of its. Corrosion. Lt De osits. 117 3632 l).t)b 0.14 53 i 3.85 Line of its. Corrosion. Lt De osits. 118 3663 U.Ut~ 0.16 59 t; 3.8 Line of its. Corrosion. 119 3695 t L I U 0.14 S 1 3.89 Line of its. 'orrosi n. 120 3726 (Ltl i 0.15 ~4 -1 3.88 Line of its. Corrosion. 121 3758 t ~.U(, 0.12 45 b 3.88 Line of 'ts. Corrosion. Lt. De osits. 122 3789 t1.11 i 0.14 5O i 3.86 Line of its. Corr Sion. Lt. De osits. 123 3820 U.t) ~ 0.13 4t3 i, 3.83 Line of its. Corrosion. 124 3850 U.t)!, 0.14 5U / 3.88 Line of its. Corrosion. Lt. De osits. 124.1 3882 t) 0.07 'S t i! 3.83 PUN Line of its. Corr lion. 124.2 3892 U 0 t) i) N A GLM 1 Latch @ 10:30 124.3 3899 a 0.05 2i) -1 3.90 PUP Line of its. Corrosion. 125 3909 t) 0.12 46 4 3.87 Line of its. Corrosion. Lt. e osits. 126 3939 t) I O 0.13 48 5 3.88 Line of its. Corrosion. Lt. De osits. 127 3971 U.12 .13 49 3 3.90 Line of its. Corrosion. Lt. De osits. 128 4003 t).OE> 0.11 42 4 3.88 Line of its. Corrosion. Lt. De osits. 129 4034 t) 0.12 46 4 3.90 Line of its. Corrosion. 130 4066 U.Ot3 0.10 t8 4 3.91 Line of its. Corrosion. 131 4098 O.U)3 0.09 31 ~ 3.91 Line of 'ts. Corrosion. 132 4130 O 0.11 4U 4 3.90 Line of its. Corrosion. 133 4162 (1.U~ 0.11 -u) 4 3.91 Line of its. Corrosion. 134 4191 (l. l U 0.12 43 4 3.89 Line of its. Corrosion. 135 4220 U.Uti 0.13 ~~ 4 3.89 Line of i .Corrosion. 136 4252 t) 0.14 5O ~i 3.92 Line of its. Corrosion. 13 4283 tLU7 0.10 . 7 3 3.91 Line of its. Corrosion. 138 4314 U.i)6 0.07 Z; 3.91 Line of its. Corrosion. 139 4346 ~J.t)~) 0.11 ,9 3.90 Line of its. Corrosion. 140 4379 U 0.09 34 ~3 3.91 Line of its. Corrosion. 141 4410 O O.U9 .32 i 3.91 Line of its. Corrosion. 142 4443 QUb 0.09 33 -1 3.92 Line of its. Corrosion. 143 4474 l~.O- 0.12 42 i 3.92 Line of its. Corrosion. 144 4506 U.U6 0.12 44 a 3.90 Line f its. C rrosion. 145 4538 U.u7 0.11 3~) ! 3.92 Line of its. Corrosion. ~ ~ 146 4570 t)_UC~ 0.13 4i 3.91 Line of its. Corrosion. _ _._ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 IBTM Well: 1 C-104 Body Wall: 0.271 in Field: West Sak Upset Wall: D.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 26, 2009 Joint No. Jt. Depth (Ft.) I'c~n. !){?scl (ln..) Pen. Body (Ins.) Nen. °io /tc~r,~l 1_oss 44, Min. LD• (Ins.) Comments Damage Profile (%walQ 0 50 100 1 7 4599 U 0.11 42 -i 3.90 Line of its. Corrosion. 148 4631 U.U;~ 0.12 X16 -i 3.90 Line of its. Corrosion. _ 149 4662 l).O(i 0.14 it -l 3.89 Line of its. Corrosion. Lt. De osits. 150 4694 0. It) 0.13 49 6 3.88 Line of its. Corrosion. 151 4726 O.Ui 0.14 50 4 3.88 Line of its. Corrosion. Lt De osits. 15 4758 U.U6 0.1 ~~ 4 3.89 Line of its. Corr Sion. - 153 4790 l~.Ot3 0.11 39 ~ 3.87 Line of its. Corrosion. Lt. De osits. 154 4821 i1.i); 0.10 37 3.89 Line of its. Corrosion. LC De osits. 1 5 4852 !t.t)c) 0.16 6U 5 3. 7 Line of 'ts. Corrosion L . De sits. 156 4884 t) 0.13 48 ~ 3.89 line of its. Corrosion. Lt. De osits. - 157 4914 O.t)0 0.11 41 ~+ 3.88 Line of its. Corrosion. Lt. De osits. 158 494" t).1 U 0.1 47 4 3.87 Line of its. Corrosion. t. De sits. - 159 4975 U.~)£3 0.09 i4 4 3.89 Isolated ittin . 160 5004 (Ltk~ 0.12 43 3.91 Isolate itti 161 5033 i).U7 0.14 50 6 3.90 Line of its. Corrosion. Lt. De osits. _ _ 162 5065 U.U9 0.12 44 4 3.91 Line f its. Corr Sion. 163 5095 U.07 0.12 43 4 3.90 Line of its. Corrosion. 164 5127 U.O~ 0.13 46 (~ 3.91 Line of its. Corrosion. 165 5159 O.Oti 0.11 41 4 3.91 Isolate ittin . 166 5190 U_O6 0.07 ~6 4 3.92 Isolated ~ttin . 167 5222 U.U9 0.10 36 4 3.90 Isolated ittin . 168 5254 U.0£i 0.10 ab ~ 3.92 Isolated ittin . 169 5286 O.OY, 0.05 1 £3 4 3.92 Shallow ittin 170 5317 0.116 0.11 42 d 3.92 Isolated ittin . 171 5349 O.U6 0.12 43 3 3.91 Line of its. C rrosi n. 172 5380 O.~)~ 0.12 45 4 3.90 Line of i Co rosion. 173 5412 t) 0.11 41 5 3.91 Line of its. Corro ion. 174 5440 O.ut, 0.08 2£3 ~t 3.91 Isolated ittin . 175 5471 il.i)~ 0.10 38 4 3.90 Isolated ittir 176 5501 i~ 0.12 46 3.92 Isolated ittin . 177 5533 U 0.10 3ti 4 3.89 Isolated ittin . 178 5565 U.O6 0.06 ~4 ? 3.89 Isolated ittin . 179 5594 U.U7 0.07 27 i 3.90 Isolated ittin . 180 5626 O.Oc) 0.14 52 ~l 3.88 Line of its. Corrosion. 181 5657 0.10 0.13 ~3 4 3.87 Li e of its. Corrosion. 182 5688 )).07 0.08 29 ) 3.92 L'ne of pits. Co r sion. 183 5720 0.1 1 0.13 ~tc) ~ 3.88 Isola d ittin . 184 5752 t) 0.06 Z 3 -1 3.92 Isolated ittin . 185 5783 U.U'> 0.09 ~ ~ -1 3.90 Line of its. Corrosi n. 186 58 4 ti 0.14 5t -1 3.89 Line of its. Corrosion. 187 5846 U.Ui 0.09 i2 -1 3.90 Isolated ittin . 188 5878 !).i)7 0.07 %t3 3 3.90 Isolated ittin . 189 5910 (}. I Z 0.13 4~) ? 3.91 Line of its. Corrosion. 190 5941 U.t~1 0.16 61 ~~ 3.91 Line of its. Corrosion. 191 5973 0. 1 I 0.16 i£3 'i 3.91 Line of its. Corrosion. 191.1 6004 0 0.05 20 -t 3. 7 PUP Isolated ittin . 191.2 6013 U 0 U U N A GLM 2 Latch @ 4:30 191.3 6019 i) 004 16 t 3.90 PUP Shallow ittin . 192 6031 ,a 0.22 £3U 4.~ 3.91 Line of its. Corrosion. Lt De osits. 193 6062 ~ ! ! 0.16 5c) ) 3.90 ine of iis. Corrosion. Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 tBTM Well: 1 C-104 Body Wall: 0.271 in Field: West Sak U{set Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 26, 2009 Joint No. )t. Depth (Ft.) Pen. UI>set (Ins.) Pen. Body (Ins.) Pen. `% Metal Loss `;'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 193.1 6093 l) 0.10 35 -1 3.88 PUP Line of its. Corrosion. 93. 6103 U 0 U N A 4.5" Phoenix Uischa e Sub 193.3 6105 U.l?~) 0. 7 24 3.91 PUP Line f its. Corrosion. - 194 61 13 ! ). I > 0.13 -1') '> 3.71 Line of .its. Corrosion. Tem . Im aired Fin er. - __ Penetration Body Metal Loss Body Page 5 ~ i i ~ ~ ~ ~ ~ ~ ! ~ ~ ~ ~ ~ ~ ~ ~ M s PDS Report Cross Sections ti Well: 1C-104 Survey Date: October 26, 2009 Field: West Sak Tool Type: UW MFC 40 No. 213120 Company: Conoco Phillips Alaska, Inc. Too- Size: 2.75 Country: USA No. of Fingers: 40 Tubin 4.5 ins 12.6 f L-80 16TM Anal st: C. Waldro Cross Section for Joint 192 at depth 6050.61 ft Tool speed = 43 Nomina{ ID = 3.958 Nominal OD = 4.500 Remaining wall area = 96 Tool deviation = 82 ° Finger 4 Penetration = 0.216 ins Line of pits 0.22 ins = 80% Wall Penetration HIGH SIDE = UP • • Cross Sections page 1 PDS Report Cross Sections \r - - ~~ Well: 1C-104 Survey Date: October 26, 2009 Field: West Sak Tool Type: UW MFC 40 No. 213120 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 4.5 ins 12.6 f L-80 IBTM Anal st: C. Waldro Cross Section for Joint 97 at depth 3034.007 ft Tool speed = 44 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 94 Tool deviation = 79 ° Finger 5 Penetration = 0.174 ins Line of pits 0.17 ins = 64% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 r1 n C i~ i~ i~ i~ i~ ii v i~ i~ ~i ii Tubing Well: is-~~» 7C-704 New Cam tenon Date: Oct.25,~Qf7 COC14C0~'II~~IpS Rig: t~~~z~,r~. Alaska, Ins. Depth Jt Number Joints WeII Equipment Description and Comments Page 1 Length Tops ~~' ",fin Distance You Speci 36.16 `v'etca Gray 11"x4 1t2" Han er 2.05 36.16 Jts 195 to 19 1 Jts ~ ?' f" ^ 2 sN, i -~~ IE3T-M Tubing, Made up in hanger wt3' xover NSCTxIBTM 32.81 38.21 Jts 99 to 194 96 Jts ~ 3,'~ '", ~ ~ ~#, 1.-SQ I EST-M Tubing 2979.03 71.02 - ~; tr?n ~F,It. # 98 . 3050.05 Jts 72 to 98 27 Jts •~`~ ' ~ 7 , "! 2 c~#, ~ ~(} ! BT-M Tubing 835.74 3050.05 -1 1J2"."<~.~~#, l_-~(7 iBT-M Tubing Pu 9.82 3885.79 ` ---~>i', ~RrfDGK-2 S17V, BEK Latch 6.85 3895.61 ~ 11f"" F 2 ~i# L-£30 IE3~i~-M Tubin Pu 9.79 3902.46 Jts 5 to 71 67 Jts + i.':%",'! 1.E~#, L-BO IE3T-M l ubing 2091.25 3912.25 ~~~ i12", 12 ~# f 80 IBT-M Tubin Pu 9.79 6003.50 %_ ~ ~~ ~v~` ~:~smm Valve, BK Latch 6.86 6013.29 r§§ 1 i2", .2.G#, I_-80 IBT-M Tubing Pup 9.79 6020.15 Jts 3 to 4 2 Jts ~ '1l~ ",' ~.E~#, l..-80 I BT-M Tubing 63.35 6029.94 ~~ il~", ; 2_~#, L.-8U iBT-M Tubin Pup 9.40 6093.29 ~,r~~,;,•,.~c Si4b (IBT-ill Box x Pinj 9.30 6102.69 °~ '~1~",`12~~#, L-d(7 IBT-M Tubin Pup 6.99 6103.99 Jts 1 tot 2Jts ~ "!1".12_~att, l_-30 IBT-M Tubing 63.12 6110.9$ t!2".12 ~#, ~ 8g 18T-M Tubing Pup 9.81 6174.10 Tr,'tyinc~ TTG crossover wtperfarated intake 10.62 6183.91 Tanclcm Seal Section GSB3DB 13.80 6194.53 ASP !tllc~tc~r 19d hp KMH 2415Vt48A 16.72 6208.33 ~h~Qa~ix ~11C~T-kT Guage 1.83 8225.05 ~1'~?1or Gentrilizer 1.92 6226.88 6228.80 622s.so 622s.so ~" 6228.80 6228.80 - 6228.80 6228.80 6228.80 622$.80 s22s.sa 622$.80 Jt in Hanger is NSCT with Xover on bottom NSCT X IBTM lJp ~nJt 92 K, 27 stainless steel bands, 55 single clamps, 88 double Gamps bn Wt a2 K (457) 5' channel, (3) 4' channel, (4) 3' channel, (5) 2' channel Block Wt 12 K Supervisors: Rick Overstreet/Dave Chapman • ConocoPhillips January 29, 2008 T. Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Subject: Additional Well Summaries Dear Mr. Maunder: J. Eggemeyer Engineering Leader `~ Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6049 ~: ~ ~,:~ .~- ~3.~;!'. a~a-offs ConocoPhillips Alaska, Inc. submits the attached well summaries for wells;- -~1-3~, 1 C-104, - ~ ~; 1~-;T T,-~',~L~; 1~-~ ^' ~~-' ~ ~ ",mac; you requested. These summaries will replace the shorter summaries already submitted with the completion reports for these wells. If you have any questions regarding this matter, please contact me at 265-6049. Sincerely, . Eggemeyer Engineering Team Leader CPAI Drilling ~ N FEe o ~ 2oa~ JE/skad Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, December 13, 2007 2:30 PM To: 'Eggemeyer, Jerome C.' Subject: 1C-104 (202-061) Detailed Report Request Jerome, Further to our discussions, would you please provide the detailed operations reports for the fiolfowing well (s)/operations. 1 G104 (202-061) workover begun 10/19//07, non-rig work summary provided is sufficient Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 12/13/2007 Cono~~-Phi~lips Time Log Summary ~ y J~~p~-t~~g ~s/( S WeIN/ew Web Repo~tJny `'U!~ .. I P Well Name: 1 C-104 Job Type: RECOMPLETION __ __ _ - Time Logs _ Uwe _ .From To_ _ Dur_ ,S, D~th E Depth Phase Codz_ Subco~i~__ T CQM ___ 10/19/2007 13:30 00:00 10.50 MIRU MOVE RURD P Lower derrick to Carrier, skid pipeshed ahead. Slowdown steam line & laydown derrick. Move pits forward. Load out auxiliary equipment on trucks. Rig down and move rig from 1 J-137 to 1 C-104. 10/20/2007 00:00 08:30 8.50 MIRU MOVE MOB P Continue to road rig to location. Spot mats and environmental barriers. Spot equipment and Rig Up. Tie in steam lines and electrical system. Raise derrick. Accepted Rig @ 08:30 hrs 10/20/2007. 08:30 12:00 3.50 COMPZ WELC KLWL P Set containment and rig up Tiger tank for returns. RU hardline from Tiger Tank to wellhead. Pull BPV. Clean its a ain for filtered water. 12:00 16:00 4.00 COMPZ RPCOf~ WOEQ T Wait on vac trucks with filtered Seawater w/6% KCL. First vac truck load of water was not clean and re'ected b Filterin Plant. 16:00 16:30 0.50 COMPZ RPCOh RURD P First load of water arrived. RU LRS Pum truck. Test lines to 1000 si. 16:30 19:30 3.00 COMPZ WELC? KLWL P Open up well 200 SITP 600 SIIAP Circulate 292 bbls Filtered Seawater w/6% KCL with hot oil pump @ 120 degrees @ 2bpm w/diesel/oil returns. RD LRS. 19:30 23:00 3.50 COMPZ WELCT KLWL P Fill rig pits. wait on dirty vac truck to empty tiger tank. Begin circ, took 20 bbls to catch circ. Circ 170 bbls @ 180 psi @ final circ pressure w/ 30 returns. Out of 460 bbls total pumped 366 bbls displacement was recovered w! 94 bbls lost to the hole. Shut down and monitor well. vacumn on both tba, and IA. RD circ equip. and blow down. 23:00 23:30 0.50 COMPZ RPCOti SFTY P Held PJSM w/ Vetco on setting of BPV and ND of tree. Begin hole fill 10 bbls eve hour 23:30 00:00 0.50 COMPZ RPCOh NUND P Set BPV. Continue to hole fill 10 bbls eve hour. 10/21/2007 00:00 04:00 4.00 COMPZ RPCOti NUND P ND tree and inspect lift threads. Install isolation plug and test plug. Stand up BOPE and install. Continuing to hole fill 10 bbls every hour. ~~ I Time Logs - - _-- - Date From To Dur- 5. e th.<-E. De th Phase Code Subcod_e T__ _COM 10/21/2007 04:00 07:30 3.50 COMPZ RPCOti SFEO P Function test and pressure test BOPE to 250 / 2500. Witness waived AOGCC Chuck Sheavy @ 06:30 on 10-20-07. 07:30 10:00 2.50 COMPZ RPCOti NUND P Pull blanking plug & BPV. Pumped 10 bbls seawater to fill hole. Install side isolation sleeve in hanger. Screw into the tubing hanger with landing jt. Mark pipe at the rotary table. BOLDS. RU spooling unit, cable sheave for both ESP cable and heat trace cable. 10:00 10:30 0.50 COMPZ RPCOti SFTY P Pre Job safety meeting covering ullin ESP. 10:30 11:30 1.00 COMPZ RPCOti PULD P Un-land tubing hanger and pulled to the rig floor. String wt = 77K. Threaded both cables over sheaves and tied into spoolers. LD tubing hanger with 1 jt. Pumped 10 bbls for hole fill. 11:30 17:30 6.00 COMPZ RPCOti PULD P POOH laying down the 4 1/2" tubing, removing all jewelry and spooling up ESP cable and heat trace. Tubing and cables pulling with small amounts of crude but not too bad. At end of heat trace. Removed s ooler from ri floor. 17:30 22:30 5.00 COMPZ RPCOti PULD P Continue to Pooh laying down production string to the ESP. The Cable armor was missing in uniformed spots from the Discharge Valve to the top of the seal section. Looked as if it was corrosion and wear @ the stainless steel bands. Two stainless steel bands were not recovered. The armor wrap for the splice to motor lead was also missing as shown in the pits. The TTC Xover coupling was also broken as seen in the its. 22:30 00:00 1.50 COMPZ RPCOh PULD P The remainder of the ESP equipment was pulled from the well and laid down and field checked OK. 10/22/2007 00:00 07:30 7.50 COMPZ RPCOh PULD P Continue to break down ESP equipment and field inspect. Check Cable and Sensor gauge. Remove old ESP cable and spool from spooler. Install new spool. Clean rig floor and turn equipment around to run back in hole. Drift and strap tubing. Recount all clam sand bands. __ _.~. ~ _... _~._~..m a Time Lo s Date From To Dur S,-De{~th E Depth Phase Code Subcode T _ COM __~ _ _ _ 10/22/2007 07:30 11:30 4.00 0 __, COMPZ _ RPCOh PULD P PU motor centrilizer, Phoenix sensor, motor and service. PU the seal section, check and service. PU and MU TTC Xover/Intake. Feed motor lead extension cable through sheave to rig floor. Install Phoenix pressure sub and connect capillary tubing to Phoenix sensor. Attach MLE cable to the ESP assy. Install the LaSalle Protectotizers with armor guards to secure the motor lead extension cable and the capillary tube. Band flat guards over the capillary tube along the entire length of the ESP motor. Perform electrical inspection/test on the ESP power cable here and every 1000' and Phoenix ua e. 11:30 18:00 6.50 3,014 COMPZ RPCOti PULD P Continue RIH w/ ESP completion as per program. Start Heat Trace @ 3014'. 18:00 00:00 6.00 3,014 4,306 COMPZ RPCOti PULD P Continue to Rih to jt# 134 w/ 4 1/2 tbg and ESP w/ heat trace Assy to 4306'. All 1000' ft electrical inspections and tests were ood. 10/23/2007 00:00 02:30 2.50 4,306 5,102 COMPZ RPCOti PULD P Continue to RIH/ new 4 1/2 ESP Com letion w/ heat trace. 02:30 04:00 1.50 5,102 COMPZ RPCOb RCST T w/ 160 jts. P/U @ 5102' Preform electrical test and inspection. Heat trace was good, Phase/Phase was good 2.80 ohms, Phase/Grd was 1.2 and 1.8 w/ no communication to Gauge at bottom of motor. Prepare to POOH standin back Tb . 04:00 14:00 10.00 COMPZ RPCOti RCST T Begin POOH inspecting ESP cable for visible damage. Located frayed spot on Gabel at 225' from bottom of pump or at the GLM #2. Cable had slipped around to off side of GLM and sharp edge rubbed between Mandrel and casin . 14:00 18:00 4.00 COMPZ RPCOh OTHR T Pulled on up to pump at MLE connection, all of cable looked good around. pump. Disconnect MLE, re-service pump. Replace control line for Phoenix Gauge. Re-connect MLE. Cut cable at MLE s lice. 18:00 22:00 4.00 COMPZ RPCOh OTHR T Pulled off 225' of cable to bad spot. Threaded back over sheave and spliced back onto MLE eliminating ones lice. 22:00 00:00 2.00 COMPZ RPCOti PULD T RIH w/ new 4 1/2" completion. Installed 2 bands below and 2 bands above the GLM #2 and will do the same on GLM #1. 10/24/2007 00:00 00:30 0.50 COMPZ RPCOti PULD T Continue to RIH w/ new 4 1/2" ESP com letion. - - w e~ m .~ ..... Time Lo s S - _ --- _ _Date _._ Fro... Tc Dur _ __.5 Depth E. Depth Phase Code___Subcode_ T COM _ _ 10/24/2007 00:30 04:00 3.50 COMPZ RPC06 PULD T While changing out seal ring to stab stand # 14 the new seal ring was dropped down the tubing. POOH and pulled seal ring out of tubing, it was at the to of the TTC crossover. 04:00 07:00 3.00 COMPZ RPCOti PULD T Turn tools around to run back with completion. Ran 15 stnds and H2S monitors went off. 07:00 08:00 1.00 COMPZ RPCOh SFTY T Stabbed safety valve and closed Annular Preventor. Evactuated rig and pad to mustering area. Check area with handheld monitors, Scott airpacks and H2S readings were'0'. Alarms would not reset. Shut off monitors and continuously monitor with handhelds until electircian repairs and adjust monitors. Reported well control actions to AOGCC (Lou Gramaldi) @ 8:12 am. Opened annular preventor and check well for H2S- none. Pulled salty valve. Pulled up and checked ESP Gabel where bag was closed on it with 1200 psi. No phisical damage. Checked electrical inte ri ,eve thin OK. 08:00 11:00 3.00 COMPZ RPCOti PULD T Continue to RIH with completion. Started heat trace at top of jt 98 3014' . 11:00 23:00 12.00 COMPZ RPCOh PULD P Continue to RIH with completion, make u landin 'oint ands ace out. 23:00 00:00 1.00 COMPZ RPC011 OTHR P Begin making splices on the heat trace and Centrilift power cable. Begin rigging down Centrilift and Ra them s oolin a ui ment. 10/25/2007 00:00 02:30 2.50 COMPZ RPCOti OTHR P Continue to make splice on power and heat trace cables, clear equiment from rig floor. Stainless steel bands: 27 Single clamps: 55 Double clamps: 88 5' channel: 457 4' channel: 3 3' channel: 4 2' channel: 5 02:30 04:00 1.50 COMPZ RPCOA PULD P Land tubing, test hanger void and pack off to 5000 si. 04:00 09:00 5.00 COMPZ RPC011 NUND P ND BOPE, NU tree and test to 5000 psi. Check the ESP cable/motor integrity and the heat trace along with the Phoenix Guage thru the penetrators. Set BPV . RD cable spooler. Release rig @ 09:00 -10/25/07. ~RE~~IV~1•.~ NOV 2 8 ~Oq7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. C~Itt~tssiort REPORT OF SUNDRY WELL OPERATIONS Anchorage t. Operations Performed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPh111ipS Alaska, InC. Development ^~ Exploratory ^ 202-061 / w 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23076-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' 1 C-104 - 8. Property Designation: 10. FieldlPool(s): ADL 25649,~ALK 467 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11560' - feet true vertical 3688' °` feet Plugs (measured) Effective Depth measured not available feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 122' 16" 158' 158' SUR/PROD 7359' 7-5/8" 7395' 3696' B-SAND LINER 3949' 4" x 4.5" 11550' 3688' Perforation depth: Measured depth: , 7446'-11395' ~~(~.HCatl~~ ~~~ ~ ~ ~~~~ HC~L true vertical depth: 3745'-3692' Tubing (size, grade, and measured depth) 4-1 /2" , L-80, 6172' MD. Packers &SSSV (type & measured depth) B-sand Baker'SCR-1' pkr @ 72oa' 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 Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 870 ° 28 1615 - 230 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Brett Packer @ 265-6845 Printed Name Brett Packer Title Wells Group Engineer ~/ ~Z~~ Signature '~~-- ~ Phone rJ~ Date Pre ar b Sharon Allsu -Drake 263-4612 Form 10-404 Revised 04/2006 ,~ /2 • d e~ Sub it O i~~~t~ • • DATE Summary 10/19/07 Rigging down moving from 1J-137 to 1C-104. 10/20/07 Finish moving to 1C-104 and MIRU. Circ and kill well ND tree and NU Bope. Accepted Rig @ 08:30 hrs 10/20/2007. 10/21/07 Finish ND Tree and NU BOPE and Test 250/2500. Unland tbg and Start to Pooh laying down all of the production string. 10/22/07 Load new equipment and stap. Rih w/ new completion 1x1 to 4300' and electrical inspections and tests were good. 10/23/07 RIH w/ new 4 1/2" ESP completion, check cable at 5,102', found that the cable had failed and also no communication w/ the Phoenix gauge. POOH and found that cable was cut at GLM #2. The cable had splipped around to the sharp edge on the pocket side and was cut. Pulled up to the MLE connection. Disconnected MLE and re-serviced the pump, replaced the gauges' control line and cut the cable at the MLE splice. Spooled off 225' of cable and re-spliced it at the MLE to eliminate an extra splice. Gean to RIH, put 2 bands on bottom and 2 bands on top of GLM #2 and will do the same on GLM #1 to keep the cable from slipping to the pocket side again. 10/24/07 At approx. 00:30 a new seal ring was dropped down the tubing with 13 stands in the hole. POOH and retrieved the seal ring off the top of the TTC crossover. Turn tools around and ran 15 stand in when H2S monintors went off. Well secured and evacuated rig as per procedure. Verified faulty alarm and monitored cellar, pits and rig floor with hand held monitors until rig electrician fixed the monitors. (AOGCC -Lou Grimaldi was notified @ 08:12) Check cable and continue to RIH. Started running heat trace @ 3014' Began making the cable splices for the heat trace and power cable at 23:00. 10/25/07 Finished running completion. Test all cables, heat trace, and Phoenix guages. ND BOPE, NU tree test to 5000 psi. released rig @ 09:00 10/25/2007 10/25/07 Pump Freeze protection with diesel pumped 45 bbls down tubing and 75 bbls down the annulus. BPV still installed 11/07/07 TAGGED ESP SPLINE @ 6166' SLM, CONFIRMED CLEAR. SET 4-1/2 TTCESP (46.06' OAL - 140FC2700) @ 6166' SLM. SET PACKOFF ASSEMBLY WITH KOBE KNOCK OUT, DART CHECK AND STINGER (100" OAL) @ 6120' SLM. SET CATCHER ON PACKOFF @ 6112' SLM. PULLED DV @ 6021' RKB. 11/08/07 SET SOV @ 6021' RKB. PULLED SOV AND SET DV @ 3860' RKB. PULLED CATCHER. TESTED PACKOFF 1000 PSI, GOOD. SET SLIP STOP ON PACKOFF @ 6114' SLM. COMPLETE. • ,~~--~-~ ~'onc~c+aPhltips Alaska, Inr^ __ ____ ~~ y c-i oa _ API: 50029: Heat Trace SSSVType: NONE (1-3014, oD:l.ooo) Annular Fluid: TUBING (o-snz. OD:4.500, ID:3.958) SEAL (6159172, OD:5.130) PUP (7287-7446, OD:4.500) i Last Tarp bate' I _ _ Casing String - - Description CSG WINC Casing String:- Tubing String -TUBING Size Top i -1.560 - - Perforations Summary Interval I TVD 7446-11395 3745-3692 Gas Lift MandrelslVaNes • KRU 1 C-104 Well T e: PROD An le TS: de Orig 7/29/2002 Angle @ TD: 91 deg @ 11560 Com letion: Last W/0: 10/25/2007 Rev Reason: WORKOVER for ESP Ref Lo Date: Last U date: 10/30/2007 TD: 11560 ftKB Max Hnle AnrJle• 95 deg (al 7655 ON STRINGS Size To bottom TVD VYt Grade Thread 7.625 0 7395 3741 29.70 L-80 BTCM 16.000 0 158 158 62.50 H-40 WELDED 6.625 7043 7044 3681 0.00 to 1C-104L1 DER (Alternating 31 __ ' blarik;pipe & 37' Ex cluder 2000 scr8e n 4"x4.5"~ Size Topes Bottom TVD Wt I Grade Thread 4.500 7206 11548 3689 12.60 ~ L-80 NSCT 4.800 7446 11395 3692 I 1260 I L-f30 I NSCT ~ Bottom TVD Wt Gr ade Thread 6172 ~ ~~31~3 ~ 12.60 ~ L -80 ~ NSCT Zone Status Ft SPF Date T Comment WS B 3949 50 7/28/2002 Screens Perfs thru 37' screens every 31' 5! MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3860 2390 CAMCO KBG-2-1 R SOV 1.0 BEK 0.000 0 10/25/200 2 6021 3354 CAMCO Oiher ~plug_s, equip., etc De th TVD T e KBG-2-1 R DMY 1.0 BK _ 0.000 _ 0 1.0/25/200 .) -COMPLETION Descri lion ~, ID 1 1 Heat Trace HEAT TRACE 3014' TO SURFACE 0.000 36 36 HANGER ABB VETCO GRAY TUBING HANGER 3.900 6067 3373 PRES SUB PHOENIX DISCHARGE PRESSURE SUB 3.948 6148 3404 XO INTAKE CROSSOVER INTAKE 0.000 6159 3409 SEAL CENTRILIFT TANDEM SEAL SECTION 0.000 6172 3414 MOTOR CENTRILIFT 190 HP MOTOR 0.000 6189 3420 GAUGE PHOENIX MS-2 GAUGE 0.000 6191 Other 3421 Centralizer CENTRILIFT MOTOR CENTRALIZER 0.000 lu s, e ui ., etc. - B-SAND DETAIL _ De th TVD T e Descri lion ID 7208 3718 PACKER BAKER 'SCR-1' PACKER W/MILLOUT EXTENSION 4.000 7216 3720 VALVE BAKER KOIV MODEL C 4.000 7256 3726 SLEEVE BAKER CMD SLIDING SLEEVE 3.430 7287 3729 PUP TUBING ABOVE SCREENS 3.958 11548 3689 SHOE BAKER MODEL'GPV' SET SHOE 3.500 General Notes Pert (7446-11395) Nabors 38 H28 alarm . . Page 1 ofl Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 24,20071:54 PM To: 'aogcc_prudhoe_bay@admin.state.ak.us' Subject: FW: Nabors 3S H2S alarm-1C-104 (202-061) FYI ._------~ ,~.---~-------- From: Packer, J.Brett [mailto:J.Brett.Packer@conocophillips.com] Sent: Wednesday, October 24,2007 1:42 PM To: Maunder, Thomas E (DOA) Subject: Nabors 3S H2S alarm S~NED NOV.,O 1 2û07 Tom, As mentioned on the phone, West Sak 1C-104 is being worked over by Nabors 3S and this morning about 5 a.m., a high-level H2S alarm went off. Subsequently, the BOP's were closed and the rig evacuated until the alarm could be verified. Further investigation revealed it to be a false alarm from a malfunctioning H2S monitor that had apparently gotten water in it. The crew was down about an hour while the rig electrician fixed the monitor. The company man and rig supervisor were in contact with Lou Grimaldi during this incident. I just wanted to let you know that there is no reason for concern regarding any well control issues. This well has a low BHP of 1511 psi and was properly killed and has been static since the beginning of the workover. All proper safety p~autions were followed in response to this alarm and the crews are back to work. If you have any questions, feel free to call or email. Thanks, J. ŒreU íPac{er (])rjn;no tt(, 'WelM 'Wor{O'fJer P.1I{Jineer 'Wor{# 265-6845 Ce{[# 230-8377 lO/24/2007 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 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 attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 Report 1C -104 Caliper Report 26-Jun-07 1) 2) 3J 4J 5) 6) 7) * * Reprint w/ Magnetic Thickness Tool Summary s~t;.O JUL 1 ~ Lot)? c90d -O(O( Signed: ()~ 1~ ---- fih ,,"-6 fJ 1-1 (¿ (Vl,.[w,{¿ ~-:l,l Date : JUL 0 9 2007 Print Name: ¡\Iaska Oil & Gas COilS. Commission Änchorag(; PROAcTIVE DIAGNOSTIC SERVICES, INc., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\Master _Copy- 00 ]DSANC-2OxxIZ _ Word\Distnòution\TransmittaC Sheets\Transmit _ Original.doc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool and Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. June 26, 2007 6658 1 4.S" 12.6 lb. L-80 Tubing Well: 1C-104 Field: Kuparuk State: Alaska API No.: SO-029-23076-oo Top Log Intvl1.: Suñace (MD) Bot. Log Intvl1.: 6,092 Ft. (MD) Inspection Type : Assess Corrosive Damage to Tubing and Production Casing COMMENTS: This CaliperlMTT data is tied into the Parker GLM 2 @ 6,021 ft. (Driller's Depth). This is the first log of this well with the 40-Arm Multi-finger Caliper (MFC) and 12 Arm Magnetic Thickness Tool (MTT). The caliper records the features of the internal surface of the 4.S" tubing in this well while the Magnetic Thickness Tool responds to the total thickness of metal of the 4.S" tubing, 7 S/8" production casing and 16" conductor pipe within the logged interval. Both tools logged the same interval, but in two separate passes. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (5,716'), where the readings are assumed to represent undamaged tubing and casing. Inspection of the data recorded at this location in the dynamic pass indicates minimal damage in the area of this calibration point. All other readings are relative to this reference point, which ¡ndude influences from the 4.S" tubing, 7 S/8" production casing and 16" conductor pipe. INTERPRETATION OF CALIPER LOG RESULTS FOR 4.5" TUBING: This log was run to assess the condition of the 4.S" tubing interval with respect to corrosive and mechanical damages. The caliper recordings indicate that the 4.S" tubing interval is in fair to poor condition. A hole is recorded in joint 172 (5,382'). Wall Penetrations in excess of 20% are recorded in 189 of 204 joints logged. The damage appears to be in the form of Une of Corrosion, General Corrosion and Isolated Pitting. No significant areas of cross-sectional wall loss or ID restrictions are recorded. Cross-sectional drawings of the most significant events recorded are induded in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. 4.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: HOLE PROBABLE HOLE POSSIBLE HOLE POSSIBLE HOLE POSSIBLE HOLE ( 100%) ( 98%) ( 91%) ( 91%) ( 87%) Jt. Jt. Jt. Jt. Jt. 172 @ 47 @ 144 @ 161 @ 1S8 @ S,382 Ft. (MD) 1,471 Ft. (MD) 4,S17 Ft. (MD) S,038 Ft. (MD) 4,949 Ft. (MD) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 RECE\VED Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog,com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 JUL 0 9 2007 Alaska Oil & Gas Cons. Co:mmission Anchprage dOd-OCo , I I I I I I I I I I I I I I I I I I I . . 4.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 13%) are recorded. 4.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. INTERPRETATION OF MTT LOG RESULTS: The MTT log results indicate average overall metal loss generally ranging from 4% to 10% in the top -SOO' of the well bore. Between -SOO' and -1,4S0' the MTT indicates very little metal loss - with only 5 of 31 joints in this interval indicating metal loss as high as 2% to S%. Below-1,4SO' the MTT indicates average overall metal loss generally ranging between 9% and 13% metal loss. A higher average metal loss of 18% to 20% is indicated in 3 of the bottom 8 joints in this log, but the accuracy of these assessments are suspect due to excessive "tool jerk", or stopping and starting, indicated in this interval. A graph of the average metal loss assessed from the MTT data on a joint-by-joint basis is included in this report. The response of the MTT data recorded closely mirrors the configuration and location of the damage recorded by the caliper on the inside of the tubing. In intervals where the caliper indicates a thin line of corrosion, the MTT indicates significant damage on only a couple of its 12 radial sensors. Whete the caliper indicates more widespread damage, the MTT response follows suite. Over the interval-SOO' to -1,4S0', both the caliper and MTT indicate very little metal loss. Based on the close correlation of the MTT data to the caliper data, no areas of substantial metal loss to the production casing are indicated. Significant "tool jerk" is indicated in the MTT data over the intervals 3,5S0' - 4,070' and 5,OSO' - 6,090', Accurate assessment of localized or isolated damage is impaired in these intervals, but the average metal loss readings taken while the tool is stopped support a lack of any substantial overall metal loss (other than that recorded on the inside of the tubing by the caliper) within these intervals. Field Engineer: Kesseru / Carpenter Caliper Analyst: J. Thompson & Bin Qi MTT Analyst: J. Burton vvrtness: Freeborn ProActive Diagnostic Services, Inc. ! P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I Average Recorded Metal Thickness Relative to Calibration Point I Pipe 1 4.5 in (24.6' - 6077,1') Well: Field: Company: Country: Survey Date: K-104 Kuparuk ConocoPhillips USA 26-Jun-07 I Decrease Increase 25 25 I I 773 50 1549 I 75 2328 I 100 3107 ..... (j) ..!2 .; E u.. ::¡ .f: z ...- GLM 1 ¡;;; 125 3907 § 150 4682 I 175 5452 GLM2 194 6077 -50% 0 50% in Metal Thickness ("/,,) I I Bottom of Survey = 194 I I Pipe 1 I I I I I I I I I I I GLM 1 GLM2 Correlation of Recorded Damage to 4.5 in (24.6'- I Bottom of Su rvey = 1 94 I I Profile Well: Field: 1 C-104 Kuparuk ConocoPhiDips USA 26-Juo-07 Country: Survey Date: Approx. Tool Deviation Approx. Borehole Profile .... ( ,) ..Q E :;, z .£; .£. 194 o 50 Profile I Tool Deviation 3107 3907 4682 5452 6077 100 25 773 1549 2328 ct:: c I I I Well: Field: Company: Country: K-104 Kuparuk ConocoPhillips USA Tubing: Nom.OD 4.5 ins Weight 12.6 f Grade 8< Thread 1:80 I Penetration and Metal loss (% wall) penetration body metal loss body I I 200 150 100 50 0 o to 1% I I pene. loss I Damage ( body) 150 o 100 50 I isolated general iine ring hole / poss pìtting corrosion corrosìon corrosion îble hofe I I I I over 85% 5 o 5 Report Overview Region Analysis Date: Type: Tool Size: No. of Fingers: Anal st: Nom.! 0 3.958 ins 26-Jun-07 MFC 40 No. 00432 2.75 40 B. Upper len. 6.0 ins Nom. Upset 4.5 ins Damage Profile (% wall) penetration body o 1 metal loss body 50 GlM 1 GLM2 Bottom of Survey = 194 Analysis Overview page 2 I I I I I I I I I I I I I I REPORT JOINT u ONSH Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: Field: 1C-104 Kuparuk ConocoPhilips USA 26-Jun-07 Country: Survey Date: Joint Jt. Depth Pen, Pen. Pen., I,Vtetal Min. 'U Profile No. (Ft) it Body LD. Comments ("/0 wall ) 111::11 (Ins.) 0 50 100 1 25 I 3.96 1.1 55 It 3.95 PUP Shallow DittinQ, 2 58 0.16 3,93 Isolated I)¡ttin~ 3 90 n 3.93 Isolated pitting. 4 120 o 0.05 3.92 Shallow nitiinli. 5 150 n~ 3.94 Isolated l)ittif1~ 6 180 0 3.94 Isolated Dittio!!. 7 211 o 0.08 ) mcorrösion. 8 243 J L . Isolated oitûn2. 9 273 J 3. Isolated oittin2. =#=+=304 3.93 Corrosion. 11 334 ( 0.10 38 3.94 Isolated Dittin~ 12 3f>ó ( I OJ)!) I . '" I 4 fït Isolated Dittin~ 13 397 ( ! ¡ 0.07 14 Isolated pjtt¡n~ 14 428 ( ~ Corrosion, 15 460 O. 3.94 Corrosion. 15,1 491 0 3.94 PUP Isolated Dittinq. 16 494 3.93 17 525 om 3 1 3.89 18 557 0.02 9 ¡ 3.95 19 588 0.05 1 1 3.95 Sha!fow oít1in!!. 20 619 ~ 1 3.94 21 649 3.94 Shallow oiUm,. 22 680 3.94 Isolated oittin2. 23 711 ') 0.05 ~ Isolated oittin2. 24 741 0 0.08 Isolated pittin~ 25 773 0.06 Isolated Dittín~ 26 805 007~ 3.94 Isolated p¡tt¡n~ 27 836 n, 0.07 1 3.95 Isolated Ditlinll. 28 867 0, 0.06 3.94 Isolated oiUioll. 29 897 0, 0.10 36 3,93 Isolated oittinll. 30 929 0,1 0,06 I 22 3.93 Isolated DiUio~ 31 960 0, ~ 3.92 Isolated Dittin~ 32 991 It 1 3,93 I solated pitting. 33 1022 o. i 3.94 Isolated pittin~ 34 1053 ( 0.08 3.94 Isolated oitting. 35 1084 ( t% 3.93 Isolated oittifll<. 36 1114 O. ìß 3.94 Isolated oittim" 37 1145 0.0 3.94 Isolated oittinll. 38 1176 o ~ 0.16 ( 3.94 Corrosion. 39 1208 0 0.11 3.94 Isolated pittin~ 40 1239 0.16 4 3.95 Isolated pitting. 41 1270 020 3.93 Corrosion. 42 1301 0.11 0.19 3.93 Corrosion. 43 1332 0.12 3.94 Isolated oitting. 44 1363 3.91 !soIated PÎttil1~ 44.1 1393 0 ) 0.00 45 1395 O. 9 ~ ") ) 3.89 Isolated pitting. 46 1424 O. 2 3 ¡ 3,94 Isolated oittinll. 47 1455 O. ß ¡fj 7 3.94 VK JKAKI F HOLE. Body Meta! Loss Body Page 1 I I I I I I I I I REPORT JOINT TABULATION SH Pipe: BodyWaJl: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf l-80 0.271 in 0.271 in 3.958 in Well: field: Company: Country: Survey Date: 1C-104 Kuparuk ConocoPhi"ips USA 26-jun-07 Joint jt Depth Pe,! :~~~ Pen.. !'v'~eti!1 Min. h", ~"C> P roflle ,~¡::' ." No. (Fl.) 1.0. Comments po Wdll} (I (Ins.) (Ins.) 0 50 100 LlR 1487 ~=1Î t; 3.92 Isolated nittinQ, 49 1518 4 3.')4 !sobted nittinQ 50 1549 nns O.1St! 3.94 Corrosion 51 1580 O¡¿j 0.13 3.93 Corrosion 52 1611 0)7 0.13 3.90 Une corrosion. 53 1643 0.19 moo'~on 54 1674 o :7 0.14 511=t: . corro"ion. 55 1705 0.14 line corrosion. 56 1716 o 1 0.16 { ') I Une corrosion. 57 1767 0 0.16 t line corrosion. 58 1798 0 0.14 'S line corrosion. 59 1830 f¡ 0.13 H 3.94 Corrosion. 60 1860 ~0.15 3 corrosion. It. Deoosits. 61 1891 ( 0.13 3.94 line corrosion. 6? FJ?? OO{, ¡ 0.15 3.94 ! ine corrosion. 63 1 c¡r:¡,1 Im$ 3.94 line corrosion. 64 1984 ; ¡{ - 0.16 { 3.96 Corro<;ion, Lt, Deoosits. 6'S 2016 3.92 line corrosion. 66 2047 3,93 line corrosion. 67 2078 I !( 0.17 61 3.93 Corrosion. 611 2110 n.17 62 3.C¡3 Line corrosion. 69 2141 0.14 ;3 3.93 Une corrosion. 70 2172 0.17 ,7 ~ Une corrosion. 71 2203 01 17 0.16 I line corrosion, 72 2234 I 0 0.17 line corrosion. 73 2265 I )1\ f}f 3.94 line corrosion. 74 2297 í 19 , 3.93 Line corrosion. 75 2328 0.14 3.94 Une corrosion. 76 2359 0.14 , 3.94 Line corrosion. 77 2390 0.14 3.89 Une corrosion. 78 7422 0.16 ¡ ¡ 3.93 Une corrosion. 79 2452 0.15 3m Corrosion, 80 2483 0 0.14 { 3, Corrosion. 81 2514 ,I fi& 5 3.94 line corrosion. 82 2545 ¡ 1 3.95 line corrn<:íon. 83 2576 0.17 13 3,94 Line corrosion, 84 2608 I 0.17 3.93 Corrosion. 85 2639 0.19 I ?~ 3.93 Corrosion. R6 2669 0.17 3.95 Line corrosion. Lt. Del1osits. 87 2700 .1) 0.18 í 3.95 Une corrosion. 8R 2732 .1 0.17 3.95 Line corrosion. It. Deoosits. 89 2763 '.H 0,17 3,92 Une corrosion. 90 2794 0.18 it 3.88 Line corrnsinr¡. Lt Deoosits. 91 2827 0.17 ( 3.94 Line corrosion. It Deposits. 92 2857 0.16 3.92 l"orI"r"Kion. U. Deno<;its. 93 2887 0.16 3.93 Corrosion, 94 2919 ¡ 0.19 3.93 line corrosion. Lt. Deposits. 95 2951 .1 0.16 3,95 line corrosion. It Deposits. 96 2982 .14 0.17 3.94 Line corrn<:ion, 97 3013 ,1,) 0.21 3.93 Une c:orrosíon. Body Metal loss Body Page 2 I I I I I I I I REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nomina! I.D.: 4.5 in 12.6 ppf l-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: 1 C- 104 Kuparuk ConocoPhiDips USA 26-Jun-07 Joint Jt. Depth Pen. PerL · ¡\¡1e¡;;! Min. Profile No. (Ft.) Body LD. Comments (% wa(1) (Ins.) (Ins.) (Ins. ) 0 50 100 98 3044 0.20 nH 3,QO line corrosion. 99 3076 0.19 i9 7 3,94 line corrosion, 100 3107 0.21 79 9 3.93 line corrosion. 101 1138 0,19 H 3.93 Line corrosion. 102 3170 on9 0.18 =ij line corrosion, 103 3201 ooc¡ 0.21 line cor ro<;Íon. 104 3232 0.09 0,21 Corrosion, 105 3261 (..¡I~ 3 3.91 line corrosion. 106 1297 in 7 1,92 line corrnsion. 107 H74 II) ! 0.19 3.86 Line corrosion. Lt. Deoosits. 108 H'1'1 I g;~ft 3,94 I inf> 109 3384 3.95 ¡ inf> 110 341'1 3.94 Line cor rosÎon. 111 3446 3.89 Line corrosion. 112 3479 ~71 3.94 line corrosion. 113 1'iOq I I ¡ 66 3.94 Line corrosion. 114 1'1411 I 87 ¡ I 3.90 ¡ inf> rorrosion. 115 3571 1B± 0.18 67 n 394 line corrosion. 116 3602 018 =1t 1 3.94 I inf> corrosion. 117 3634 h 0.191¡ 3.93 Line corrosion. Lt, Dennsits. 118 3664 .1 0.19 6B B 3.94 line cnrrosion Lt. Deoosits. 119 3695 .12 0.20 73 3.94 line corrosion. 120 3726 1'¡ 0.18 68 3.92 line corrnsion. 121 3758 ffti 0.18 Ji:t 3.89 line corrosion. It. Deoosits. 122 3790 0.19 3.A9 line rorro"ion, Lt. Denosit". 123 3822 o1T 0.19 3.91 line corrosion. It. DepOSits. 123.1 3851 (17) 0.17 i7 3.93 PUP Corrosion. 123.2 3860 ( 0 N/A GLM 1 {latch @ 1 :00\ 123.3 3867 ( () =tlf PUP 124 3877 0.22 Corrosion. 125 3907 0.72 n 3.94 line 126 3937 0.20 3,92 line It. Deoosits. 177 3968 0.18 3.95 Corrosion. Lt. DennsÎts. 128 3999 ( 0.20 In 3.94 Corrosion. 129 4031 { 0.21 'I 3.94 line corrosion. 130 4062 0.20 3.90 line corrosion. 131 4091 0,19 ¡ 3.94 line c'ûrrosion. It Deoosits. 132 4124 m 3,90 line corrosion. 133 4156 3.88 line corrosion. It. f)pnosits. 134 4188 nl, 0.21 ,Ö 3.93 line corrosion. 135 4218 17 0.20 3.93 line corrosion. 136 4249 (^I 0.19 3,89 line corrosion. 137 4278 .1 0.20 3.93 line corrosion. 138 4310 I 0.16 3.88 line corrosion. It, DepOSits. 139 4341 0.19 3.94 Corrosion. 140 4372 0.21 3.88 line corrosion. 141 4404 0.20 In 3.93 line corrosio n. 142 4435 0.21 1'\ i.9S line corrosion. 143 4465 Ii II 0.18 , '111 i.R9 ! ;nn It Denosits. 144 4497 iii 0.25 W 3.93 ¡Jl I¡:: Page 3 I I REPORT JOINT ONSH I Pipe: Body Wall: Upset WaD: Nominal 1.0.: 4.5 in 12.6 ppf l-80 0.271 in 0.271 in 3.958 in Well: Field: 1C-104 Kuparuk ConomPhiDips USA 26·Jun-O7 Country: Date: I Joint Jt. Depth Pen. Pen, Pen. ¡\¿Ielal Min. n ,~...~ No. (Ft.) Body 1.0. Comments (Ins.) (Ins.) (Ins. ) 0 50 100 145 4526 O.!I Hft 3.93 line mrrosion. r- 146 4557 3.95 line mrrosion. 147 4589 3.94 . 148 4619 ILl 79 , Corrosion. 149 4651 0.1 Line 150 4682 ILl line 151 4712 0.1 1. 152 4743 0 line ("'orrosion. 153 4774 3.94 Line mrrosiol1. 154 4005 .14 oJ?" 3.94 line corrosion. 155 4836 11 1 3.92 line mrrnsion. 1 Sf) 4866 13 I) 3.94 line corrosion. 157 4897 '.11) B 3.95 Line mrrosÎon. It. DeoosÎts. 158 4928 '.11 1.90 POSSIBLf HOLE. 159 960 Line mtrosion. 160 991 .10 0.21 line 161 ~O.25 3.94 '( J.....IKI E HOLES. 162 )53 0.22 3.94 line rnrrosion. 163 184 ¡ 0.21 3.90 line mrrosion 164 5116 0.\2 :fJtlit í 3.94 Une mrrosÎon. 165 5146 . (un 1 3.94 Uhe corrosion. 166 5178.OZ 0.17 II 3.94 ¡ ine mrrosion. 167 5209 0.20 q ~ line mrrosion. 168 5239 0.19 it': 3 line mrrosiol1. 169 5')69 0.17 '1.89 ! ¡tie mrrosion 170 5301 0.20 3.95 Une corrosion. 171 5330 0.19 i94 line mrrosion. 172 5361 0.27 3.93 HOLE 173 5392 0.22 10 3.94 Line corrosion, Lt DelJOSits. 174 5423 0.22 9 3.93 line mrrosion. 175 5452 3.95 line mrro5Íon. Lt. Oeoosits. 176 5483 .111 3.95 Corrosion. 177 5514 iqt¡ ( 178 5545 '1.Q5 line mrrosion. 179 '>576 .1) 3.95 Corrosion, 180 5607 .10 c¡ 3.96 Line corrosion. 181 5638 '.OH ¡¡ 3.94 Line mrrosion. 182 5670 '.1 í 3.96 Corrosion. 183 5701 IHI' 0.16 ¡ 3.95 line Lt Deoosits, 184- 5732 10J ~ ¡ 3.88 Line 185 5762 .1 1 3.87 Line mrrosíon. 186 5794 O. 0.18 3.93 Line corrosion. 187 \~5 tfu~. 3.93 Line corrosion. 188 5856 _ 3.94 Line mrrosion. 189 5887 0< 0.17 HI 3.94 Une mrrosion. 190 5918 0 ~ 3.94 Corrosion. 191 .0 O. 3.94 COrfrwion, 192 :1 o. 0.19 69 3.95 Corrosion. Lt. Demsits. 192.1 I 1 0 0,19 70 I 3.91 PUP line cOrfŒion. 192.2 I 0 ( ° o ¡ ( NIA GLM 2 (latch @ 5:30} Body Metal Loss Body 4 I I I I I I JOINT TABULATION SH Pipe: BodyWali: Upset Wall: Nominall.D,: 4.5 in 12.6 ppf 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: Joint No. I I I I I I I 5 1C-104 Kuparuk ConocoPhiU¡ps USA 26-Jun·07 Comments .. WeU: Field: Company: Country: Tubin: .. .. 1 C-104 Kuparuk ConocoPhillips USA 4.5 ins 12.6 f L-80 Tool '" 64 Nomina! 10'" 3.958 Nominal 00 '" 4.5 Tool deviation 690 .. .. .. .. .. S Repo ross S Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: 26-jun..o7 MFC 40 No. 00432 2.75 40 B. i for ft HOLE .271 ins'" 100% Walt Penetration HIGH SIDE '" UP Cross Sections page "I .. s .. .. .. - Well: Field: Company: Country: Tubin : Tool speed = 71 Nominal ID = 3.958 Nominal OD = 4.5 Tool deviation = 47 " - 1C-104 Kuparuk ConocoPh¡ ips USA 4.5 ins 12.6 f L-80 for Joint 47 - - -- - P S Report ross Secti ns Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st; 26-jun-07 MFC 40 No. 00432 2.75 40 B. i depth 1470.65 ft Probable Hole .266 ins = 98% Wall Penetration HIGH SIDE = UP Sections page 2 I I KRU 1C-104 PUMP (6144-6145, I OD:3.958) I SEAL (615;>.6169, 00:5.130) MOTOR (6169--6185, 00:5.620) I I I I I ,I PUP I (7287-7445, OD:4.500) I I I Perf (7446--11395) I I II I I . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: Aa3CC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 SCANNED JUL 0 5 2007 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 retuming a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AI< 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5] 6) 7) 1 Report / EDE 1C-104 Caliper Report 26-Jun-07 c9c8--o<er .. 1595"] RECEIVED Signed: o~JL- Date: JUL 0 2 Z007 Print Name: n. r'i :c., t-J 11 ,p {1A t1. {AAA (¡ f'-1. AJaska Oil & Gas Coos. Commission Anchorage PRoACTIVE DtAoNOS11C SERVICES, INc., 130 W.INTERNATIONAL AIRPORT AD SUITE C, ANCHORAGE, AK 99618 PHoNE: (907)245-8961 FAX: (907.245-8962 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:lMester _copy _ 00 ]DSANC-2Oxx\Z_ Word\Distribution\Transmittal_ Sheeœ\Tl1wmiUJIÌgina1.doo I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. June 26, 2007 6658 1 4.5" 12.6 lb. L-80 Tubing Well: 1C-104 Field: Kuparuk State: Alaska API No.: 50-029-23076-00 Top Log Intvl1.: Surface (MD) Bot. Log Intvl1.: 6,092 Fl (MD) Inspection Type : COMMENTS: Corrosive & Mechanical Damage Inspection This Caliper data is tied into the Parker GUI 2 @ 6,021 ft. (Driller's Depth). This Jog was run to assess the condition ofthe 4.5" tubing interval with respect to corrosive and mechanical damages. The caliper recordings indicate that the 4.5" tubing interval is in fair to poor condition. A hole is recorded in joint 172 (5,382'). Wall Penetrations in excess of 20% are recorded in 189 of 204 joints Jogged. The damage appears to be in the form of Line of Corrosion, General Corrosion and Isolated Pitting. No significant areas of cross-sectional wall loss or 10 restrictions are recorded. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is induded in this report. 4.5" TUBING - MAXIMUM RECORDED WALL PENETRA 110NS: HOLE PROBABLE HOLE POSSIBLE HOLE POSSIBLE HOLE POSSIBLE HOLE 172 @ 47 @ 144 @ 161 @ 158 @ 5,382 Ft. (MD) 1,471 Ft. (MD) 4,517 Ft. (MD) 5,038 Ft. (MD) 4,949 Ft. (MD) ( 100%) ( 98%) ( 91%) ( 91%) ( 87%) Jt. Jt. Jt. Jt. Jt. 4.5" TUBING - MAXIMUM RECORDED CROSS-SEC110NAL METAL LOSS: No significant areas of cross-sectional wall loss (> 13%) are recorded. 4.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. I Field Engineer: Kesseru / Carpenter Analyst: J. Thompson & Bin Qi Witness: Freeborn ProActive Diagnostic Services, Inc. í P.O. Box 1369, Stafford, TX 77497 . Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memOryl09.ccmECE IVE C~ Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 If\. / JUL 0 2 Z007 ~Dd -60 I :¡t: tS"<9S-3 Alaska Oil & Gas Cons. Commission Anchorage I of to I 4.5 in - 6077.1') Well: 1 C-104 Field: I Company: USA Survey 26-Jun-07 I I Tool Deviation Approx. Borehole Profiie 25 I 25 773 I 50 1549 I I 75 2328 I 100 3107 ..... ( ) ..s:;¡ cr:: E :::¡ ¡;; z I GLM 1 .£ 125 3907 .£. I 150 4682 I 175 5452 GLM2 194 6077 0 50 100 I Profile wall) / Tool Deviation I Bottom of 194 I I I I We!!: Field: Company: Country: 1C- 104 Kuparuk USA I Nom.OD 4.5 ins 12.6 Grade 1& Thread l-80 I Penetration and Metal loss I 5 o I 150 100 I 50 o 40 to over 85% 85''/0 I I I Configuration ( body) 150 I 100 I 50 o I isolated general line ring pitting corrosion corrosion corrosion I 5 I I Survey Date: Too! Type: Tool Size: No. of Ana! st: NomJD 3.958 ins 26-jun-07 MFC 40 No. 00432 2.75 40 B. len. 6.0 ins Lower len. 6.0 ins Nom. 4.5 ins Damage Profile ('Yo wall) penetration metal loss SO 100 GLM 1 GlM2 Bottom of Survey = 194 Analysis Overview page 2 I I I REPORT JOINT ULATION SHEET I I Pipe: Body Wail: Upset Wall: Nominal 1.0.: 4.5 in '12.6 0.271 in 0.271 in 3.958 in L-80 Well: Fieid: Company: Countl)': Survey Date: 1 C-104 Kuparuk USA 26-Jun-O7 I I Joint Jt. Depth Pen. Pen. Pen. !vletJI Min. n,,~ m= Profile -= No. (Ft.) I~:::E;I Loss 1.0. Comments (%wall) (Ins.) (Ins.) 0 50 100 1 ~ 0 0 3.96 1.1 0.03 12 ¡ 3.95 pIIP $h:./lownittinu. 2 0.06 '1 ') 3.93 Isolated nittinu 3 90 0 0.06 'i 3.91 Isolated nittin<> 4 120 0.05 1.92 '>h;¡lIow nitlÎnQi. 5 150 0.10 3.94 Isolated nittiru;¡ 6 HID 0.06 3.94 Isol;¡ted niUin2:. 7 211 0.08 3.94 Corrosion. S 243 0.08 3.92 Isolated nittina 9 273 0.10 3.93 Isolated ",mine. 10 304 0.09 3.93 Corrosion. 11 334 O.! 05 0.10 ;1 '1.94 Isolated nittine 12 366 o o Ii, 0.09 d ±m <:ol;¡tpcJ nittinQi 13 397 1.06 ~m .Q3 <:obtpn nittinQ 14 478 1"í orrosion. 15 460 In 0.08 3.94 Corrosion. 15.1 491 Hi 0.08 '.' Ü 2 3.94 PUP isolatprt nittin<>. 16 494 0.02 ¡ 3.Q-:¡ ! 17 525 0 om ¡ 3.R9 ! 18 557 0 0.02 ¡ 3.95 19 588 0.05 I 3.95 Shallow nitlÍnll. 20 619 0.03 I 3.94 21 649 0.04 1 3.94 Shallow nittina. 22 680 I 0.07 1 3.94 Isolated oittina 23 711 I 0.05 1 '{.93 isolated nittina 24 741 0 0.08 3.95 Isolated nittÎng 25 773 I 0.06 1 3.88 Isolated niUing 26 805 I 0.07 b 3.94 Isolated nittínQ! 27 836 o.! i5 ¡ti 3.G5 Isolated nittinº 28 867 CUb 3.94 Isolated nitting:. 29 897 . 3.93 isolated nittinº" 30 929 Iso!aæd nittiOIL 31 960 0"11 J 3.92 Isolated nittin'" 32 991 O. ·1 0.11 3.93 Isolated nittinº 33 1022 O. ·3 0.09 3.9L1 Isolated nittinº 34 1053 0 0.08 3.94 Isolated nittinl2". 35 1084 I 0.07 3~ nítti02 36 1114 If\ 0.11 3.94 solated nittiml. 37 1145 0 0.07 3.94 Isolated nittiOIL 38 1176 17 °dtl61 4 3.94 Corrosion. 39 1208 II O. 40 3.94 ¡ <:n!ated nittina 40 1239 0.11 0.16 61 3.95 Isolated nittiog 41 1270 0.14 020 Kit 3.93 Corrosion. 42 1301 0.11 0.19 3.93 Corrosion. 43 1332 012 0.10 !H 3.94 Isolated nittinº 44 1363 I 0.10 17 3.91 Isolated nittinlL 44.1 1393 I ° 0 I 0.00 45 1395 O. 19 0.14 52 3.89 Isolated niUinº 46 1424 O. 12 0.06 23 1 3.94 Isolated nittin'" 47 1455 o. In 0.27 9f\ 7 3.94 PROBABLE HOLE. I I I I I I I I I I I I Body Metal Loss Body I I PDS JOINT LATION SH Pipe: Body WaJl: Upset Wall: NominaII.D.: 4.5 in 12.6 ppf l-80 0.271 in 0.271 in 3.958 in WeU: Field: Country: Survey Date: 1 C-104 Kuparuk ConocoPhiUips USA 26-Jun-07 I Joint Jt. Depth Per Pen~ Pen. Melal Min. Profile No. (Ft.) ': Body !.D. Comments waJl) (Ins) (Ins.) (Ins.) 0 50 100 48 1487 0.1', 0.13 3.92 Isolated nittin2. 49 1518 OOB 0.14 3.94 Isolated oittin2. 50 corros~on. 51 52 3.90 line corrosion. 53 1643 0 0.19 ( 9 7 3.93 Line corrosion. 54 1674 007 0.14 4 3.94 line corrosion. S5 1705 0 0.14 il 3.95 Line corrosion. 1 0.16 I {) 3.93 line corrosion. ~ '.W 0.16 ~o~ 58 .It . ro5io n. 59 1830 ~0.13 60 1860 0.15 3.94 corrosion. Lt. Dennsits. 61 1891 1'.0 0.13 48 4 3.94 line corrosion. 62 1922 ,¡ 15 ~ line corrosion. 63 19541 16 3.94 line corrosion. 64 1984 12 3.96 Corrosion. Lt. !Jel1OSits. 65 Line corrosion. 66 2047 61 7 3.93 Une corrosion. 67 2078 61 I 6 3.93 Corrosion. 68 Line corrosion. 69 2141 O. 0.14 --L- 3.93 line corrosion. 70 2172:±& 0.17 ~ 3q4 line cor!"n'cion. 71 2203 0.16 I I 3.93 line corrosion. 72 2234 0 17 I i=t 3.95 Line corrosion. 73 2265 0, 0.15 t 3.94 line corrosion. 74 2297 O. 0.16 t I 3.93 line corrosion. 75 2328 011 0.14 '10 t 3.94 line corrosion. 76 2359 (to' 0.14 ;0 3.94 line corrosion. 77 2390 nm 0.14 10 3.89 line corrosion. 78 2422 01 ±ftl I 3.93 line corrosion. 79 2452 0 3.94 Corrosion. 80 2483 1 3.95 Corrosion. 81 2514 O. 0.15 3.94 line corrosion. 82 2545 O. 0.20 ~line corrosion. 83 2576 00; 0.17 6 6 line corrosion. 84 2¡:;O8 )1 0.17 I 3.93 Corrosion. 85 2639 .1. 0.19 I 3.93 Corrosion. 86 2669 0 0.17 3.95 Unp corrosion. It Dpnnsits. 87 2700 I 0.18 3.95 line corrosion. 88 2732 .1 0.17 3.95 line corrosion. It. DeDOsits. 89 2763 ( .H 0.17 64 3.92 line corrosion. 90 2794 0.18 66 3.88 line corrosion. Lt. Del1OSits. 91 2827 J)9 0.17 6) 3.94 Line corrosion. It. Deposits. 92 28')7 o·lttlt 3.92 Corrosion. It. Denrn;its. 93 2887 0.1 3.93 Corrosion. 94 2919 0.19 ~ '¡ne """,,,on. It D"""". 95 2951 0.16 3 line corrosion. It. Del1OSits. 96 2982 0.17 3 line corrosion. 97 3013 0.21 3.93 line corrosion. I I I I I I I I I I I I Body Meialloss Body Page 2 I I I PDS REPORT INT u I I Pipe: Body Wall: Upset Waft: NominalI.D.: 4.5 in 12.6 ppf l-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Date: 1C·104 Kuparuk ConocoPhillips USA 26-Jun-07 I Joint Ji. Depth Pen Pen. t' Melal Min. n~~ ,~~ Profile -'" No. (Ft.) !.D. Comments wall) (Ins.) (Ins.) (Ins.) 0 50 100 98 3044 O.201~ 3.90 Line corrosion. 99 3076 0.19 f94 line corro<:ion. 100 3107 0.21 . 3.93 Line corrosion. 101 3138 0.19 "I 3.93 Line corrosion. 102 3170 0 0.18 3.93 Line corrosion. ~ 3201 co' 0.21 3.94 Line corrosion. 3232 0.09 () 11 3.95 Corrosion. 3261 II 3.91 I ine corrosion. 106 3292 3.92 n. 107 3314 3.86 Line mrrosion. Lt. Denosits. 108 3355 ±i 3.94 Line corrosion. 109 3384 3.95 Line corrosion. 110 3415 3.94 Lin'" corrosion. 111 3446 0.13 0.22 7 3.89 line corrosion. 112 1479 01;> iiEâilir=;on 113 3509 11 0.18 ~, Line corrosion. 114 3540 11 o 3.90 Line corrosion. 115 3571 11 o 3.94 Line corrosion 116 3602 '.21 0.18 67 11 < q.d Line corrn<:ion. 117 3634 11 0.19 I 3.93 Line corrosion. Lt. Denosits. 118 3664 I'll 0.19 11 3.94 Line corrosion. It. Denosits. 119 3695 0.11 0.20 1, <.94 Line corrosion. 120 3726 01' 0.18 1 3.92 I ine corrosion. 121 3758 0.1 0.18 m 3.89 Line corrosion. Lt. Denosits. 122 3790 0 0.19 1.119 I ine corrosion. Lt. Dennsits. 123 3822 0 0.19 3.91 line corrosion. L t. Denosits. 123.1 3851 0 0.17 3.93 PUP Corrosion. 123.2 3860 ¡ 0 0 N/A GlM 1 (latch @ 1 :001 123.3 3867 ( 0 0 3.96 PUP 124 3877 0.13 0.22 112 3.92 Corrosion. 125 3907 1 0.22 3 3.94 line c:orrosion. 126 3937 'R 3.92 Line corrosion. Lt Deoosits. 127 3968 'I 3.95 Corrosion. Lt. ne.-.n<:its. 128 3999 10 3.94 Corrosion. 129 4031 I 3.94 line corrosion. 130 4062 1.14 btj 3.90 Line corrosion, 131 4091 0.14 0.19 -.94 I ¡ne r.nrro"¡on. U. Denosits. 132 4124 0.12 0.18 3.90 Line corrosio n. 133 4156 OJ 0.20 3.88 Line corrosion. It.Oenosits. 134 4188 01 0.21 3.93 Line COfrosion. 135 4218 01 0.20 3.93 Un!" corrosion 136 4249 OJ 0.19 3.89 Une corrosion. 137 4.278 111 0.20 3,93 Line COfro<:¡On. 138 4310 0.1 0.16 )! 1.2 3.88 line corrosion. U. Denosits. 139 4341 ( I 0.19 q 3.94 Corrosion. 140 4372 1 '.H 0.21 11 3.88 Line corrosion. 141 I 4404 0.20 10 3.93 Line corrosion. 142 4435 ¡ 1 11 corrosion. 143 4465 8 I 10 3.89 . ¡ ine corrosion. Lt Dennsits. 144 4497 I '5 10 3.93 POSSIBLE HOLE. I I I I I I I I I I I I Body Me1a1 Loss Body 3 I I I PDS REPORT JOINT TABULATION SHEET I I Pipe: Body Wall: Upset Wall: NominaIID.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Coun try: Survey Date: 1 C-104 Kuparuk ConocoPhiøips USA 26-jun-07 I I joint jt. Depth 'erL Pen. Pen, :\11.'1;]1 Min. Damage Profile No. (Ft.) ,Jpse! Body oss !.D. Comments (%wall) :~':- (Ins.) 0 50 100 145 =illt a 3.93 Line corrosion. 146 0.11 ') 395 Line cnrrosion. 147 4589 0.11) 0.21 7 3.94 Corrosion. 148 4619 ( .15 0.21) 3.90 Corrosion. 149 4651 (:7 0.21 3.94 Line corrosion. 150 4682 ¡ 0 0.18 i a 3.93 Line corrosion. 151 4712 4 0.22 j 3.95 Corrosion. 152 4743 I 01 0.20 7 3.94 Line corrosion. 153 4774 I 0.0') 0.16 60 7 3.94 Line corrosion. 154 4805 04 0.17 7 3.94 Line corrosion. 155 4816 Oil 0.17 II 3.92 Line corrosion. 156 4866 ()II 0.20 3.94 Line corrosion. 157 4897 o :f, 0.18 I' 3.95 Line corrosion. Lt Denosits. 158 4928 m I 3.90 POSSIBLE HOLE. 159 4960 I' 3.95 Line corrosion. 160 4991 ±ì3.94 Line corrosion. 161 5022 0.25 3.94 POSSIBLE HOLES. 162 5053 0.22 3.94 Line corrosion. 163 5084 Oon 0.21 n 10 3.90 Line corrosion. 164 5116 012 0.19 I 12 3.94 Line corrosion. 165 5146 0 0 0.20 0 3.94 Line corrosion. 166 5178 )q 0.17 394 Line corrosion. 167 5209 J 0.20 3.94 Line corrosion. 168 5239 2 0.19 I 3.94 line corrosion. 169 <;169 0 0.17 1 3.89 I ine corrosion. 170 5301 .10 0.20 ') 3.95 Line corrosion. 171 5330 11 0.19 I 3.94 Line corrosion. 172 5361 11' 0.27 3.93 HOLE. 173 5392 (), 0.22 1 3.94 line corrosion. Lt Deoosits. 174 5423 ()1 0.22 3.93 Line corrosion. 175 5452 ( 0.19 3.95 Line corrosion. Lt Deoosits. 176 5483 0.21 3.95 Corrosion. 177 5514 0 0.19 3.95 Corrosion. 178 5545 0.07 0.19 10 3.95 Line corrosion. 179 5576 0.17 3.95 Corrosion. 180 5607 0.18 3.96 line corrosion. 181 5638 0.21 3.94 Line corrosion. 182 5670 ( 0.17 3.96 Corrosion. 183 5701 (if 0.16 3.95 Line corrosion. Lt Deoosits. 184 ')732 o.on 0.17 0 3.88 line corrosion. 185 5762 0.11 0.17 3.87 Line corrosion. 186 5794 0.10 0.18 66 3.93 Line corrosion. 187 5825 O.I( 0.18 3.93 Line corrosion. 1RR 5856 (,.( 0.17 3.94 Line corrosion. 189 5887 :( 0.17 3.94 Line corrosion. 190 5918 0.17 3.94 Corrosion. 191 5950 0.17 3.94 Corrosion. 192 5981 ! I 0.19 3.95 Corrosion. Lt. Deoosits. 192.1 6011 ( .10 0.19 ( 3.93 PUP Line corrosion. 192.2 6020 0 0 0 N/A GLM 2 (latch @ 5:30\ I I I I I I I I I I I Body Metal Loss Body Page 4 I I I JOINT ONSH I 4.5 in 12.6 ppf l-80 Well: 1G104 Wall: 0.271 in Field: I Upset Wall: 0.271 in Nominal I.D.: 3.958 În USA Survey 26-Jun-07 I Joint Profile No. Comments 0 50 100 I I I I I I I I I I I I I 5 I I .. .. .. .. .. Well: K-104 Field: Kuparuk Country: USA Tubin : 4.5 ins 12.6 f L-80 .. .. .. .. .. .. .. .. s Survey Date: Too! Type: Tool Size: No. of Ana! st. 26-jun-07 MfC 40 No. 00432 2.75 40 B. i Tooj '" 64 Nomina! 10'" 3.958 Nomina! 00 '" 4.5 Tool deviation 690 ft HOLE .271 ins'" 1 00"/" Wan Penetration HIGH SIDE '" UP Cross Sections page 1 .. s .. .. .. ------ - - - - -.. -.. .. .. - Well: Field: Company: Country: Tubin : S Repo ross S ons lC-l04 Kuparuk ConocoPhillips USA 4.5 ins 12.6 f l-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: 26-jun-07 MFC 40 No. 00432 2.75 40 B. i Tool = 71 NominallD = 3.958 Nominal OD = 4.5 Tool deviation = 47 0 nt 47 at depth 1470.65 it Probable Hole .266 ins = 98% Wall Penetration HIGH SIDE = UP Cross Sections page 2 I I I PUMP I (5144-<>145, 00:3.958) I SEAL (5155-6159, 00:5.130) I MOTOR (5159-6185, 00:5.620) I I 6093' RKB . I I I I pUP (7287-7445, 00:4.500) I I Pert (7445-11395) I I I KRU 1C-104 .-......- Schlumberger ¿JO'd -Q(of _' ~ . ~1 1..{){)1 i{;ANNt.OJ\j NO. 4300 06/14/07 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ;.~ 0 zom .' "c;,øJRf)ar1V='~'" "Alaska Oil & Gas Cons Comm '" .' ,'" Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 (j ,n Field: Kuparuk Well Job# Log Description Date BL Color CD 2M-16 11629024 SBHP SURVEY 06/06/07 1 2N-306 11629025 SBHP SURVEY 06/06/07 1 2H-07 11638870 PRODUCTION PROFILE 06/07/07 1 2N-323 11629027 SBHP SURVEY 06/08/07 1 2N-313 11629027 SBHP SURVEY 06/08/07 1 2M-29 11638871 SBHP SURVEY 06/08/07 1 1C-104 11638872 LDL 06/08/07 1 1 G-08A 11629026 PRODUCTION PROFILE 06/09/07 1 2N-308 11638874 SBHP SURVEY 06/09/07 1 2M-10 11629031 SBHP SURVEY 06/10/07 1 1A-27 11638876 PRODUCTION PROFILE 06/10/07 1 2M-12 11629030 SBHP SURVEY 06/10/07 1 2L-311 11638881 SBHP SURVEY 06/11/07 1 2N-317 11638878 SBHP SURVEY 06/11/07 1 2B-08 11629032 INJECTION PROFILE 06/11/07 1 1 H-08 11638882 INJECTION PROFILE 06/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . RE: lC-104 (PTD 202-061) Report oftbg leaks . . Subject: RE: 1C-104 (PTD 202-061) Report oftbg leaks From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Wed, 13 lun 200713:57:32 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Tom, 1. This is the first WS ESP that has had a tbg failure. We have not seen any corrosion in the tbg or casing of our west sak ESPs. The lDl log was completed on 6/8/07 and found tbg leaks at 1491' and 5383'. This well was worked over in Sept 2005 to replace the failed ESP. There is a good chance that the tbg installed in this well was recycled tbg rather than new tbg. The ratty CCl response on the lDl log indicates tbg corrosion from surface to bottom of the log interval which was just above the pump. This is the 3rd well that was worked over in the last few years that has sprung a tbg leak within 1-2 years. There seems to be an issue with the quality of the new tbg we've been receiving or with the inspection process of recycled tbg. Our RWO engineers are on top of investigating the cause to prevent future failures. 2. Yes, the temperature drop is associated with the reduce flow from the well. The well was SI on 4/26/07. Based on welltests, wellhead temp, and flowing bottom hole pressure trends, the pump efficiency slowly decreased from 4/9/07 until if was SI on 4/26/07. Typically, pump performance falls off when solids wear the bearing surfaces on the stages or scale deposits on the stages inside the ESP pump. 3. Daily production dropped from 917 BFPD on 3/29/07 to 156 BFPD by the last test on 4/26/07. 4/9/07 welltest = 695 BFPD, 4/16/07 welltest = 382 BFPD, 4/25/07 welltest = 163 BFPD. 4. I think the flowrate wouldn't have been high enough to erode the casing at the leak points, but that is a good question. It probably depends on what the cause of the leaks are. The CCl of the lDl log shows the leaks are in the tbg joints, so I suspect a corrosion hole that would have quickly degraded rather than remaining a small leak that would jet fluids against the csg wall. Consideration of casing damage....Yes, I am in the process of investigating the condition of the casing thru the tbg since this a single casing well. I've issued a procedure for slickline to run a tbg caliper log and an MTT log (magnetic thickness log) to determine if there is internal tbg corrosion vs external tbg corrosion/internal casing corrosion. The log should be ran in a week or sooner. Thanks for the reminder to consider casing problems during the RWO, I'll forward the recommendation to the RWO engineers to test the casing and/or run a USIT log to verify the casing wasn't damaged in light of the tbg leaks. Please let me know if there are any other questions, Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com SCANNED JUN 1 4 2007 From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, June 13, 2007 11:47 AM To: NSK Problem Well Supv Subject: Re: lC-l04 (PTD 202-061) Report of tbg leaks Marie, Thanks for the information. A couple of questions. 1. Is this the first WS ESP well to have experienced a tubing failure? 2. On the no plot, is the drop in temperature when it is estimated that the leak developed? lof2 6/13/2007 2: 11 PM RE: 1 C-l 04 (PTD 202-061) Report of tbg leaks . . 3. How much did the daily production change? 4. Is there any concern for where fluid ftom the tubing leaks might have impacted the casing? Consideration should be given to investigating this when the well is worked over. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 6/13/2007 11 :28 AM: Tom & Jim, Packerless West Sak ESP producer, 1C-104 (PTD 202-061) is currently shut in due to 2 tbg leaks that were identified during wellwork to troubleshoot poor ESP performance. Diagnostics are planned to determine the cause of the tbg leaks and evaluate if the tbg can be repaired with retrievable patches while waiting on a RWO to run new tbg. If the tbg is patched, a 10-404 report will be submitted. Attached is a schematic and 90 day TIO plot. Since this well doesn't have a packer, the tbg was not a barrier and does not effect the well integrity. The loss of tbg integrity only effects the performance of the ESP pump as the discharged fluids from the pump are returned to the IA before reaching surface. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com «1C-104 90 day TIO plot 6-13-07.gif» «1C-104.pdf» 2 of2 6/13/2007 2: 11 PM c- 104 90 AM e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc ') ') Jim Ennis Wells Group Engineer Drilling & Wells Conocó'Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 October 20, 2005 RECEIVED OCT 2 4 Z005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas COilS. Comm¡ssim~ Anchorage J., Cd-,-O (pj Subject: Reports of Sundry Well Operations for 1 C-1 04 & 1 C-1 04L 1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Reports of Sundry Well Operations for the recent workover on the West Sak multilateral1C-104 and 1C-104L 1 to replace the failed ESP. If you have any questions regarding this matter, please contact me at 265-1544. Sincerely, ~ J. Ennis ,!'ells Group Engineer CPAI Drilling and Wells ·5ÇANNED NOV () 1 2005 JE/skad RECEIVED STATE OF ALASKA 2005 ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 2 4 REPORT OF SUNDRY WELL OPERA TION~~~k~ nit & Gas Cons. Commission Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other AnctKmage Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPh ill ips Alaska, Inc. Development 0 Exploratory 0 202-061 1 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 '50-029-23076-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' 1C-104 1. Operations Performed: ) ) 8. Pr~perty Designation: ADL 25649, ALK 467 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF/PROD SCREEN B-SAND LINER Perforation depth: 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool measured 11560' feet true vertical 3688' feet measured 11550' feet true vertical 3688' feet Length Size MD 122' 16" 158' 7359' 7-5/8" 7395' 4342' 4"x4.5" 11550' 3949' 4-1/2" 11548' Plugs (measured) Junk (measured) TVD Burst Collapse 158' 3696' 3688' 3689' Measured depth: screens from 7446'-11395' true vertical depth: 3745'-3692' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6172' MD. RBDMS BFl OCT ~~.~.~, 'iOn'; Packers & SSSV (type & measured depth) Baker 'SCR-1' packer @ 7208' no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) none 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 122 721 189 657 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Oil-Bbl 1186 701 Casinç¡ Pressure Tubinç¡ Pressure 324 369 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Contact WDSPL 0 Jim Ennis @ 265-1544 r~~~ , Form 10-404 Revised 04/2004 Printed Name Signature Wells Group Engineer t 0 Date ¡ Ò ~ 'j OS'" Precared bv S ron All uc-Drake 263-4612 Title Phone ORIG\NAL Submit Original Only TUBING (0-6172, OD:4.500, ID:3.958) PUMP (6144-6145, OD:3.958) SEAL (6155-6169, OD:5.130) MOTOR (6169-6185, OD:5,620) GAUGE (6185-6187, OD:6,250) PUP (7287-7446, OD:4.500) Perf (7446-11395) ConocoPhillip$ AlasJa. Inc. 1C..104 I - ~ ,I - ) KRU £-104 API: 500292307600 SSSV Type: NONE Well Type: PROD Orig 7/29/2002 Completion: Last W/O: 9/10/2005 Angle @ TS: deg @ Angle @ TD: 91 deg @ 11560 Annular Fluid: Rev Reason: Workover/set Pump Last Update: 1017/2005 Reference Log: 36.1' RKB Ref Log Date: Last Tag: TD: 11560 ftKB Last Tag Date: Max Hole Angle: 95 deg @ 7655 Casing String - ALL COMMON STRINGS Description Size Top SUR/PROD 7.625 0 CONDUCTOR 16.000 0 CSG WINDOW 6.625 7043 Wt Grade Thread 29.70 L-80 BTCM 62.50 H-40 WELDED 0.00 to 1C-104L 1 Casing Strinç¡ - B-SAND LINER (Alternating 31' blank pipe & 37' Excluder 2000 screen 4"x4.5") Description Size Top Bottom TVD Wt Grade Thread B-SAND LINER 4.500 7206 11548 3689 12.60 L-80 NSCT SCREEN 4.800 7446 11395 3692 12.60 L-80 NSCT ! Tubing String - TUBING Size I Top 4.500 0 Perforations-Surnmary Interval TVD 7446 - 11395 3745 - 3692 TVD 3741 158 3681 Bottom 7395 158 7044 Bottom 6172 I Wt I Grade I 12.60 L-80 Thread NSCT TVD 3414 Zone WSB Status Ft SPF Date Type Comment 3949 50 7/28/2002 Screens Perfs thru 37' screens every 31' Gas Lift Mandrels/Valves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 3864 2391 CAMCO KBG-2 DMY 1.0 BK 0.000 0 9/10/2005 2 6021 3354 CAMCO KBG-2 SOV 1.0 BK 0.000 0 10/1/2005 Other ~plugs. equip. I etc.) .. COMMON JEWELRY Depth TVD Type Description ID 36 36 HANGER ABB VETCO GRAY TUBING HANGER 4.500 6072 3375 PRES SUB PHOENIX DISCHARGE PRESSURE SUB 0.000 6144 3403 PUMP SET 4.5" TTC ESP ( 44.85' OAL ) @ 6144' RKB. SET 4 1/2 D&D 0.000 PACKOFF W/ KOBE KNOCK OUT AND STINGER ASSEMBLY ( 102 1/4" OAL) @ 6099' RKB. SET 41/2 SLIP STOP @ 6093' RKB - 10/212005 6145 3403 COLLAR TCC Crossover w/5.13" OD collar 5.000 XO 6155 3407 SEAL CENTRILlFT TANDEM SEAL SECTION 0.000 6169 3413 MOTOR CENTRILlFT 190 HP MOTOR 0.000 6185 3419 GAUGE PHOENIX MS-2 GAUGE 0.000 6187 3420 Centralizer CENTRILlFT MOTOR CENTRALIZER 0.000 Other :plugs, equip., etc;) - B-SAND LINER JEWELRY Depth TVD Type Description ID 7208 3718 PACKER BAKER 'SCR-1' PACKER W/MILLOUT EXTENSION 4.000 7216 3720 VALVE BAKER KOIV MODEL C 4.000 7256 3726 SLEEVE BAKER CMD SLIDING SLEEVE 3.430 7287 3729 PUP TUBING ABOVE SCREENS 3.958 11548 3689 SHOE BAKER MODEL 'GPV' SET SHOE 3.500 GèneralNötes Date I Note 7/29/2002 MULTI-LATERAL WELL: B-SAND (1C-104), D-SAND (1C-104L 1) ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 04 1 C-1 04 WORKOVER/RECOMP Nabors 38 Start: 9/3/2005 Rig Release: 9/10/2005 Rig Number: Spud Date: 6/24/2002 End: 9/10/2005 Group: .:$u~::·: :SOQ~ 9/2/2005 16:00 - 00:00 8.00 MOVE DMOB DEMOB Rig down and prepare to move rig from 1 B-15 to 1 C-1 04 9/3/2005 00:00 - 06:00 6.00 MOVE DMOB DEMOB Rig down and prepare to move rig from 1 B-15 to 1 C-1 04 06:00 - 09:00 3.00 MOVE MOB MOVE Rig on location and spotted. Herculite layed out and mats dwn. Back in pits and pipe shed. 09:00 - 12:00 3.00 MOVE RURD RIGUP Prepare to raise derrick. Install pump lines. Welders to begin on pits. Mechanics begin on transmission prep. 12:00 - 13:00 1.00 MOVE RURD RIGUP Rig accept @ 1300 9-3-2005 13:00 - 00:00 11.00 RIGMNT RGRP RIGUP Begin repairs on pits and transmission replacement. «Code 8)) 9/4/2005 00:00 - 13:30 13.50 RIGMNT RGRP RIGUP Continue repairs on pits and transmission replacement. Crane on location @ 7:00 AM «Code 8)) 13:30 - 18:00 4.50 RIGMNT RGRP RIGUP Lou Grimaldi waived the witness of the BOP test at 13:45. Still working on rig. Begin pumping KWF of 3% KCL water at 2.5 BPM dwn tubing at 650 PSI. 180 DEG. Taking returns up the IA. Returns 1-1. After 275 BBLS away begin losing returns. By 310 BBLS away lost all returns. Set BPV 0 PSI WHP. 18:00 - 20:00 2.00 WELCTL NUND DECOMP Rig repairs completed as far as they can go, waiting on parts. Nipple down well-head 20:00 - 00:00 4.00 WELCTL NUND DECOMP Nipple up BOP's 9/5/2005 00:00 - 05:00 5.00 WELCTL NUND DECOMP Nipple up BOP's 05:00 - 11 :00 6.00 WELCTL BOPE DECOMP Testing BOP's PASSED 11 :00 - 13:30 2.50 WELLSR NUND DECOMP Prepare to pull BPV. Rig up Centrilift spooling unit and sheaves. Install empty spool. 13:30 - 14:00 0.50 WELLSR NUND DECOMP Pull BPV. Initial gas bubbles venting through poppet valve. After pulling BPV Liquid level in BOPE dropped out of sight. 14:00 - 16:32 2.53 WELLSR NUND DECOMP Install landing joint. Continue rigging up Centrilift. 16:32 - 17:10 0.63 FISH PULL DECOMP Pull hanger out of bowl. 125K up wt to pull out. Wt dropped to 72K free hanging wt. 130 BBL in pit 1 - 127 BBL in pit 2. initial tally. 17:10 -18:00 0.83 WELCTL OBSV DECOMP Monitor well for fluid after injecting 10 BBLS into IA. Shot fluid level 1 0 min intervials for 40 min. Fluid level consistant at 150' below LDS. 18:00 - 21 :00 3.00 FISH RURD DECOMP Continue rigging up Centrilift equipment. 21 :00 - 00:00 3.00 FISH PULL DECOMP Pull production tubing with up weight of 72K standing back, spool ESP and heat trace cables. One 9.78' pup and one 1.18' pup have bad threads and will be taken out of the string. 9/6/2005 00:00 - 06:00 6.00 FISH PULL DECOMP Continue pulling production tubing standing back, spool ESP and heat trace cables 06:00 - 07:30 1.50 FISH PULL DECOMP Tower meeting continue out of hole, filling hole with metal displacement every 5 stands and pumping an extra 5 bbls each hour. Heat trace out of well in one piece. 07:30 - 07:45 0.25 WELCTL OBSV DECOMP Shoot two fluid levels. Fluid level = 178' Continue to POOH. 07:45 - 12:00 4.25 FISH PULL DECOMP All the tubing out of the hole. Cable" 1- leg grounded, Motor lead insulation in good shape, Failure in the power cable. Begin breaking down pump. Found spline/coupling damaged and worn, bearing shattered. 12:00 - 13:00 1.00 FISH OTHR DECOMP Pump out of hole; lay down equipment. Clean up rig floor. Order out I I DECOMP necessary crossovers for re-running tubing and test packer/RBP. Note: All clamps/channel accounted for, missing (2) stainless bands. 13:00 - 16:00 3.00 WAlTON! EQIP Wait for crossovers. Set wear ring. RD ESP cable 16:00 - 18:00 i 2.00 WELLSR OTHR i WRKOVR Make room in pits for fluid; pump 20 bbls SW/KCL into well. Let settle I I I I and call out DHD to shoot a fluid level. Level at 252'. I , I I 6.00 l WELLSR TRIP !WRKOVR Begin running RBP/test packer on original 4-1/2" completion string. 18:00 - 00:00 I 9/7/2005 ! 00:00 - 11 :45 ! 11.75 WELLS~ TRIP i WRKOVR : Continue running in hole with RBP and test packer on NSCT I completion string. Layed down 10 jts of NSCT 4-1/2" tubing with I corrosion pits or gualded threads. Will replace with 4-1/2" IBT. Printed: 1011812005 2:50:34 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 04 1 C-1 04 WORKOVER/RECOMP Nabors 3S Start: 9/3/2005 Rig Release: 9/10/2005 Rig Number: Spud Date: 6/24/2002 End: 9/10/2005 Group: 0.75 WELLSR PLGM WRKOVR At +-7000' (13' in on jt 140). Attempt to rotate pipe with power tongs; unable to get pipe to turn static with 4000# of torque. Attempt to turn while raising/lower pipe...able to rotate slightly, pipe "torquing up" to 4000#, back out of it with power tongs- get back nearly all torque. Call Workover Engineer to discuss options. 1.00 WELLSR TRIP WRKOVR Pull out of hole to 6200'; re-attempt to set RBP. Same results. Unable to set plug, torqued up again while trying to rotate. 1.50 WELLSR PLGM WRKOVR Pull out of to 4980' orig RKB (20' of stand #32 showing). RIW=32k, PUW=50k, Block Wgt=1 Ok. Rotate w/ power tongs 4 turns. Back off torque. Stack wgt, 10k. Pick up to 75k- RKB appears set. Work pipe and release fom RKB. Pull 1 jt. 2.00 WELLSR DEQT WRKOVR Rig up to PIT casing. Top off hole with fluid, approx 15 bbls to fill. Shut pipe rams and pressure up on casing to 2500 psi. Chart and watch for 1/2 hr. Good PIT; casing pressure bleed off 50 psi to 2450 in 30 mins. Bleed off pressure. Circulate crude back to tiger tank until clean SW/KCL is seen across shaker. Shut down. Run back in hole with jt of IBT to retrieve RBP. Ran back in hole with remainder of IBT tubing. Pull out of hole laying down 32 jts of IBT tubing and strapping out of hole with remainder of IBT and NSCT. Continue pulling out of hole with RBP & test packer re-strapping pipe. ND test packer and RBP. Clear rig floor. Pull wear ring. Pick up 4.5", 12.6#, L-80 ESP completion equipment. Rig up sheave for power cable. Break out crossovers from orig completion needed in new. Shot fluid level= 240'. Run motor assembly in hole; top off with oil, bleed air. make up seal assembly. Perform voltage test, verify gauge function- good. Continue running completion. Perform prejob safety meeting. Cont. to run 4.5" ESP completion. Shoot fluid level= 150'. Rig up Heat Trace spool and sheave in derrick. Continue RIH with ESP, heat trace and power cable on 4.5" tubing installing Cannon cable clamps, performing electrical inspections/tests on ESP cable and heat trace every 1000'. Cont. RIH with new ESP completion. Shoot fluid level= 75'. Make up hanger w/ full jt to string; isolation sleeve is in place in hanger. Align hanger, make up landing jt. Prep to make up heat trace/power cable splice. Conduct pre-job safety meeting. Shoot fluid level= 204'. Begin making final splice of ESP cable and heat trace to to penetrators. Perform test cable / motor / heat trace integrity. Landed the tubing with extreme caution and hanger landed smooth. Up wt.= 49K Dwn wt = 27K. RILDS. Layed down landing jt Tested hanger and top hydraulic wiper packing and it leaked. BOLDS. Pull tubing hanger back to rig floor. Redressed hydraulic wiper I packing on hanger. Lowered hanger back and landed. RILDS. Pulled side port seal sleave. Installed 2-way check. I Nipple down BOPE. Check the ESP cable / motor integrity. I Unable to get packoff test; bleeding from 2500 psi to 1200 psi in approx 10 mins. Pressure up tree to to 5000 psi and test tree-good. Pressure I up void to 5000 psi, watch for bleed off. Held tight, seals below void I holding. Bleed off tbg (tree) pressure to 4000 psi. Void bleeding off I slightly to 4900 psi in 10 mins. Verify hanger neck seal "flexing" I 9/7/2005 11 :45 - 12:30 12:30 - 13:30 13:30 - 15:00 15:00 - 17:00 17:00 - 18:00 1.00 WELLSR CIRC WRKOVR 18:00 - 22:00 4.00 WELLSR PLGM WRKOVR 22:00 - 00:00 2.00 WELLSR TRIP WRKOVR 9/8/2005 00:00 - 04:45 4.75 WELLSR TRIP WRKOVR 04:45 - 06:00 1.25 WELLSR TRIP WRKOVR 06:00 - 10:00 4.00 CMPL TN RUNT CMPL TN 10:00 - 18:00 8.00 CMPL TN RUNT CMPL TN 18:00 - 00:00 6.00 CMPL TN RUNT CMPL TN 9/9/2005 00:00 - 01 :30 1.50 CMPL TN RUNT CMPL TN 01 :30 - 06:00 4.50 CMPL TN RUNT CMPL TN 06:00 - 14:30 8.50 CMPL TN RUNT CMPL TN 14:30 -15:30 1.00 CMPL TN RUNT CMPL TN 15:30 - 19:30 4.00 CMPL TN DEQT CMPL TN 19:30 - 20:30 1.00 CMPL TN SOHO CMPL TN I 20:30 - 00:00 3.50 CMPL TN SOHO CMPL TN 9/10/2005 100:00 - 00:30 0.50 CMPL TN SEQT CMPL TN 00:30 - 01 :00 0.50 WELLSR PLGM CMPL TN 101 :00 - 06:00 I 5.00 WELCTU NUND CMPL TN ! 06:00 - 10:00 4.00 CMPL TN! SEQT CMPL TN ¡ I Printed: 1011812005 2:50:34 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 04 1 C-1 04 WORKOVER/RECOMP Start: 9/3/2005 Rig Release: 9/10/2005 Rig Number: Spud Date: 6/24/2002 End: 9/10/2005 Group: Nabors 3S bate From - To Hours Code Sub Phase Code Description of Operations 9/1 0/2005 06:00 - 10:00 10:00 - 13:00 13:00 - 14:30 14:30 - 19:00 19:00 - 21 :30 21 :30 - 00:00 4.00 CMPL TN SEaT CMPL TN allowing leakoff from void to tbg. Confer w/ WO Engineer & Vetco-Gray Rep in town. 3.00 CMPL TN SEaT CMPL TN Remove checks and bleed void to 0 psi, pressure up tree again to 5000 psi. Slow leak at tree, 2-way check leaking. Redress 2- way check, re-install Replace 1500 series flange on wing valve to 5000 series. 1.50 CMPL TN SEaT CMPL TN Test hanger neck seals at flowing pressure (250 psi), pump up tbg to 250 psi; 0 psi on void. Monitor for 10 mins.- void still reading 0 psi. Bring tree pressure up to 5000' psi, hold for 10 mins flatline- good (0 psi on void). 4.50 CMPL TN RURD CMPL TN Remove 2-way check, install BPV. Install otis cap, dress out tree. Release rig at 16:00, 9/10/05. Continue to rig down and prep to move. 2.50 MOVE RURD MOVE Scope derrick down and laid down on carrier. Hook up trucks. Pulled rig forward enough to get 11" Stacka out from behind well. Left location at 21 :30 hrs 2.50 MOVE MOVE MOVE Arrived on 1 D pad @ 22:45 hrs. Unload 11" stack, haul gravel in behind well to level up. Worked 11" stack in behind well before spotting rig. Printed: 1 0/18/2005 2:50:34 PM Re: lC-104 PTD (202-061) ESP failure 07-11)5 Tom, -; dO'd-Oeo \ dO d ~ aeo 'd- As reported on July 11 2005 the ESP failed on 1 C-1 04. Per your request, ConocoPhìllíps is notífying the AOGCC that a Ríg workover is planned for later this month to pull and run a new pump and motor. Please let me know if you have any questíons. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: NSK Problem Well Supv Sent: Monday, July 11, 2005 3:05 PM To: 'Thomas Maunder' Cc: NSK Problem Well Supv Subject: FW: lC-l04 PTD (202-061) ESP failure 07-11-05 Tom, The ESP on Westsak well 1 C-1 04 (prD 202-061/062) failed last night. It appears that the problem is the motor and will require a rig workover to repair. Please let me know if you have any questions. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 SCANNELl J.\UG 0 2 7..005 -----Original Message----- From: Nezaticky, Peter On Behalf Of NSK West Sak Prod Engr Sent: Monday, July 11, 2005 7:23 AM To: ' CPFl Prod Supv; Rodgers, James T; Jenkins, Lubbie Allen; Ennis, J J; Gober, Howard; Dinkins, Walter R Subject: FW: lC-l04 1 C-1 04 went down last night and this time it looks like the motor is done. The pump ran for about 34 hrs and the trends looked good. We lost the down hole pressure and temperature gauges 14 hours 20f3 8/2/2005 8:06 AM Re: lC-104 PTD (202-061) ESP failure 07-1 ')5 ), after starting the pump due to burnt fuses caused by current leakage to ground. We new that the current leakage to ground would eventually cause us problems, but hoped it would run longer then it did. I will try to get the pump ASAP to confirm that there were no pump or pump eye problems. This well is a 600 bopd producer, what are we looking at in terms of a workover? Can we use the equipment from one of the other workover candidates and move this one up regarding timing or should I plan on trying to get this well on gas lift if the workover will be several months down the road? Thanks, Peter Nezaticky I Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 -----Original Message----- From: NSK Centrilift Fld Srv Sent: Monday, July 11, 2005 12:16 AM To: NSK West Sak Prod Engr; dan.benson@centrilift.com; walter.dinkins@centrilift.com; steve.tetzlaff@centrilift.com; Fisher, Matt A; robert.dowdy@bakerhuqhes.com Subject: lC-l04 All, An unfortunate event took place tonight after all of our hard work & problems. 1 C-1 04 burnt down hole @ 22:56. All 3 legs to Grnd. Are unbalanced 6.9, 6.5, & 6.2 Ohms. Regards, Dwayne Weythman FS Tech. Spec. AK E-Mail: n..136s@conocophillips.C01TI Phone: (907)659-7257 Cell: (907)448-1484 30f3 8/2/2005 8:06 AM ~"' ~ iJ.- ~~V\ cÁ. '''"'V) DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2020610 Well Name/No. KUPARUK RIV U WSAK 1C-104 Operator CONOCOPHILLlPS ALASKA INC JI "1 rL ,t 'I J vt~. )"\1'1 Á- API No. 50-029-23076-00-00 MD 11560 TVD 3688 Completion Date 7/29/2002 Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~ - ----~-_.~--~ Directional Survey 1 8791 11560 Open 8/9/2002 ~D Directional Survey 1 0 9331 Open 8/9/2002 PB1 ~ Directional Survey 1 0 9331 Open 8/9/2002 PB1 MWD r ~ Directional Survey 1 0 9331 Open 8/9/2002 PB1 ~ LIS Verification 1 2384 9277 Open 9/13/2002 PB1 LftÐ C (/1'1608 See Notes 2375 9331 Case 3/5/2003 digital well logging data PB1 ~ Directional Survey 8791 11560 Open 8/9/2002 MWD ~~D Directional Survey 8791 11560 Open 8/9/2002 ßÐ/ D Directional Survey 8791 11560 Open 8/9/2002 MWD ~D {,)'r035 ws-VerIffëãflõñ" 2384 11506 Open 9/13/2002 c.æ-D Directional Survey 0 9331 Open 8/9/2002 PB1 MWD -~ ~~ LIS Verification 2384 11506 Open 9/13/2002 !% C v14 607 See Notes 2375 11561 Case 3/5/2003 digital well logging data ~D ~6 LIS Verification 2384 9277 Open 9/13/2002 PB1 ------------- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Current Status 1-01L UIC N -~~--~----~------ --_.'-~----_.-'-'- Directional Survey Yes --~--~-----~.-'--~---- ------------.--- (data taken from Logs Portion of Master Well Data Maint) DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2020610 Well Name/No. KUPARUK RIV U WSAK 1C-104 Operator CONOCOPHILLlPS ALASKA INC MD 11560 TVD 3688 Completion Date 7/29/2002 Completion Status 1-01L Current Status 1-01L ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? .v I N ~/ Daily History Received? é)N ð:)N Formation Tops Analysis Received? ~ Comments: Compliance Reviewed By: l~ Date: API No. 50-029-23076-00-00 UIC N ----~---~~-_..-,--_.- --~~~---_._~-~~--- /-, --_.~-_._--~--- ~g' t¡J-J-l'HJi WELL LOG TRANSMITfAL L I dc:i)--Olo~ tlloOt.&> IC"¡ 0'-/ oOé}-'O({)) Hl.pO-¡ I C í oLf P6 I a Qd-.c::k¡ I 10°'6 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 03, 2003 RE: MWD Fonnation Evaluation Logs: 1 C-l 04, PB 1 & Ll AK-MW-22102 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, AK 9951 g lC...104: Digital Log Images: 50-029-23076-00 1 CD Rom lC...104 PDt: Digital Log Images: 50-029-23076-70 1 CD Rom lC-104 Ll: Digital Log Images: 50-029-23076-60 1 CD Rom RECEIVED MAR 05 2003 AlaSfœ Oil & Gas Cons "\ . And1~ Comrniwion \ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Oil 0 Gas 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended 0 Abandoned 0 Service 0 (ASP: 561631, 5968797) 1437' FNL, 625' FWL, Sec. 12, T11 N, R10E, UM At Top Producing Interval 684' FNL, 929' FWL, Sec. 11, T11 N, R10E, UM At Total Depth 411' FSL, 1085' FWL, Sec. 11, T11 N, R10E, UM (ASP: 556842, 5965327) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. OF @ 101.8' AMSL AOL 25649 ALK 467 12. Date Spudded 13. Date T.D. Reached " 14. Date Comp., Susp. Or Aband. June 24, 2002 July 7,2002 July 29,2002 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 11560' MO 1 3688' TVO 11550' MO 1 3688' TVO YES 0 No 0 22. Type Electric or Other Logs Run GR/Res 23. (ASP: 556650, 5969510) Classification of Service Well 7. Permit Number 202-061 1 8. API Number 50-029-23076-00 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1C-104/1C-104PB1 11. Field and Pool Kuparuk River Field West Sak Oil Pool ,; 15. Water Depth, if offshore 16. No. of Completions NI A feet MSL 1 20. Depth where SSSV set 21. Thickness of Permafrost NI A feet MD 2419' CASING SIZE CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 158' Surface 7395' 7208' 11550' 16" 24" CEMENTING RECORD 285 sx AS I 900 sx ASLite, 290 sx Class G HOLE SIZE WT. PER FT. 62.5# 29.7# 9.5# GRADE H-40 L-80 L-80 7.625" 9.875" 6" 4" x4.5" screen 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 4.5" No perfs - Pre-pack screens in horizontal laterals AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 6172' PACKER SET (MD) 7208' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11396' - 9809', 9736' - 8286', 240 bbls HCI acid 8210' - 7179' 26. 27. Date First Production September 19, 2002 Date of Test Hours Tested 9/25/2002 4 hours Flow Tubing Casing Pressure Press. 411 psi not available 28. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing - shares production with 1 C-1 04L 1 Production for OIL-BBL GAS-MCF Test Period> 134 29 Calculated OIL-BBL GAS-MCF 24-Hour Rate> 805 174 CORE DATA W A TER-BBL 0 W A TER-BBL 4 Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A ocr I 4 RBOMS 8Ft Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE CHOKE SIZE 100 bean OIL GRAVITY - API (corr) not available GAS-Oil RATIO 216 RE€EIVED OCT 0 1 .2002 Alaska Oi~& Gas Ooos. Commission Anchorage c,\~ Submit in duplicate 29. ( 30. GEOLOGIC MARKERS 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 Sand West Sak B 7045' 7361' 3681' 3737' Annulus left open - freeze protected with diesel. RIElel'VED OCT 0 1. 2002 Alaska Oil & Gas Gons. Commission Anchorage 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Steve McKeever 265-6826 . '0-~~\ .. >----...,~ . Signed Title Randy Thomas Kuparuk Drilling Team Leader ~o/( (Ot. Date 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 (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ( ~~ T¡rfi ~ Page 1 of 22 PHilLIPS ALASKA INC. Operations Summary Report Legal Well Name: 1 C-1 04 Common Well Name: 1 C-1 04 Event Name: ROT - DRILLING Contractor Name: n1268@ppco.com Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 6/20/2002 12:00 - 14:00 2.00 MOVE DMOB MOVE 14:00 - 15:30 1.50 MOVE DMOB MOVE 15:30 - 16:30 1.00 MOVE DMOB MOVE 16:30 - 18:30 2.00 MOVE DMOB MOVE 18:30 - 00:00 5.50 MOVE MOVE MOVE 6/21/2002 00:00 - 01 :30 1.50 MOVE MOVE MOVE 01 :30 - 03:30 2.00 MOVE RGRP MOVE 03:30 - 04:00 0.50 MOVE DMOB MOVE 04:00 - 22:30 18.50 MOVE MOVE MOVE 22:30 - 00:00 1.50 MOVE RGRP MOVE 6/22/2002 00:00 - 04:30 4.50 MOVE MOVE MOVE 04:30 - 05:30 1.00 MOVE MOVE MOVE 05:30 - 06:30 1.00 MOVE RGRP MOVE 06:30 - 07:00 0.50 MOVE MOVE MOVE 07:00 - 07:30 0.50 MOVE RGRP MOVE 07:30 - 08:30 1.00 MOVE MOVE MOVE 08:30 - 09:30 1.00 MOVE RGRP MOVE 09:30 - 19:30 10.00 MOVE MOVE MOVE 19:30 - 21 :00 1.50 MOVE MOVE MOVE 21 :00 - 00:00 3.00 MOVE MOVE MOVE 6/23/2002 00:00 - 02:00 2.00 MOVE POSN MOVE 02:00 - 04:00 2.00 MOVE POSN MOVE 04:00 - 06:00 2.00 MOVE OTHR MOVE 06:00 - 07:30 07:30 - 08:30 08:30 - 09:30 09:30 - 10:30 10:30 - 11 :00 1.50 MOVE 1.00 MOVE 1.00 MOVE 1.00 MOVE 0.50 MOVE POSN MOVE RURD MOVE RURD MOVE RURD MOVE POSN MOVE 11 :00 - 13:00 2.00 WELCTL NUND RIGUP 13:00 - 14:00 1.00 DRILL SFTY RIGUP 14:00 - 22:30 8.50 WELCTL NUND SURFAC 22:30 - 00:00 1.50 DRILL PULD SURFAC 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations Prepair rig floor to skid Skid rig floor to center of drilling complex Pull high line power lines Raise cellar box, Stomper & secure same, In stall crib blocks Move rig off well, Change out MWD units fro m Baker to Sperry- Sun Line up Sub module to move down the road Repair hydraulic leak in #4 Lampson jack Jack & install tall crib blocks Move rig & Utility complexes to KOC Repair chain on #2 Lampson Service Both modules, Lay matting boards a round KOC tent & down 1 C road Move Both module around KOC tent & Utility module down 1C road Repair chain on Drilling module #2 Lampson Right side Move Drilling module down 1C road Install secondary chain keeper pins & Chang e out lub. pump Move Drilling module down 1C road & Lay m atting boards down 1 C road Repair chain on Drilling module #2 Lampson Right side Move both modules down 1 C road to 1C Pad Repair chain on Drilling module #2 Lampson Right side Move Ball Mill from 1 D Pad to 1 C Pad Lay matts, Spot Utility module on matts Lay spin pads for Drilling module & counter Lampsons for moving rig into position Nipple down & remove 21-1/4" Diverter from cellar box prior to moving rig into position. (21-1/4" Diverter will not be used for this w ell, and must be removed to allow diverter Ii ne to exit out back of cellar box.) Spot Drilling module over 1 C-1 04 Drop Stomper, Lower cellar box Skid rig floor 40' to center Drop plumb bob & set drilling module down Spoy Utility module into position ( Accept ri g @ 1100 hrs. 6/23/02) Nipple up BOPE/Diverter & Hook up service lines on rig Held Pre-Spud meeting with all crews & serv ice personal Nipple up 13-5/8" BOPE as Diverter system with 16" diverter line, Work diverter line out the back & under flow lines, Nipple up Kill & Choke lines, Flow & fill up lines, Turn buc kels & riser Pick up 4" DP & stand back in derrick Printed: 8/16/2002 4:18:11 PM ( ~. T¡T¡t ~ Page.2of 22 PHILLIPS ALASKA INC. Operations S.ummaryReport Legal Well Name: 1 C-1 04 Common Well Name: 1 C-1 04 Event Name: ROT - DRILLING Contractor Name: n1268@ppco.com Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 6/24/2002 00:00 - 01 :00 1.00 DRILL PULD SURFAC 01 :00 - 02:00 1.00 WELCTL BOPE SURFAC 02:00 - 06:30 4.50 DRILL PULD SURFAC 06:30 - 10:00 3.50 DRILL PULD SURFAC 10:00 - 11 :00 1.00 DRILL PULD SURFAC 11 :00 - 12:00 1.00 DRILL REAM SURFAC 12:00 - 13:30 1.50 DRILL DRLG SURFAC 13:30 - 15:00 1.50 DRILL PULD SURFAC 15:00 - 16:00 1.00 DRILL PULD SURFAC 16:00 - 00:00 8.00 DRILL DRLG SURFAC 6/25/2002 00:00 - 01 :30 1.50 DRILL TRIP SURFAC 01 :30 - 02:00 0.50 DRILL TRIP SURFAC 02:00 - 04:30 2.50 DRILL DRLG SURFAC 04:30 - 05:30 1.00 DRILL TRIP SURFAC 05:30 - 06:00 0.50 DRILL TRIP SURFAC 06:00 - 07:00 1.00 DRILL REAM SURFAC 07:00 - 07:30 0.50 DRILL CIRC SURFAC 07:30 - 08:30 1.00 DRILL TRIP SURFAC 08:30 - 09:30 1.00 DRILL OTHR SURFAC 09:30 - 10:00 0.50 DRILL TRIP SURFAC 10:00 - 13:00 3.00 DRILL REAM SURFAC 13:00 - 14:30 1.50 DRILL CIRC SURFAC 14:30 - 15:30 1.00 DRILL DRLG SURFAC 15:30 - 16:00 0.50 DRILL CIRC SURFAC 16:00 - 16:30 0.50 DRILL DRLG SURFAC 16:30 - 20:00 3.50 DRILL CIRC SURFAC 20:00 - 20:30 0.50 DRILL DRLG SURFAC 20:30 - 21 :30 1.00 DRILL CIRC SURFAC 21 :30 - 22:00 0.50 DRILL DRLG SURFAC 22:00 - 22:30 0.50 DRILL CIRC SURFAC 22:30 - 23:00 0.50 DRILL DRLG SURFAC 23:00 - 00:00 1.00 DRILL REAM SURFAC 6/26/2002 00:00 - 06:00 6.00 DRILL DRLG SURFAC 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations Pick up 4" Drill pipe Function test Diverter - AOGCC John Crisp waived test Pick up 4" Drill pipe, Total of 210 joints (R abbit all pipe to 2.375") Load pipe shed wI HWDP & DC's, Strap sam e, Pick up & stand back 23 jts. HWDP, DC's Pick up Bit, Motor, Pony collar, Stab, Float sub Wash ice plug f/ 44' to 158', Spud well @ 12 00 hrs. 6/24/02 Drill f/ 158' to 199' ART: 1.0 hrs POOH, Set motor at 1.5 deg. Up load MWD, Orient motor & UBHO sub, RI H to 199' Drill & GYRO f/ 199' to 692' ART= 1.7 hrs AST= 2.7 hrs Circ total of 160 bbls. POOH to change moto r setting to 2 deg. Trip in hole to 692'. Directional drill 9 7/8" hole f/ 692' to 843' ( 151 '). TVD 833' AST = 1.04 hrs ART = 0.11 hrs Ream out f/ 843' to 719'. Survey @ 811' & 7 80'. Too much build. POOH to change motor t01.5deg. RIH to 780'. Ream hole f/ 780' to 843'. Survey @ 811'. Circulate & WOO. POOH. Displacement 7.6 bbls over calculate d. Sperry sun plug into MWD, Download while WOO. RIH to 692'. Reaming to drop high angle in hole f/ 692' t 0 843'. Circulate and WOO. Directional drill 9 7/8" hole fl 843' to 998'. (155') AST = .5 hrs. Circulate and WOO. Directional drill 9 7/8" hole f/ 998' to 1032'. (34') AST = .5 hrs Circulate and WOO. Directional drill 9 7/8" hole f/ 1032' to 1093 '. (61') AST = .5 hrs Circulate and WOO. Directional drill 9 7/8" hole f/ 1093' to 1148 '. (55') AST : .5 hrs. Circulate and WOO. Directional drill 97/8" hole f/ 1148' to 1188 '. (40') AST = .6 hrs ART:.1 hrs Ream and circulate f/ 1093' to 1188'. Directional drill 97/8" hole fl 1188' to 1613 Printed: 8/16/2002 4:18:11 PM ~~ r¡r¡¡ ~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/26/2002 ( PHilliPS ALASKA INC. Operations Summary Report 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 Sub From - To Hours Code Code Phase 00:00 - 06:00 06:00 - 12:00 6.00 DRILL DRLG SURFAC 6.00 DRILL DRLG SURFAC 12:00 - 13:00 1.00 DRILL DRLG SURFAC 13:00 - 14:30 1.50 DRILL REAM SURFAC 14:30 - 17:30 3.00 DRILL DRLG SURFAC 17:30 - 18:30 1.00 DRILL CIRC SURFAC 18:30 - 22:00 3.50 DRILL TRIP SURFAC 22:00 - 23:00 1.00 DRILL OTHR SURFAC 23:00 - 00:00 1.00 DRILL OTHR SURFAC 6/27/2002 00:00 - 02:00 2.00 DRILL OTHR SURFAC 02:00 - 03:00 1.00 RIGMNT RSRV SURFAC 03:00 - 03:30 0.50 DRILL TRIP SURFAC 03:30 - 04:30 1.00 DRILL TRIP SURFAC 04:30 - 05:30 05:30 - 12:00 12:00 - 18:00 1.00 DRILL CIRC SURFAC 6.50 DRILL DRLG SURFAC 6.00 DRILL DRLG SURFAC Page 3 of 22 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Opérations '(425'). TVD = 1421' AST = 2.65 hrs. ART = 0.43 hrs. Gas hydrates encountere d @ 1209' MD. TVD = 1157' MW cut to 7.3 P P g. Directional drill 9 7/8" hole fl 1613' to 2014 '(401'). TVD = 1613' AST = 5.4 hrs. ART = 0.09 hrs. More gas hydrates encoun tered @ 1761' MD. TVD = 1491'. Directional drill 9 7/8" hole fI 2014' to 2086 '(72'). TVD = 1631' ART = 0.3 hrs A ST = 0.01 hrs. Ream fl 1946' to 2086' (140') Directional drill 9 7/8" hole fI 2086' to 2419 '(333'). TVD = 1761' ART = 2.0 hrs Circulate hole clean prior to POOH fI BHA & bit. Monitor well. POOH. Tight spot @ 1378'. Wo rk through, OK. Take MWD check shots @ 11 92' and 787'. No change fI original surveys. Monitor well @ BHA. Download MWD. Change bit. Reset motor to 1.22 deg. Chang e B H A. LID & PU stabilizer, sperry gamma ray. Orie nt tools. Plug in & program tools. Service top drive. Trip in hole wi BHA # 4, bit # 2. Test Sperry tools @ 267'. OK. Continue in hole. Tight @ 1339'. Work throu gh tight hole @ 1339'. Fill pipe. Orient motor to high side. Pump @ 20 spm. Slide throug h. Hole little tight and able to just work thr ough (no pump) to 1451'. Continue to trip to 2419'. Pipe displacement 3.9 bbls less t han calc wi RIH. Circ bottoms up while precautionary ream 80 , to bottom. Time Weight out Vis Out Fann PV YP strokes 0445 9.5 300+ 1 95/140/115/84/31/27 55 85 59 8 0500 9.8 300+ 208/1511 128/93135130 57 94 2548 051 5 9.4+ 300+ 181/133/111/81 131/27 48 85 4200 gels 30/44/54 API Filt. 6.2 Cake 2 NAP/water 1/92 Sand 1.75 MBT 20 PH 8.2 PflMF 01. 3 Chlor 500 Hardness 30 Directional drill 9 7/8" hole fI 2419' to 3465 , (1046'). TVD = 2223'. AST = 0.68 hrs ART = 3.02 hrs. Directional drill 9 7/8" hole fI 3465' to 4221 '(756'). TVD = 2553.6'. AST = 0.58 hr Printed: 8/16/2002 4: 18: 11 PM ( ~S'I TjTfi ~ Page 4 of 22 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 Date Sub FrOm-To Hours Code Code Phase 6/27/2002 6.00 DRILL DRLG SURFAC 6.00 DRILL DRLG SURFAC 12:00 - 18:00 18:00 - 00:00 6/28/2002 5.00 DRILL DRLG SURFAC 00:00 - 05:00 05:00 - 07:00 2.00 DRILL CIRC SURFAC 07:00 - 12:00 5.00 DRILL DRLG SURFAC 12:00 - 15:00 3.00 DRILL DRLG SURFAC 15:00 - 17:30 2.50 DRILL CIRC SURFAC 17:30 - 19:30 2.00 DRILL DRLG SURFAC 19:30 - 20:00 0.50 DRILL OTHR SURFAC 20:00 - 00:00 4.00 DRILL DRLG SURFAC 6/29/2002 00:00 - 08:00 8.00 DRILL DRLG SURFAC 08:00 - 12:00 4.00 DRILL CIRC SURFAC 12:00 - 14:00 2.00 DRILL DRLG SURFAC 14:00 - 15:00 1.00 DRILL CIRC SURFAC 15:00 - 00:00 9.00 DRILL DRLG SURFAC 6/30/2002 00:00 - 01 :30 1.50 DRILL DRLG SURFAC 01 :30 - 06:30 5.00 DRILL CIRC SURFAC 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description ÖfOperations s ART = 2.58 hrs Directional drill 9 7/8" hole f/ 4221' to 4885 (664'). TVD = 2841'. AST = 0.64 hrs. ART = 2.77 hrs. Directional drill 9 7/8" hole f/ 4885' to 5548 '(663'). TVD = 3148' AST = 0.97 hrs. ART = 2.25 hrs. Ratty w/ drilling clay @ 4925' to 4980'. Ream tight hole. Circ 762 bbls fluid. Set back a stand each 3 0-35 min. Directional drill 9 7/8" hole f/ 5548' to 6021 '(473'). TVD = 3350' AST = 2.15 hrs. ART = 6.07 hrs. Directional drill 9 7/8" hole f/ 6021' to 6200 '(179'). TVD = 3424.64' Pump sweep, circ hole clean. Directional drill 9 7/8" hole f/ 6200 to 6265' (65'). TVD = 3450.05' AST = 1.57 hrs. Rig went off HI-LINE. Back on generators. Note: Hi line cable between pole and subs tation has evidence of causing failure. Directional drill 9 7/8" hole f/ 6265' to 6500 '(235'). TVD = 3537.43' AST = 2.07 hrs Directional drill 9 7/8" hole f/ 6500' to 6968 '(468') TVD = 3662.86' ART = 0.0 hrs. AST = 5.53 hrs Circ to clean hole. Pump 42 bbl Hi-Vis (300 +) sweep @ 11.6 ppg. Rotating @ 120 RPM, pumping @ 573 GPM (13.6 bpm) (135 spm), with 3700 psi. Circ total of 2000 bbls. Did not notice sweep. Set back a stan d every 30 min. ending up @ 6305'. Total of 7 stands out. RIH to 6968'. No fill on bo ttom. Directional drill 9 7/8" hole f/ 6968' to 7051 '(83') TVD = 3682.97 Top of West Sak D sands @ 7045' MD 3682.5' TVD Flow ch eck well. OK. Circulate BU, Observe well. OK. Directional drill 97/8" hole f/ 7051' to 7315 '(264') TVD = 3732.32' AST = 7.05 hrs ART = 0.5 hrs. Directional drill 9 7/8" hole f/ 7315' to 7400 '(85') TVD =3742' AST = 1.41 hrs. FI ow check well. OK. Note: Top of West sak D sand @ 7045' MD = 3682' TVD T op of West sak B sand @ 7368' MD = 3739' TVD TD 9 7/8" hole @ 7400' MD = 3742' TVD Circulate hole clean while rotating @ 120 R PM w/ 573 gpm & 3700 psi. Set back a st and every 15 min. Reamed out to 5831' (16+ Printed: 8/16/2002 4: 18: 11 PM ~~ ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( Page 5 of 22 PHILLIPS ALASKA INC. Operations Summary Report 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ ppco.com Nabors 245 Date Sub From - To Hours Code Code Phase 6/30/2002 01 :30 - 06:30 06:30 - 07:00 07:00 - 09:30 5.00 DRILL CIRC SURFAC 0.50 DRILL TRIP SURFAC 2.50 DRILL CIRC SURFAC 09:30 - 11 :00 1.50 DRILL TRIP SURFAC 11 :00 - 12:00 1.00 DRILL REAM SURFAC 12:00 - 13:00 1.00 DRILL REAM SURFAC 13:00 - 13:30 0.50 DRILL TRIP SURFAC 13:30 - 14:30 1.00 DRILL TRIP SURFAC 14:30 - 00:00 9.50 DRILL REAM SURFAC 7/1/2002 00:00 - 00:30 0.50 DRILL REAM SURFAC 00:30 - 01 :30 1.00 DRILL TRIP SURFAC 01 :30 - 05:00 05:00 - 06:30 06:30 - 08:30 3.50 DRILL TRIP SURFAC 1.50 DRILL OTHR SURFAC 2.00 CASE RURD SURFAC 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations 56.53 Total volume pumped 2730 bbls (4 Survey check shots @ Pump Tang Bit depths of: Survey depth Inc. deg. Az Az 6261.62' 6200.05' 3448' 66.92 256.99 6211.35' 6149.78' 3429' 66.92 258.84 6161.53' 6099.96' 3409' 66.91 259.32 6111.51' 6049.94' 3390' 66.57 259.84 6055.00' 6000.27' 3370' 66.52 259.67 stands). 1/2 BU). ent area. of: TVD Cor r. 2 259.70 259.99 260.10 260.33 RIH to TO @ 7400'. No fill. Check flow. No f low. Pump 50 bbls Hi Vis sweep 11.6 ppg & 300+ vis, circulate hole clean while rotating @ 12 0 RPM wI 573 gpm & 3700 psi. Set back a st and every 15 min. Ream out to 6783'. Pump total of 1283 bbls (2+ BU). Monitor well. No Flow. Pump dry job. POOH to 4506'. Gathering up cuttings bed. MU top drive. Circ @ 577 gpm & rotate @ 12 0 rpm. Set back a stand every 15 min. Ende d up @ 4311'. Continue to ream out f/ 4311' to 4132' wI 57 7 gpm & 120 rpm. RIH fl 4132' to 4606'. No problems. Down wt 100 k. POOH f/ 4606' to 3745'. Pulling 5-25k over. Ream out of hole f/ 3745' to 1100'. Pumpin g @ 577 gpm, rotating wI 120 rpm. Take survey check shot @ 1189'. No change. Continue to ream out f/ 1100' to 913'. T otal volume pumped while backreaming f/374 5' to 913' was-- 6324 bbls. Trip in hole. Fill pipe @ 2334' and 3753'. Ci rc air out of pipe. monitor well. No problems on trip in. Recording torque and drag data wI R I H. POOH. Pulled good back to 913'. Worked thr ough tight spots fl 913' to 634'. PU weig ht on first pass was 150 k. Second pass 103 k. Continue to pull f/ 634' to DC's and hol e was good. LID drill collars, MWD, LWD, stab's, motor a nd bit. Threads on bit and motor bit box wer e galled. Pull Vetco Grey wear bushing. Make up hang er on landing joint. Dummy run hanger. Mark on landing joint, landed position. Pull hang Printed: 8/16/2002 4:18: 11 PM ( (~~ r¡r¡t ~~ Page.6 of 22 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 Date From - To Hours Code Sub Phase Code 7/1/2002 06:30 - 08:30 2.00 CASE RURD SURFAC 08:30 - 09:00 0.50 CASE SFTY SURFAC 09:00 - 12:00 3.00 CASE RUNC SURFAC 12:00 - 13:30 1.50 CASE RUNC SURFAC 13:30 - 14:30 1.00 CASE CIRC SURFAC 14:30 - 16:30 2.00 CASE RUNC SURFAC 16:30 - 17:30 1.00 CASE CIRC SURFAC 17:30 - 00:00 6.50 CASE RUNC SURFAC 7/2/2002 00:00 - 00:30 0.50 CASE OTHR SURFAC 00:30 - 01 :00 0.50 CASE CIRC SURFAC 01 :00 - 02:30 1.50 CASE RUNC SURFAC 02:30 - 03:30 1.00 CEMENTCIRC SURFAC 03:30 - 04:00 0.50 CEMENT OTHR SURFAC 04:00 - 10:30 6.50 CEMENTCIRC SURFAC 10:30 - 12:00 1.50 CEMENT PUMP SURFAC 12:00 - 13:30 1.50 CEMENT PUMP SURFAC 13:30 - 14:30 1.00 CEMENT DISP SURFAC 14:30 - 15:30 1.00 CEMENTOTHR SURFAC 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations RU GBR to run 7 er and put in "V" door. 5/8" casing. Pre job safety meeting on running 7 5/8" ca sin g. Run 7 5/8",29.7 #, L-80, BTC-Mod casing to 1 485' . Continue to run 7 5/8",29.7#, L-80, BTC-Mo d casing f/ 1485' to 2590 (60 jts in hole)'. PU wt 140k SO wt 106k Circ and condition mud and hole. Stage rate up to 4.5 bpm @ 390 psi Run casing f/ 2590' to 4707'. (110 jts total i n hole). Taking weight. SO wt 82 k Circ and recip casing. Stage up to 5.5 bpm @ 515psi. PU wt 180 K SO wt 110 K Run casing f/ 4707' to 4835' (total of 113 jo ints in hole). Washed f/ 4835' to 5136' Ra n f/ 5136' to 5310' Washed f/ 5310' to 6060 Continue to run f/ 6060' to 6397' (total of 149 joints in hole) SO wt 112 k PU wt 225-235 k PU Tam port collar on top of joint # 149, PU jt#150. PUwt=270K SOwt=107 k Circ @ 5.5 bpm wI 600 psi. Total volume cir culated 300 bbls. Vis out 200-231 PU wt =240k SOwt=110k Run 7 5/8", L-80, 29.7 #/ft, BTC-Mod casing f/ 6440' to 7395' (landed on hanger). Circ and condo mud prior to cement job, cir c @ 5.5 bpm wI 650 psi. Circ 290 bbls. P Uwt=240k SOwt=110k LID frank's fill up tool. PU/MU Dowell cemen t head wI first bottom plug in place. Circulate and condition mud prior to cement job. Circulate total of 2725 bbls. Circ @ 5. 5 bpm wI 500 psi. Held pre job safety meeti ng fl cement job. PU wt = 245 k SO wt =118k Test lines to 3500 psi. Pump total of 50 bbl s CW 100, Drop bottom plug, reload head, p ump 50 bbls of 10.2 ppg mudpush, pumping 289 bbls lead AS lite cement @ 10.7 ppg. A total of 686 bbls lead cement planned to be pumped. Continue to pump lead AS lite cement @ 10. 7 ppg, drop bottom plug, follow wI 64 bbls t ail cement class G @ 15.8 ppg, drop top plu g, dowel! pump 10 bbls water. Displace cement wI rig pump @ 6 bpm, 600+ psi. Bum p p lug w I 3 2 2 7 s t r 0 ke s . C I P @ 1415 hrs. Hold f/ 15 min. Check floats. Floats held. LID cement equip Printed: 8/16/2002 4: 18: 11 PM ( ~~ r¡r¡I ~ (' Page 7 of 22 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 Date From- To Hours Code Sub Phase Code 7/2/2002 14:30 - 15:30 1.00 CEMENTOTHR SURFAC 15:30 - 17:30 2.00 CEMENT OTHR SURFAC 17:30 - 19:00 1.50 WELCTL OTHR SURFAC 19:00 - 20:00 1.00 WELCTL NUND SURFAC 20:00 - 21 :00 1.00 WELCTL BOPE SURFAC 21 :00 - 00:00 3.00 WELCTL BOPE SURFAC 7/3/2002 5.50 WELCTL BOPE SURFAC 00:00 - 05:30 05:30 - 06:30 1.00 WELCTL BOPE SURFAC 06:30 - 07:00 0.50 DRILL OTHR SURFAC 07:00 - 07:30 0.50 DRILL OTHR SURFAC 07:30 - 09:30 2.00 DRILL OTHR SURFAC 09:30 - 11 :00 1.50 DRILL OTHR SURFAC 11 :00 - 11 :30 0.50 DRILL OTHR SURFAC 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations ment & landing joint. Remove 16" diverter Ii n e. RU to flush stack wI wash tool. Flush BOP s tack. LID wash tool. Set Vetco Gray packoff. Test packoff to 500 0 psi. fI 10 min. N/D 16" knife valve on diverter line. NU 16" 5000 psi blind flange on wellhead. RU to test BOPE. Test BOPE. Test witnessed by AOGCC inspe ctor Jeff Jones, Test annular to 250 psi low & 3500 psi. high. Test upper pipe rams, kill line HCR, choke manifold valves 1,2,3 t 0 250 psi low & 5000 psi high. (retightened flange on 16" blind flange on wellhead. Test manual kill line valve & choke manifold valves 4,6,7,9.250 psi low & 5000 psi high . (change out 2" OTECO valve). Function test Flowline sensor, Pit volume & trip tank alarms. Test choke manifold valves 5,10, 11,12,15.250 psi low & 5000 psi high. F unction test super choke & manual chokes 0 n choke manifold. Continue to test 13 5/8" BOPE. Test upper pipe rams (3 1/2" x 6" variables) with manu al kill line valve & choke manifold valves 5, 6,7,8,9,10,11,13. Test upper pipe rams (3 1 I 2" x 6 " va ria b I es ) with m an u a I c h 0 k e val v e . Test upper pipe rams (3 1/2" x 6" variable s) with outside choke valve (HCR). Test low er pipe rams (3 1/2" x 6" variables). Test B lind rams with choke manifold valvesa 13 & 14. Test upper IBOP Test Lower IBOP Tes t floor safety valve Test IBOP All these te st @ 250 psi low, and 5000 psi high. Held fI . 5 min each. Function test accumulator. This entire test witnessed by AOGCC inspe ctor Jeff Jones. Rig down BOP test tools. Set wear bushing with (2) lockdown screws. Blow down choke manifold. Install corrosion ring in saver sub--- 4 1/2" IF fI top drive. Move HWDP to driller's side of derrick. LID jars, PU a replace. joint of HWDP (30.71). PU/MU BHA. MU PDC bit, mud motor, change setting to 1.5 deg, float sub, MWD, LWD, P WD, hang off collar. Orient tools and progra m. PU 4.75" DC. Install corrosion ring in top D C. MU x-o, jars, then PU 4" 14#/ft, HT-38, S 135 DP fI pipe shed. Pump test Sperry Sun tools @ 67 spm wI 95 Printed: 8/16/2002 4:1 8: 11 PM ( ~~ r¡t¡I ~ Page 8 of 22 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 Date Sub From - To Hours Code Code Phase 7/3/2002 0.50 DRILL OTHR SURFAC 6.00 DRILL TRIP SURFAC 11 :00 - 11 :30 11 :30 - 17:30 17:30 - 20:00 2.50 DRILL TRIP SURFAC 20:00 - 20:30 0.50 DRILL CIRC SURFAC 20:30 - 21 :00 0.50 CEMENT COUT SURFAC 21 :00 - 23:00 2.00 DRILL CIRC SURFAC 23:00 - 23:30 0.50 DRILL OTHR SURFAC 23:30 - 00:00 0.50 DRILL OTHR SURFAC 7/4/2002 00:00 - 01 :00 1.00 DRILL OTHR SURFAC 01 :00 - 05:00 4.00 CEMENT DSHO SURFAC 05:00 - 05:30 0.50 DRILL CIRC SURFAC 05:30 - 06:00 0.50 DRILL OTHR SURFAC 06:00 - 07:30 1.50 DRILL CIRC SURFAC 07:30 - 08:00 0.50 DRILL OTHR SURFAC 08:00 - 08:30 0.50 DRILL CIRC SURFAC 08:30 - 09:00 0.50 DRILL FIT SURFAC 09:00 - 12:00 3.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD 7/5/2002 00:00 - 06:00 6.00 DRILL DRLG PROD 06:00 - 12:00 6.00 DRILL DRLG PROD 12:00 - 16:00 4.00 DRILL DRLG PROD 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations 0 ps i. Continue to PU/MU 4", 14#/ft, HT-38, S 135 DP from pipe shed. Run in f/ 247' to 4,980'. Install Cutting Blade Impellar's (CBI's) eve ry 500' f/ total of 8 in hole. RIH wI 4" drill pipe f/ derrick. Tag cement 1 9' in on stand #75 in hole (7271') Circ and condition mud @ 6 bpm. Circ total of 1800 strokes (181 bbls). Drill cement f/ 7271' to 7305' (34'). Tag Flo at collar wiper plugs @ 7305'. Circulate & condition mud @ 6 bpm wI 1450 psi for total of 8301 strokes (838 bbls) RU to test 7 5/8",29.7 #/ft, L-80, BTC-Mod casing. Test 7 5/8",29.7 #/ft, L-80, BTC-Mod casing to 3000 psi fl 30 min. Volume to press ure up to 3000 psi. was 3.7 bbls.(37 strokes ) Continue to test 7 5/8",29.7 #/ft, L-80, BTC -mod casing to 3000 psi for total of 30min. Lost 26 psi. Good test. Drill FC @ 7305', cement, FS @ 7393-7395', rat hole & 20' new hole to 7420'. 7420' MD = 3742'TVD ART = .8 hrs Circ hole clean. Total volume pumped 439 b bls. Shut down pumps, monitor well. Clean pit an d mix sweeps to do fluid change out. Pump 53 bbls low 35vis sweep @ 9.0 ppg, th en 80 bbls hi 80vis sweep @ 9.4 ppg, circul ate out with 442 bbls. Shut down pump. Monitor well. Clean under shakers. Condition mud and circulate for FIT. FIT wI 9.0 ppg fluid @ 3742' TVD and 710 p si. EMW 12.65 PWD test prior to drilling further. Directional drill 6 3/4" hole f/ 7420' to 7568 '(148') TVD = 3741' AST = .78 hrs A RT = .27 hrs Directional drill 6 3/4" hole f/ 7568' to 8327 '(759') TVD = 3724' AST = 3.5 hrs A RT = 3.25 hrs Directional drill 6 3/4" hole f/ 8327' to 8668 I (341 ') TVD = 3711' AST = 2.00 hrs ART = 1.42 hrs Survey every 30' Directional drill 6 3/4" hole f/ 8668' to 8951 '(283') TVD = 3712' AST = 2.00 hrs ART = 2.83 hrs Survey every 30' Directional drill 6 3/4" hole f/ 8951' to 9330 '(379') TVD = 3706' AST = .82 hrs A RT = 1.8 hrs Printed: 8/16/2002 4: 18: 11 PM ( ~~ ~ ~ ( Page 9 of 22 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 1 C-1 04 Common Well Name: 1 C-1 04 Event Name: ROT - DRILLING Contractor Name: n1268@ppco.com Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 7/5/2002 16:00 - 17:00 1.00 DRILL CIRC PROD 17:00 - 17:30 0.50 DRILL CIRC PROD 17:30 - 18:30 1.00 DRILL TRIP PROD 18:30 - 19:00 0.50 DRILL CIRC PROD 19:00 - 21 :00 2.00 DRILL OTHR PROD 21 :00 - 22:00 1.00 DRILL CIRC PROD 22:00 - 22:30 0.50 DRILL OBSV PROD 22:30 - 00:00 1.50 DRILL TRIP PROD 7/6/2002 00:00 - 04:00 4.00 DRILL TRIP PROD 04:00 - 04:30 0.50 DRILL TRIP PROD 04:30 - 05:00 0.50 DRILL TRIP PROD 05:00 - 06:00 1.00 DRILL OTHR PROD 06:00 - 07:00 1.00 DRILL OTHR PROD 07:00 - 08:00 1.00 DRILL TRIP PROD 08:00 - 12:00 4.00 DRILL TRIP PROD 12:00 - 13:30 1.50 RIGMNT RSRV PROD 13:30 - 15:00 1.50 RIGMNT RSRV PROD 15:00 - 16:00 1.00 DRILL TRIP PROD 16:00 - 17:30 1.50 DRILL TRIP PROD 17:30 - 18:00 0.50 DRILL REAM PROD 18:00 - 21 :30 3.50 DRILL DRLG PROD 21 :30 - 00:00 2.50 DRILL DRLG PROD 7/7/2002 00:00 - 06:00 6.00 DRILL DRLG PROD 06:00 - 12:00 6.00 DRILL DRLG PROD 12:00 - 16:00 4.00 DRILL DRLG PROD 6/20/2002 Spud Date: 6/24/2002 End: G ro u p: Start: Rig Release: Rig Number: 245 Description of Operations Circ and condition mud and hole. Circ and condition mud and hole. Decision m ade to Pull up and sidetrack hole. Backream out of hole f/ 9330' to 8830' (500' ). Ream back to stand 91 in hole (8830'). LI D a single DP. Circulate & orient BHA to 180 deg. toolface to trough well and sidetrack 8799' to 8830' Start cutting trough to undercut hole. Sidetr ack hole @ 8840'. Rotate to 8865'. Circ and condition mud and hole (2 BU's). P U single of DP. Set back a stand. Monitor well. Pump Dry job. POOH wet. Record torque and drag @ 5 stan d stations. Continue to POOH f/ new motor wi ABI. Moni tor well @ BHA, record torque and drag data every 10 stands wi POOH. Set back drill collars. Download Sperry Sun MWD/LWD info. Break off bit, change motor, adjust motor f/ 1.22 deg. bend. Change out pulsar in hang-off sub. Up load MWD. RIH wi BHA # 6 on 4" drill pipe. RIH 10 stan ds, rotate through TAM port collar @ 995'. Continue to RIH wI BHA # 6, record torque a nd drag data every 10 stands to shoe @ 737 5' Service rig and top drive. Slip and cut drilling line. Cut 141'. Continue to RIH wi BHA # 6 f/ 7375' to 8762 '. Record torque and drag data every 10 sta nds, fill pipe every 10 stands. Circulate and condition mud prior to drilling new hole. Swap out mud in hole. Ream and clean out hole f/ 8762' to 8860' (9 8'). TVD = 3712' Directional drill 6 3/4" hole f/ 8860' to 9330 '(470') TVD = 3707' AST = 0.40 hrs. ART = 1.93 hrs. Directional drill 6 3/4" hole f/ 9330' to 9461 '(131') TVD = 3707' AST = 0.30 hrs. ART = 1.19 hrs. Directional drill 6 3/4" lower lateral fI 9461' to 10161' (700') TVD = 3701' AST = 2. 37 hrs. ART = 1.55 hrs. Directional drill 6 3/4" lower lateral fI 1016 l' to 10845' (684') TVD = 3698' AST = 0.5 hrs. ART = 3.0 hrs. Directional drill 6 3/4" lower lateral fI 1084 5' to 11560' TD of hole (715') TVD = 3 688' AST = 0.22 hrs. ART = 1.89 hrs. Printed: 8/16/2002 4: 18: 11 PM .~~ ~ ~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/7/2002 7/8/2002 7/9/2002 Page 10 of 22 PHilliPS ALASKA INC. Operations Summary Report 2.00 DRILL CIRC PROD 1.00 DRILL TRIP PROD 1.00 DRILL REAM PROD 1.50 DRILL CIRC PROD 0.50 DRILL TRIP PROD 2.00 DRILL TRIP PROD 0.50 DRILL TRIP PROD 3.50 DRILL CIRC PROD 6.50 DRILL REAM PROD 0.50 DRILL REAM PROD 1.00 RIGMNT RSRV PROD 1.50 DRILL TRIP PROD 0.50 DRILL SURV PROD 0.50 DRILL REAM PROD 1.00 DRILL CIRC PROD 0.50 DRILL TRIP PROD 2.50 DRILL TRIP PROD 4.00 DRILL CIRC PROD 1.50 DRILL CIRC PROD 1.50 DRILL CIRC PROD 6/20/2002 Spud Date: 6/24/2002 End: Group: 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 Start: Rig Release: Rig Number: 245 Description of Operations Sub From - To Hours Code Code Phase 16:00 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 21 :30 21 :30 - 22:00 22:00 - 00:00 00:00 - 00:30 00:30 - 04:00 04:00 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 - 13:30 13:30 - 14:00 14:00 - 14:30 14:30 - 15:30 15:30-16:00 16:00 - 18:30 18:30 - 22:30 22:30 - 00:00 00:00 - 01 :30 Pump up survey. Circ and condition mud and hole @ 8.8 bpm=370 gpm & 2600 psi. for s hort trip. Pump total of 8500 strokes. Set ba ck a stand every 30 min. Monitor well. POOH wet. record PU wt every stand. Hole swabbing f/ 11134' to 10787'. MU top drive. Wash and ream in hole f/ 10,818' to 11,134'. Circ and condition hole wi 87 spm & 100 rpm .Set back a stand every 30 minutes. POOH wet wlo pumps. POOH f/ 10845' to 10 561'. Hole still swabbing. RIH f/ 10561' to 11115'. Fill pipe, continue i n hole. Taking excess wt @ 11,234'. MU top drive, work through wi 30 spm 900 psi to 11 ,319'. Continue to RI H f/ 11,319'. Pump down fl 11 ,282' to 11,414' wi 30 spm and 800 psi. Pum p & rotate fl 11,414' to 11,560'. Circulate and clean hole while monitoring E CD's. Pump rate 75 SPM wi 2350 psi and 10 0 RPM wi picking up. Slow pumps to 80 goin g slacking off. Pump sweep around after fir st BU, Got back wall cake in returns. Monitor well, POOH, backreaming out wi 75 spm @ 2300 psi. Rotating wi 100 RPM's. SL M on way out to shoe. Back ream last stand slow into shoe @ 7395 , Circ a bottoms up in doing so. Monitor well and lubricate top drive and dra wworks. RIH. Replace joint off top of stand 96. Conti nue in hole. Tag up @ 9330' (Old hole which was side tracked @ 8860' to 9330'). Pump up survey. We are in wrong hole. Pump out of hole fl 9330' to 8767'. Orient a nd go into the right well. Circ and condition hole @ sidetrack. Continue to RIH to 8920'. verify in sidetrack ed hole. Cleanup hole POOH f/8920' to 8767', RIH to 8925' wi no p umps. Pump up survey. Continue RIH to 115 60' . Circulate and condition hole @ 87 spm (370 gpm) with 2900 spi. Pump total of 17319 str okes (1749 bbls). PJSM for fluid change out to brine. Flush pumps 1,2,3, kill line, fillu p line. Working on trip tank pump cleanup. Pump 26 bbls Flovis spacer, followed by 650 bbls 8.9 ppg brine @ 87spm & 2950 psi whi Ie rotating @ 100 rpm. Finish Displacing to 8.9 ppg Brine, Spot 290 Printed: 8/16/2002 4:18:11 PM D?Od- CXo ) 05-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-1 04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,791.38' MD Window / Kickoff Survey 8,823.35' MD (if applicable) Projected Survey: 11,560.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 0 9 2002 AlaskaOü & Gas Cons. Commission Anchorage KuparuklColville North Slope, Alaska Kuparuk 1C, Slot 1C-104 1C-104 Job No. AKZZ22102, Surveyed: 7 July, 2002 D~~ ~'~ ~~ . ¡ 1 " ,'~ /.-". SURVEY REPORT 31 July, 2002 Your Ref: API 500292207600 Surface Coordinates: 5968796.65 N, 561631.04 E (70019' 31.0425" N, 149030' 00.8575" W) Kelly Bushing: 101.85ft above Mean Sea Level 5pE!r''-'Y-SUf1 OFtILL'N'G SERVices A Halliburton Company Survey Ref: svy9937 Sperry-Sun Drilling Services " . Survey Report for 1 C-1 04 D~~ IA Your Ref: API 500292207600 Job No. AKZZ22102, Surveyed: 7 July, 2002 KuparuklColville N~~~S~~ Measured Sub-Sea Vertical Local Cøordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8791.38 90.980 173.790 3611.42 3713.27 667.31 S 4911.31 W 5968089.02 N 556725.38 E 667.31 Tie On Point ~~ 8823.35 90.680 174.300 3610.96 3712.81 699.11 S 4907.99 W 5968057.25 N 556728.95 E 1.851 699.11 Window Point 8858.47 89.380 174.720 3610.94 3712.79 734.07 S 4904.63 W 5968022.33 N 556732.60 E 3.890 734.07 8886.02 89.690 175.030 3611.16 3713.01 761.51 S 4902.17 W 5967994.91 N 556735.29 E 1.591 761.51 8949.35 89.080 173.600 3611.84 3713.69 824.52 S 4895.90 W 5967931.95 N 556742.08 E 2.455 824.52 8980.88 89.940 174.680 3612.11 3713.96 855.88 S 4892.68 W 5967900.61 N 556745.55 E 4.378 855.88 9076.36 92.280 175.020 3610.26 3712.11 950.95 S 4884.11 W 5967805.62 N 556754.90 E 2.476 950.95 9171.05 91.230 174.220 3607.36 3709.21 1045.18 S 4875.24 W 5967711.47 N 556764.55 E 1.394 1045.18 9265.36 89.880 172.880 3606.45 3708.30 1138.88 S 4864.64 W 5967617.85 N 556775.91 E 2.017 1138.88 9357.69 89.820 172.410 3606.69 3708.54 1230.45 S 4852.82 W 5967526.38 N 556788.49 E 0.513 1230.45 9454.05 90.680 173.130 3606.27 3708.12 1326.04 S 4840.70 W 5967430.89 N 556801.40 E 1.164 1326.04 9548.88 89.820 175.100 3605.86 3707.71 1420.37 S 4830.97 W 5967336.65 N 556811.89 E 2.267 1420.37 9643.01 92.770 176.750 3603.73 3705.58 1514.22 S 4824.29 W 5967242.86 N 556819.35 E 3.591 1514.22 9737.36 90.000 176.710 3601.45 3703.30 1608.38 S 4818.91 W 5967148.74 N 556825.50 E 2.936 1608.38 9830.95 89.450 176.700 3601.90 3703.75 1701.82 S 4813.53 W 5967055.36 N 556831.65 E 0.588 1701.82 9925.88 90.800 179.670 3601.69 3703.54 1796.69 S 4810.52 W 5966960.52 N 556835.44 E 3.437 1796.69 10022.36 91.050 179.280 3600.13 3701.98 1893.15S 4809.64 W 5966864.06 N 556837.11 E 0.480 1893.15 10116.69 89.820 178.470 3599.42 3701.27 1987.45 S 4807.79 W 5966769.78 N 556839.74 E 1.561 1987.45 10211.34 91.040 179.430 3598.71 3700.56 2082.08 S 4806.05 W 5966675.16 N 556842.25 E 1.640 2082.08 10306.51 89.020 177.870 3598.66 3700.51 2177.22 S 4803.81 W 5966580.05 N 556845.27 E 2.682 2177.22 10401.17 89.510 179.580 3599.87 3701.72 2271.84 S 4801.70 W 5966485.45 N 556848.16 E 1.879 2271.84 10495.78 87.970 179.680 3601.95 3703.80 2366.43 S 4801.09 W 5966390.87 N 556849.54 E 1.631 2366.43 10589.89 88.340 179.470 3604.98 3706.83 2460.48 S 4800.40 W 5966296.82 N 556851.01 E 0.452 2460.48 10685.04 91.230 182.460 3605.34 3707.19 2555.60 S 4802.00 W 5966201.70 N 556850.19 E 4.370 2555.60 10777.71 90.980 181.920 3603.55 3705.40 2648.18 S 4805.54 W 5966109.09 N 556847.41 E 0.642 2648.18 10874.89 90.680 181.440 3602.14 3703.99 2745.31 S 4808.39 W 5966011.94 N 556845.36 E 0.582 2745.31 10969.63 91.660 181.780 3600.21 3702.06 2839.99 S 4811.05 W 5965917.24 N 556843.48 E 1.095 2839.99 11063.89 91.420 181.110 3597.68 3699.53 2934.19 S 4813.42 W 5965823.03 N 556841.88 E 0.755 2934.19 11158.56 90.860 180.730 3595.79 3697.64 3028.83 S 4814.94 W 5965728.38 N 556841.13 E 0.715 3028.83 11 ~~53.60 91.170 180.440 3594.11 3695.96 3123.85 S 4815.91 W 5965633.35 N 556840.94 E 0.447 3123.85 --. "-------~_..-._._._-_._-----------_._- 31 July, 2002 - 14:52 Page 2 0'4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1 C-1 04 Your Ref: API 500292207600 Job No. AKZZ22102, Surveyed: 7 July, 2002 KuparuklColville Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11348.55 92.150 180.560 3591.36 3693.21 3218.75 S 4816.74 W 5965538.45 N 556840.90 E 11443.29 91.660 180.190 3588.21 3690.06 3313.44 S 4817.36 W 5965443.76 N 556841.05 E 11488.03 90.620 179.970 3587.32 3689.17 3358.17 S 4817.42 W 5965399.03 N 556841.36 E 11560.00 90.620 179.970 3586.54 3688.39 3430.13 S 4817.39 W 5965327.07 N 556841.99 E 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 1431' FNL, 625' FWL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1431' FNL, 625' FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11560.00ft., The Bottom Hole Displacement is 5913.80ft., in the Direction of 234.548° (True). Comments :~~ Measured Depth (ft) Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8791.38 8823.35 11560.00 667.31 S 699.11 S 3430.13 S Tie On Point Window Point Projected Survey 3713.27 3712.81 3688.39 4911.31 W 4907.99 W 4817.39 W . .'~-' ----.. '" -..----.---------"..-------.-..--- ".------ 31 July, 2002 - 14:52 Page 3 of4 . D~¡4.~~; .:¡¡ ~J¡' '-. N:rihl'~J. . It.ska KJf)~ 1C Dogleg Vertical Rate Section Comment (0/100ft) 1.040 3218.75 0.648 3313.44 2.376 3358.17 0.000 3430.13 Projected Survey ~, DrillQuest 2.00.08.005 -i' KuparuklColville Survey tool program for 1C-104 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 168.00 0.00 168.00 168.00 11560.00 168.00 Tolerable Gyro (1C-104PB1) 3688.39 AK-6 BP _IFR-AK (1C-104PB1) \....._" 31 July, 2002 - 14:52 Sperry-Sun Drilling Services Survey Report for 1C-104 Your Ref: API 500292207600 Job No. AKZZ22102, Surveyed: 7 July, 2002 Survey Tool Description -~-.._---_.__u_-------_._- ----.----... Page 40f4 . Ds ~J, 1t/h,"J»)Qe. Alaska . '~Uk1C -", ~.-",., Dril/Quest 2.00.08.005 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-1 04 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,791.38' MD Window / Kickoff Survey 8,823.35' MD (if applicable) Projected Survey: 11,560.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) OCB-ŒJ/ 05-Aug-02 RECE\"EO ~UG 0 9 ê~Q2 _n a~&GasCO\\s.CottØ A\a- Anr),Ø -- ~L 0 ~ CO -~ KuparuklColville North Slope, Alaska Kuparuk 1C, Slot 1C-104 1C-104 MWD Job No. AKMW22102, Surveyed: 7 July, 2002 SUR VE Y R E PO R T 8 August, 2002 Your Ref: API 500292207600 Surface Coordinates: 5968796.65 N, 561631.04 E (700 19' 31.0425" N, 149030' 00.8575" W) Kelly Bushing: 101.85ft above Mean Sea Level "- =par-''-'Y-SUI! C'RIL. L:I~N§ 5ie RVÎc::es A Halliburton Company Survey Ref: svy9940 Sperry-Sun Drilling Services Survey Report for 1C-104 MWD Your Ref: API 500292207600 Job No. AKMW22102, Surveyed: 7 July, 2002 North Slope, Alaska KuparuklColville Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/1 OOft) 8791.38 90.980 174.530 3611.47 3713.32 657.61 S 4919.74 W 5968098.66 N 556716.87 E 657.61 Tie On Point 8823.35 90.680 174.760 3611.01 3712.86 689.44 S 4916.75 W 5968066.85 N 556720.12 E 1.182 689.44 Window Point 8858.47 89.380 175.250 3610.99 3712.84 724.42 S 4913.69 W 5968031.89 N 556723.46 E 3.956 724.42 8886.02 89.690 175.580 3611.21 3713.06 751.88 S 4911.49W 5968004.45 N 556725.89 E 1.643 751.88 8949.35 89.080 174.340 3611.89 3713.74 814.96 S 4905.93 W 5967941.42 N 556731.97 E 2.182 814.96 ~ 8980.88 89.940 175.430 3612.16 3714.01 846.37 S 4903.12 W 5967910.04 N 556735.04 E 4.403 846.37 9076.36 92.280 175.810 3610.31 3712.16 941.54 S 4895.83 W 5967814.93 N 556743.11 E 2.483 941.54 9171.05 91.230 174.930 3607.41 3709.26 1035.88 S 4888.19 W 5967720.66 N 556751.52 E 1.447 1035.88 9265.36 89.880 173.180 3606.50 3708.35 1129.67 S 4878.42 W 5967626.95 N 556762.06 E 2.343 1129.67 9357.69 89.820 172.810 3606.74 3708.59 1221.31 S 4867.16 W 5967535.41 N 556774.07 E 0.406 1221.31 9454.05 90.680 172.890 3606.32 3708.17 1316.92 S 4855.17 W 5967439.90 N 556786.85 E 0.896 1316.92 9548.88 89.820 175.570 3605.91 3707.76 1411.26 S 4845.63 W 5967345.64 N 556797.16 E 2.968 1411.26 9643.01 92.770 177.410 3603.78 3705.63 1505.17 S 4839.87 W 5967251.78 N 556803.69 E 3.693 1505.17 9737.36 90.000 177.430 3601.50 3703.35 1599.39 S 4835.63 W 5967157.60 N 556808.71 E 2.936 1599.39 9830.95 89.450 177.570 3601.95 3703.80 1692.89 S 4831.55 W 5967064.13 N 556813.56 E 0.606 1692.89 9925.88 90.800 180.280 3601.74 3703.59 1787.79 S 4829.76 W 5966969.25 N 556816.12 E 3.189 1787.79 10022.36 91.050 179.840 3600.18 3702.03 1884.26 S 4829.87 W 5966872.79 N 556816.81 E 0.524 1884.26 10116.69 89.820 179.220 3599.47 3701.32 1978.58 S 4829.09 W 5966778.4 7 N 556818.36 E 1.460 1978.58 10211.34 91.040 179.900 3598.76 3700.61 2073.22 S 4828.36 W 5966683.84 N 556819.87 E 1.476 2073.22 10306.51 89.020 178.910 3598.71 3700.56 2168.38 S 4827.38 W 5966588.69 N 556821.64 E 2.364 2168.38 10401.17 89.510 180.400 3599.92 3701.77 2263.03 S 4826.81 W 5966494.05 N 556822.98 E 1.657 2263.03 ~- 10495.78 87.970 179.910 3602.00 3703.85 2357.61 S 4827.06 W 5966399.47 N 556823.50 E 1.708 2357.61 10589.89 88.340 179.320 3605.03 3706.88 2451.67 S 4826.43 W 5966305.42 N 556824.91 E 0.740 2451.67 10685.04 91.230 182.510 3605.39 3707.24 2546.79 S 4827.95 W 5966210.30 N 556824.17 E 4.524 2546.79 10777.71 90.980 182.190 3603.60 3705.45 2639.36 S 4831.75 W 5966117.69 N 556821.13 E 0.438 2639.36 10874.89 90.680 181.540 3602.19 3704.04 2736.48 S 4834.91 W 5966020.55 N 556818.77 E 0.737 2736.48 10969.63 91.660 182.340 3600.26 3702.11 2831.14 S 4838.12 W 5965925.87 N 556816.34 E 1.335 2831.14 11063.89 91.420 181.640 3597.73 3699.58 2925.31 S 4841.39 W 5965831.67 N 556813.84 E 0.785 2925.31 11158.56 90.860 181.350 3595.84 3697.69 3019.93 S 4843.86 W 5965737.04 N 556812.15 E 0.666 3019.93 11253.60 91.170 180.910 3594.16 . 3696.01 3114.94 S 4845.73 W 5965642.02 N 556811.05 E 0.566 3114.94 8 August, 2002 - 18:45 Page 20f4 DrilIQuest20~0~003 Sperry-Sun Drilling Services Survey Report for 1C-104 MWD Your Ref: API 500292207600 Job No. AKMW22102, Surveyed: 7 July, 2002 KuparuklColville Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 11348.55 92.150 180.870 3591.41 3693.26 11443.29 91.660 180.630 3588.26 3690.11 11488.03 90.620 180.220 3587.37 3689.22 11560.00 90.620 179.970 3586.59 3688.44 Local Coordinates Northings Eastings (ft) (ft) 3209.83 S 3304.51 S 3349.24 S 3421.21 S 4847.21 W 4848.45 W 4848.78 W 4848.90 W - Global Coordinates Northings Eastings (ft) (ft) 5965547.11 N 5965452.43 N 5965407.70 N 5965335.73 N 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 1437' FNL, 625' FWL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1437' FNL, 625' FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11560.00ft., The Bottom Hole Displacement is 5934.35ft., in the Direction of 234.795° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8791.38 8823.35 11560.00 3713.32 3712.86 3688.44 657.61 S 689.44 S 3421.21 S 4919.74 W 4916.75 W 4848.90 W Tie On Point Window Point Projected Survey 8 August, 2002 - 18:45 Page 30f4 556810.36 E 556809.90 E 556809.93 E 556810.40 E Dogleg Rate (0/100ft) Vertical Section North Slope, Alaska Kuparuk 1 C Comment 1.033 3209.83 0.576 3304.51 2.499 3349.24 0.347 3421.21 Projected Survey DrnIQuest20~0~003 Kuparuk/Colvilfe Survey tool program for 1C-104 MWD From Measured Vertical Depth Depth (ft) (ft) "'%~ 0.00 168.00 0.00 168.00 168.00 11560.00 168.00 Tolerable Gyro (1C-104PB1 MWD) 3688.44 MWD Magnetic (1C-104PB1 MWD) '- 8 August, 2002 - 18:45 To Measured Vertical Depth Depth (ft) (ft) Sperry-Sun Drilling Services Survey Report for 1C-104 MWD Your Ref: API 500292207600 Job No. AKMW22102, Surveyed: 7 July, 2002 North Slope, Alaska Kuparuk 1 C Survey Tool Description Page 4 of4 DrillQuest 2.00.09.003 aOd-OttJj 05-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-1 04PB 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD , M D (if applicable) 9,331.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED A'I~ 0 9 1"1'002 v.J ; . D . Alaska Oil & Gas Cons. Commission Anchorage .~ Kuparuk/Colville North Slope, Alaska Kuparuk 1C, Slot 1C-104 1 C-104PB 1 Job No. AKZZ221 02, Surveyed: 7 June, 2002 SURVEY REPORT 31 July, 2002 DS~ ~/~' I7v~ ~ Your Ref: API 500292207670 Surface Coordinates: 5968796.65 N, 561631.04 E (700 19' 31.0425" N, 149030' 00.8575" W) Kelly Bushing: 101.85ft above Mean Sea Level ,\c~~p !5pE!'-''''Y-~ . ~111 pAILL~ING SEAVlces A Halliburton Company ~~ Survey Ref: svy9936 Sperry-Sun Drilling Services . Survey Report for 1C-104PB1 D~~ Your Ref: API 500292207670 Job No. AKZZ22102, Surveyed: 7 June, 2002 ~/llk'~ rt ~e. Alaska Kuparuk/Colville uparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) _. 0.00 0.000 0.000 -101.85 0.00 O.OON O.OOE 5968796.65 N 561631.04 E 0.00 Tolerable Gyro ~~ 168.00 0.150 140.000 66.15 168.00 0.17 S 0.14 E 5968796.48 N 561631.18 E 0.089 0.17 AK-6 BP_JFR-AK 292.00 0.390 295.810 190.15 292.00 0.11 S 0.13W 5968796.54 N 561630.91 E 0.428 0.11 384.00 1.850 358.180 282.13 383.98 1.51 N 0.46 W 5968798.16 N 561630.56 E 1.853 -1.51 476.00 3.950 4.510 374.01 475.86 6.16 N 0.26W 5968802.80 N 561630.73 E 2.306 -6.16 568.00 4.600 358.980 465.75 567.60 13.00 N 0.08W 5968809.65 N 561630.86 E 0.836 -13.00 613.00 5.870 353.140 510.56 612.41 17.09 N 0.38W 5968813.74 N 561630.51 E 3.057 -17.09 632.00 6.510 349.130 529.45 631.30 19.11 N 0.70W 5968815.76 N 561630.18 E 4.063 -19.11 660.00 8.070 344.700 557.23 659.08 22.57 N 1.52W 5968819.21 N 561629.33 E 5.918 -22.57 691.00 10.380 339.790 587.82 689.67 27.29 N 3.06W 5968823.91 N 561627.75 E 7.866 -27.29 722.00 13.500 333.600 618.15 720.00 33.15 N 5.64W 5968829.76 N 561625.13 E 10.865 -33.15 752.00 16.420 331.860 647.13 748.98 40.03 N 9.19W 5968836.60 N 561621.52 E 9.847 -40.03 783.00 19.050 329.970 676.65 778.50 48.28 N 13.79 W 5968844.81 N 561616.85 E 8.684 -48.28 843.00 19.100 329.610 733.36 835.21 65.22 N 23.66 W 5968861.67 N 561606.85 E 0.213 -65.22 939.64 19.830 325.410 824.48 926.33 92.35 N 40.96 W 5968888.67 N 561589.32 E 1.633 -92.35 1033.00 26.420 318.950 910.31 1012.16 121.09 N 63.62 W 5968917.21 N 561566.43 E 7.554 -121.09 1127.57 36.100 314.950 ~ 991.06 1092.91 156.73 N 97.24 W 5968952.57 N 561532.52 E 10.463 -156.73 ~~ 1222.27 39.570 313.480 1065.84 1167.69 197.21 N 138.88 W 5968992.71 N 561490.54 E 3.786 -197.21 ~~,~ 1316.10 42.290 311.170 1136.73 1238.58 238.56 N 184.34 W 5969033.69 N 561444.74 E 3.317 -238.56 1412.84 46.800 308.600 1205.66 1307.51 282.01 N 236.43 W 5969076.71 N 561392.30 E 5.020 -282.01 1508.27 54.780 305.660 1265.95 1367.80 326.52 N 295.39 W 5969120.73 N 561332.98 E 8.695 -326.52 1602.14 59.370 302.680 1316.97 1418.82 370.71 N 360.58 W 5969164.38 N 561267.42 E 5.568 -370.71 1697.39 61.630 298.380 1363.88 1465.73 412.77 N 431.98 W 5969205.86 N 561195.69 E 4.589 -412.77 1791.27 61.650 297.240 1408.48 1510.33 451.31 N 505.05 W 5969243.80 N 561122.30 E 1.069 -451.31 1886.24 62.990 295.150 1452.60 1554.45 488.43 N 580.51 W 5969280.29 N 561046.54 E 2.406 -488.43 1980.79 67.880 292.850 1491.90 1593.75 523.36 N 659.05 W 5969314.58 N 560967.72 E 5.625 -523.36 2075.05 71.450 289.100 1524.66 1626.51 554.95 N 741.56 W 5969345.49 N 560884.95 E 5.315 -554.95 2169.29 67.450 288.680 1557.73 1659.58 583.52 N 825.03 W 5969373.37 N 560801.25 E 4.265 -583.52 2262.19 66.590 289.070 1594.00 1695.85 611.19 N 905.96 W 5969400.38 N 560720.09 E 1.003 -611~19 2359.87 64.070 287.650 1634.77 1736.62 639.15 N 990.19 W 5969427.65 N 560635.63 E 2.898 -639.15 _..._~----._-- 31 July, 2002 - 14:50 Page 2 of7 DrillQllest 2.00.08.005 Sperry-Sun Drilling Services () . Survey Report for 1 C-1 04PB1 Your Ref: API 500292207670 ~~ Job No. AKZZ22102, Surveyed: 7 June, 2002 /¡~ 7~e, Alaska KuparuklColville paruk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) '.1;....,.". 2455.87 61.220 287.880 1678.88 1780.73 665.16 N 1071.38 W 5969452.99 N 560554.23 E 2.976 -665.16 ~~~ 2551.42 63.040 286.230 1723.54 1825.39 689.93 N 1152.13 W 5969477.09 N 560473.28 E 2.441 -689.93 2646.73 63.860 290.560 1766.16 1868.01 716.83 N 1233.00 W 5969503.33 N 560392.19 E 4.154 -716.83 2741 .17 65.170 287.080 1806.81 1908.66 744.31 N 1313.68 W 5969530.15 N 560311.29 E 3.604 -744.31 2834.94 64.080 287.620 1846.99 1948.84 769.58 N 1394.55 W 5969554.75 N 560230.22 E 1.274 -769.58 2930.61 63.520 287.390 1889.23 1991.08 795.40 N 1476.41 W 5969579.89 N 560148.14 E 0.624 -795.40 3027.20 64.560 287.430 1931.51 2033.36 821.38 N 1559.28 W 5969605.20 N 560065.07 E 1.077 -821.38 3124.35 64.550 287.550 1973.25 2075.10 847.75 N 1642.95 W 5969630.87 N 559981.19 E 0.112 -847.75 3216.98 63.870 287.570 2013.55 2115.40 872.91 N 1722.46 W 5969655.38 N 559901.46 E 0.734 -872.91 3309.24 64.060 287.650 2054.05 2155.90 897.99 N 1801.48 W 5969679.81 N 559822.25 E 0.220 -897.99 3403.29 64.330 288.070 2094.99 2196.84 923.96 N 1882.07 W 5969705.12 N 559741.45 E 0.494 -923.96 3494.73 64.960 287.730 2134.14 2235.99 949.35 N 1960.70 W 5969729.87 N 559662.61 E 0.767 -949.35 3590.07 65.210 287.650 2174.31 2276.16 975.63 N 2043.08 W 5969755.47 N 559580.02 E 0.273 -975.63 3682.14 65.340 288.540 2212.82 2314.67 1001.60 N 2122.57 W 5969780.79 N 559500.32 E 0.889 -1001.60 3779.93 65.490 288.720 2253.50 2355.35 1030.01 N 2206.84 W 5969808.50 N 559415.82 E 0.227 -1030.01 3875.30 64.010 289.480 2294.18 2396.03 1058.23 N 2288.34 W 5969836.05 N 559334.08 E 1.711 -1058.23 3967.48 63.510 290.670 2334.94 2436.79 1086.61 N 2366.00 W 5969863.79 N 559256.20 E 1.279 -1086.61 ~",~ 4060.54 62.830 289.650 2376.94 2478.79 1115.23 N 2443.95 W 5969891.77 N 559178.01 E 1.221 -1115.23 ~, 4160.89 62.770 291.110 2422.82 2524.67 1146.31 N 2527.61 W 5969922.16 N 559094.10 E 1.295 -1146.31 4255.16 61.720 291.520 2466.72 2568.57 1176.63 N 2605.33 W 5969951.85 N 559016.13 E 1.178 -1176.63 4349.4 7 63.540 291.210 2510.07 2611.92 1207.14 N 2683.32 W 5969981.71 N 558937.89 E 1.952 -1207.14 4443.66 65.040 290.600 2550.93 2652.78 1237.42 N 2762.60 W 5970011.34 N 558858.37 E 1.696 -1237.42 4534.08 64.260 290.540 2589.64 2691.49 1266.13 N 2839.10 W 5970039.42 N 558781.63 E 0.865 -1266.13 4634.12 64.410 290.350 2632.97 2734.82 1297.63 N 2923.59 W 5970070.22 N 558696.89 E 0.228 -1297.63 4729.05 64.630 290.300 2673.81 2775.66 1327.39 N 3003.96 W 5970099.33 N 558616.28 E 0.237 -1327.39 4823.73 64.850 289.800 2714.21 2816.06 1356.75 N 3084.39 W 5970128.02 N 558535.61 E 0.531 -1356.75 4915.72 63.300 289.700 2754.43 2856.28 1384.71 N 3162.26 W 5970155.34 N 558457.52 E 1.688 -1384.71 5012.56 62.480 289.910 2798.56 2900.41 1413.91 N 3243.36 W 5970183.87 N 558376.18 E 0.868 -1413.91 5107.03 62.710 289.940 2842.04 2943.89 1442.49 N 3322.20 W 5970211.81 N 558297.10 E 0.245 -1442.49 5203.31 62.130 287.580 2886.62 2988.47 1469.94 N 3403.00 W 5970238.59 N 558216.08 E 2.255 -1469.94 --_.._--~_.- 31 July, 2002. 14:50 Page 3 of7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 1C-104PB1 Your Ref: API 500292207670 Job No. AKZZ22102, Surveyed: 7 June, 2002 ð ~~ Zrth Slope, Alaska KuparuklColville '11'; Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical /Y'¡:; Depth Incl. Azim. Depth Depth Northlngs Eastlngs~ Northlngs Eastlngs Rate Section C (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) "",-. 5294.26 61.950 284.860 2929.27 3031.12 1492.38 N 3480.13 W 5970260.39 N 558138.77 E 2.649 -1492.38 ~.-,." 5391.75 61.720 284.930 2975.29 3077.14 1514.47 N 3563.18 W 5970281.80 N 558055.54 E 0.244 -1514.47 5480.77 63.180 284.250 3016.46 3118.31 1534.35 N 3639.56 W 5970301.05 N 557979.00 E 1.774 -1534.35 5576.96 63.790 281.130 3059.41 3161.26 1553.25 N 3723.52 W 5970319.26 N 557894.89 E 2.971 -1553.25 5676.37 64.080 277.260 3103.10 3204.95 1567.51 N 3811.65 W 5970332.80 N 557806.65 E 3.509 -1567.51 5766.61 62.620 274.030 3143.59 3245.44 1575.45 N 3891.89 W 5970340.09 N 557726.34 E 3.585 -1575.45 5862.02 63.930 268.780 3186.52 3288.37 1577.52 N 3977.04 W 5970341.45 N 557641.18 E 5.102 -1577.52 5954.25 65.860 263.120 3225.67 3327.52 1571.59 N 4060.30 W 5970334.84 N 557557.97 E 5.937 -1571.59 6051.28 66.850 260.200 3264.60 3366.45 1558.69 N 4148.23 W 5970321.22 N 557470.15 E 2.939 -1558.69 6147.35 67.030 259.790 3302.23 3404.08 1543.34 N 4235.28 W 5970305.15 N 557383.23 E 0.435 -1543.34 6196.84 66.980 258.590 3321.56 3423.41 1534.79 N 4280.02 W 5970296.24 N 557338.55 E 2.234 -1534.79 6243.48 66.990 256.580 3339.80 3441.65 1525.56 N 4321.94 W 5970286.67 N 557296.71 E 3.967 -1525.56 6338.49 67.200 249.810 3376.81 3478.66 1500.28 N 4405.66 W 5970260.69 N 557213.21 E 6.567 -1500.28 6433.52 68.900 243.390 3412.36 3514.21 1465.27 N 4486.48 W 5970225.02 N 557132.67 E 6.516 -1465.27 6528.44 73.720 237.540 3442.80 3544.65 1420.92 N 4564.62 W 5970180.04 N 557054.90 E 7.736 -1420.92 6623.47 76.340 231.710 3467.36 3569.21 1367.78 N 4639.41 W 5970126.28 N 556980.55 E 6.536 -1367.78 6718.32 74.100 226.560 3491.57 3593.42 1307.82 N 4708.76 W 5970065.75 N 556911.70 E 5.756 -1307.82 -~ 6810.43 72.890 220.260 3517.76 3619.61 1243.71 N 4769.42 W 5970001.15 N 556851.57 E 6.688 -1243.71 6904.76 74.090 213.340 3544.60 3646.45 1171.34N 4823.54 W 5969928.33 N 556798.04 E 7.147 -1171.34 7001.54 76.390 206.030 3569.29 3671.14 1090.09 N 4869.82 W 5969846.70 N 556752.43 E 7.680 -1090.09 7094.62 75.760 200.410 3591.70 3693.55 1007.10 N 4905.43 W 5969763.43 N 556717.50 E 5.899 -1007.10 7188.97 78.340 196.390 3612.85 3714.70 919.87 N 4934.43 W 5969675.96 N 556689.22 E 4.972 -919.87 7221.70 80.030 195.460 3618.99 3720.84 888.96 N 4943.25 W 5969644.98 N 556680.65 E 5.869 -888.96 7250.47 82.540 194.000 3623.35 3725.20 861.46 N 4950.48 W 5969617.42 N 556673.65 E 10.063 -861.46 7278.22 84.080 193.740 3626.59 3728.44 834.70 N 4957.09 W 5969590.61 N 556667.26 E 5.627 -834.70 7335.64 83.830 192.430 3632.63 3734.48 779.08 N 4970.02 W 5969534.89 N 556654.79 E 2.310 -779.08 7436.35 84.360 188.390 3643.00 3744.85 680.58 N 4988.11 W 5969436.24 N 556637.51 E 4.025 -680.58 7497.17 90.120 187.190 3645.93 3747.78 620.42 N 4996.34 W 5969376.01 N 556629.77 E 9.673 -620.42 7529.16 90.860 185.990 3645.65 3747.50 588.64 N 5000.01 W 5969344.20 N 556626.36 E 4.407 -588.64 7559.68 91.850 184.420 3644.93 3746.78 558.25 N 5002.78 W 5969313.80 N 556623.84 E 6.080 -558.25 ._.._._~.- --.---.. ---. 31 July, 2002 - 14:50 Page 4 of7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 1C-104PB1 Your Ref: API 500292207670 b~~. Job No. AKZZ22102, Surveyed: 7 June, 2002 ~ .lJ,rth Slope, Alaska Kuparuk/Colville "h Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical I ~ Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Co e t (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) ',,-.. 7593.17 92.710 182.150 3643.60 3745.45 524.85 N 5004.70W 5969280.38 N 556622.20 E '7.243 -524.85 7623.91 94.250 180.100 3641.73 3743.58 494.17 N 5005.30 W 5969249.70 N 556621.85 E 8.331 -494.17 7654.90 94.810 177.940 3639.28 3741.13 463.29 N 5004.77 W 5969218.82 N 556622.63 E 7.179 -463.29 7686.49 93.260 176.520 3637.06 3738.91 431.81 N 5003.25 W 5969187.36 N 556624.41 E 6.647 -431.81 7718.83 92.590 176.250 3635.41 3737.26 399.58 N 5001.21 W 5969155.14 N 556626.72 E 2.233 -399.58 7748.70 91.420 177.070 3634.37 3736.22 369.78 N 4999.47 W 5969125.36 N 556628.70 E 4.782 -369.78 7780.55 91.050 176.410 3633.68 3735.53 337.99 N 4997.66 W 5969093.58 N 556630.77 E 2.375 -337.99 7813.60 90.370 175.810 3633.27 3735.12 305.02 N 4995.42 W 5969060.63 N 556633.28 E 2.744 -305.02 7842.23 90.180 175.310 3633.13 3734.98 276.47 N 4993.20 W 5969032.11 N 556635.73 E 1.868 -276.47 7873.77 90.430 174.450 3632.97 3734.82 245.06 N 4990.39 W 5969000.72 N 556638.81 E 2.840 -245.06 7937.32 89.630 173.480 3632.93 3734.78 181.86 N 4983.71 W 5968937.58 N 556646.01 E 1.978 -181.86 8007.51 89.510 173.130 3633.46 3735.31 112.16 N 4975.52 W 5968867.94 N 556654.76 E 0.527 -112.16 8032.31 90.370 174.400 3633.48 3735.33 87.50 N 4972.83 W 5968843.31 N 556657.66 E 6.185 -87.50 8127.50 90.610 178.110 3632.67 3734.52 7.46 S 4966.62 W 5968748.39 N 556664.65 E 3.905 7.46 8153.18 90.800 178.320 3632.35 3734.20 33.13 S 4965.82 W 5968722.74 N 556665.66 E 1.103 33.13 8193.25 92.460 180.400 3631.21 3733.06 73.18 S 4965.37 W 5968682.69 N 556666.44 E 6.640 73.18 8223.06 93.320 181.080 3629.71 3731.56 102.95 S 4965.75 W 5968652.92 N 556666.30 E 3.676 102.95 '........ 8252.27 94.440 181.220 3627.74 3729.59 132.08 S 4966.34 W 5968623.78 N 556665.96 E 3.864 132.08 ~. 8285.80 94.560 180.460 3625.10 3726.95 165.51 S 4966.83 W 5968590.36 N 556665.74 E 2.288 165.51 8317.46 93.570 178.060 3622.86 3724.71 197.08 S 4966.42 W 5968558.79 N 556666.41 E 8.182 197.08 8351.32 91.970 176.090 3621.22 3723.07 230.85 S 4964.69 W 5968525.03 N 556668.41 E 7.490 230.85 8382.53 91.480 174.860 3620.28 3722.13 261.95 S 4962.23 W 5968493.95 N 556671.13 E 4.241 261.95 8411.73 92.160 172.240 3619.36 3721.21 290.95 S 4958.95 W 5968464.98 N 556674.64 E 9.265 290.95 8445.90 92.520 171.970 3617.96 3719.81 324.77 S 4954.26 W 5968431.20 N 556679.61 E 1.317 324.77 8476.79 93.760 172.270 3616.27 3718.12 355.32 S 4950.04 W 5968400.69 N 556684.09 E 4.130 355.32 8505.87 94.130 173.160 3614.27 3716.12 384.10 S 4946.36 W 5968371.94 N 556688.01 E 3.308 384.10 8550.75 93.080 173.260 3611.45 3713.30 428.57 S 4941.06 W 5968327.51 N 556693.67 E 2.350 428.57 8600.32 89.510 173.250 3610.33 3712.18 477.78 S 4935.24 W 5968278.35 N 556699.89 E 7.202 477.78 8652.32 89.080 172.100 3610.97 3712.82 529.35 S 4928.61 W 5968226.84 N 556706.94 E 2.361 529.35 8697.32 89.260 172.460 3611.62 3713.47 573.94 S 4922.57 W 5968182.30 N 556713.35 E 0.894 573.94 - -_._~._-'-'._---'----'- _.-.~~---- 0- 31 JulYf 2002.14:50 Page 50f7 Dri/lQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1C-104PB1 Your Ref: API 500292207670 Job No. AKZZ22102, Surveyed: 7 June, 2002 KuparuklColville Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) ~;~t.:~ 8791.38 90.980 173.790 3611.42 3713.27 667.31 S 4911.31 W 5968089.02 N 556725.38 E 8885.50 92.890 174.170 3608.24 3710.09 760.86 S 4901.44 W 5967995.56 N 556736.01 E 8981.48 93.270 173.560 3603.09 3704.94 856.15 S 4891.20 W 5967900.36 N 556747.04 E 9074.60 92.030 174.020 3598.78 3700.63 948.62 S 4881.14 W 5967807.97 N 556757.86 E 9170.86 88.090 174.930 3598.68 3700.53 1044.42 S 4871.87 W 5967712.26 N 556767.91 E 9261.53 87.970 175.440 3601.80 3703.65 1134.71 S 4864.27 W 5967622.03 N 556776.26 E 9331.00 87.970 175.440 3604.26 3706.11 1203.92 S 4858.75 W 5967552.87 N 556782.34 E 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 1437' FNL, 625' FWL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1437' FNL, 625' FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9331.00ft., The Bottom Hole Displacement is SOOS.68ft., in the Direction of 256.083° (True). ',,- _...... -~....._-_.__._- 31 July, 2002 - 14:50 Page 60'7 . D(:~iA~~e. Alaska 4'1''W 17?aruk 1C Vertical ~~t7: Dogleg . Commen t Section Ra e (0/100ft) 2.312 667.31 2.069 760.86 0.748 856.15 1 .420 948.62 4.201 1044.42 0.578 1134.71 0.000 1203.92 Projected Survey ~~, A~, DrillQuest 2.00.08.005 KuparuklColville Comments i \-. Measured Depth (ft) 9331.00 Sperry-Sun Drilling Services Survey Report for 1 C-1 04PB1 Your Ref: API 500292207670 Job No. A KZZ221 02, Surveyed: 7 June, 2002 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 3706.11 1203.92 S 4858.75 W Projected Survey Survey tool program for 1C-104PB1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 168.00 \...- 31 July, 2002 - 14:50 0.00 168.00 168.00 9331.00 168.00 Tolerable Gyro 3706.11 AK-6 BP _IFR-AK - - ----J.. --.---- - .-- --.---------.----'- Page 70f7 . D~~ ~ ~h Slope, Alaska , IIt?jparUk1C .~ "'-" DrilfQuest 2.00.08.005 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 00a-CfoI 05-Aug-02 Re: Distribution of Survey Data for Well 1 C-1 04PB 1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD , MD (if applicable) 9,331.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECEIVED AUG 0 9 2.002 Alaska Oil & Gas Cons. Commission Anchorage "~ <J } f(5 0 1) KuparuklColville North Slope, Alaska Kuparuk 1C, Slot 1C-104 1C-104PB1 MWD Job No. AKMW22102, Surveyed: 7 July, 2002 SUR VE Y R EP 0 R T 8 August, 2002 Your Ref: API 500292207670 Surface Coordinates: 5968796.65 N, 561631.04 E (70019" 31.0425" N, 149030"00.8575" W) Kelly Bushing: 101. 85ft above Mean Sea Level 5pa'-''''Y-5iUI! [) R I L. LING ..~ s e R \ÌÎc:'êfs A Halliburton Company Survey Ref: svy9939 Sperry-Sun Drilling Services Survey Report for 1C-104PB1 MWD Your Ref: API 500292207670 Job No. AKMW22102, Surveyed: 7 July, 2002 North Slope, Alaska Kuparuk/Colville Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 0.00 0.000 0.000 -101.85 0.00 0.00 N 0.00 E 5968796.65 N 561631.04 E 0.00 Tolerable Gyro 168.00 0.150 140.000 66.15 168.00 O.17S 0.14 E 5968796.48 N 561631.18 E 0.089 0.17 MWD Magnetic 292.00 0.390 295.780 190.15 292.00 0.11 S 0.13W 5968796.54 N 561630.91 E 0.428 0.11 384.00 1.850 358.530 282.13 383.98 1.51 N 0.45 W 5968798.16 N 561630.57 E 1.855 -1.51 476.00 3.950 4.570 374.01 475.86 6.16 N 0.24W 5968802.80 N 561630.75 E 2.303 -6.16 568.00 4.600 359.060 465.75 567.60 13.00 N 0.05W 5968809.65 N 561630.89 E 0.835 -13.00 613.00 5.870 352.260 510.56 612.41 17.09 N 0.39W 5968813.73 N 561630.51 E 3.136 -17.09 632.00 6.510 349.220 529.45 631.30 19.11 N 0.72W 5968815.75 N 561630.16 E 3.783 -19.11 660.00 8.070 345.180 557.23 659.08 22.57 N 1.52W 5968819.20 N 561629.34 E 5.861 -22.57 691.00 10.380 340.170 587.82 689.67 27.30 N 3.02W 5968823.92 N 561627.79 E 7.882 -27.30 722.00 13.500 333.600 618.15 720.00 33.17 N 5.58W 5968829.77 N 561625.19 E 10.963 -33.17 752.00 16.420 331.820 647.13 748.98 40.04 N 9.14W 5968836.62 N 561621.57 E 9.852 -40.04 783.00 19.050 330.080 676.65 778.50 48.29 N 13.73 W 5968844.83 N 561616.91 E 8.654 -48.29 843.00 19.100 329.660 733.36 835.21 65.25 N 23.58 W 5968861.71 N 561606.93 E 0.243 -65.25 939.64 19.830 325.690 824.48 926.33 92.44 N 40.80 W 5968888.75 N 561589.48 E 1.563 -92.44 1033.00 26.420 319.290 910.31 1012.16 121.30 N 63.31 W 5968917.43 N 561566.74 E 7.545 -121.30 1127.57 36.100 315.320 991.06 1092.91 157.15 N 96.70 W 5968953.00 N 561533.05 E 10.460 -157.15 1222.27 39.570 314.140 1065.84 1167.69 198.00 N 137.98 W 5968993.51 N 561491.44 E 3.743 -198.00 1316.10 42.290 311.660 1136.73 1238.58 239.81 N 183.02 W 5969034.95 N 561446.06 E 3.376 -239.81 1412.84 46.800 309.140 1205.66 1307.51 283.73 N 234.72W 5969078.44 N 561394.00 E 5.007 -283.73 1508.27 54.780 306.460 1265.95 1367.80 328.93 N 293.14 W 5969123.16 N 561335.20 E 8.639 -328.93 1602.14 59.370 302.190 1316.97 1418.82 373.26 N 358.22 W 5969166.96 N 561269.77 E 6.202 -373.26 1697.39 61.630 298.380 1363.89 1465.74 415.03 N 429.80 W 5969208.14 N 561197.85 E 4.213 -415.03 1791.27 61.650 297.750 1408.48 1510.33 453.90 N 502.69 W 5969246.40 N 561124.63 E 0.591 -453.90 1886.24 62.990 295.150 1452.60 1554.45 491.34 N 577.99 W 5969283.23 N 561049.04 E 2.805 -491.34 1980.79 67.880 292.850 1491.90 1593.75 526.27 N 656.53 W 5969317.51 N 560970.21 E 5.625 -526.27 2075.05 71.450 292.720 1524.65 1626.50 560.50 N 738.00 W 5969351.07 N 560888.46 E 3.790 -560.50 2169.29 67.450 287.910 1557.74 1659.59 591.16N 820.69 W 5969381.05 N 560805.52 E 6.391 -591.16 2262.19 66.590 288.690 1594.01 1695.86 618.01 N 901.89 W 5969407.23 N 560724.10 E 1.206 -618.01 2359.87 64.070 288.120 1634.78 1736.63 646.04 N 986.11 W 5969434.57 N 560639.66 E 2.634 -646.04 8 August, 2002 - 18:43 Page 20f7 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services , Survey Report for 1C-104PB1 MWD Your Ref: API 500292207670 Job No. AKMW22102, Surveyed: 7 July, 2002 North Slope, Alaska Kuparuk/Colville Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 2455.87 61.220 287.800 1678.89 1780.74 672.33 N 1067.21 W 5969460.19 N 560558.34 E 2.983 -672.33 2551.42 63.040 286.150 1723.55 1825.40 696.98 N 1147.99 W 5969484.18 N 560477.36 E 2.441 -696.98 2646.73 63.860 290.580 1766.17 1868.02 723.85 N 1228.88 W 5969510.38 N 560396.26 E 4.246 -723.85 2741.17 65.170 285.920 1806.82 1908.67 750.51 N 1309.81 W 5969536.38 N 560315.11 E 4.665 -750.51 2834.94 64.080 287.900 1847.01 1948.86 775.15 N 1390.87 W 5969560.35 N 560233.85 E 2.234 -775.15 2930.61 63.520 286.910 1889.25 1991.10 800.83 N 1472.78 W 5969585.35 N 560151.74 E 1.098 -800.83 3027.20 64.560 286.960 1931.53 2033.38 826.12 N 1555.85 W 5969609.97 N 560068.45 E 1.078 -826.12 3124.35 64.550 287.550 1973.27 2075.12 852.15 N 1639.63 W 5969635.30 N 559984.47 E 0.548 -852.15 3216.98 63.870 288.430 2013.57 2115.42 877.90 N 1718.96 W 5969660.40 N 559904.93 E 1.127 -877.90 3309.24 64.060 287.420 2054.07 2155.92 903.41 N 1797.83 W 5969685.27 N 559825.85 E 1.005 -903.41 3403.29 64.330 286.790 2095.01 2196.86 928.32 N 1878.75 W 5969709.51 N 559744.72 E 0.668 -928.32 3494.73 64.960 287.820 2134.17 2236.02 952.90 N 1957.64 W 5969733.44 N 559665.64 E 1.229 -952.90 3590.07 65.210 288.280 2174.33 2276.18 979.69 N 2039.85 W 5969759.55 N 559583.21 E 0.510 -979.69 3682.14 65.340 289.740 2212.84 2314.69 1006.93 N 2118.92 W 5969786.14 N 559503.92 E 1.447 -1006.93 3779.93 65.490 289.180 2253.53 2355.38 1036.56 N 2202.76 W 5969815.08 N 559419.84 E 0.543 -1036.56 3875.30 64.010 292.010 2294.22 2396.07 1066.88 N 2283.50 W 5969844.74 N 559338.85 E 3.100 -1066.88 3967.48 63.510 290.670 2334.97 2436.82 1096.97 N 2360.51 W 5969874.20 N 559261.60 E 1.412 -1096.97 4060.54 62.830 289.420 2376.98 2478.83 1125.43 N 2438.52 W 5969902.02 N 559183.36 E 1.404 -1125.43 4160.89 62.770 290.680 2422.85 2524.70 1156.03 N 2522.36 W 5969931.93 N 559099.27 E 1.118 -1156.03 4255.16 61.720 290.810 2466.75 2568.60 1185.58 N 2600.37 W 5969960.83 N 559021.02 E 1.120 -1185.58 4349.47 63.540 291.100 2510.10 2611.95 1215.53 N 2678.58 W 5969990.14 N 558942.56 E 1.949 -1215.53 4443.66 65.040 291.360 2550.96 2652.81 1246.27 N 2757.69 W 5970020.22 N 558863.21 E 1.612 -1246.27 4534.08 64.260 291.610 2589.68 2691.53 1276.19 N 2833.72 W 5970049.53 N 558786.93 E 0.898 -1276.19 4634.12 64.410 290.850 2633.01 2734.86 1308.84 N 2917.77 W 5970081.49 N 558702.62 E 0.701 -1308.84 4729.05 64.630 290.710 2673.84 2775.69 1339.25 N 2997.89 W 5970111.23 N 558622.25 E 0.267 -1339.25 4823.73 64.850 289.440 2714.25 2816.10 1368.64 N 3078.32 W 5970139.96 N 558541.59 E 1.235 -1368.64 4915.72 63.300 289.500 2754.46 2856.31 1396.21 N 3156.31 W 5970166.89 N 558463.36 E 1.686 -1396.21 5012.56 62.480 289.730 2798.59 2900.44 1425.15 N 3237.51 W 5970195.16 N 558381.93 E 0.873 -1425.15 5107.03 62.710 290.440 2842.08 2943.93 1453.95 N 3316.28 W 5970223.31 N 558302.93 E 0.710 -1453.95 5203.31 62.130 288.000 2886.66 2988.51 1482.04 N 3396.85 W 5970250.75 N 558222.13 E 2.326 -1482.04 8 August, 2002 - 18:43 Page 30f7 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for 1C-104PB1 MWD Your Ref: API 500292207670 Job No. AKMW22102, Surveyed: 7 July, 2002 North Slope, Alaska Kuparuk/Colville Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 5294.26 61.950 284.810 2929.31 3031.16 1504.73 N 3473.90 W 5970272.80 N 558144.90 E 3.104 -1504.73 5391.75 61.720 284.410 2975.33 3077.18 1526.41 N 3557.07 W 5970293.79 N 558061.56 E 0.432 -1526.41 5480.77 63.180 284.650 3016.50 3118.35 1546.21 N 3633.47 W 5970312.97 N 557985.00 E 1.657 -1546.21 5576.96 63.790 281.280 3059.45 3161.30 1565.51 N 3717.33 W 5970331.58 N 557900.98 E 3.198 -1565.51 v-- 5676.37 64.080 276.990 3103.15 3205.00 1579.68 N 3805.47 W 5970345.02 N 557812.73 E 3.887 -1579.68 5766.61 62.620 273.690 3143.63 3245.48 1587.20 N 3885.75 W 5970351.88 N 557732.38 E 3.647 -1587.20 5862.02 63.930 268.710 3186.56 3288.41 1588.96 N 3970.91 W 5970352.95 N 557647.21 E 4.860 -1588.96 5954.25 65.860 262.720 3225.72 3327.57 1582.69 N 4054.14 W 5970345.99 N 557564.04 E 6.241 -1582.69 6051.28 66.850 259.330 3264.64 3366.49 1568.82 N 4141.91 W 5970331.40 N 557476.38 E 3.359 -1568.82 6147.35 67.030 259.680 3302.27 3404.12 1552.72 N 4228.83 W 5970314.58 N 557389.60 E 0.384 -1552.72 6196.84 66.980 259.080 3321.61 3423.46 1544.32 N 4273.60 W 5970305.82 N 557344.90 E 1.121 -1544.32 6243.48 66.990 256.730 3339.84 3441.69 1535.33 N 4315.58 W 5970296.48 N 557303.00 E 4.638 -1535.33 6338.49 67.200 249.790 3376.86 3478.71 1510.14 N 4399.32 W 5970270.60 N 557219.47 E 6.732 -1510.14 6433.52 68.900 243.540 3412.41 3514.26 1475.22 N 4480.18 W 5970235.02 N 557138.89 E 6.356 -1475.22 6528.44 73.720 237.730 3442.84 3544.69 1431.11 N 4558.45 W 5970190.27 N 557060.99 E 7.706 -1431. 11 6623.47 76.340 231.880 3467.41 3569.26 1378.20 N 4633.41 W 5970136.75 N 556986.47 E 6.554 -1378.20 6718.32 74.100 226.180 3491.62 3593.4 7 1318.12 N 4702.64 W 5970076.10 N 556917.73 E 6.272 -1318.12 6810.43 72.890 220.040 3517.81 3619.66 1253.69 N 4762.97 W 5970011.18 N 556857.94 E 6.524 -1253.69 6904.76 74.090 213.130 3544.65 3646.50 1181.11 N 4816.82 W 5969938.16 N 556804.68 E 7.137 -1181.11 7001.54 76.390 206.050 3569.33 3671.18 1099.78 N 4862.97 W 5969856.45 N 556759.20 E 7.462 -1099.78 7094.62 75.760 200.430 3591.75 3693.60 1016.81 N 4898.61 W 5969773.19 N 556724.25 E 5.899 -1016.81 7188.97 78.340 196.620 3612.90 3714.75 929.64 N 4927.80 W 5969685.79 N 556695.77 E 4.792 -929.64 7221.70 80.030 195.770 3619.04 3720.89 898.77 N 4936.76 W 5969654.84 N 556687.06 E 5.759 -898.77 7250.47 82.540 194.490 3623.40 3725.25 871.32 N 4944.18 W 5969627.33 N 556679.87 E 9.770 -871.32 7278.22 84.080 196.150 3626.63 3728.48 844.74 N 4951.47W 5969600.70 N 556672.80 E 8.130 -844.74 7335.64 83.830 193.500 3632.68 3734.53 789.55 N 4966.07 W 5969545.38 N 556658.65 E 4.610 -789.55 7436.35 84.360 188.350 3643.05 3744.90 691.22 N 4985.05 W 5969446.90 N 556640.48 E 5.114 -691.22 7497.17 90.120 187.360 3645.97 3747.82 631.07 N 4993.35 W 5969386.68 N 556632.68 E 9.609 -631.07 7529.16 90.860 186.170 3645.70 3747.55 599.30 N 4997.12 W 5969354.89 N 556629.17 E 4.380 -599.30 7559.68 91.850 184.650 3644.98 3746.83 568.93 N 4999.99 W 5969324.49 N 556626.54 E 5.942 -568.93 8 August, 2002 - 18:43 Page 4 of7 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for 1C-104PB1 MWD Your Ref: API 500292207670 Job No. AKMW22102, Surveyed: 7 July, 2002 North Slope, Alaska KuparuklColville Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7593.17 92.710 182.340 3643.65 3745.50 535.53 N 5002.03 W 5969291.08 N 556624.78 E 7.355 -535.53 7623.91 94.250 180.190 3641.78 3743.63 504.86 N 5002.71 W 5969260.40 N 556624.35 E 8.593 -504.86 7654.90 94.810 178.540 3639.33 3741.18 473.97 N 5002.37 W 5969229.51 N 556624.95 E 5.607 -473.97 7686.49 93.260 177.340 3637.11 3738.96 442.48 N 5001.24 W 5969198.03 N 556626.34 E 6.199 -442.48 -~- 7718.83 92.590 177.030 3635.46 3737.31 410.22 N 4999.65 W 5969165.79 N 556628.19 E 2.282 -410.22 7748.70 91.420 177.550 3634.42 3736.27 380.40 N 4998.24 W 5969135.99 N 556629.84 E 4.286 -380.40 7780.55 91.050 176.790 3633.73 3735.58 348.60 N 4996.67 W 5969104.20 N 556631.68 E 2.653 -348.60 7813.60 90.370 176.260 3633.32 3735.17 315.61 N 4994.66 W 5969071.23 N 556633.95 E 2.609 -315.61 7842.23 90.180 175.780 3633.18 3735.03 287.05 N 4992.68 W 5969042.68 N 556636.17 E 1.803 -287.05 7873.77 90.430 175.230 3633.01 3734.86 255.61 N 4990.21 W 5969011.26 N 556638.90 E 1.915 -255.61 7937.32 89.630 174.270 3632.98 3734.83 192.32 N 4984.39 W 5968948.03 N 556645.24 E 1.966 -192.32 8007.51 89.510 173.790 3633.51 3735.36 122.52 N 4977.09 W 5968878.29 N 556653.11 E 0.705 -122.52 8032.31 90.370 174.900 3633.53 3735.38 97.84 N 4974.65 W 5968853.63 N 556655.76 E 5.662 -97.84 8127.50 90.610 178.110 3632.72 3734.57 2.84N 4968.84 W 5968758.68 N 556662.34 E 3.381 -2.84 8153.18 90.800 178.770 3632.40 3734.25 22.83 S 4968.15 W 5968733.02 N 556663.25 E 2.674 22.83 8193.25 92.460 180.590 3631.26 3733.11 62.88 S 4967.92 W 5968692.97 N 556663.80 E 6.146 62.88 8223.06 93.320 181.060 3629.76 3731.61 92.65 S 4968.35 W 5968663.20 N 556663.62 E 3.287 92.65 8252.27 94.440 181.670 3627.78 3729.63 121.78 S 4969.04 W 5968634.06 N 556663.16 E 4.364 121.78 8285.80 94.560 180.640 3625.15 3727.00 155.20 S 4969.72 W 5968600.64 N 556662.76 E 3.083 155.20 8317.46 93.570 178.560 3622.91 3724.76 186.78 S 4969.50 W 5968569.06 N 556663.24 E 7.261 186.78 8351.32 91.970 176.680 3621.27 3723.12 220.57 S 4968.09 W 5968535.29 N 556664.93 E 7.286 220.57 ~,- 8382.53 91.480 175.570 3620.33 3722.18 251.69 S 4965.98 W 5968504.18 N 556667.29 E 3.886 251.69 8411.73 92.160 173.880 3619.40 3721.25 280.75 S 4963.30 W 5968475.15 N 556670.21 E 6.236 280.75 8445.90 92.520 172.800 3618.01 3719.86 314.66 S 4959.34 W 5968441.27 N 556674.45 E 3.329 314.66 8476.79 93.760 172.610 3616.32 3718.17 345.25 S 4955.43 W 5968410.71 N 556678.62 E 4.061 345.25 8505.87 94.130 173.390 3614.32 3716.17 374.05 S 4951.89 W 5968381.94 N 556682.39 E 2.963 374.05 8550.75 93.080 173.480 3611.50 3713.35 418.54 S 4946.77 W 5968337.49 N 556687.88 E 2.348 418.54 8600.32 89.510 173.850 3610.38 3712.23 467.79 S 4941.30 W 5968288.29 N 556693.75 E 7.240 467.79 8652.32 89.080 172.700 3611.01 3712.86 519.43 S 4935.21 W 5968236.70 N 556700.26 E 2.361 519.43 8697.32 89.260 173.280 3611.67 3713.52 564.09 S 4929.72 W 5968192.09 N 556706.12 E 1.349 564.09 8 August, 2002 - 18:43 Page 50f7 DrillQuest 2.00.09.003 KuparuklColville Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 8791.38 90.980 174.530 3611.47 3713.32 8885.50 92.890 174.750 3608.29 3710.14 8981.48 93.270 173.900 3603.13 3704.98 9074.60 92.030 174.620 3598.83 3700.68 ~~ 9170.86 88.090 175.360 3598.73 3700.58 9261.53 87.970 175.440 3601.85 3703.70 9331.00 87.970 175.440 3604.31 3706.16 Sperry-Sun Drilling Services Survey Report for 1C-104PB1 MWD Your Ref: API 500292207670 Job No. AKMW22102, Surveyed: 7 July, 2002 North Slope, Alaska Kuparuk 1 C Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (°/1 0 Oft) 657.61 S 4919.74 W 5968098.66 N 556716.87 E 2.260 657.61 751.26 S 4910.95 W 5968005.08 N 556726.43 E 2.043 751.26 846.63 S 4901.47 W 5967909.79 N 556736.69 E 0.969 846.63 939.18 S 4892.17 W 5967817.32 N 556746.75 E 1.539 939.18 1035.06 S 4883.76 W 5967721.52 N 556755.94 E 4.165 1035.06 1125.38 S 4876.50 W 5967631.26 N 556763.95 E 0.159 1125.38 1194.59 S 4870.98 W 5967562.10 N 556770.04 E 0.000 1194.59 Projected Survey 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 1437' FNL, 625' FWL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1437' FNL, 625' FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9331.00ft., The Bottom Hole Displacement is 5015.32ft., in the Direction of 256.220° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 9331.00 3706.16 1194.59 S 4870.98 W 8 August, 2002 - 18:43 Comment Projected Survey Page 60f7 DrillQuest 2.00.09.003 KuparuklColville Survey tool program for 1C-104PB1 MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 168.00 0.00 168.00 8 August, 2002 - 18:43 To Measured Vertical Depth Depth (ft) (ft) 168.00 9331.00 Sperry-Sun Drilling Services Survey Report for 1C-104PB1 MWD Your Ref: API 500292207670 Job No. AKMW22102, Surveyed: 7 July, 2002 North Slope, Alaska Kuparuk 1 C Survey Tool Description 168.00 Tolerable Gyro 3706.16 MWD Magnetic Page 70f7 DrillQuest 2.00.09.003 õ1 0 ~-OtD/ J I D3S WELL LOG TRANSMfITAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Lisa Weepie 33 3 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 11, 2002 RE: MWD Formation Evaluation Logs 1 C-l 04, AK-MW-22102 1 LDWG formatted Disc with verification listing. ~I#: 50-029-23076-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~> 6 Ooor~:J RECEIVED SEP 1 3 2002 Alaska O¡i & Gas Cons. Commission Anchorage WELL LOG TRANSMfITAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 11, 2002 RE: MWD FonnationEvaluationLogs IC-I04 PBI, AK-MW-22I02 1 LDWG fonnatted Disc with verification listing. API#: 50-029-23076-70 a D~- D(o/ I I D -Stp 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 Date: Si~~ RECE\\IED $EP' 1~. 2002. "' f'nmm\l$ion þj a\ta œ & Gas cons. \IV . a. Ancttoœ96 ( ( tPHilliPš\ PHilLIPS Alaska, Inc. æ A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 . Fax: (907) 265-6224 July 2, 2002 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approvals for 1 C-1 04 Dear Commissioner: Phillips Alaska, Inc. submits the attached Application for Sundry Approvals for 1 C-1 04. We are requesting approval to change the approved program for this well. If you have any questions regarding this matter, please contact Tom Brockway at 263-4135. Sincerely, 't<--~\~. R. Thomas Kuparuk Team Leader P AI Drilling ORIGINAL RT/skad RECEIVED JUL .} 2002 Alaska Oil & Gas Cons. Commission Anchorage W6^ df{ Of-\' 1/ ~I 0 L Î/~/~ " f 7/(12:- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well - 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 1437' FNL, 625' FWL, Sec. 12, T11 N, R10E, UM At top of productive interval 36' FNL, 1053' FWL, Sec. 11, T11 N, R10E, UM At effective depth At total depth 412' FSL, 1083' FWL, Sec. 11, T11N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 7400 3741 7400 3741 measured true vertical Casing Conductor Surface Intermediate Production Size 16" Length 158' 6518' 7.625" Perforation depth: measured N/A true vertical NI A Tubing (size, grade, and measured depth NIA Packers & SSSV (type & measured depth) NIA 13. Attachments Description summary of proposal _X 14. Estimated date for commencing operation / July 2, 2002 16. If proposal was verbally approved Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service - (as proposed) (as proposed) feet feet feet feet Plugs (measured) Junk (measured) Cemented 285 sx AS 1 810 sx AS Lite, 290 sx Class G Detailed operations program - 15. Status of well classification as: Oil_XX Name of approver Date approved Service - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,. ,<-~ \. \.......;.~ Randv Thomas \ Title: Kuparuk Drilling Team Leader FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance- Mechanical Integrity Test - ~ . Subsequent form required 10- vlIglnal Signed OJ Cammy Qechsli T aylo: Approved by order of the Commission Form 10-403 Rev 06/15/88 . 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 04 9. Permit number 1 approval number 202-061 10. API number 50-029-23076-00 11. Field I Pool Kuparuk River Field/Kuparuk Oil Pool Measured Depth 158' 7400' /' True vertical Depth 158' 3741' OR\G\NAL RECEIVED JUL 3 2002 Alaska Oil & Gas Cons. Commission Anchorage BOP sketch - Gas- Suspended - Questions? Call Tom Brockway 263-4135 Date') Ij.../ ðL Prepared by Sharon Allsup-Drake t/oï Approval no. ?:-P':1. - ~Cio Commissioner 1hÞ~ Date SUBMIT IN TRIPLICATE .gf::::= Kuparu¡{t!River Unit North Slope, Alaska Kuparuk 1C, Slot 1C-104 Plan: 1C-104 - 1C-104 (wp05) Revised: 1 July, 2002 PROPOSAL REPORT 1 July, 2002 ^~ Your Ref: 'B' Lateral Plan tied onto (ACTUAL) 7-5/8" Csg Pt. Surface Coordinates: 5968796.65 N, 561631.04 E (70019' 31.0425" N, 149030' 00.8575" W) Surface Coordinates relative to Project H Reference: 968796.65 N, 61631.04 E (Grid) Surface Coordinates relative to Stucture Referance: 280.27 N, 738.73 W (True) Kelly Bushing: 101.80ft above Mean Sea Level sper-aI'Y-SUI'1: t;1RII.,.,I...'ti J£:i 5fiRV-c;:;es A hiiliiWl'ttlm ;þdØip.$"'¥ Proposal Ref: pro9918 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 Your Ref: '8' Lateral Plan tied onto (ACTUAL) 7-5/8" Csg Pt. Revised: 1 July, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) 'i¡!!¡lê1100ft) 1C-104 (Rig Gyro) 0.00 0.000 0.000 -101.80 0.00 0.00 N 0.00 E 5968796.65 N 0.00 100.00 0.089 140.000 -1.80 100.00 0.06 S 0.05 E 5968796.59iN 0.089 0.06 200.00 0.046 204.713 98.20 200.00 0.21 S 0.16 E 5968796.44 N 0.081 0.21 300.00 0.454 314.120 198.20 300.00 0.08 S 0.18W 5968796.57 N 0.471 0.08 400.00 2.212 0.141 298.17 399.97 2.08 N 0.47 W 5968798.72 N 1.925 -2.08 500.00 4.116 2.900 398.00 499.80 0.15W 5968804.49 N 561630.82 E 1.909 -7.84 600.00 5.498 354.550 497.68 599.48 0.25W 5968812.46 N 561630.66 E 1.546 -15.81 700.00 11.271 337.646 596.71 698.51 3.68W 5968825.48 N 561627.13 E 6.217 -28.86 800.00 19.064 329.868 692.77 794.57 16.57 W 5968849.59 N 561614.03 E 8.037 -53.08 843.00 19.100 329.610 733.41 835.21 23.66 W 5968861 .67 N 561606.85 E 0.213 -65.22 1C-104 (Rig IFR+CAZ) 900.00 19.519 327.096' 81 .26 N 33.55 W 5968877.63 N 561596.82 E 1.633 -81.26 1000.00 24.062 320.850 110.34 N 54.55 W 5968906.53 N 561575.58 E 5.095 -110.34 1100.00 33.276 315.896 145.56 N 86.23 W 5968941 .50 N 561543.62 E 9.509 -145.56 1200.00 38.754 313.805 187.51 N 128.72 W 5968983.09 N 561500.79 E 5.613 -187.51 1300.00 41 .820 311.549 231.44 N 176.26 W 5969026.64 N 561452.88 E 3.395 -231.44 1400.00 46.198 308.918 1196.86 1298.66 276.19 N 229.18 W 5969070.95 N 561399.60 E 4.744 -276.19 1500.0 54:0'86 "@w305.890 1261.18 1362.98 322.59 N 289.94 W 5969116.85 N 561338.46 E 8.221 -322.59 1600.0 59.265 302.745 1315.91 1417.71 369.72 N 359.05 W 5969163.41 N 561268.97 E 5.807 -369.72 1700.00 61.630 298.348 1365.16 1466.96 413.87 N 434.01 W 5969206.94 N 561193.64 E 4.496 -413.87 1800.00 61 .772 297.046 1412.66 1514.46 454.83 N 511.90W 5969247.26 N 561115.42 E 1.1 56 -454.83 1900.00 63.699 294.804 1458.81 1560.61 493.62 N 591.67 W 5969285.40 N 561035.34 E 2.772 -493.62 2000.00 68.601 292.071 1499.06 1600.86 530.18 N 675.55 W 5969321.26 N 560951.16 E 5.501 -530.18 2100.00 70.391 288.991 1532.85 1634.65 562.65 N 763.86 W 5969353.01 N 560862.59 E 3.395 -562.65 2200.00 67.166 288.808 1569.62 1671 .42 592.63 N 851.87 W 5969382.26 N 560774.33 E 3.230 -592.63 2300.00 65.613 288.527 1609.36 1711 .16 622.33 N 938.69 W 5969411 .25 N 560687.27 E 1.574 -622.33 1 July, 2002 - 15:06 Page 2 of8 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 Your Ref: '8' Lateral Plan tied onto (ACTUAL) 7-5/8" Csg Pt. Revised: 1 July, 2002 Slope, Alaska Kuparuk River Unit Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) '60ft) 2400.00 62.879 287.745 1652.73 1754.53 650.08 N 1024.41 W 5969438.29 N 560601.33 E 2.824 -650.08 2500.00 62.058 287.111 1699.88 1801 .68 676.84 N 1108.43 W 596~~§;~.37 N 60517.09 E 0.994 -676.84 2600.00 63.442 288.445 1745.46 1847.26 702.86 N 1193.54 W 5969489.68 N 431 .76 E 1.822 -702.86 2700.00 64.589 288.588 1789.37 1891.17 732.91 N 1278.21 W 5969519.03 N 5 46.86 E 1.154 -732.91 2800.00 64.486 287.418 1831.87 1933.67 760.11 N 1364.54 W 5969545.53 N 560260.30 E 1.061 -760.11 2900.00 63.699 287.464 1875.66 1977.46 1450.26 W 5969571 .90 N 560174.36 E 0.788 -787.19 3000.00 64.267 287.419 1919.80 2021 .60 1535.88 W 5969598.05 N 560088.52 E 0.569 -814.04 3100.00 64.552 287.520 1962.83 2064.63 1621.99 W 5969624.43 N 560002.19 E 0.300 -841.13 3200.00 63.995 287.566 2006.13 2107.93 1707.93 W 5969650.91 N 559916.03 E 0.559 -868.31 3300.00 64.041 287.642 2050.04 2151.84 793.57 W 5969677.37 N 559830.17 E 0.082 -895.48 3400.00 64.321 288.055 2093.60 1879.26 W 5969704.23 N 559744.26 E 0.465 -923.05 3500.00 64.974 287.726 2136.41 1965.26 W 5969731.29 N 559658.04 E 0.718 -950.81 3600.00 65.224 287.746 2178.51 2051.68 W 5969758.14 N 559571 .40 E 0.251 -978.38 3700.00 65.367 288.573 2220.31 2137.97 W 5969785.83 N 559484.87 E 0.765 -1006.78 3800.00 65.178 288.878 2261.92 2224.11 W 5969814.24 N 559398.49 E 0.336 -1035.90 3900.00 63.875 289.798 305~O;ZHP' 2406.87 1065.70 N 2309.25 W 5969843.34 N 559313.11 E 1.545 -1065.70 4000.00 63.272 290.315 9.55 2451.35 1096.80 N 2393.25 W 5969873.75 N 559228.87 E 0.761 -1096.80 4100.00 62.805 290.224 95.01 2496.81 1127.21 N 2476.96 W 5969903.47 N 559144.91 E 0.474 -1127.21 4200.00 62.334 291 .279 2440.88 2542.68 1158.87 N 2559.98 W 5969934.45 N 559061 .62 E 1.048 -1158.87 4300.00 62.585 291 .371 2487.70 2589.50 1191.14 N 2642.24 W 5969966.04 N 558979.10 E 0.264 -1191.14 .~~ 4400.00 64.344 290.881 2532.31 2634.11 1223.45 N 2725.70 W 5969997.67 N 558895.38 E 1.813 -1223.45 4500.0 64.554 \itw290.563 2574.96 2676.76 1255.35 N 2810.34 W 5970028.87 N 558810.49 E 0.355 -1255.35 4600.0 64.359 290.415 2618.26 2720.06 1286.92 N 2894.77 W 5970059.75 N 558725.80 E 0.236 -1286.92 4700.00 64.563 290.315 2661.39 2763.19 1318.29N 2979.36 W 5970090.43 N 558640.96 E 0.223 -1318.29 4800.00 64.795 289.925 2704.16 2805.96 1349.46 N 3064.21 W 5970120.90 N 558555.85 E 0.422 -1349.46 4900.00 63.565 289.717 2747.44 2849.24 1379.97 N 3149.03 W 5970150.71 N 558470.78 E 1.244 -1379.97 5000.00 62.586 289.883 2792.81 2894.61 1410.13 N 3232.89 W 5970180.18 N 558386.68 E 0.990 -1410.13 5100.00 62.693 289.938 2838.86 2940.66 1440.37 N 3316.34 W 5970209.73 N 558302.98 E 0.117 -1440.37 5200.00 62.149 287.662 2885.12 2986.92 1469.06 N 3400.22 W 5970237.73 N 558218.87 E 2.089 -1469.06 5300.00 61.936 284.864 2932.01 3033.81 1493.68 N 3485.03 W 5970261.66 N 558133.86 E 2.480 -1493.68 1 July, 2002 - 15:06 Page 3 of8 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 Your Ref: '8' Lateral Plan tied onto (ACTUAL) 7-5/8" Csg Pt. Revised: 1 July, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) iOOft) 5400.00 61 .855 284.866 2979.23 3081.03 1516.35 N 3570.22 W 5970283.62 N 558048.48 E '0.081 -1516.35 5500.00 63.297 283.624 3025.16 3126.96 1538.49 N 3656.24 W 597üJ,Q§.06 N 557962.29 E 1.815 -1538.49 5600.00 63.848 280.231 3069.62 3171.42 1557.08 N 3743.85 W 5970322.93 N 874.53 E 3.087 -1557.08 5700.00 63.688 276.416 3113.55 3215.35 1570.04 N 3832.73 W 5970335.16, N 5, 85.55 E 3.426 -1570.04 5800.00 63.062 272.157 3158.88 3260.68 1577.04 N 39411J;p7 Y)JÆ~ ÓHá,97Q8,~ 1.43tN 557696.65 E 3.859 -1577.04 5900.00 64.707 266.427 3203.02 3304.82 4011 .25 W 5970339.71 N 557606.98 E 5.401 -1576.05 6000.00 66.331 261.738 3244.23 3346.03 4101.78JÌ'vwmt¥S970328.95 N 557516.54 E 4.566 -1566.05 6100.00 66.941 259.992 3283.73 3385.53 4192.40"W 5970313.12 N 557426.04 E 1.715 -1550.95 6200.00 66.980 258.454 3322.81 3424.61 282.90 W 5970295.60 N 557335.68 E 1.416 -1534.18 6300.00 67.080 252.550 3361.87 3463.67 4372.12 W 5970272.37 N 557246.65 E 5.436 -1511.68 6400.00 68.272 245.637 4458.35 W 5970238.64 N 557160.70 E 6.504 -1478.66 6500.00 72.257 239.258 4541.49 W 5970194.44 N 557077.92 E 7.204 -1435.14 6600.00 75.679 233.137 4621.39 W 5970140.28 N 556998.45 E 6.805 -1381.64 6700.00 74.524 227.563 4695.87 W 5970077.84 N 556924.49 E 5.509 -1319.80 6800.00 73.017 220.977 4762.96 W 5970008.74 N 556857.97 E 6.500 -1251.25 6900.00 74.024 213.687 3645.10 1175.12 N 4821 .04 W 5969932.13 N 556800.51 E 7.062 -1175.12 7000.00 76.352 206.145 3670.74 1091.39 N 4869.19 W 5969848.02 N 556753.05 E 7.653 -1091.39 7045.00 76.080 203.410 3681.44 1051.71 N 4887.50 W 5969808.18 N 556735.06 E 5.934 -1051.71 Top West Sak 0 (Measured) 7100.00 75.905 ~ 200.178 3694.83 1002.17 N 4907.27 W 5969758.48 N 556715.70 E 5.709 -1002.17 7200.00 78.909 196.075 3716.84 909.45 N 4937.48 W 5969665.52 N 556686.25 E 5.005 -909.45 7300.00 83.~85,,"« 193.243 3628.86 3730.66 813.60 N 4962.17 W 5969569.47 N 556662.36 E 5.797 -813.60 7377.9 84.597 '{""190.175 3636.91 3738.71 737.79 N 4978.29 W 5969493.53 N 556646.86 E 3.996 -737.79 Top West Sak B (Measured) 7400.0 85.000 189.000 3638.91 3740.71 716.12 N 4981 .95 W 5969471.83 N 556643.38 E 5.607 -716.12 7-5/8" Casing Shoe: 7400.00ft MD, 3740.711t TVD (Drill out 20' in 6-3/4 Hole) 7-5/8" Casing 1 July, 2002 - 15:06 Page 4 of8 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 Your Ref: 'B' Lateral Plan tied onto (ACTUAL) 7-5/8" Csg Pt. Revised: 1 July, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) '!;llilli[¡~:1100ft) 1C-104 (wp05) 7420.00 85.000 189.000 3640.65 3742.45 696.44 N 4985.06 W 0.000 -696.44 Begin Dir @ 5.00/100ft : 7420.0'-' MD, 3742.45ft TVD 7500.00 87.560 184.931 3645.85 3747.65 617.22 N 4994.74 W 5969372.83'N 556631 .40 E 6.000 -617.22 7600.00 90.776 179.864 3647.30 3749.10 517.37 N 4998.92 W 5969272.94 N 556628.04 E 6.000 -517.37 7667.01 92.929 176.466 3645.13 3746.93 450.44 N 4996.78 W 5969206.03 N 556630.73 E 6.000 -450.44 End Dir, Start Sail @ 92.93° : 7667.01ft MD, 3746.93ft TVD 7700.00 92.929 176.466 3643.45 3745.25 994.74W 5969173.17 N 556633.03 E 0.000 -417.56 7800.00 92.929 176.466 3638.34 3740.14 988.59 W 5969073.54 N 556640.01 E 0.000 -317.88 7900.00 92.929 176.466 3633.23 3735.03 4982.43 W 5968973.92 N 556646.98 E 0.000 -218.20 7941.77 92.929 176.466 3631.09 3732.89 4979.86 W 5968932.31 N 556649.90 E 0.000 -176.56 Begin Dir @ 3.00/100ft: 7941.77ft MD, 3732.89ft TVD 8000.00 91.182 176.421 118.48 N 4976.25 W 5968874.26 N 556653.98 E 3.000 -118.48 8000.26 91.175 176.420 118.22 N 4976.24 W 5968874.00 N 556654.00 E 3.000 -118.22 TARGET (B-wp05) End Dir, Start S, @ 91.19°: 8000.26ft MD, 3730.801 TVD 1 C-1 04 (wp05 Target), Current Tar~ 8100.00 91.175 176.420 3728.76 18.70 N 4970.01 W 5968774.53 N 556661 .04 E 0.000 -18.70 8200.00 91.175 176.420 3726.71 81.09 S 4963.77 W 5968674.80 N 556668.10 E 0.000 81.09 8300.00 91.175 176.420 3724.65 180.87 S 4957.53 W 5968575.07 N 556675.17 E 0.000 180.87 8400.00 91.175 176.420 3722.60 280.65 S 4951.28 W 5968475.34 N 556682.23 E 0.000 280.65 ~ 8500.00 91.175 176.420 3720.55 380.44 S 4945.04 W 5968375.61 N 556689.29 E 0.000 380.44 8600.0 91.175 176.420 3616.70 3718.50 480.22 S 4938.80 W 5968275.88 N 556696.35 E 0.000 480.22 8700.00 91.175 176.420 3614.65 3716.45 580.01 S 4932.56 W 5968176.15 N 556703.41 E 0.000 580.01 8800.00 91.175 176.420 3612.60 3714.40 679.79 S 4926.32 W 5968076.42 N 556710.47 E 0.000 679.79 8900.00 91.175 176.420 3610.55 3712.35 779.57 S 4920.07 W 5967976.69 N 556717.53 E 0.000 779.57 9000.00 91.175 176.420 3608.50 3710.30 879.36 S 4913.83 W 5967876.96 N 556724.60 E 0.000 879.36 9100.00 91.175 176.420 3606.45 3708.25 979.14 S 4907.59 W 5967777.24 N 556731.66 E 0.000 979.14 9200.00 91.175 176.420 3604.40 3706.20 1078.92 S 4901 .35 W 5967677.51 N 556738.72 E 0.000 1078.92 9300.00 91.175 176.420 3602.35 3704.15 1178.71 S 4895.11 W 5967577.78 N 556745.78 E 0.000 1178.71 9317.24 91.175 176.420 3602.00 3703.80 1195.91 S 4894.03 W 5967560.58 N 556747.00 E 0.000 1195.91 TARGET (B-Mid Pt) Begin Dír @ 3.00/100ft: 9317.24ft MD, 3703.801 TVD Target - 1 C-1 04 (B-Mid-pt), Current Target 1 July, 2002 - 15:06 Page 5 of 8 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 Your Ref: 'B' Lateral Plan tied onto (ACTUAL) 7-5/8" Csg Pt. Revised: 1 July, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) OOft) 9367.33 90.835 177.885 3601.12 3702.92 1245.93 S 4891 .54 W 3.000 1245.93 End Dir, Start Sail @ 90.840 : 9367.33ft MD, 3702.92ft TVD ~~ 9400.00 90.835 177.885 3600.65 3702.45 1278.57 S 4890.34 W 5967477.95 N 0.000 1278.57 9500.00 90.835 177.885 3599.19 3700.99 1378.50 S 4886.65 W 5967378.01'N 0.000 1378.50 9600.00 90.835 177.885 3597.73 3699.53 1478.42 S 4882.95 W 5967278.18 N 0.000 1478.42 9700.00 90.835 177.885 3596.28 3698.08 1578.34 S 4879.26 W 5967178.29 N 0.000 1578.34 9800.00 90.835 177.885 3594.82 3696.62 1678.26 S 4875.57 W 5967078.40 N 0.000 1678.26 9900.00 90.835 177.885 3593.36 3695.16 1 .18 S 871.88 W 5966978.52 N 556773.93 E 0.000 1778.18 10000.00 90.835 177.885 3591.91 3693.71 1878.10 S 868.19 W 5966878.63 N 556778.44 E 0.000 1878.10 10100.00 90.835 177.885 3590.45 3692.25 1978.02 S 4864.50 W 5966778.74 N 556782.95 E 0.000 1978.02 10200.00 90.835 177.885 3588.99 3690.79 2077.94 S 4860.81 W 5966678.85 N 556787.46 E 0.000 2077.94 10300.00 90.835 177.885 3587.53 3689.33 2177.87 S 4857.12 W 5966578.97 N 556791 .97 E 0.000 2177.87 10400.00 90.835 177.885 3586.08 2277.79 S 4853.43 W 5966479.08 N 556796.48 E 0.000 2277.79 10500.00 90.835 177.885 3584.62 3 .2 2377.71 S 4849.74 W 5966379.19 N 556801.00 E 0.000 2377.71 10600.00 90.835 177.885 3583.16 3684.96 2477.63 S 4846.05 W 5966279.30 N 556805.51 E 0.000 2477.63 10700.00 90.835 177.885 581.71 3683.51 2577.55 S 4842.35 W 5966179.41 N 556810.02 E 0.000 2577.55 10800.00 90.835 177.885 0.25 3682.05 2677.47 S 4838.66 W 5966079.53 N 556814.53 E 0.000 2677.47 10809.28 90.835 177.885 3580.12 3681.92 2686.74 S 4838.32 W 5966070.26 N 556814.95 E 0.000 2686.74 Begin Dir @ 3.00/100ft : 10809.28ft MD, 3681.92ft TVD 10861.58 89.419 178.561 3580.00 3681.80 2739.02 S 4836.70 W 5966018.00 N 556817.00 E 3.000 2739.02 TARGET (B-Crest) End Dir, Stê~ @ 89.420: 10861.58ft MD, 368 TVD Target - 1 C-1 04 (B-Crest-pt), Currel Target 10900.00 89.419 178.561 3580.39 3682.19 2777.42 S 4835.73 W 5965979.60 N 556818.28 E 0.000 2777.42 11000.00 89.41 9 178.561 3581.40 3683.20 2877.39 S 4833.22 W 5965879.66 N 556821.61 E 0.000 2877.39 11100.00 89.419 178.561 3582.42 3684.22 2977.35 S 4830.71 W 5965779.72 N 556824.94 E 0.000 2977.35 11200.00 89.419 178.561 3583.43 3685.23 3077.31 S 4828.20 W 5965679.79 N 556828.27 E 0.000 3077.31 11300.00 89.419 178.561 3584.45 3686.25 3177.28 S 4825.69 W 5965579.85 N 556831.61 E 0.000 3177.28 11400.00 89.419 178.561 3585.46 3687.26 3277.24 S 4823.18 W 5965479.91 N 556834.94 E 0.000 3277.24 11500.00 89.419 178.561 3586.47 3688.27 3377.20 S 4820.67 W 5965379.97 N 556838.27 E 0.000 3377.20 1 July, 2002 - 15:06 Page 6 0'8 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 Your Ref: 'B' Lateral Plan tied onto (ACTUAL) 7-5/8" Csg Pt. Revised: 1 July, 2002 Kuparuk River Unit Measured Depth (ft) 11552.00 89.419 178.561 Sub-Sea Depth (ft) 3587.00 Vertical Depth (ft) 3688.80 Incl. Azim. orth Slope, Alaska Kuparuk 1C Local Coordinates Northings Eastings (ft) (ft) 3429.18 S 4819.37 W Global Coordinates Northings Ea (ft) 5965328.00 N Dogleg Vertical Rate Section 'OOft) .000 3429.18 Comment TARGET (B-Toe) Total Depth: 11552.00ft MD, 3688.80ft TVD 4-1/2" Liner Target - 1 C-104 (B-Toe), Currer~~ Target 'wf.}t}, All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North; Vertical depths are relative to RKB = 101.8' (MSL). Northings and Eastings are relative to 1437' FN The Dogleg Severity is in Degrees per 100 feet (US). ,,¡tIt Vertical Section is from 1437' FNL,625' FWL and calculated along an Azimuth"of 180.0 :True). Based upon Minimum CUNature type calculations, at a Measured Depth of 11552.00ft., The Bottom Hole Displacement is 5914.86ft., in the Direction of 234.567° (True). Comments Measured Depth (ft) Stathpn Coordinates TVD hingswM" Eastings (ft) ~ ) (ft) 1051.71 N 4887.50 W 737.79 N 4978.29 W 716.12 N 4981.95 W 696.44 N 4985.06 W 450.44 N 4996.78 W 3732.89 176.56 N 4979.86 W 3730.80 118.22 N 4976.24 W 3703.80 1195.91 S 4894.03 W 3702.92 1245.93 S 4891.54 W 3681.92 2686.74 S 4838.32 W 10861 .58 3681.80 2739.02 S 4836.70 W 11552.00 3688.80 3429.18 S 4819.37 W 1 July, 2002 - 15:06 Comment Top West Sak 0 (Measured) Top West Sak B (Measured) 7-5/8" Casing Shoe: 7400.00ft MD, 3740.71ft TVD (Drill out 20' in 6-3/4" Hole) Begin Dir @ 5.00/100ft: 7420.00ft MD, 3742.45ft TVD End Dir, Start Sail @ 92.93° : 7667.01ft MD, 3746.93ft TVD -'" Begin Dir @ 3.00/100ft: 7941.77ft MD, 3732.89ft TVD TARGET (B-wp05) End Dir, Start Sail @ 91.19° : 8000.26ft MD, 3730.80ft TVD TARGET (B-Mid Pt) Begin Dir @ 3.00/100ft: 9317.24ft MD, 3703.80ftTVD End Dir, Start Sail @ 90.84° : 9367.33ft MD, 3702.92ft TVD Begin Dir @ 3.00/100ft : 1 0809.28ft MD, 3681.92ft TVD TARGET (B-Crest) End Dir, Start Sail @ 89.42° : 10861.58ft MD, 3681.80ft TVD TARGET (B-Toe) Total Depth: 11552.00ft MD, 3688.80ft TVD Page 70f8 DrillQuest 2.00.09.006 Kuparuk River Unit Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> 7400.00 3740.71 Targets associated with this wellpath Target Name 1 C-1 04 (B-Crest-pt) 1 C-1 04 (B-Mid-pt) 1C- (wp05 Target) 1 July, 2002 - 15:06 To Measured Vertical Depth Depth (ft) (ft) 7400.00 11552.00 3740.71 3688.80 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 Your Ref: '8' Lateral Plan tied onto (ACTUAL) 7-5/8" Csg Pt. Revised: 1 July,2002 orth Slope, Alaska Kuparuk 1C Casing Detail ,-.... 7-5/8" Casing 4-1/2" Liner Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 3681.80 2739.02 S 4836.70 W Point Current Target Mean Sea Level/Global Coordinates: 3580.00 5966018.00 N 556817.00 E Geographical Coordinates: 700 19' 04.0865" N 1490 32' 21.9976" W 3703.80 1195.91 S 4894.03 W Point Current Target Mean Sea Level/Global Coordinates: 3602.00 5967560.58 N 556747.00 E Geographical Coordinates: 700 19' 19.2640" N 149032' 23.7000" W 3688.80 3429.18 S 4819.37 W Point Current Target Mean Sea LeveVGlobal Coordinates: 3587.00 5965328.00 N 556840.00 E Geographical Coordinates: 700 18' 57.2982" N 149032' 21.4789" W 3730.80 118.22 N 4976.24 W Point Current Target Mean Sea LeveVGlobal Coordinates: 3629.00 5968874.00 N 556654.00 E Geographical Coordinates: 700 19' 32.1891" N 1490 32' 26.1248" W Page 8 0!8 DrillQuest 2.00.09.006 0 ------- -- 600 - 1200 - :::J C/) 6 ~ § 1800- 1/ CD ~ ~ .J:: ã. Q) 0 (ij .2 2400- t Q) > 3000 - ¡¡:: 0 0 to II .r. 0 .S: 3600 - ¡¡¡ (ij 0 C/) Scale: 1 inch = 600ft DrillQuest 2.00.09.006 --~- ~- -~- -°- 6GHÜ. (I -, 7-5/8" Casing 7400.0ft MD 3740.7ft TVD I -1800 I -1200 I -600 i 0 ;;- r!A '.. ~" '" 2000 - ! 1000- -5000 I -4000 I 7-5/8" Casing 7400.0ft MD 3740.7ft TVD 0-- -_.- - -~ - Scale: 1inch = 1000ft I -5000 I -4000 Eastings r~>~. .'.~./::;:"'~"'" ~.~.~.':..'~, 1:'PH I LLI PS,.. ~I~j c~=~~ ~~~~/ ~~~.,~~/.. -3000 I ~; 1 ~T1 H~f<1(;E) -~ - ~~ - ~-~- -- I -3000 Phillips Alaska, Inc. Kuparuk River Unit 1 C Pad 1 -104 -2000 I 0 ! - 2000 -1000 I - 1000 ~ c: :ë t 0 Z ~~ - -_.~--- - -0 -2000 I -1000 i i 0 @ Reference is True North ~". Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: 5968796~65 N, 561631.04 E Ref. Stucture Referance: 280~27 N. 738~73 W Ref~ Geographical Coordinates: 700 19' 31.0425" N, 149030' 00.8575" W 1437' FNl & 625' FWl. SEC. 12 - T11N - R10E RKB Elevation: North Reference: Units: Plan: 1C-104 1 01 ~80ft above Mean Sea level True North Feet (US) 1C-104 Surveys (to 7..5/8" Casing Pt) spar"r"y-sUI1 ê Rle L.' ì Ñ'c;''''''sfë 'Ä 'vI t: 'e 5 A Halliburton Company Scale: 1 inch = 1000ft Eastings -5000 -4000 -3000 I I I " ~:;, I Top West Sak D (Meusured) - .. ..,ß~."""" (88"7' FN.. ~& 1017' FWl.. SEC~ 11.T11N.r~110E) 1 000 ~,::~ Top Wesl Suk B (Measured) ¿,:~ (7GO'FNL &926 'FWL,SEC. 11.TI1N.R1GE) ~:%~~(~:~~6t. ~r/oj;~l', 7.5/8- Casing Shoe: 3740~7nTVD '-'--, 7400~OOfI MD. 3740.7111 TVD '--',- (Drill otA 20' In 6-314' Hole) ""''-... '--"~ -"''-... ErKlt:~i~!;!~~::t r:,~;o:;::::;. ~4::~~~~: I~~'(::~:;¡:[;::';:~~I:) Begin Dir @ :!.O"i!OO!t : 794U'lft MD, :,1:)2~89fl TVD Phillips Alaska, Inc. Kuparuk River Unit 1 C Pad 4 (w 05) 1C-1 :3130.8 "!. 0 _m ~fl~ô.5 . Reference is True North -1 000 - 310(¡.~~ ft ...~-' i?~~" Current Well Properties Plan: 1C-104 "-""""''''''''''''''''''' End Oir, Start Sail ¡(~ 90.04') : 9367~331t MD. 3702.921t TVD Horizontal Coordinates: Ref. Global Coordinates: 5968796.65 N, 561631.04 E Ref. Stucture Referance: 280.27 N, 738.73 W Ref. Geographical Coordinates: 70019' 31.0425" N, 149030' 00.8575" W 1437' FNL & 625' FWL, SEC. 12 - T11N - R10E Ë -2000 - 0 0 369fi.B t\ .-.. '.1 Õ .¡;.,. ~ -0 0 (}1 3681 -9 . "'-' Be,linDir @ :ur'!IOOII: 1 G80R ~!8tt MD. :J68 U)2H TVD RKB Elevation: North Reference: 1 01.8Oft above Mean Sea Level True North Feet (US) // // f~. ~ .".... . II .J:: () .£ A ¡¡¡ (¡j () (J) n( . ray. DA'I-":'tNG S~AV'CeS $I; Hjl!itwirlWtlCêfí1f,Þi4l!i roved 0 ~~$r),.1.2 . -3000 - n $ S. </SI9.37 If 4''-1151~~'~~..~,~nJ.,~~~:,:// iH?' PSI. & IOS3' FIFf, SU. if,TIIN-IWili) __..I:f~l- ~f.;J~(}'. 3686.8ft TVD I -5000 I -3000 I -4000 :::J (J) ~ ÍX! T Ci' West Sak D (Measured) (387' FNL& 1017' FWL, SEC.11-T11N~R10E) ¡ L. T7go:t=~~~~q~~'(~~.~~~~~1H11N-RI0E), TAnGCf{G-Mid ..~. Dir\ ... : MD~ 1VD (4U'F.~' 3500 - J n ,,¡.. 'n. ~ I \, End D~r, Start Sail @ 90.84° : 9367.331t MD, 3702.92ft TVD .;;~~: ' ,,~~,,\: ",~9 ~~~g:~f~~;~~~ : é"'~ ~'òv",,,, ,¿F''''~ d)~~\ //c ð,{i'~ . ~.p'" ¡p'&'" e</"<:> i~/"'~.r,r /'i"::? .(!(X¡(~,~ ~~ '\ ~ '\' . ~ ~ C ~5 . W 1C-104 (wp05) ¡ ,.s"I'(.y~,; '''-''''-. ~'-"'" . r ",. . .. - - Sla;T ~~}~,~ ,~~1HY: 8GGG::Ur MD, ?!3G.BliH -rVO //~/ ! 7-5/8" Casing Shoe: "" '-, Dlr ,0) 3.0 "OOft ~ 1941. 17ft MD, .:!7~2.8"fl TVD / r::nd 74~O.OOft M,~' 3740';,1ft lVD "" EM Dir, Start Sail!@ 92.93" : 7667.01ft MD, 3746.93ít TVD ,/ : MD, 4000 - (Dnll out 20 In 6-3/4 Hole) Begin Dir @ 5.0oí100ft: 742Q.OOft MD, 3742.45ft TVD Begin Dir @ 3.00í100ft : 10809.28ft MD. 3681 ,92ft TVD - I I ¡ I I I I I -¡----- -1000 -500 0 500 1 000 1500 2000 2500 3000 Scale: 1 inch = 500ft 4Nlt.¡.}/' Hi SI..('. í/.lli N../>fIlIOj § II CI) ~ ~ - 1 000 -0 ~ - -1000 en C> c :ë t 0 Z - -2000 Ë 0 0 II .J:: () C - -3000 :;: ¡¡¡ (¡j () (J) ~...-.." , " C) ~§):':I' .. 4~1!2' U!1'j' '~ 1~~~~~~~g 7 OCf~ ;:.;~:¡~.:~e~~f~~:~;)~Ott .J:: ã. Q) D ãi £ Qj > TVD Drill Quest 2.00.09.006 I 3500 Phillips Alaska, Inc. 1 ..» Summary) MD Inc Azim. SSTVD TVD N/S EIW Y X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) (ft) 7045.00 76.08 203.41 3579.64 3681.44 1051.71 N 4887.50 W 596980R 18 N 556735.06 E 5.90 -1051.71 Top West Sak D (Measured) 7377.93 84.60 190.18 3636.91 3738.71 737.79 N 4978.29 W 5969493.53 N 556646.86 E 5.61 -737.79 Top West Sak B (Measured) 7400.00 85.00 189.00 3638.91 3740.71 716.12 N 4981.95 W 5969471.83 N 556643.38 E 5.61 -716.12 7 -5/8" Casing Shoe... (Drill out 20' in 6-314" Hole) 7420.00 85.00 189.00 3640.65 3742.45 696.44 N 4985.07 W 5969452.13 N 556640.42 E 0.00 -696.44 Begin Dir @ 5.00/100ft 7667.01 92.93 176.47 3645.13 3746.93 450.44 N 4996.78 W 5969206.03 N 556630.73 E 6.00 -450.44 End Dir; Start Sail 7941.77 92.93 176.47 3631.09 3732.89 176.56 N 4979.86 W 5968932.31 N 556649.90 E 0.00 -176.56 Begin Dir @ 3.0"/100ft 8000.26 91.18 i '76.42 3629.00 3730.80 118.23 N 4976.24 'vV 5968874,00 N 556654,00 E 3.00 .~i18.23 TAnGET (B"wp05) End Dir: Start Sad 92t17 ~~~4 91.18 1 '76.42 3602.00 3703.80 1195.91 S 4894.03 W 596756059 N 556747.00 E (LOO 1195.9'j TARGET (fJ.Mid Pt) Begin D¡r @ 3.0"/1 DOn 9367.33 90.84 177.89 3601 .12 3702.92 1245.93 S 4891.54 W 5967510.58 N 556749.90 E 3.00 1245.93 End Dir; Start Sail 10809.28 90.84 177.89 3580.12 3681.92 2686.74 S 4838.32 W 5966070.26 N 556814.95 E 0.00 2686.74 Begin Dir @ 3.0<'/1 0 Oft 10861.5B ß9A2 178.56 35BO.OO 3681 J10 2739'()2 S 4B3fL70 IN 5966018.00 N 5S6B17.00 E 3.00 273i)'()2 TARGET End Dìr; Start SaH 11552.00 89.42 i 78.56 3587.00 3688.80 3429,18 S 4819.37 VV 5965328.00 N 556840,00 E 0.00 3429.18 TAnOET (B-Toe) Total Depth Tubing Head Assy, (497-0055) Vetco-Gray Gen II for Single Completion, API 13-5/8" 5000 psi Flange up x Vetco 13-5/8" Female Overshot Bottom Casing Head: ~ l ~ Vetco-Gray, 16" Weld on Bottom x ~ 13-5/8" Male Overshot Top ~ 16" Conductor ~ @ +1-15S' MD Centralization: Weatherford 7-5/8" x 10-1/2" Bowsprings (1) on a stop collar 10ft above the float shoe (1) on a stop collar 10 ft above the float collar (1) on each collar above the float collar to a depth of 6,000' (1) on stop collars located 10ft above and below the port collar. (1) on each of the two collars above and below the port collar PHilLIPS PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY L ~'\~ I ~ I I I I I I I I ~ I I I I I ~ I I I I ~ (X) PUp Joints Casing: I 7-5/8", 29.7#, L-80, BTCM, as ~ ~ required to space out window ~ joint. I (498-6805) 4 foot pup I (498-6800) 6 foot pup ~ (498-6795) 10 foot pup I ~(477-8475) 20 foot pup I I (x) Joints Casing: ~ 7-5/8",29.7#, L-80, BTCM I I I I I I I § I I I mmmt. ~ I I I ( (2) Joints Casing: ~ I 7-5/8",29.7#, L-80, BTCM I I Joint with Thread Locked Box I I ~ ~ ------ Float Shoe: ~ Weatherford Model 303, 7-5/8",29.7#, BTCM 7 -5/S" Shoe: Joint with Float Shoe 7,400' MD /3,739' TVD +/- 85 degrees ~ ~ I ~ ~ I I ~ ~ I ~ I ¡ ~ ~ I I ~ I I I I I I I I I I ~ ~ ~ I I I I I I I I I ~ I I ~ I I TD 9-7/S" Hole: 7,400' MD /3,739' TVD +/- 85 degrees Nabors Rig 245 RKB @ 0' Eastings: 561,631.04 Northings: 5,968,796.65 Elevation: 101.8' AMSL Casing Hanger: Vetco-Gray, with 7-5/8", 29.7#, BTC pin down x Acme box up Port Collar: TAM, 7-5/8", 29.7#, L-80, BTC Pin Set @ +1- 1,000' MD 19S2'.TVD Planned Top of Whipstock @ 7045' MD / 3681 TVD Float Collar: Weatherford Model 402, 7-5/8", 29.7#,BTCM Joint with Float Shoe West Sak WeIl1C-104, AFC AK 0233 Planned Completion Schematic Sheet 1 of 4: Surface Casing Details prepared by Thomas A. Brockway Rev 2 FINAL July 01, 2002 ~'"tJ §-::t 15:- ë)~ . -<I ~... :g'"tJ Fen ~:Þ m- :riD» ot/) hi" ~D» 0'" 0- ~~ z(') -<. :e en." CD :s"-cn CDQ)... CD:Jen ~:JQ) .- CD " 0D.:e ;OCD .. 0 - ....3:::: o'E.o ~ CD I <.......¡" CD -. 0 "'°.þ. .... :J ... -. en :Þ :J(')." ~:s"o CCD:Þ CD3" ;rao -. -. ~ ëñ(')w w ;! 0 3 Q) c... en c:: ::0)::. 't) ~ ( ). ~ C '" OJ {g ....d\) a Q) .. ." (') ~ ~~~[ cþQ)t:)" ~ r- "" 'c:::: Top of Whipstock to be @ +1-7,045' MD /3,681 TVD See Sheet 1 for Casing Details Liner Top Packer Set @ +1- 7,250' MD I 3,725 TVD (1) Set Shoe Assembly, Baker, consisting of: (1) Set Shoe, Baker Model 'GPV', 5.560" Max aD, 5", 18# SLHT Box. (1) 18.5 ft Pup Joint, 5", 15#, SLHT, with weephole. (1) Crossover, 4", 11.6#, SLHT Box x 5", 18#, SLHT Pin (2) Joints 4" Blank Pipe, 4", 9.5#, L-80, SLHT. (x) joints 4" x 4-1/2" Screen, Baker Excluder 2000,4",9.5#, SLHT (Screen aD = 4.9") (x) joints 4" Blank Pipe, 4",9.5#, L-80, SLHT Note: Screen and blank pipe will be run by alternting (1) joint of Excluder screen with (1) joint of Blank pipe through the production zone as required from 'GPV' Set Shoe Assembly to Model 'CMD' Sliding Sleeve. (x) Joints 4" Blank Pipe, 4", 9.5#, L-80, SLHT, as required inside the 7-5/8" Casing to space out the packer +/- 80 feet below the bottom trip anchor of the whipstock assembly (i.e. 103 feet below the top of th whipstock. Top of the whipstock is planned for 7,045') (1) Crossover Sub, 4-1/2", 11.6#, SLHT Box x 4",9.5#, SLHT Pin. (1) Joint 4-1/2" Blank Pipe, 4-1/2", 11.6#, L-80, SLHT (1) Sliding Sleeve, Baker Model 4-1/2" 'CMD', wI 3.43" ID, 4-1/2", 11.6# SLHT Box x Pin (1) Joint 4-1/2" Blank Pipe, 4-112",11.6#, L-80, SLHT. (1) Crossover Sub, Baker, 5", 18#, SLHT Box x 4-112", 11.6#, SLHT Pin (1) KOIV (Knockout Isolation Valve), Baker Model'C', 5",18#, SLHT Box x Pin (1) Packer Assembly, Baker, consisiting of: (1) Crossover Sub, Baker, 5-112", 17#, SLHT Box x 5" 18# SLHT Pin (1) Mill Out Extension, Baker, 3' Long, 5-112", 17# SLHT pin x pin (1) Packer, Baker Model'SC1-R' (76B2-40), 7-5/8",24-29.7#, wI 5-112", 17#, SLHT box down. Il~=~~~=~=~=~~~=~=~~=~~= I l~~~~~~~~~~~~~~ 1~~~~~~~~~~~~~3 ) 6-3/4" Open Hole TD: +1- 11,552' MD I 3,689' TVD Surface I Production Casing 7-5/8" 29.7# L-80 BTC Mod Set @ 7,400' MD /3,741 TVD Directional Profile Revision for KRU well 1 C-l 04 - APD#202-061 ~ '2.-- OG:, I --~~---- Subject: Directional ProfIle Revision for KRU welllC-104 - APD#202-061 Date: Mon, 24 Iun 2002 15:18:44 -0800 From: "Thomas A Brockway" <tbrockw@ppco.com> To: winton_aubert@admin.state.ak.us CC: "Steve McKeever" <smckeev@ppco.com>, "Lewis Ledlow" <l1edlow@ppco.com> Winton, Attached is the revised directional profile and updated cement calculations for KRU well 1C-104ML. As I mentioned in my earlier phone message, we needed to revise the directional path of the surface hole to avoid crossing a large fault that was identified by the asset team over the weekend. The entry point target at the top of the West Sak sands has changed as a result of this profile modification, but is less than 500 feet from the target point identified on the original permit. No other changes are planned from the original permit. If you have any questions or require and further information, please don't hesitate to contact me. Tom Brockway Lead Drilling Engineer Phillips Alaska, Inc. Ph: (907) 263-4135 Cell: (907) 244 - 5956 Fax: (907) 265-1535 (See attached file: 1C 104 wp03 v622.pdf) (See attached file: 1C-104 Surface Cementing Summary V4.doc) - . -or ~r" . ...--._....-.... ..... ".- -~ h'" " .. -_...-.. .. ..,.. -u ".... .. .-.. ....- . -.. -....-.-, ..-..-... ..-. "--.. -- --... ......-.... ......... -. --.... -. ,-. .... .._~.. ft. ... . ~~ , ._.._-..-...",.,-.. ....... ............r.... ....n. . .-. ....... ,. - ... , , Name: lC_lO~_\\"p03 \'622.pdf IIIC 104 wp03 V622.Pd1 Type: Portable Document Format (applicationJpdf)ì I....¥,<~.~,.",»,.,,,,,,,,.~~~.,~»»,,,,........~~..,,...~..w~w~..w~.~.,.,,,,.,,,«<.,,*..,,~~,""»»»....ww... .~.~.~~.~,~,~~,,~~.~:~..:?~.~.~~~~""""~..~"»~..~.~.......~..,.,~...."....~..w,~.,w..,~.~.~..~~w~~..~~,..~,..,.~~...~..<.,......~w........~",'.,.w,....~~...~..,~.....~..~..~..w~w.",.w~.~J ---~"""_"N"''''''~~-' '-"-'.'"''''''''''''--'''~_''N''"''''W'''~''''' Name: lC-104 Surtàce Cementing Summary V4.doc [j] 1 C-1 04 Surfàce Cementing Sunn11ary V 4.doc I: Type: WINWORD File (application/msword) »,~oV......'....'~'~O~N"~.""»'»».,"."~~,O~......"v",>"W_O~"OO,.W......"...,..,>"OW~'">"'~,,!~"~~,~~,~!~>~:M~'~~~~^~'W~"-"~"~"='""".'..'."".""~"""">.'M"...,.~ ~~~i~~ ~,~ Kupl!rql!9RiVer Unit tlortfl¿.f~1oPé; Alaska /f¡tip,f rukt1C, Slot 1C-104 <P(an:.,Jl'C-104 - 1C-104 (wp03) ~ ~ Revised: 21 June, 2002 PROPOSAL REPORT 21 June, 2002 Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Surface Coordinates: 5968796.65 H, 561631.04 E (70° 19' 31.0425" H, 149030' 00.8575" W) Surface Coordinates relative to Project H Reference: 968796.65 H, 61631.04 E (Grid) Surface Coordinates relative to Stucture Referance: 280.27 H, 738.73 W (True) Kelly Bushing: 101.80ft above Mean Sea Level sp .I''''''Y-SLJr1 DPULL.,tf,l'. ~~..."V , C... Á kiüÌ<b.ntãn .:;;.oNpiimy Proposal Ref: pr09902 Sperry-Sun Drilling Services . Proposal Report for Plan: 1C-104 - 1C-104 (wp03) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 21 June, 2002 Slope, Alaska Kuparuk River Unit Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Easting s Northings Eastinå~t Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -101.80 0.00 0.00 N 0.00 E 0.00 SHL: X=561631.04'E & Y=5968796.65'N (1437' FNL & 625 FWL, SEC. 12-T11N-R10E) 100.00 0.000 0.000 -1.80 100.00 0.00 N 0.000 0.00 200.00 0.000 0.000 98.20 200.00 0.00 N 0.000 0.00 250.00 0.000 0.000 148.20 250.00 0.00 N 0.000 0.00 Begin Dir @ 3.00/100ft (in 9-718" c;j:~\;;w5968797.30 N Hole) : 250.00ft MD, 250.00ft TVD 300.00 1.500 0.000 198.19 299.99 561631.03 E 3.000 -0.65 400.00 4.500 0.000 298.05 399.85 5968802.54 N 561630.99 E 3.000 -5.89 500.00 7.500 0.000 397.49 499.29 5968812.99 N 561630.91 E 3.000 -16.34 516.67 8.000 0.000 414.00 515.80 5968815.24 N 561630.89 E 3.000 -18.59 Increase in Dir Rate @ 5.00/100ft : 516.67ft MD, 515.80ft TVD 600.00 10.592 339.501 2.68W 5968828.19 N 561628.10 E 5.000 -31.57 700.00 14.684 326.166 12.97 W 5968847.26 N 561617.66 E 5.000 -50.71 800.00 19.204 318.761 73.62 N 30.87 W 5968870.02 N 561599.56 E 5.000 -73.62 900.00 23.910 314.138 100.12 N 56.28 W 5968896.30 N 561573.94 E 5.000 -1 00.1 2 1000.00 28.711 310.974 130.00 N 88.98 W 5968925.92 N 561541.00 E 5.000 -130.00 1100.00 33.566 308,655 163.04 N 128.72 W 5968958.63 N 561500.98 E 5.000 -163.04 1200.00 38.454~ 306,864 198.98 N 175.22 W 5968994.19 N 561454.19 E 5.000 -198.98 1300.00 43.364 305.422 1114.07 1215.87 237.56 N 228.11 W 5969032.33 N 561400.99 E 5.000 -237.56 1333.23 45.000 305.000 1137.91 1239.71 250.92 N 247.03 W 5969045.53 N 561381.96 E 5.000 -250.92 Decrease in Dir Rate @ 3.0°/1 OOft . 1333.23ft MD, 1239.70ft TVD 1184.39 1286.19 277.92 N 286.62 W 5969072.21 N 561342.15 E 3.000 -277.92 1251.21 1353.01 318.06 N 349.24 W 5969111.83 N 561279.20 E 3.000 -318.06 1313.12 1414.92 356.83 N 414.15 W 5969150.06 N 561213.97 E 3.000 -356.83 Increase in Dir Rate @ 5.0°/1 OOft : 1597.73ft MD, 1414.92ftTVD 1600.00 52.090 299.911 1314.52 1416.32 357.72 N 415.70 W 5969150.95 N 561212.41 E 5.000 -357.72 1700.00 56.090 296.206 1373.17 1474.97 395.74 N 487.17 W 5969188.38 N 561140.63 E 5.000 -395.74 1800.00 60.191 292.837 1425.95 1527.75 430.93 N 564.44 W 5969222.93 N 561063.08 E 5.000 -430.93 1891.19 64.000 290.000 1468.63 1570.43 460.31 N 639.44 W 5969251.69 N 560987.84 E 5.000 -460.31 End Dir, Start Sail @ 64.0° : 1891.19ft MD, 1570.43ft TVD 1900.00 64.000 290.000 1472.49 1574.29 463.02 N 646.89 W 5969254.34 N 560980.37 E 0.000 -463.02 --"---'-'---'----""--'-------------"-'-'---'------'---'-----..---....-..-------- 21 June, 2002 - 21 :31 Page 2 of 10 DrillQuest 2.00.09.006 Kuparuk River Unit Measured Depth (ft) Incl. Azim. 2000.00 64.000 290.000 2100.00 64.000 290.000 2200.00 64.000 290.000 2277.56 64.000 290.000 2300.00 64.000 290.000 2400.00 64.000 290.000 2500.00 64.000 290.000 2600.00 64.000 290.000 2700.00 64.000 290.000 2800.00 64.000 290.000 2866.10 64.000 290.000 2900.00 64.000 290.000 3000.00 64.000 290.000 3100.00 64.000 290.000 3200.00 64.000 290.000 3300.00 64.000 3400.00 64.000 3500.00 64.000 : 3509.3;,,9> 64.000 3600 .0;ff¡¡~~,~64. oé}o 3700. 3800.0 3900.0 4000.00 4100.00 290:OQ:O .,.' 29GiOÖO ~~ ~. 290,POO ~ 290.0QP'~ 290.dðo 290.000 290.000 290.000 290.000 290.000 4200.00 64.000 290.000 4300.00 64.000 290.000 4400.00 64.000 290.000 4500.00 64.000 290.000 4600.00 64.000 290.000 21 June, 2002 - 21 :31 -.------------ Sub-Sea Depth (ft) 1516.33 1560.1 6 1604.00 1638.00 1647.84 1691.68 1735.51 1779.35 1823.19 1867.02 Vertical Depth (ft) 1618.13 1661.96 1705.80 1739.80 1749.64 1793.48 1837.31 1881 .15 1924.99 1968.82 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 - 1C-104 (wp03) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 21 June, 2002 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates ~~ Northings EasJ~ng~~. (ft) (ft) 493.76 N 524.50 N 555.24 N 579.08 N 585.98 N 616.72 N6 ,; :t~ç~i:~ayv~:";i,,}'!5969404.57 N 647.46 N:{i>\ .,,~~iŠ3.64':W''C 5969434.62 N .20 N :,'; " ::"1~238.1 oW 5969464.66 N 5 N 322.56 W 5969494.71 N N 407.02 W 5969524.75 N p86.2.1;j1,, 0.05 73.88 2178.00 2217.72 2261.56 2305.40 2349.23 2393.07 2436.91 2480.74 2524.58 2568.42 2612.26 2656.09 2188.01 2231.85 2275.68 2279.80 2319.52 2363.36 2407.20 2451.03 2494.87 2538.71 2582.54 2626.38 2670.22 2714.06 2757.89 893.39 N 924.13 N 954.87 N 957.76 N 985.61 N 1016.35 N 1047.09 N 1077.83 N 1108.57 N 1139.31 N 1170.05 N 1200.79 N 1231.53 N 1262.28 N 1293.02 N 731.35 W 5969284.39 N 815.80 W 5969~,lf1..43 N 900.26 W 5!!6Ø34;ifi~8 N 965.77 W .,,'~ ,. 59tf~361{V:8\ N 98'?,h72 W;;1"~969374.5ä"N ~:5~;'. . ,',,» -~ .':,..~ >.':, 1462.85 W 1491.48 W 1575.94 W 1660.39 W 1744.85 W 1829.31 W 1913.77 W 1998.23 W 2006.16 W 2082.69 W 2167.15 W 2251.61 W 2336.07 W 2420.53 W 2504.98 W 2589.44 W 2673.90 W 2758.36 W 2842.82 W 2927.28 W Page 3 of 10 5969544.61 N 5969554.80 N 5969584.85 N 5969614.89 N 5969644.94 N 5969674.98 N 5969705.03 N 5969735.08 N 5969737.90 N 5969765.12 N 5969795.17 N 5969825.21 N 5969855.26 N 5969885.30 N 5969915.35 N 5969945.40 N 5969975.44 N 5970005.49 N 5970035.53 N 5970065.58 N 560895.66E 60810.96 E 726.25 E 5 60.55 E 560641.54 E 560556.83 E 560472.12 E 560387.41 E 560302.70 E 560217.99 E 560162.00 E 560133.29 E 560048.58 E 559963.87 E 559879.16 E 559794.45 E 559709.74 E 559625.03 E 559617.08 E 559540.33 E 559455.62 E 559370.91 E 559286.20 E 559201.49 E 559116.78 E 559032.07 E 558947.36 E 558862.66 E 558777.95 E 558693.24 E 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 . Slope, Alaska Kuparuk 1 C Comment -493.76 -524.50 -555.24 -579.08 Base Permafrost -585.98 -616.72 -647.46 -678.20 -708.95 -739.69 -760.01 Top T-3 -770.43 -801.17 -831.91 -862.65 -893.39 -924.13 -954.87 -957.76 Top K-15 -985.61 0.000 -1016.35 0.000 -1047.09 0.000 -1077.83 0.000 -1108.57 0.000 -1139.31 0.000 -1170.05 0.000 -1200.79 0.000 -1231.53 0.000 -1262.28 0.000 -1293.02 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 - 1C-104 (wp03) Your Ref: Parameters (60 DLS, 650 inc, 200' Pump Tangent) Revised: 21 June, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eas" (ft) (ft) (ft) (ft) (ft) (ft) 4700.00 64.000 290.000 2699.93 2801.73 1323.76 N 3011.74W 5970095.63 N 4800.00 64.000 290.000 2743.77 2845.57 1354.50 N 3096.20 W 5970~1~~.67 N 4900.00 64.000 290.000 2787.60 2889.40 1385.24 N 3180.66 W 5970155.72 N 5000.00 64.000 290.000 2831.44 2933.24 1415.98 N 3265.12 W 5970185:76 N 5100.00 64.000 290.000 2875.28 2977.08 1446.72 N 334t.57 97.Q~J5.817N , 34;f:': >2'40. 5200.00 64.000 290.000 2919.12 3020.92 ,.; ~~ 5970245.86 N 558184.99 E 5300.00 64.000 290.000 2962.95 3064.75 ~,(~'18.4 .i\1ff0"5970275.90 N 558100.28 E 5391.19 64.000 290.000 3002.93 3104.73 ~ 595.51 5970303.30 N 558023.04 E 5400.00 63.955 289.512 3006.79 3108.59 602.96 W 5970305.91 N 558015.56 E 5466.16 63.668 285.839 3036.00 3137.80 3659.51 W 5970323.47 N 557958.86 E 5500.00 63.557 283.955 3051.04 3688.81 W 5970331.03 N 557929.51 E 5600.00 63.376 278.369 3095.74 3776.53 W 5970347.62 N 557841.64 E 5700.00 63.413 272.777 3140.55\, ~~ 3865.47 W 5970355.56 N 557752.63 E 5800.00 63.668 267.199 ~3185¡¡14 3954.95 W 5970354.81 N 557663.16 E 5900.00 64.137 261.655 3229n,6 . " 4044.28 W 5970345.35 N 557573.91 E :::4'-, ~tÎi68 .~;4if§ 5991.19 64.747 256.646, 3370.32 1566.48 N 4125.03 W 5970329.20 N 557493.28 E 6000.0q 64.747 256:646 3272.28 3374.08 1564.64 N 4132.79 W 5970327.29 N 557485.54 E 6025.13 64.747 256.646 3283.00 3384.80 1559.39 N 4154.90 W 5970321.86 N 557463.47 E 6100.00 64.747 256.646 3314.94 3416.74 1543.75 N 4220.79 W 5970305.68 N 557397.72 E 6135. 4'f~4;7 ~.,~z 256.646 3330.00 3431.80 1536.38 N 4251.85 W 5970298.05 N 557366.72 E 6200.0 64.747 256.646 3357.60 3459.40 1522.86 N 4308.78 W 5970284.07 N 557309.89 E 6201.41 64.747 256.646 3358.20 3460.00 1522.57 N 4310.02 W 5970283.77 N 557308.66 E 6300.00 65.366 248.910 6400.00 66.393 241.166 6490.20 67.644 234.302 3501.63 3542.55 3577.80 3399.83 3440.75 3476.00 1496.11 N 1457.61 N 1413.30 N 4395.32 W 4477.97 W 4548.12 W 5970256.61 N 5970217.44 N 5970172.55 N 557223.58 E 557141.25 E 557071.47 E --'----'--"---'----'-'---'---"'-------'-'--'---"'--.---.---.-----.--- --------.--- ----..---- DrillQuest 2.00.09.006 21 June, 2002 - 21:31 Page 4 of 10 . Slope, Alaska Kuparuk 1C Comment -1323.76 -1354.50 -1385.24 -1415.98 -1446.72 0.000 -1477.46 0.000 -1508.20 0.000 -1536.23 Begin Dir @ 5.001100ft : 5391.19ft MD, 3104.73ft TVD 5.000 -1538.91 5.000 -1556.93 Top Ugnu C 5.000 -1564.73 5.000 -1582.04 5.000 -1590.72 5.000 -1590.69 5.000 -1581.97 5.000 -1566.48 BEGIN PUMP TANGENT @ 64.75 5991.19ft MD, 3370.32ft TVD 0.000 -1564.64 0.000 -1559.39 Top Ugnu B 0.000 -1543.75 0.000 -1536.38 Top Ugnu A _.~ 0.000 -1522.86 0.000 -1522.57 END PUMP TANGENT; Begin Dir @ 7.14°/100ft: 6201.41ft MD, 3460.00ft TVD 7.141 -1496.11 7.141 -1457.61 7.141 -1413.30 K-13 Kuparuk River Unit Measured Depth (ft) Incl. Azim. 6500.00 67.797 233.564 6600.00 69.546 226.130 6700.00 71.603 218.878 6728.33 72.237 216.857 6728.43 72.237 216.857 6786.29 74.118 212.611 6800.00 74.576 211.617 6900.00 78.040 204.493 6938.95 79.440 201.771 7000.00 81.679 197.554 7085.21 84.875 191.745 7100.00 85.436 190.744 7200.00 89.257 184.005 7224.33 90.190 182.370 Sub-Sea Depth (ft) 3479.72 3516.13 3549.42 3558.22 3558.25 3575.00 3578.70 3602.39 3610.00 3620.02 Vertical Depth (ft) 3581.52 3617.93 3651.22 3660.02 3660.05 3676.80 3680.50 3704.19 3711.80 3721.82 3731.80 5 8 .00 7244. 182.370 180.756 179.296 7400.00 91.005 179.296 7500.00 91.005 179.296 7600.00 91.005 179.296 7700.00 91.005 179.296 7800.00 91.005 179.296 7900.00 91.005 179.296 8000.00 91.005 179.296 8100.00 91.005 179.296 21 June, 2002 - 21 :31 3635.93 3635.54 3634.83 3633.96 3632.20 3630.45 3628.70 3626.94 3625.19 3623.44 3621.68 3737.73 3737.34 3736.63 3735.76 3734.00 3732.25 3730.50 3728.74 3726.99 3725.24 3723.48 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 - 1C-104 (wp03) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 21 June, 2002 Local Coordinates Northings Easting s (ft) (ft) 1407.96 N 1347.92 N 1278.43 N 1257.17 N 4555.45 W 4626.55 W 4690.19 W 4706.72 W . Global Coordinates Northings East.ings ~ (ft) (ft} 5970167.15 N 5970Jt9,ê.53 N 59,7963~ió1 N ~~ 59.1~?15-;:tg~N 783.34 N 727.70 N 677 .39 N 627.72 N 527.74 N 427.76 N 327.79 N 227.81 N 127.83 N 27.85 N 72.12 S 4847.58 W 4850.45 W 4863.25 W 4864.61 W 4865.43 W 4866.95 W 4866.97 W 4866.36 W 4865.14 W 4863.91 W 4862.68 W 4861.45 W 4860.22 W 4859.00 W 4857.77 W Page 5 of 10 ~ I. - 75-?iP:'0?,' i'f!j¡èj" 5969969.28 N 5969958.04 N 5969871.98 N 5969836.73 N 5969779.87 N 5969697.87 N 5969683.39 N 5969584.30 N 5969560.00 N 5969540.01 N 5969484.35 N 5969434.04 N 5969384.38 N 5969284.41 N 5969184.45 N 5969084.49 N 5968984.52 N 5968884.56 N 5968784.59 N 5968684.63 N 556914.10 E 556882.94 E 556876.01 E 556831.10 E 556816.38 E 556796.60 E 556775.90 E 556773.14 E 556761.15 E 556760.00 E 556759.34 E 556758.28 E 556758.67 E 556759.68 E 556761.73 E 556763.78 E 556765.83 E 556767.88 E 556769.93 E 556771.98 E 556774.03 E Slope, Alaska Kuparuk 1 C Comment -1407.96 7.141 -1347.92 7.141 -1278.43 7.141 -1257.17 Continue Dir @ 7.74°/100ft: 6728.33ft MD, 3660.02ft TVD 0.000 -1257.09 .~ 7.739 -1211.59 TopWestSakD 7.739 -1200.40 Planned Window Pt for '0' Lateral 7.739 -1114.72 7.739 -1079.59 Top West Sak C 7.739 -1022.89 7.739 7.739 7.739 7.739 0.000 3.000 3.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 -941.06 Top West Sak B -926.61 -827.62 -803.33 -783.34 TARGET (B-Heel) 7-5/8" Casing Pt 7224.33ft MD, 3737.80ft TVD ... Dr out 6-314" Hole 7 -518/1 Casing Target - 1 C-1 04 (B-Heel), Current Target Begin Dir @ 3.00° /1 OOft : 7244.33ft MD, 3737.73ft TVD -727.70 -677.39 End Dir, Start Sail @ 91.01 ° : 7350.32ft MD, 3736.63ft TVD -627.72 -527.74 -427.76 -327.79 -227.81 -127.83 -27.85 72.12 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for Plan: 1C-104 - 1C-104 (wp03) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 21 June, 2002 Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Easting s Northings Ea~ting!~, Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) {ft},~, ~~~' 8200.00 91.005 179.296 3619.93 3721.73 172.10 S 4856.54 W 5968584.67 N 556176~08 E 0.000 172.10 8300.00 91.005 179.296 3618.18 3719.98 272.08 S 4855.31 W 59681~~. 70 N «,;,;556718.13 E 0.000 272.08 8400.00 91.005 179.296 3616.42 3718.22 372.05 S 4854.09 W 5968364174 N 'iV($,f¡)p780.17 E 0.000 372.05 8500.00 91.005 179.296 3614.67 3716.47 472.03 S 4852.86 W ~~.. 59è~284~78 N 5~~782.22 E 0.000 472.03 8600.00 91.005 179.296 3612.92 3714.72 572.01 S 485~,~63 W;: ";.'&96a~84.a1?ÞN 556784.27 E 0.000 572.01 8700.00 91.005 179.296 3611 .16 3712.96 ~ 4ßpO':4ÖW~:~~:;6968084.85 N 556786.32 E 0.000 671.99 8800.00 91.005 179.296 3609.41 3711.21 ,~4'849. fiV¡J .~,:,,~ 5967984.89 N 556788.37 E 0.000 771.96 8900.00 91.005 179.296 3607.66 3709.46 ~ ~~ 847.95\1\1 5967884.92 N 556790.42 E 0.000 871.94 9000.00 91.005 179.296 3605.90 3707.70 846.72 W 5967784.96 N 556792.4 7 E 0.000 971.92 9100.00 91.005 179.296 3604.15 3705.95 845.49 W 5967685.00 N 556794.52 E 0.000 1071.89 ~).~"^~ 9200.00 91.005 179.296 3602.40 3704.20~ < 4844.26 W 5967585.03 N 556796.57 E 0.000 1171.87 9208.35 91.005 179.296 3602.25 3704;05 " 4844.16 W 5967576.69 N 556796.74 E 0.000 1180.22 Begin Dir @ 3.00°/1 OOft : 9208.35ft MD, 3704.05ft TVD 9224.04 90.817 179.728 1195.91 S 4844.03 W 5967561.00 N 556797.00 E 3.000 1195.91 TARGET (B-Mid pt) Start Sail @ 90.81 r : 9224.04ft MD,3703.80ft TVD Target-1C-104 (B-Mid-pt), Current Target 9300.00 90.817 ~ 179.728 3702.72 1271.86 S 4843.66 W 5967485.05 N 556797.98 E 0.000 1271.86 9400.00 90.8107 179.7-28 3701.29 1371.85 S 4843.19 W 5967385.07 N 556799.28 E 0.000 1371.85 9500.00 90.817 ~ 179.728 3598.07 3699.87 1471.84 S 4842.72 W 5967285.09 N 556800.58 E 0.000 1471.84 9600.0;0, <. 90.8l7 ~.: 179.728 3596.64 3698.44 1571.82S 4842.24 W 5967185.11 N 556801.87 E 0.000 1571.82 9700.0ff: 90.817 ~~ 179.728 3595.22 3697.02 1671.81 S 4841.77 W 5967085.13 N 556803.17 E 0.000 1671.81 9800.0(j)L'c 90.817 179.728 3593.79 3695.59 1771 .80 S 4841.29 W 5966985.15 N 556804.46 E 0.000 1771.80 9900.00 90.817 179.728 3592.36 3694.16 1871.79S 4840.82 W 5966885.16 N 556805.76 E 0.000 1871.79 10000.00 90.817 179.728 3590.94 3692.74 1971.78S 4840.34 W 5966785.18 N 556807.06 E 0.000 1971.78 10100.00 90.817 179.728 3589.51 3691.31 2071.77 S 4839.87 W 5966685.20 N 556808.35 E 0.000 2071.77 10200.00 90.817 179.728 3588.09 3689.89 2171.76 S 4839.39 W 5966585.22 N 556809.65 E 0.000 2171.76 10300.00 90.817 179.728 3586.66 3688.46 2271.75 S 4838.92 W 5966485.24 N 556810.94 E 0.000 2271.75 10400.00 90.817 179.728 3585.24 3687.04 2371.73 S 4838.44 W 5966385.26 N 556812.24 E 0.000 2371.73 -------'--.------..---- ---------- 21 June, 2002 - 21 :31 Page 6 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 1 C-1 04 - 1 C-1 04 (wp03) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 21 June, 2002 . Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates A Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastingt;. ~ (ft) (ft) (ft) (ft) (ft) (ft) (1*)1" 10500.00 90.817 179.728 3583.81 3685.61 2471.72 S 4837.97 W 10600.00 90.817 179.728 3582.39 3684.19 2571.71 S 4837.49 W 0.000 10700.00 90.817 179.728 3580.96 3682.76 2671.70 S 4837.02 W 0.000 10767.33 90.817 179.728 3580.00 3681.80 2739.02 S 4836.70 W 0.000 10800.00 90.064 179.100 3579.75 3681.55 2 .69 S ~836.36'W 5965985.33 N 556817.60 E 3.000 10830.94 89.352 178.505 3579.91 3681.71 '2802)62 S ~~.. ~~ 835.72 W 5965954.41 N 556818.50 E 3.000 10900.00 89.352 178.505 3580.69 ':287J~65 S 4833.92 W 5965885.39 N 556820.87 E 0.000 11000.00 89.352 178.505 3581.82 ' 2971.61 S 4831.31 W 5965785.46 N 556824.30 E 0.000 111 00.00 89.352 178.505 3582.95 ~4:/:~' 3071.57 S 4828.70 W 5965685.52 N 556827.73 E 0.000 11200.00 89.352 178.505 3584,O&~' 3'171.53 S 4826.09 W 5965585.59 N 556831 .16 E 0.000 , . 11300.00 89.352 178.505 358~¡21 ~. 3687.01 3271.49 S 4823.48 W 5965485.65 N 556834.59 E 0.000 11400.00 89.352 17:~*~~~¡,;\",ê586:35 ' 3688.15 3371.45 S 4820.87 W 5965385.72 N 556838.02 E 0.000 11457.75 89.352 1~ .' :St)87.00 3688.80 3429.18 S 4819.37 W 5965328.00 N 556840.00 E 0.000 et (US) unless otherwise stated. Directions and coordinates are relative to True North. are relative to RKB = 101.8' (MSL). Northings and Eastings are relative to 1437' FNL, 625' FWL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1437' FNL, 625' FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11457.75ft., The Bottom Hole Displacement is 5914.86ft., in the Direction of 234.56r (True). 21 June, 2002 - 21:31 Page 7 of 10 ~--_._-----~--_._~~-._-_.~..~---_._...__._---- 2471.72 2571.71 2671.70 2739.02 2771.69 Slope, Alaska Kuparuk 1 C Comment TARGET (B-Crest pt) Begin Dir @-'~ 3.000/100ft: 10767.33ft MD, 3681.80ft TVD Target - 1C-104 (B-Crest-pt), Currel Target 2802.62 End Dir, Start Sail @ 89.35° : 10830.94ft MD, 3681.71ftTVD 2871.65 2971.61 3071.57 3171.53 3271.49 3371.45 3429.18 TARGET (B-Toe) Total Depth: 11457.75ft MD, 3688.80ft TVD 4-1/2" Liner Target -1C-104 (B-Toe), Current Target -" DrillQuest 2.00.09.006 Kuparuk River Unit Comments Measured Depth (ft) 0.00 250.00 516.67 1333.23 1597.73 1891.19 5391.19 5991.19 6201.41 6728.33 6800.00 7224.33 7244.33 7350.32 9208.35 ____m-"___"'~---,----""-' .. 21 June, 2002 - 21 :31 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 - 1C-104 (wp03) Your Ref: Parameters (60 DLS, 650 inc, 200' Pump Tangent) Revised: 21 June, 2002 Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 250.00 515.80 1239.70 1414.92 1570.43 3104.73 3370.32 3460.00 3660.02 0.00 N 0.00 N 18.59 N 250.91 N 356.83 N 460.31 N 1536.23 N 1566.48 N 1522.57 N 1257.17 N 1200AON ~. 8D3.3'3 W~ ~. ~~783:;g4 N ..:.' 7 .38~tt& 0.22 S 1195.91 S 2739.02 S 2802.62 S 3429.18S 0.00 E O.OOE 0.00 E 247.03 W 414.15 W SHL: X=561631.04'E & Y0~~68,?~6.65~~(1437' FN1:}I& 625' FWL, SEC. 12-T11N-R10E) Begin Dir @ 3.00t~:9°ft(ipg~i'Iß" HQle) : 250.00ft MD, 250.00ft TVD IncreaseiRH~~.;Råt~~@ KOtÍ1qQ~ :-S16.67ft MD, 515.80ft TVD Decre~~~:¡n Di~:fat~;:@ 3..~.~11bOft: 1333.23ft MD, 1239.70ft TVD Increa$éjnQjf:;~ate ~{9.0õ/1 OOft : 1597.73ft MD, 1414.92ft TVD d Dir, ail @ 64.0° : 1891.19ft MD, 1570.43ft TVD in Dir .00/100ft: 5391.19ft MD, 3104.73ft TVD ,N PUMP TANGENT @ 64.75° : 5991.19ft MD, 3370.32ftTVD PUMP TANGENT; Begin Dir@ 7.14°/100ft: 6201.41ft MD, 3460.00ftTVD Continue Dir @ 7.74°/100ft: 6728.33ft MD, 3660.02ft TVD Planned Window pt for 'D' Lateral TARGET (B-Heel) 7-5/8" Casing pt: 7224.33ft MD, 3737.80ft TVD ... Drill out 6-3/4" Hole Begin Dir @ 3.00°/1 OOft: 7244.33ft MD, 3737.73ft TVD End Dir, Start Sail @ 91.01 ° : 7350.32ft MD, 3736.63ft TVD Begin Dir @ 3.00°/1 OOft : 9208.35ft MD, 3704.05ft TVD 4844.03 W 4836.70 W 4835.72 W 4819.37 W TARGET (B-Mid pt) Start Sail @ 90.81 r : 9224.04ft MD,3703.80ft TVD TARGET (B-Crest pt) Begin Dir@ 3.000/100ft: 10767.33ft MD, 3681.80ft TVD End Dir, Start Sail @ 89.35° : 10830.94ft MD, 3681.71ft TVD TARGET (B-Toe) Total Depth: 11457.75ft MD, 3688.80ft TVD --.-...-----.--"-....------------- Page 8 of 10 . . North Slope, Alaska Kuparuk 1C ~~\ DrillQuest 2.00.09.006 Kuparuk River Unit Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 - 1C-104 (wp03) Your Ref: Parameters (60 DLS, 650 inc, 200' Pump Tangent) Revised: 21 June, 2002 Profile Penetration Point Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) Northings (ft) 1625.87 1 .200 180.000 2277.56 1739.80 1638.00 W '["'Base Permafrost 1880.08 1.200 180.000 2866.10 1997.80 ~ 1896.00 Top T -3 2157.94 1.200 180.000 3509.39 2279.80 2178.00 Top K-15 3003.39 1.200 180.000 5466.16 3137.80 3036.00 Top Ugnu C 3250.33 1.200 180.000 6025.13 3384.80 3283. Top Ugnu B 3297.82 1.200 180.000 6135.30 15 .38 N 4251.85 W Top Ugnu A 3446.40 1.200 180.000 6490.20 1413.30 N 4548.12 W K-13 3549.62 1.200 180.000 6786.29 1211.59 N 4738.31 W Top West Sak 0 3587.39 1.200 180.000 6938.95 1079.59 N 4805.95 W Top West Sak C 3610.29 1.200 180.000 7085.21 941.06 N 4847.58 W Top West Sak B Casing details .'i1fí From To Measured Vertical Measured Vertical Depth Depth Depth Casing Detail (ft) (ft) (ft) <S7i\5~~~ ¿i~;,~S31~~~:; 7224.33 3737.80 7 -5/8" Casing 11457.75 3688.80 4-1/2" Liner 21 June, 2002 - 21:31 -....----.--.----.---..-.- . Slope, Alaska Kuparuk 1 C - DrillQuest 2.00.09.006 Page 9 of 10 Kuparuk River Unit Targets associated with this wellpath Target Name 1 C-1 04 (B-Crest-pt) 1C-104 (B-Heel) 1C-104 (B-Mid-pt) 1C-104 (B-Toe) --.-----.-----..--.---..- '-----'-~'--' 21 June, 2002 - 21:31 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 - 1C-104 (wp03) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 21 June, 2002 Target TVe (~l~,~,~ ~ 3681,80 - ~~ Mean Sea Level/Global Coord;Ó.Ç)tes;;;> 358()jQO Geograph ica[,"~QQrdir,Jätes:" /~: f --,~,;£~\~~r,r.{~';\~~~::n~" "~~~;~~-":c, ,~(-?. - .~'< '~'~ êC}!;':~;'~ ~>r' 3737.80 Mean seaL:evel/GI;bãt~ðordinatei:' 3636.00 qè~raPhidÌ"g9ordinates : ~ . t0eåhSea:'LeveifGlobal Coordinates: ~ ~~~~ Geographical Coordinates: 3703.80 3602.00 ,,~ / ""'~ Mean Sea Level/Global Coordinates: Geographical Coordinates: 3688.80 3587.00 Page 10 of 10 9.02 S 4836.70 W 5966018.00 N 556817.00 E 700 19' 04.0865" N 149032' 21.9976" W 803.33 N 4864.61 W 5969560.00 N 556760.00 E 70019' 38.9284" N 149032' 22.8790" W 1195.91 S 4844.03 W 5967561.00 N 556797.00 E 70019' 19.2643" N 149032' 22.2405" W 3429.18 S 4819.37 W 5965328.00 N 556840.00 E 70018' 57.2982" N 149032' 21.4789" W ~------ --- --_.._----~---_......_---~- . Slope, Alaska Kuparuk 1 C Target Target Shape Type Point Current Target Point Current Target Point Current Target Point Current Target ~--. Dri/lQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Data - Plan: 1C-104 - 1C-104 (wp03) MD . Delta i Indin.¡ Azimuth TVD 1 Northings ¡ Eastings Dogleg: A.Build i A. Tum ¡ Toolface (ft) . MD (ft) . ! (°) . (°) (tt): (ft) (ft) e/100ft):. (0/100tt) i e /1 OOft) ¡ (°) ::J+d~~--~~Q'Qol-ö:~l- . :::j~¥=.:;~,~:-:::::~j---:;oro~~:~':=~,~ 3 ¡. 5~(),~7 2~~.671 8.000 0'000;~1q,~(t;,>J8,~~~ ~ .. ~ OpØ¡-- 3.000: 3.QPO . o'O()O ,.,----,"Jt~~~_: ----_! I 133~~?~ 8:1~.?! __~_~:2g~_,_~g?:9g9 :;J~~~~~~1;~';:'~~~~~~:;~"i~4:?:9~-'!Yí~~-_?:9g9i . , . ;.4;?~}; . '. ~.!~~.' .,.:?,,~b~,~~, 5 ì ~ 1591.73264A:g 52.000 300.000i'.j41~92.::::;.~â56;83.';N'I'~_4t4.15:W 3.0001'-' 2:64:1. , ~ ~j.890 '330:164: ~i:.~~~: -~~:¡-~:~-i~Öi.~~~~,;¡i;~;,~',~:~:t§}§, ¿:: .~: _32::: 8 I,' 599.1':19 600.00. ,64~74l';' ~~~,~~~:~á7Q~~2/:.:,~ØØ,6:~Ø/~::~#25::Ó~íW: 5.000 ¡ . - ''';Q~ 12$,.5:~~9 264.000 t '~?Þ;~;~1,:"~'?1'A:2~+:~:147:-.::; ?~,f),iØ,4~ 3460.ooi&r:Aï~~i5~;~~::;)~3:;j,q;Q~;~-~--O-.~oOÓ!::' ::,>:Ò~~' - '~~b,.(jQØ~'-:~-~:co:Oóf 21 June, 2002,. 12:01 - 1,. DrillQuest .6HIUIPs'~ .~. 0 - 700 - 1400 - 2100 - 2800 - 3500- -2100 Drill Quest 2.00.09.006 Phillips Alaska, Inc. Kuparuk River Unit 1C Pad 1C-104 (wp03) Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates : 5968796~65 N. 561631~04 E Ref~ Stucture Referance : 280.27 N. 738.73 W Ref~ Geographical Coordinates: 70° 19' 31 ~0425" N, 149° 30' 00~8575" W 1437' FNL & 625' FWl, SEC~ 12 - T11N - R10E ~.........v-su., ,tß. ~.~J Nrt~._1.Pll'l1~JU' A H"III~"~ CI)M!*IY Plan: 1C-104 RKB Elevation: North Reference: Units: 101 ~80ft above Mean Sea level True North Feet (US) ~ ~ ~ ~ 6 ~I:>¡ Begin Dir @ 3.00/1001t (in 9-7/8" Hole) : 250.000 MD, 250.00ft TVD ~ "J' ~~~ ~ ~O ð\'lß "ø Ò' .~-<..~ - t 0 (jø O~ ø~ :\ ~ø~ R ~ø ~ç Increase in Dir Rate @ 5.00/100ft: 516.67ft MD. 515.80ft TVD ~ 9 ": "'" '~ ~ Decrease in Dir Rate @ 3.0°/1000 : 1333.23ft MD, 1239.70ft TVD ~! """ Increase in Dir Rate @ 5.0"/1001t: 1597.73ft MD. 1414.92ft TVD "" End qir, Start Sail @ 64.0° : 1891.19ft MD, 1570.43ft TVD 31\oO~0 / Begin Dir @ 5~00/1þ01t : 5391.100 MD, 3104.73ft TVD 1 BEGIN PUMP TANGENT @ 64.75. : 5991.19ft MD, 3370.32ft TVD ! //1 END PUM~TANGENT; Begin Dir@7.14./100ft:6201.41ftMD,3460.00ftTVD II ,~.:::: çI,~~ / ' ! $:)" .\" 4500~0 / ~ Continue plr @ 7~74°/1001t : 6728.33ft MD. 3660.02ft TVD . @;o; 0,\.'0 // // ¡ , ~ (t'Y ~ / / ! Plar'l,.ned Window pt for 'D' lateral (238' FNL & 1159' FWL, SEC. 11-T11N-R10E) 0-'0..:c,0 .. 0~ ~~ <.):":"0 / / /- i '0''1>'S:--'" ",,'<oJ.) 'òC>.J,?~y 00 ~/ ' /' ; I TARGET (B-Heel) 7-5/8" Casing Pt: I ò<i\'ò'" r:;."..:c,0 .,,:;.,e:~t'~@,'\' ~ / // // ¡ ¡7224.33ft MD, 3737.80ft TVD... Drill out 6-3/4" Hole '<:í~ ~ç., ,Çj<::i 9t' ¿,. <:¡ 'ò"o '0'1>\ro'ò / /' / /it ~ I ,'V.,;P Çj<$\~<:¡) C}e.' 'è~' ø'~. // / / i 0<;" ~ ",. 4 {ö ",,p ~~~""~ / / ~/ I.. Begin Dir@3.00C/100ft:7244.33ft MD, 3737'73..f~t TVD.~ ~.~~ . .<.,'?-1" ~c:J'~~~, ..,... {; o.,"'t' ¡:?~ r¿\i. .~<§>}Y /' / / ' riY <:i ~:.... Þ ". <v<:' ""Çj r /'/ / // ! End Dir. Start Sail @ 91.01° : / ~ <è~\'?<,j <\cJ.Co / ,r;§:> /' // / / ~ 7350.32ft MD, 3736.63ft TVD / ~ 0;,17 ,/' -(\~./ ~¡ /~./ :\""?' / ~.. () ,() () 'ó / r::, I:> r::,9: ~ dJ'" dJ~ /' r::,()~ R¡dJ() ()'ò()()' ()1()() ~~()()~ "':t/ ," . t" : .p" .' j' '.r~;' j . !/ '/ ¡ .:t> 4-1/2" liner ,- ! ,,'- ~ f 11457.8ft MD / i 3688.8ft TVD -1400 I C-I04 !(B-/l1id-pt) J íOJ.8f) TVD, //9S. 9/ S, 4844.03 11' (2635' ~.!W & W59' nVL, SEC ll-T/ IN-R/(Œ) I 700 1 C-I 04 (H-Crest-pt) I C-/ (/4 m- 7(1(') 3681.8(/ Tl1). 2 739.(IJ S, 48.;6.70 W 368li.80 TlD. 3429./ R S, ,1819.37 II (/ W2' FSL & 1066' nIL, 5iEC 11- TIIN-R I Of;) (41 J' FSL & lOR]' FilL. SIT 11- /"I/\-R 101;) I c- lO4 (B-lIeel) , J737.80nv, 803.33 N, 4864.61 II' (635' flY/- & f()4(1' FW/-, Sfe / I-TI IN-R/OE) ----¡------------ . 2100 2800 r 3500 -700 0 1400 0 700 1400 :::J (f) ~ ~ .- 0 .- II co ::¿ 2100 ~ .c ã. Q) 0 ro ü :e Q) > ~ 2800 3500 ¡¡:: C> C> r-- II .c () ~~ Qj (õ () Cf) /pafWPS\ CÐ ~ooo I I 2000 -' 1000 0 (f) C) c: E t 0 Z -1 000 ~ I -2000 _. -3000 § 0 0 II ..c: u ~S: ¡¡¡ ro u If) Drill Quest 2.00.09.006 I -8000 Scale: 1 inch = 1000ft -7000 I Phillips Alaska, Inc. Kuparuk River Unit 1C Pad 1C-104 (wp03) -5~00 -4~00 -3000 -6000 I i BEGIN PUMP TANGENT@64.75°: ! 5991.19ft MD, 3370.32ft TVD I END PUMP TANGENT; I Begin Dir@ 7.14°/1000 : I 6201.41ft MD, 3460.00ft TVO J ~ Continue Oir @ 7.74'/10Oft: 6728.33ft MD. 3660.02ft TVO "'-"-"-,,- Planned Window pt for '0' Lateral l~ 3~ (238' FNL & 1159' FWL, SEC. 11-T11N-R10E) ~:>' C\:>o TARGET (B-Heel) ~ 3704 7224.3~f~/~~~~~~¡:~;t TVD :,¡,:~ I '.- ~ ~2 I D lfN (R-lIeel) '" Drill out 6-3/4" Hole . ~ 3ì37.80 TV/). 803.33 N, 4864.61 II' ~ / 3134~O (635' FNL & /(140' FIlL. SEe. II-T/IN-RIOE) Begin Dir @ 3.000/100ft: 7244.33ft MD, 3737~73ft TVO / . / / =-I--tEilr'r'Y-1lU11 n~ð l","-_~J.lN~-..~. ~ .f'!J/lr-~~1 A "."'IM.! /'1 c.'1 C Cft"f pI4'I Y -2000 I -1 000 ~_~___L ",?,<:,"'''' . Begin Oir @ 5.0Q/10Oft: 5391.19ft MD, 3104.73ft TVO .---- End Dir. Start Sail @ 91.01° : 7350.32ft MD, 3736.63ft TVD '51..þ<;J ~. C') 0 a. !. '<t 0 Ó ",1.\"'''' .....- Begin Oir @ 3.00Q/100ft : 920B.35ft MD. 3704.05ft TVO TARGET (B-Mid pt) Start Sail @ 90~81 r 9224~04ft MD.3703,8Oft TVD ~ ~\)?,-:I ~/~-~ ",1. ~ -.... . /C-/04 (B-JHd-pt) 3ì03.80 nn. /195.9/ S. 4844.03 ,,. (2635' FNL & 1059' FJlL. SEC I /.TI /N-Rl/JE) iò~~ ",6 . TARGET (B-Crest pt) Begin Dir @ 3~OO-!100ft: 10761~33ft MD. 3681 ~8Oft TVD <¡;,<;,'?J .",6 End Oir, Start Sail @ 89,35' : 10830.94ft MD, 3681.71ft TVD ~~'O.- /C-/04 (B-Cre.'t-PtJ -368/.80 lTD. 2ì39.02 S. 4836.ìO W (1102' FSL & /066' FWL, S'EC II-T/IN-RIOE) Well: Horizontal Coordinates: Ref. Global Coordinates: 596879665 N, 56163104 E Ref. Stucture Referance: 2BO~27 N, 738~73 W Ref~ Geographical Coordinates : 70' 19' 31,0425" N, 149' 30' 00,B575"W 1437' FNL & 625' FWL, SEC~ 12 - T11N - R10E 9>~'?> .",<0 TARGET (B-Toe) Total Depth: 11451.75tt MD, 3688.8Oft TVD '-.~ lC..104 (II-Toe) 3688.80 T/D. .?429.18 S, 4819.3ì IJ (412' F5;L & IOll3' FWI,. SEC II-TlIS-RIOI:) 4-112" Liner 11457.8f1 MD 3688.8ft TVD I -7000 I -6000 -5000 -4000 -3000 Eastings 0 j SHL: X=561631~04'E & Y=5968796,65'N (1437' FNL & 625' FWL, SEC~ 12-T11N.R10E) ~. - :;~,.... Reference is True North Current Well Properties ~~ (;.~" ~~ _,\~1'0~ .. f?J~ .A.l~ ~~. ,,(;.,,(;.. d-"" -<¡--.!~ ,,'\~~ ~~' '1-~~~ 'ò'0" -<¡--.!~ . ,\'ò~ 1~" 0," ~,,~' '0'0" ç)" RJ1' ~~ ~~' ~'0~ qJ>. ~ ~. "I';; ~'1-'5 <õ1" °,'); 'èJi'/¡.@ 0\"'0'0" . ,,~~ . ~,\'ò~ '0'0"~ 'èJ>Ø~ ~5) 0\'\'0'\)" ~ ,\rjJ~ ~ ~ ').~'\)~ Ò ~\I' <¡1..'ð\e @ @ ~~ ~r;:¡Q\ y..o\eì ' «;.{" \~ ,)-1 <¡1..'ð,e 'ð,e @ :\ \~' 'ð",e . 'i)-I ,\>\1 ~ , ï::::~ ~ \~c,<e e'ð",e \~ 'ð",e\~ çf\"'\)'\)~ ~e':'< \~,,(e ~ @~. ~\I ,;.\~ <òe'<> Plan: 1C-104 RKB Elevation: North Reference: Units: 101~80ft above Mean Sea Level True North Feet (US) ~-~--~----_.~------- Approved Plan (wp03) -2000 -~~-----T----~--- --~-~---- T-- -1 000 0 2000 1000_-. 0 (f) C) c: E t 0 Z I ¡ ~ -1000 i ~- .200 -3000 0 0 0 II .c ~~ Qj Iii (.) (/) Phillips Alaska, Inc. 1C-104 (wp 03) MD Inc Azim. SSTVD TVD N/S E/W Y X DLS v.s. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) (ft) 0.00 0.00 0.00 -101.80 0.00 0.00 N 0.00 E 5968796.65 N 561631.04 E 0.00 0.00 SHL 250.00 0.00 0.00 148.20 250.00 0.00 N 0.00 E 5968796.65 N 561631.04 E 0.00 0.00 Begin Dir @ 3.00/100ft (in 9-718" Hole) 516.67 8.00 0.00 414.00 515.80 18.59 N O.OOW 5968815.24 N 561630.89 E 3.00 -18.59 Increase in DLS to 5.00/100ft 1333.24 45.00 305.00 1137.91 1239.71 250.92 N 247.03 W 5969045.53 N 561381.96 E 5.00 -250.92 Decrease in DLS to 3.00/100ft 1597.73 52.00 300.00 1313.12 1414.92 356.83 N 414.15 W 5969150.06 N 561213.97 E 3.00 -356.83 Increase in DLS to 5.00/100ft 1891.19 64.00 290.00 1468.63 1570.43 460.31 N 639.44 W 5969251.69 N 560987.84 E 5.00 -460.31 End Dir; Start Sail 2277.56 64.00 290.00 1638.00 1739.80 579.08 N 965.77 W 5969367.78 N 560660.55 E 0.00 -579.08 Base Permafrost 2866.10 64.00 290.00 1896.00 1997.80 760.01 N 1462.84 W 5969544.61 N 560162.00 E 0.00 -760.01 Top T-3 3509.39 64.00 290.00 2178.00 2279.80 957.76 N 2006.16 W 5969737.90 N 559617.08 E 0.00 -957.76 Top K-15 5391 .19 64.00 290.00 3002.93 3104.73 1536.23 N 3595.51 W 5970303.30 N 558023.04 E 0.00 -1536.23 Begin Dir @ 5.00/100ft 5466.16 63.67 285.84 3036.00 3137.80 1556.93 N 3659.52 W 5970323.47 N 557958.86 E 5.00 -1556.93 Top Ugnu C 5991.19 64.75 256.65 3268.52 3370.32 1566.48 N 4125.03 W 5970329.20 N 557493.28 E 5.00 -1566.48 BEGIN PUMP TANGENT @ 64.75° 6025.13 64.75 256.65 3283.00 3384.80 1559.39 N 4154.91 W 5970321.86 N 557463.47 E 0.00 -1559.39 Top Ugnu B 6135.30 64.75 256.65 3330.00 3431.80 1536.38 N 4251.85 W 5970298.05 N 557366.71 E 0.00 -1536.38 Top Ugnu A 6201.41 64.75 256.65 3358.20 3460.00 1522.57 N 4310.02 W 5970283.77 N 557308.66 E 0.00 -1522.57 END PUMP TANGENT; Begin Dir @ 7.14°/100ft 6490.20 67.64 234.30 3476.00 3577.80 1413.30 N 4548.12 W 5970172.55 N 557071.47 E 7.14 -1413.30 K-13 6728.33 72.24 216.86 3558.22 3660.02 1257.17 N 4706.72 W 5970015.12 N 556914.16 E 7.14 -1257.17 Continue Dir @ 7.74°/100ft 6786.29 74.12 212.61 3575.00 3676.80 1211.59 N 4738.31 W 5969969.28 N 556882.94 E 7.74 -1211.59 Top West Sak D 6800.00 74.58 211.62 3578.70 3680.50 1200.41 N 4745.33 W 5969958.04 N 556876.01 E 7.74 -1200.41 Planned Window pt for 'D' Lateral 6938.95 79.44 201.77 3610.00 3711.80 1079.59 N 4805.95 W 5969836.73 N 556816.38 E 7.74 -1079.59 Top West Sak C 7085.21 84.88 191.75 3630.00 3731.80 941.06 N 4847.58 W 5969697.87 N 556775.90 E 7.74 -941.06 Top West Sak B 7224.33 90.19 182.37 3636.00 3737.80 803.33 N 4864.61 W 5969560.00 N 556760.00 E 7.74 -803.33 TARGET (B-Heel) 7-5/8" Csg pt; Drill 6-3/4" Holf'~ 7244.33 90.19 182.37 3635.93 3737.73 783.34 N 4865.43 W 5969540.01 N 556759.34 E 0.00 -783.34 Begin Dir @ 3.00°/1 OOft 7350.32 91.01 179.30 3634.83 3736.63 677.39 N 4866.97 W 5969434.04 N 556758.67 E 3.00 -677.39 End Dir; Start Sail 9208.35 91.01 179.30 3602.25 3704.05 1180.22 S 4844.16 W 5967576.69 N 556796.74 E 0.00 1180.22 Begin Dir @ 3.000/100ft 9224.04 90.82 179.73 3602.00 3703.80 1195.91 S 4844.03 W 5967561.00 N 556797.00 E 3.00 1195.91 TARGET (8-Mid pt) Start Sail @ 90.817° 10767.33 90.82 179.73 3580.00 3681.80 2739.02 S 4836.70 W 5966018.00 N 556817.00 E 0.00 2739.02 TARGET (B-Crest pt) Beqin Dir @ 3.00"/100ft 10830.94 89.35 178.51 3579.91 3681.71 2802.62 S 4835.72 W 5965954.41 N 556818.50 E 3.00 2802.62 End Dir; Start Sail 11457.76 89.35 178.51 3587.00 3688.80 3429.18 S 4819.37 W 5965328.00 N 556840.00 E 0.00 3429.18 TARGET (8-Toe) Total Depth ( Sperry-SuD Anticollision Report Company: Phillips Alaska Inc. Field: Kuparuk River Unit Reference Site: Kuparuk 1 C Pad Reference Well: Plan: 1C-104 Reference Wellpatb: 1C-104 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MO Interval: 50.000 ft Depth Range: 41.200 to 11458.733 ft Maximum Radius: 1387.291 ft Date: 6/21/2002 Time: 11:47:59 Page: Co-ordinate(NE) Reference: Vertical (TVO) Reference: We/I: Plan: 1C-104, True North 1C-104 @ 101.8 101.8 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNEO PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 1/11/2002 Validated: No Planned From To Survey ft ft 41.200 900.000 900.000 11458.733 Version: Toolcode 13 Tool Name Planned: 1C-104 (wp 03) V1 Planned: 1C-104 (wp 03) V1 CB-GYRO-SS Camera based gyro single shot MWO+IFR-AK-CAZ-SC MWO+IFR AK CAZ SCC Casing Points MD TVO Diameter Hole Size Name ft ft in in 7244.270 3737.733 7.625 9.875 7-5/8" 11458.100 3688.876 4.500 6.750 4-1/2" Summary <", Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 1 C Pad 1 C-06 1 C-06 V1 550.905 550.000 237.491 10.693 226.798 Pass: Major Risk Kuparuk 1 C Pad 1C-07 1C-07 V1 655.799 650.000 169.018 11.380 157.661 Pass: Major Risk Kuparuk 1 C Pad 1 C-08 1 C-08 V2 914.887 900.000 132.816 15.044 117.819 Pass: Major Risk Kuparuk 1 C Pad 1 C-09 1 C-09 V2 862.285 850.000 47.655 15.271 32.414 Pass: Major Risk Kuparuk 1 C Pad 1C-10 1C-10 V1 299.013 300.000 61.282 5.846 55.436 Pass: Major Risk Kuparuk 1 C Pad 1C-102 1C-102 V1 400.655 400.000 31.542 6.791 24.900 Pass: Major Risk Kuparuk 1 C Pad 1 C-1 02 1C-102L 1 V3 Plan: Plan 400.655 400.000 31.542 6.660 25.030 Pass: Major Risk Kuparuk 1 C Pad 1C-109 1C-109 V4 395.979 400.000 86.699 7.311 79.411 Pass: Major Risk Kuparuk 1 C Pad 1C-109 1C-109L 1 V2 395.979 400.000 86.699 7.223 79.500 Pass: Major Risk Kuparuk 1 C Pad 1C-111 1C-111 V2 3502.431 3750.000 190.762 177.561 38.870 Pass: Major Risk Kuparuk 1 C Pad 1C-11 1C-11 VO 792.856 750.000 191.867 15.032 177.626 Pass: Major Risk Kuparuk 1 C Pad 1C-117 1C-117 V2 344.182 350.000 210.780 6.578 204.207 Pass: Major Risk Kuparuk 1 C Pad 1C-119 1C-119 VO 296.701 300.000 240.735 4.961 235.774 Pass: Major Risk Kuparuk 1 C Pad 1C-121 1C-121 V1 296.297 300.000 271.390 5.337 266.066 Pass: Major Risk Kuparuk 1 C Pad 1C-12 1C-12 VO 731.238 700.000 184.540 13.672 171.257 Pass: Major Risk Kuparuk 1 C Pad 1 C-125 1C-125 V3 295.494 300.000 332.515 4.934 327.585 Pass: Major Risk Kuparuk 1 C Pad 1C-17 1C-17 VO 1478.730 1450.000 56.098 38.287 24.185 Pass: Major Risk Kuparuk 10 Pad 10-112 1 0-112 V2 Out of range Kuparuk 1 0 Pad Plan: 10-103 10-103 (Rig) V1 11433.202 8700.000 1129.334 197.643 932.059 Pass: Major Risk Kuparuk 10 Pad Plan: 10-103 10-103 V15 Plan: 10-10 7359.884 12750.000 953.162 209.886 743.488 Pass: Major Risk ¡an~ Ian: IC-104 -164 ~150 ~-~125 --100 ----75 ----50 ~25 -0 ---25 -50 ---75 ~IOO -----125 --ISO -164 280.366 -ï38. 776 -N/-S WELL DETAILS SURVEY PROGRAM {'('~H'.-\1'\Y r)(~TAII'" ANTI-COLLISION SETTINGS ~ß'-W Date: 111 J,'2002 Validated: No VCI'3iün: 1J I'¡~~~þ~~~~/r\.' Kup.mik Northing 5<)6879<'.65 r:.asring LarìludL' Longintde SJot Interpolation Method:MD Interval: 20.000 Depth Range From: 41.200 To: 11458.733 Maximum Range: 1387.291 Rcfèrence: Principal Plan CH~(jYR()-SS MWD"IFR-AK.('AZ-SC (;¡b!t¡I).'JI Method: Mi1~rUl1 ('Il(\~il1lh' ~~~r ~~~:~~ ~~L~\;'~~~lcl ~nr1h WII~;.~~II~~~~: ~~~¡~:I'u~n:: 561631.04 W19'31.042N 149ò30'OO~857W NiA )epth Fm Depth To Survl.ry/Plan 11.200 <)OO.lJOO Planned: IC-I04I\\1' (3) VI ;oo~OOO 1l458~733 Planned: IC-I04 (wp nJI VI Tool ID-I03 (wp 03) Approved Plan 0 1G4 From 0 200 400 600 800 1000 ISOO 2000 2S00 3S00 4S00 SSOO 6S00 7S00 8S00 9S00 10SOO IISOO 12S00 no ,::::- ~ ~ ---~100 :-- -----~~-t!5-- ~ /r '/ Ci£¡ r/ í~ '/ °'l '~ --- t~O 50 I(:I}!) 1(' rl(' -/0(1 . '(¡VI Ie/ c/o J I (Ie') -"I) . ~1!\i.",~\..~:\\I}.\ \C\~ 180 jò4 wn U" 111 OEI,"I S Iht~ Rrl: ).¡(1111 "\¡¡I..u~ N5 !(' !/14 fl/. HI1.1' ".Scrhm \n¡!It 1;;1:nn 's,'.s f)l\,jn FJ-W ~t.l11¡¡".! r:\lrnTVD Colour ToMD 200 400 600 ROO 1000 ISOO 2000 2S00 3S00 4S00 5S00 6500 7500 RSOO ()SOO IOSOO IISOO 12S00 14000 LEGI:ND - IC-06(IC-06). Major Risk IC.07 (IC-07), Maior Risk - IC-OM (IC-O~). Mo)",. Risk - I C-09 (I C -(9). Ma~jor Risk 1('-10 (IC-IO). Mlljnr Risk - IC-102 (IC-102). ¡ì"lnj()r Risk IC-I02 (IC-102L1). Maior Risk - 1('-109 (IC-IO,}). Major~Risk - IC-I09(IC-109Ll).MajorRisk - IC-11l (IC-II I). Major Risk IC-11 (IC-II), Malor Risk - IC-117(1('.117),~1ajDrRisk IC-I 19 (IC-119). Major Risk - 1('-121 (1('-121), Major Risk - IC-12 (1C-12). Major Risk - IC-125 (1C-125). Maior Risk I C-17 (!C- I 7). Major Risk - 1l)-112 (ID-112). Major Risk - Plan: I D-103 (I D-IO.i (Rig)). Major Risk - \¿~I_nio~D- I 03 (I D-I 0)- Major Risk ~...-,." Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [50ftJin] MWD+IIFR+CAZ --------------- Rig: Nabors 245E Location: West Sak Client: Phillips Alaska, Inc. Revision Date: 6/24/2002 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com Schlumberger I ~ ,lADE Preliminary Job Design 7 5/8" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 350% excess in the permafrost and 45% excess below the permafrost. The top of the tail slurry is designed to be at 6,200' MD. Lead Slurrv Minimum pump time: 270 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.28 ft3/sk < TOC at Surface 0.9513 felft x (120') X 1.00 (no excess) = 0.2148 ft3/ft x (2295' - 120') x 4.50 (350% excess) = 0.2148 ft3/ft x (6200' - 2295') x 1.45 (45% excess) = 114.2 ft3 + 2102.4 ft3+ 1216.3 ft3 = 3432.9 ft31 4.28 ft3/sk = Round up to 810 sks 114.2 ft3 2102.4 fe 1216.3fe 3432.9 ft3 802.1 sks Have 230 sks of additional Lead on location for Top Out stage, if necessary. Pre~ous Csg. < 16",62.6# casing at 120' MD Tail Slurrv Minimum pump time: 160 min. (pump time plus 90 min.) GasBLOK wi Class G @ 15.8 ppg - 1 .2 ft3/sk 0.2148 ft3/ft x (7224' - 6200') x 1.45 (45% excess) = 0.2578 ft3/ft x 80' (Shoe Joint) = 318.9 ft3 + 20.6 fe = 339.5 ft3/1.2 ft3/sk = Round up to 290 sks 318.9 ft3 20.6 fe 339.5 fe 282.9 sks BHST = 76°F, Estimated BHCT = 78°F. < Base of Permafrost at (BHST calculated using a gradient of 2.4°F/1 00 ft. below the permafrost) 2,295' MD (1,741' TVD) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 6 50 8.3 8.3 < Top of Tail at Drop Bottom Plug 5.0 13.3 6,200' MD MudPUSH XL 6 50 8.3 21.6 Lead Slurry 6 617 102.8 124.4 Drop Bottom Plug 5.0 129.4 Tail Slurry 6 62 10.3 139.7 Drop Top Plug 5.0 144.7 Displacement 6 308 51.3 196.0 Slow Rate 3 20 6.7 202.7 < 7 5/8", 29.7# casing in 9 7/8" OH MUD REMOVAL 1D at 7,224' MD (3,661' TVD) Recommended Mud Properties: 9.4 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.2 ppg MudPUSH* XL, Pv ~ 17-21, Ty ~ 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. * Mark of Schlumberger ~~l~!:F !Æ~!Æ~~~!Æ AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 Re: Kuparuk River Unit 1C-104 Phillips Alaska, Inc Permit No: 202-061 Sur Loc: 1437' FNL, 625' FWL, Sec. 12, T11N, R10E, UM Btmhole Loc. 412' FSL, 1083' FWL, Sec. 11, T11N, R10E, UM Dear Mr. Mallary: 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 of drilling wastes will not be approved for this well until sufficient data is subrilitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confIrmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. 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 Kuparuk River Unit 1 C 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 25035. 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. Sincerely, (j~(k~L ~~ Cammy ~chsli Taylor . Chair BY ORDER q~ THE COMMISSION DATED this~ay of March, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ( 1 a. Type of work: Drill 0 Redrill 0 Re-entry [Joeepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1437' FNL, 625' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 36' FNL, 1053' FWL, Sec. 11, T11 N, R10E, UM At total depth 412' FSL, 1083' FWL, Sec. 11, T11N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well 412' @ TO feet 1C-102, 31' @ 401' 16. To be completed for deviated wells Kickoff depth: 250' MO 18. Casing program size ( ItJbA- -s I ¡¡J (;) Ì- 4- -S/\~ 1b. Type of well. Exploratory 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) RKB 41 feet 6. Property Designation Kuparuk River Field AOL 25649 ALK 467 West Sak Oil Pool 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Kuparuk River Unit Statewide 8. Well numbe/ Number 1 C-1 04 #59-52-180 9. Approximate spud date Amount May 7,2002 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11914' MD /3687 I TVD 17. Anticipated pressure (see" AAC 25.035 (e)(2» Maximum surface 1309 psig At total depth (TVD) 1720 psig Setting Depth 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth plot LRefraction analysis 0 Seabed report 020 AAC 25.050 requirements 0 21.sl .ghneeredby C¡Ii; th"forego;ng is ten C(torrect to the best of my knowledge Questions? CDaalt'e' ~~ M::~: æ;~:., ~ "" Title: Drilling Engineering Supervisor 7 r IKA{;JIt ,.¿..vu ~ Chuck Ma/lary Prt:m::m:~rl hv Shamn AII.cwn-nral<p. Commission Use Only Permit Number I API umber I Approval date/)~ f¡u!íJ~ ~ee cover letter 2 0 ¿ - e>C:; I 50- 0.2 <; - :2.. 3 0 ? 6 7/1 71lt V for other requirements Conditions of approval Samples required 0 Yes ~ No Mud log required' Yes ~ No Hydrogen sulfide measures 0 Yes ~ No Directional survey required j8 ' Yes 0 No Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M; 0 0 Other: ~C ~,:.\ """\~\~\,,)""'" ~()'?~~~~ Original Signed By Approved by CammyOoch~i Commissioner Maximum hole angle Hole Casing Weight 24" 16" 62.5# 9.875" 7.625" 29.7# 6.75" 4" 9.5# Specifications Grade Coupling H-40 Weld L-80 BTCM L-80 HSLHT Length 120' 7190' 4914' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Effective Depth: measured true vertical feet feet Casing Conductor Surface Intermediate Production Liner Length Size Cemented Perforation depth: measured true vertical Form 10-401 Rev. 12/1/85. Development Oil 0 Multiple Zone 0 10. Field and Pool feet 91 0 Top MD TVD 41' 41' 41' 41' 7000' 3724' Bottom Quantity of Cement TVD (include stage data) 161' 1;1 285 sx AS 1 ~ ~sx AS Lite &.3'ð"sx Class G .~ sg,A~n 2-1() -; ¿,"\'1 MD 1..ftt ~' ut.lSi \JJ6A- Plugs (measured) Junk (measured) Measured depth True Vertical depth RECEijVE MAR 0 5 2002 Alaska Oil & Gas Cons. Commission Anchorage by order of the commission Date J /¡ L//c ~~ , irm8 Submit in triplicate Or J :1""" 11 IVi Î ¡ ( A~ø:" ~tion for Permit to Drill, Well 1 C-1 04 ~. Revision No.1 ". Saved: 22-Feb-02 Permit It - West Sak Well #1C-104 Application for Permit to Drill Document M(lximizE Well Volu~ Table of Contents 1. Well Name................................................................................................................. 2 Requirements of 20 AAC 25.005 (f)................ .......,...... ............ ............... .............. ..... ...... ..... ......... ........ 2 2. Location Summary.... ......... .... .................. ................ ...... .......... ................................ 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 Cementi ng Program. ....... .... ....... ............. ... .......... ..... ..... .... ..... ............. 4 Requirements of 20 AAC 25.005(c)(6) ........... .......,.... .......... ........,.......... ....... ....... ..................... ............ 4 7. Diverter System Information.... ............... ... ..... .... .... ............. ....... ......... ... ...... ..... ..... 4 Requirements of 20 AAC 25.005(c)(7) .................. ................ ............... ........ ....... ...... .................. ........... 4 8. Dri II i ng FI uid Program ..... ........ .... .............. ....... ......... .... ..... ..... .......... .... ......... ... ...... 4 Requirements of 20 AAC 25.005(c)(8) .. ....... .............. ..................,.... ............. ......... .................... ........... 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 10. Seismic 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 Bondi ng ......... ... ....... ... .... .... ..... ... ........ ....... ....... ...... ..... ... ...... ...... ... ...... 5 Requirements of 20 AAC 25.005 (c)(12) ...........................................................................................,.... 5 .J 1C-104 PERMIT IT ver.1.doc Page 1 of 7 þ ,'f1 .~ ,~ rrinted: 22-Feb-02 Ä I , - j ( A~r""'ation for Permitto Drill, We1l1C-104 \ Revision NO.1 . Saved: 22-Feb-02 13. Proposed Drilling 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) Each well must be identified by a unique name designated by tlie operator and a unique API number assigned by the commi.sion under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similady be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as lC-l04. 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 fìle with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface" at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface¡ referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,968,796.65 Eastings: 561,631.04 1437' FNL, 625' FWL, Section 12, TllN, Rl0E, UM RKB Elevation 101.8' AMSL Pad Elevation 60.8' AMSL Location at Top of Productive Interval (West Sak "8" Sand) NGS Coordinates Northings: 5,970,158.95 36' FNL, 1053' FWL, Section 11, TllN, Rl0E, UM Eastings: 556,767.86 Measured Depth/ RKB: Total Vertical Depth/ RKB: Total Vertical Depth 55: 7081 3734 3632 Location at Total Depth NGS Coordinates Northings: 5,965,328 Eastings: 556,840 412' FSL, 1083' FWL, Section 11, TllN, Rl0E, UM Measured Depth/ RKB: 11914 Total Vertical Depth/ RKB: 3686 Total Vertical Depth/55: 3585 OR, 1C-104 PERMIT IT ver.1.doc Page20f 7 , ~"f1nted: 22-Feb-02 I ¡ j U,œ ( A~...r "~ation for Permit to Drill, WeIl1C-104 , Revision NO.1 Saved: 22-Feb-02 and (D) other information required by 20 MC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatect the application for a Permit to Drill (Form 10-401) must (1) indude a plat, drawn to a suitable scale,. showing the path of the proposed wellbore,. induding all adjacent wellbores within 200 feet of any portion of the proposed well; 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 records,. and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that 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 of the blowout prevention equipment (80PE) as required by 20 MC 25.035,. 20 MC 25.036; or 20 MC 25.037,. as applicable,.. I' . An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete well 1C-104. 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 for a Permit to Dlill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (4) information on drilling hazards,. induding (A) the maximum downhole pressure that may be encountered,. criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1C pad area vary from 0.41 to 0.46 psi/ft, or 7.8 to 8.8 ppg EMW (equivalent mud weight). These are pressures obtained from actual well test data from the nearby 1C-111, 1C-125, and 1C-121 wells. 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 1309 psi, calculated thusly: MPSP =(3740 ft)(0.4;6 - 0.11 psi/ft) I; =1309 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems ~"UcfJ as abnol7nally geo-pressured strata, lost circulation zones,. 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 applícatíon for a Permit to Dlifl must be accompanied by each of the followfÌ1g items,. except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity test::,",. as required under 20 MC 25.030(f),.- ORi 1C-104 PERMIT IT ver.1.doc Page 30f? :iPtlntfd: 22-Feb-02 I ¡ - A~.t"''''ation for Permit to Drill, WeIl1C-104 , Revision No.1 Saved: 22-Feb-02 lC-l04 will be completed with 7-5/8" surface casing landed in the West Sak S-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 MC 25.03~ and a description of any slotted fine~ pre- perforated line0 or screen to be installed; CasinCi and CementinCi PrOCiram Hole Top Btm Csg/Tbg Size Weight Length MDfTVD MDfTVD 00 (in) (in) (lblft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 120 41/41 161 / 161 Cemented to surface with 265 cf -/ ArcticSet 1 7-5/8 9-7/8 29.7 L-80 STCM 7190 41/41 7231 / 3740 Cemented to Surface with 580 sx ASLite / Lead, 370 sx Class G Tail 4 6-3/4" 9.5 L-80 HSLHT 4914 7000/ 3724 11914/3687 Screens - no / screen Lower cement Lateral 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application lor a Permit to Dliff must be accompanied by each of the following item~ except for an item already on fife with the commission and Identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25. 035.- unless this requirement is waived by the commission under 20 MC 25.035(h)(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 Drill must be accompanied by each of the following item::,.., except for an item already on file with the commission and identitìed in the application: (B) a drilling fluid program, including a diagram and description of the dli/kng fluid systeml 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 8.5 ~ 9.4 / ~ 9.4* ~ 9.4* " 150-200 150-200 150 75 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) 10 second Gel Strength (lb1100 sf) 30-60 8-15 30-60 11- 22 10-30 10-25 20-40 15-30 10-25 18- 30 15-30 10-25 JR. ~~ ~l ¡ 1C-104 PERMIT IT ver.1.doc Page 4 of 7 rrinted: 22-Feb-02 .- Alt.... "'ation for Permit to Drill, Well 1 C-1 04 \, Revision NO.1 ~ Saved: 22-Feb-02 10 minute Gel Strength (/b/100 sf) pH API Filtrate(cc) Solids (%) 25-55 8-9 8-15 5-8 25-55 8-9 6 5-8 20-40 8-9 5-6 5-8 20-40 8-9 5-6 6-11 *9.8 ppg if hydrates are encountered Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 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, pvr System with visual and audio alarms, Trip Tank, Flow Sensor, and Fluid Agitators. I 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 itemSr except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally gea-pressured strata as required by 20 AAC 25.033{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 PermIt to Drill must be accompanied by each of the following Items, except for an item already on tile with the commission and Identified in the application: (10) for an exploratory or stratigraphic test well a seismic refraction or reflection analysis 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 item~ except for an item already on file with the commission and identified in the application: (11) for a well ddlled from an off::,1Jore platform/ mobile bottom-founded structure/ jack-up dg/ or floating drilling vessel, an analysis of seabed conditions as required by 20 MC 25.061(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 Dlill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {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 applk:ation 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: 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. 1C-104 PERMIT IT ver.1.doc Page 5 of 7 0 R i ì..111 'led: 22-Feb-02 AQI.. ~tion for Permit to Drill, Well 1 C-1 04 ~ Revision No.1 Saved: 22-Feb-02 / 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 +/- 7231' MD / 3740' 1VD 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 +/- 11914' MD / 3,687' 1VD 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 sea per 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 @ +/- 7000' MD / 3724' 1VD 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 lC-l04 Ll 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 by each of the tollowing items, except for an item already on tile with the commission and identified in the application: (14) a general description of how the operator plans to dispo~ì3 of drilling mud and cuttings and a statement of whether the operator ¡{¡tends to request authorization under 20 MC 25.080 for an annular disposal operation in the we/I.,: Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lC 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 lC 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-104 PERMITITver.1.doc J " II ,1\ J?aç;,e 6 of 7 . R I' ,. Ir(.1?,..t...Jd~.. ';,..,' F<. eb-02 o;')I¡V/ii. ( At 'ition for Permit to Drill, Well 1 C-1 04 Revision No.1 Saved: 22-Feb-02 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 1C-104 PERMIT ITver.1.doc P~e 70f7 0 R,\,i .~.,r., /Ø'Prrntè..,..cl..,.,..'/ .1i'.,;;'..~ -1....,eb-02 " " , 11:,\ I S iii l'c~ ¡., ( lC-l04 Drillinq Hazards Summa~ (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) ,9-7/8" Open Hole / 7-5/8" Casina Interval Hazard Broach of Conductor Gas Hydrates Running Sands and Gravels Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Risk Level Low Low Moderate ./ Low ~i~igél~tion Strategy - ~ Monitor cellar continuously during interval. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Dri Itreat. Maintain planned mud parameters, Increase mud weight, use weighted sweeps, run qravel isolation string. Diverter drills, increased mud weight. Low / Reduced pump rates, mud rheoloqy, LCM Moderate Trip speeds, Proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pi pe Lost Circulation Hole Swabbing on Trips Risk Level Low Low Low Moderate / ~~~igation Strategy ~ Stripping drills, Shut-in drills, Increased mud weiqht. Good hole cleaning, PWD Tools, Hole Opener, Decreased mud weight , Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumpinq out 6" Open~Hole / 4" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Lost Circulation Hole Swabbing on Trips Risk Level Low Low Low Moderate I Mitigation Strategy Stripping drills, Shut-in drills, Increased mud weight. Good hole cleaning, PWD Tools, Hole Opener, Decreased mud weight / Reduced pump rates, Mud rheology, LCM / Trip speeds, Proper hole filling (use of trip sheets), Pumping out 1 C-1 04 Drilling Hazards Summary ~ . d..rÞ.. O.'cJ. ä,.J..:~. U.Sh. O~ViC !:i iNt/t. ~~2¡;2 '~ . ~., IS ¡J J. , ."1.' . , li ~ !i \1 it- { ( Volume Calculations and Cement Systems Volumes are based on 300% excess in the permafrost and 450/0 excess below the permafrost. The top of the tail slurry is designed to be at 5,940' MD. Lead Slurrv Minimum pump time: 240 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg, Class G + 500/0D124, 9%(BWOW)D44, 0.60/0D46, 300/oD53, 1.5%S1, 1.5%D79, 0.5%D65 - 4.44 ft3/sk 0.9513 ft3/ft x (158') x 1.00 (no excess) = 0.2148 felft x (1236' -158') x 4.00 (300% excess) = 0.2148 felft x (5940' - 1236') x 1.45 (45% excess) = 150.3 fe + 926.2 fe + "!f65.1 fe = 2541.6 fe 14.44 fe/sk = Round up to 580 sks / 150.3 ft3 926.2 ft3 1465.1 fe 2541.6 ft3 572.4 sks ÇvL rJ97i/- t L ~ &Ili/DL Have 200 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 160 min. (pump time plus 90 min.) 15.8 ppg Class G + 0.45%D065, 2.00/0D600, 0.20/0D047 - 1.16 ft3/sk 0.2148 felft x (7231' - 5940') x 1.45 (45% excess) = 0.2578 felft x 80' (Shoe Joint) = 402.1 fe + 20.6 fe = I 422.7 fel 1.16 ft3/sk = /, Round up to 370 sks ./ 402.1 fe 20.6 ft3 422.7 ft3 364.4 sks BHST = 96°F, Estimated BHCT = 88°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 6 50 8.3 8.3 Drop Bottom Plug 3.0 11.3 MudPUSH XL 6 50 8.3 19.6 Lead Slurry 6 459 76.5 96.1 Tail Slurry 6 76 12.7 108.8 Drop Top Plug 3.0 111.8 Displacement 6 308 51.3 163.1 Slow Rate 3 20 6.7 169.8 MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv ::::: 17-21, T y ::::: 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. 0 C) ::t:J -.,..,,,, ,'" ~¡-"" ~ r--- -., ^~*'%" '. Kuparuk" River Unit North Slope, Alaska Kuparuk 1C, Slot 1C-104 Plan: 1C-104 - 1C-104 (wp01) Revised: 20 January, 2002 if) i >:- G-. PROPOSAL REPORT 29 January, 2002 ~ \' ---- ~ ..ç... ------ Q r> Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Surface Coordinates: 5968796.65 N, 5616~1.04 E (70° 19' 31.0425" N, 149030' 00.8575" W) Surface Coordinates relative to Project H Reference: 968796.65 N, 61631.04 E (Grid) Surface Coordinates relative to Stucture Referance: 280.27 N, 738.73 W (True) Kelly Bushing: 101.80ft above Mean Sea Level 5pe""""y-5Ui'1 D.A~iLL..ÎNG..~..~.~~..~SEA\j1C1i'ii A HaUlbuttQn CQmp:any Proposal Ref: pr09805 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 -1C-104 (wp01) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 20 January, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) jfiOOft) 0.00 0.000 0.000 -101.80 0.00 0.00 N 0.00 E 0.00 SHL: X=561631.04'E & Y=5968796.65'N (1437' FNL & 625 FWL, SEC. 12-T11N-R10E) ~ 100.00 0.000 0.000 -1.80 100.00 0.00 N 5968796.65 N 0.000 0.00 200.00 0.000 0.000 98.20 200.00 0.00 N 5968796.65 N 0.000 0.00 250.00 0.000 0.000 148.20 250.00 0.00 N 5968796.65 N 0.000 0.00 Begin Dir @ 3.5°/100ft (9-7/8" Hole 250.00ft MD, 250.00ft TVD 300.00 1.750 0.000 198.19 299.99 561631.03 E 3.500 -0.76 400.00 5.250 0.000 297.99 399.79 561630.98 E 3.500 -6.87 478.57 8.000 0.000 376.03 477.83 561630.91 E 3.500 -15.93 Increase in Dir Rate @ 5.00/100ft : 478.57ft MD, 477.83ft TVD 500.00 8.586 353.773 397.23 499.03 0.17W 5968815.66 N 561630.71 E 5.000 -19.01 600.00 12.217 334.351 495.60 597.40 5.57W 5968832.58 N 561625.18 E 5.000 -35.98 700.00 16.569 324.327 592.46 694.26 18.47 W 5968853.61 N 561612.10 E 5.000 -57.12 800.00 21.203 318.481 687.06 7~8.6 82.26 N 38.79 W 5968878.58 N 561591.58 E 5.000 -82.26 900.00 25.969 314.678 778.68 880.48 111.21 N 66.36 W 5968907.31 N 561563.77 E 5.000 -111.21 1000.00 30.804 311.993 866.&3",,, 968.43 143.75 N 100.98 W 5968939.57 N 561528.88 E 5.000 -143.75 1100.00 35.681 309.978 0.25 1052.05 179.65 N 142.38 W 5968975.12 N 561487.19 E 5.000 -179.65 1178.57 39.532 308.703 12.48 1114.28 210.01 N 179.47 W 5969005.18 N 561449.85 E 5.000 -210.01 Decrease in Dir Rate @ 3.00/100ft: 1178.57ft MD, 1114.28ft TVD 1200.00 40.090 308.204 1028.94 1130.74 218.55 N 190.22 W 5969013.63 N 561439.04 E 3.000 -218.55 ~ 1300.00 42.719 306.019 1103.95 1205.75 258.42 N 242.97 W 5969053.06 N 561385.96 E 3.000 -258.42 1400.0 45:386 '''%4*304.043 1175.81 1277.61 298.30 N 299.91 W 5969092.48 N 561328.69 E 3.000 -298.30 1500.0 48.084 302.241 1244.35 1346.15 338.08 N 360.89 W 5969131.76 N 561267.39 E 3.000 -338.08 1600.00 50.808 300.586 1309.36 1411.16 377.66 N 425.73 W 5969170.80 N 561202.22 E 3.000 -377.66 1628.57 51.591 300.137 1327.26 1429.06 388.91 N 444.94 W 5969181.89 N 561182.92 E 3.000 -388.91 Increase in Dir Rate @ 6.00/100ft : Co) 1628.57ft MD, 1429.06ft TVD 1700.00 55.332 297.533 1369.78 1471.58 416.55 N 495.22 W 5969209.12 N 561132.42 E 6.000 -416.55 =0 1800.00 60.652 294.258 1422.78 1524.58 453.50 N 571 .49 W 5969245.44 N 561055.85 E 6.000 -453.50 1868.57 64.342 292.207 1454.44 1556.24 477.47 N 627.37 W 5969268.95 N 560999.77 E 6.000 -477.47 End Dir, Start Sail @ 64.34°: ~-"" 1868.57ft MD, 1556.24ft TVD 1900.00 64.342 292.207 1468.05 1569.85 488.18 N 653.60 W 5969279.44 N 560973.45 E 0.000 -488.18 ~-.. ~-~ ~= ~ r--- 29 January, 2002 - 10:08 Page 2 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 - 1C-104 (wp01) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 20 January, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Doglég Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Ea . Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) OOft} 2000.00 64.342 292.207 1511.35 1613.15 522.25 N 737.05 W 5969312.83 N 0.000 -522.25 2100.00 64.342 292.207 1554.65 1656.45 556.32 N 820.50 W 5969"~'R.21 N 0.000 -556.32 2200.00 64.342 292.207 1597.95 1699.75 590.39 N 903.96 W 5969379.59 N 0.000 -590.39 /o~--:. 2294.81 64.342 292.207 1639.00 1740.80 622.69 N 983.08 W 5969411 .24 N 0.000 -622.69 Base Permafrost 2300.00 64.342 292.207 1641.25 1743.05 624.46 N 987.41 W 5969412.98 N 0.000 -624.46 2400.00 64.342 292.207 1684.55 1786.35 1070.86 W 5969446.36 N 560554.80 E 0.000 -658.53 2500.00 64.342 292.207 1727.85 1829.65 1154.32 W 5969479.74 N 560471.07 E 0.000 -692.60 2600.00 64.342 292.207 1771 .15 1872.95 1237.77 W 5969513.12 N 560387.34 E 0.000 -726.66 2700.00 64.342 292.207 1814.45 1916.25 321.22 W 5969546.51 N 560303.61 E 0.000 -760.73 2800.00 64.342 292.207 1857.74 1959.54 404.68 W 5969579.89 N 560219.88 E 0.000 -794.80 2900.00 64.342 292.207 1901.04 1488.13 W 5969613.27 N 560136.15 E 0.000 -828.87 3000.00 64.342 292.207 1944.34 1571.58 W 5969646.66 N 560052.42 E 0.000 -862.94 3100.00 64.342 292.207 1987.64 1655.04 W 5969680.04 N 559968.69 E 0.000 -897.01 3200.00 64.342 292.207 2030.94 1738.49 W 5969713.42 N 559884.96 E 0.000 -931.08 3300.00 64.342 292.207 2074.24 1821.94 W 5969746.80 N 559801 .23 E 0.000 -965.15 3400.00 64.342 292207 117:5'4.t::4V? 2219.34 999.22 N 1905.40 W 5969780.19 N 559717.50 E 0.000 -999.22 3500.00 64.342 292207 0.84 2262.64 1033.29 N 1988.85 W 5969813.57 N 559633.77 E 0.000 -1033.29 3569.66 64.342 292207 91.00 2292.80 1057.02 N 2046.98 W 5969836.82 N 559575.45 E 0.000 -1057.02 Top K-15 3600.00 64.342 292.207 2204.14 2305.94 1067.36 N 2072.30 W 5969846.95 N 559550.04 E 0.000 -1067.36 3700.00 64.342 292.207 2247.44 2349.24 1101.43 N 2155.76 W 5969880.34 N 559466.31 E 0.000 -1101.43 ~,~ 3800.00 64.342 292.207 2290.74 2392.54 1135.50 N 2239.21 W 5969913.72 N 559382.58 E 0.000 -1135.50 3900.0 64.342 '\]:*'292.207 2334.04 2435.84 1169.57 N 2322.66 W 5969947.10 N 559298.85 E 0.000 -1169.57 4000.0 ~ 64.342 292.207 2377.34 2479.14 1203.64 N 2406.12 W 5969980.48 N 559215.12 E 0.000 -1203.64 4100.00 64.342 292.207 2420.63 2522.43 1237.71 N 2489.57 W 5970013.87 N 559131.39 E 0.000 -1237.71 4200.00 64.342 292.207 2463.93 2565.73 1271.78 N 2573.02 W 5970047.25 N 559047.66 E 0.000 -1271.78 4300.00 64.342 292.207 2507.23 2609.03 1305.84 N 2656.48 W 5970080.63 N 558963.93 E 0.000 -1305.84 C) 4400.00 64.342 292.207 2550.53 2652.33 1339.91 N 2739.93 W 5970114.02 N 558880.20 E 0.000 -1339.91 ::t:J 4500.00 64.342 292.207 2593.83 2695.63 1373.98 N 2823.38 W 5970147.40 N 558796.47 E 0.000 -1373.98 4600.00 64.342 292.207 2637.13 2738.93 1408.05 N 2906.84 W 5970180.78 N 558712.74 E 0.000 -1408.05 ~""... 4700.00 64.342 292.207 2680.43 2782.23 1442.12 N 2990.29 W 5970214.16 N 558629.01 E 0.000 -1442.12 r--- 29 January, 2002 - 10:08 Page 3 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 -1C-104 (wp01) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 20 January, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Ea Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) 'OOft) 4800.00 64.342 292.207 2723.73 2825.53 1476.19 N 3073.74 W 5970247.55 N ~ 0.000 -1476.19 4900.00 64.342 292.207 2767.03 2868.83 1510.26 N 3157.20 W 5970g§Q.93 N 0.000 -1510.26 5000.00 64.342 292.207 2810.33 2912.13 1544.33 N 3240.65 W 5970314.31 N 0.000 -1544.33 5100.00 64.342 292.207 2853.63 2955.43 1578.40 N 3324.10 W 5970347.69 N 0.000 -1578.40 5200.00 64.342 292.207 2896.93 2998.73 1612.47 N 3407.56 W 5970381.08 N 0.000 -1612.47 5300.00 64.342 292.207 2940.22 3042.02 1646.54 N 3491.01 W 5970414.46 N 558126.62 E 0.000 -1646.54 5400.00 64.342 292.207 2983.52 3085.32 1680.61 N 3574.46 W 5970447.84 N 558042.89 E 0.000 -1680.61 5500.00 64.342 292.207 3026.82 3128.62 1 .68N 3657.92 W 5970481.23 N 557959.16 E 0.000 -1714.68 5514.27 64.342 292.207 3033.00 3134.80 1 .4N 669.82 W 5970485.99 N 557947.22 E 0.000 -1719.54 Top Ugnu C 5600.00 64.342 292.207 3070.12 3171.92 1748.75 N 741.37 W 5970514.61 N 557875.43 E 0.000 -1748.75 5700.00 64.342 292.207 3113.42 3215.22 1782.82 N 3824.82 W 5970547.99 N 557791.70 E 0.000 -1782.82 5753.57 64.342 292.207 3136.62 3238.42 1801.07N 3869.53 W 5970565.88 N 557746.85 E 0.000 -1801.07 Begin Dir @ 6.00/100ft : 5753.57ft MD, 3238.42ft TVD 5800.00 63.963 289.141 3156.86 1815.82 N 3908.62 W 5970580.31 N 557707.64 E 6.000 -1815.82 5900.00 63.370 282.478 3201.26 1840.23 N 3994.78 W 5970604.01 N 557621.28 E 6.000 -1840.23 6000.00 63.090 275.764 3246.34 1854.38 N 4082.86 W 5970617.43 N 557533.09 E 6.000 -1854.38 6046.31 63.068 272 .648 ~"7.32 3369.12 1857.41 N 4124.04 W 5970620.12 N 557491.89 E 6.000 -1 857.41 Begin (200') PUMP TANGENT @ 63.07° : 6046.31ft MD, 3369.12ft TVD 6080.94 63.068 272.648 3283.00 3384.80 1858.83 N 4154.87 W 5970621.29 N 557461.04 E 0.000 -1858.83 Top Ugnu B 6100.00 63.068 272.648 3291.63 3393.43 1859.62 N 4171 .85 W 5970621.94 N 557444.06 E 0.000 -1859.62 -, 6186.91 63.068 272.648 3331.00 3432.80 1863.20 N 4249.25 W 5970624.88 N 557366.63 E 0.000 -1863.20 Top Ugnu A 6200.0 63~Õ68 'WiP272.648 3336.93 3438.73 1863.73 N 4260.91 W 5970625.33 N 557354.97 E 0.000 -1863.73 6248.81 63.068 272.648 3359.04 3460.84 1865.75 N 4304.38 W 5970626.98 N 557311.48 E 0.000 -1865.75 End of PUMP TANGENT; Resume Dir @ 9.5°/100ft: 6248.81ft MD, 3460.84ft TVD 6300.00 63.119 267.194 3382.21 3484.01 1865.68 N 4350.00 W 5970626.54 N 557265.86 E 9.500 -1865.68 6400.00 63.819 256.602 3426.98 3528.78 1853.07 N 4438.40 W 5970613.21 N 557177.57 E 9.500 -1853.07 C) 6500.00 65.280 246.203 3470.05 3571.85 1824.28 N 4523.80 W 5970583.72 N 557092.41 E 9.500 -1824.28 -=> 6581.31 66.986 237.963 3503.00 3604.80 1789.48 N 4589.41 W 5970548.37 N 557027.09 E 9.500 -1789.48 K-13 ...>eft, -~~ -., -" 29 January, 2002 - 10:08 Page 4 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 -1C-104 (wp01) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 20 January, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) OOft) 6600.00 67.438 236.101 3510.24 3612.04 1780.10 N 4603.86 W 5970538.88 N 557012.71 E ~~9.500 -1780.10 6700.00 70.205 226.351 3546.44 3648.24 1721.75 N 4676.40 W 597Q~tß.93 N 56940.66 E 9.500 -1721.75 6800.00 73.481 216.964 3577.66 3679.46 1650.81 N 4739.41 W 5970408.48 N 878.24 E 9.500 -1650.81 ~- 6837.87 74.832 213.498 3588.00 3689.80 1621.05 N 4760.42 W 5970378.55 N 5 57.47 E 9.500 -1621.05 Top West Sak D 6900.00 77.160 207.907 3603.05 3704.85 1569.24 N 4791.17 W 5970326.49 N 556827.15 E 9.500 -1569.24 6943.11 78.845 204.091 3612.01 3713.81 4809.64 W 5970288.44 N 556808.98 E 9.500 -1531.35 Top West Sak C 7000.00 81.140 199.122 3621 .90 3723.70 4830.26 W 5970236.20 N 556788.80 E 9.500 -1479.28 7080.74 84.504 192.173 3632.00 3733.80 4851.83 W 5970158.95 N 556767.86 E 9.500 -1402.19 Top West Sak B 7100.00 85.320 190.529 3633.71 3735.51 855.60 W 5970140.11 N 556764.24 E 9.500 -1383.38 7200.00 89.604 182.039 3638.14 3739.94 866.52 W 5970040.83 N 556754.14 E 9.500 -1284.20 7230.84 90.931 179.428 3638.00 3739.80 4866.91 W 5970010.00 N 556754.00 E 9.500 -1253.37 7-5/8" Casing Pt ... Drill out 6-3/4" Hole 7-5/8" Casing Target -1C-104 Geo-Poly, Current Target 7300.00 90.931 3738.68 1184.21 N 4866.22 W 5969940.86 N 556755.26 E 0.000 -1184.21 7400.00 90.931 3737.05 1084.23 N 4865.22 W 5969840.89 N 556757.08 E 0.000 -1084.23 7500.00 90.931 3735.43 984.25 N 4864.22 W 5969740.92 N 556758.90 E 0.000 -984.25 7600.00 90.931 3733.80 884.27 N 4863.22 W 5969640.95 N 556760.72 E 0.000 -884.27 7700.00 90.931 3630.38 3732.18 784.29 N 4862.22 W 5969540.98 N 556762.54 E 0.000 -784.29 7800.00 90.931 3628.76 3730.56 684.31 N 4861.22 W 5969441.01 N 556764.36 E 0.000 -684.31 - 7900.00 90.931 3627.13 3728.93 584.32 N 4860.22 W 5969341 .04 N 556766.18 E 0.000 -584.32 8000. 90."§31 3625.51 3727.31 484.34 N 4859.23 W 5969241 .07 N 556768.00 E 0.000 -484.34 81 00.0 ~ 90.931 3623.88 3725.68 384.36 N 4858.23 W 5969141.10 N 556769.82 E 0.000 -384.36 8200.00 90.931 179.428 3622.26 3724.06 284.38 N 4857.23 W 5969041.12 N 556771 .64 E 0.000 -284.38 8300.00 90.931 179.428 3620.64 3722.44 184.40 N 4856.23 W 5968941.15 N 556773.46 E 0.000 -184.40 8400.00 90.931 179.428 3619.01 3720.81 84.41 N 4855.23 W 5968841.18 N 556775.28 E 0.000 -84.41 8500.00 90.931 179.428 3617.39 3719.19 15.57 S 4854.23 W 5968741.21 N 556777.10 E 0.000 15.57 a 8600.00 90.931 179.428 3615.76 3717.56 115.55 S 4853.23 W 5968641.24 N 556778.92 E 0.000 115.55 :::0 ~ ~ ~ ~....'''''~ ""h ,Jr~:~ r--- 29 January, 2002 - 10:08 Page 5 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 -1C-104 (wp01) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 20 January, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) 'OOft) 8700.00 90.931 179.428 3614.14 3715.94 215.53 S 4852.23 W 5968541.27 N 556780.74 E 6.000 215.53 8800.00 90.931 179.428 3612.51 3714.31 315.51 S 4851.23 W 5968 ON 56782.56 E 0.000 315.51 8900.00 90.931 179.428 3610.89 3712.69 415.49 S 4850.23 W 3N 784.38 E 0.000 415.49 -~ 9000.00 90.931 179.428 3609.27 3711.07 515.48 S 4849.24 W N 5 86.20 E 0.000 515.48 9100.00 90.931 179.428 3607.64 3709.44 615.46 S 48i'à?4 N 556788.02 E 0.000 615.46 9200.00 90.931 179.428 3606.02 3707.82 4847.24 W 5968041 .42 N 556789.84 E 0.000 715.44 9300.00 90.931 179.428 3604.39 3706.19 4846.24!ÌY <WMWW"5967941.45 N 556791 .66 E 0.000 815.42 9400.00 90.931 179.428 3602.77 3704.57 845.24~ 5967841.48 N 556793.48 E 0.000 915.40 9500.00 90.931 179.428 3601.15 3702.95 844.24 W 5967741.51 N 556795.30 E 0.000 1015.39 9600.00 90.931 179.428 3599.52 3701.32 843.24 W 5967641 .54 N 556797.12 E 0.000 1115.37 9700.00 90.931 179.428 3597.90 4842.24 W 5967541 .57 N 556798.94 E 0.000 1215.35 9800.00 90.931 179.428 3596.27 4841.24 W 5967441.60 N 556800.76 E 0.000 1315.33 9900.00 90.931 179.428 3594.65 4840.24 W 5967341.63 N 556802.58 E 0.000 1415.31 10000.00 90.931 179.428 3593.02 4839.24 W 5967241.66 N 556804.40 E 0.000 1515.29 10100.00 90.931 179.428 3591 .40 4838.25 W 5967141 .69 N 556806.22 E 0.000 1615.28 10200.00 90.931 179.428 589.78 3691.58 1715.26 S 4837.25 W 5967041.72 N 556808.04 E 0.000 1715.26 10300.00 90.931 179.428 8.15 3689.95 1815.24S 4836.25 W 5966941.75 N 556809.86 E 0.000 1815.24 10400.00 90.931 179.428 6.53 3688.33 1915.22 S 4835.25 W 5966841.78 N 556811.68 E 0.000 1915.22 10500.00 90.931 179.428 3584.90 3686.70 2015.20 S 4834.25 W 5966741.81 N 556813.50 E 0.000 2015.20 10600.00 90.931 179.428 3583.28 3685.08 2115.19S 4833.25 W 5966641 .84 N 556815.33 E 0.000 2115.19 - 10700.00 90.931 179.428 3581.66 3683.46 2215.17S 4832.25 W 5966541 .87 N 556817.15 E 0.000 2215.17 10800. 90.'931 TiW179.428 3580.03 3681.83 2315.15 S 4831.25 W 5966441.90 N 556818.97 E 0.000 2315.15 10801.9 90.931 179.428 3580.00 3681 .80 2317.05 S 4831.23 W 5966440.00 N 556819.00 E 0.000 2317.05 Begin Dir @ 2.0o/100ft: 10801.90t MD, 3681.80ft TVD Target - 1 C-1 04 (B-Mid-pt), Current Target 10863.02 89.709 179.388 3579.66 3681.46 2378.16 S 4830.60 W 5966378.89 N 556820.13 E 2.000 2378.16 End Dir, Start Sail @ 89.71 ° : 1 0863.02ft MD, 3681.46ft TVD C".:::) 10900.00 89.709 179.388 3579.85 3681.65 2415.14 S 4830.21 W 5966341.92 N 556820.83 E 0.000 2415.14 :J::J ---- ~ ---- ?-: :r~ r-- 29 January, 2002 -10:08 Page 6 of 10 DrillQuest 2.00.09.006 <::) =0 ---... ~ --.. ~ ...~~ w...;:...... r-- Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 11000.00 89.709 179.388 3580.35 3682.15 11100.00 89.709 179.388 3580.86 3682.66 11200.00 89.709 179.388 3581.37 3683.17 11300.00 89.709 179.388 3581.88 3683.68 11400.00 89.709 179.388 3582.39 3684.19 11500.00 89.709 179.388 3582.90 3684.70 11600.00 89.709 179.388 3583.40 3685.20 11700.00 89.709 179.388 3583.91 3685.71 11800.00 89.709 179.388 3584.42 3686.22 11900.00 89.709 179.388 3584.93 3686.73 11914.11 89.709 179.388 3585.00 3686.80 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 -1C-104 (wp01) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 20 January, 2002 Local Coordinates Northings Eastings (ft) (ft) 2515.13 S 2615.13 S 2715.12 S 2815.11 S 2915.11 S 4829.14 W 4828.07 W 4827.00 W 4825.93 W 4824.86 W 4823.79 W 4822.72 W 4821.66 W 820.59 W 819.52 W 4819.37 W Global Coordinates Northings Ea .' (ft) 5966241.94 N 5966Ji¡'.l-96 N 5966041 .98 N 5965942.00 N 5965842.01 N 5965742.03 N 5965642.05 N 5965542.07 N 5965442.09 N 5965342.11 N 5965328.00 N All data is in Feet (US) unless otherwise stated. DirRtlõns and coordinates are relative to True North. Vertical depths are relative to RKB = 101.8' (MSL). Northings and Eastings are relative to 1431' FNL, 625' FWL. The Dogleg Severity Is in Degrees per 100 feet (US). Vertical Section is from 1437' FNL, 625' FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations. at a Measured Depth of 11914.11 ft., The Bottom!llfé DispÎacemênt is 5914.86ft., in the Direction of 234.567° (True). 29 January, 2002 -10:08 Page 7 of 10 556832.17 E 556834.06 E 556835.95 E 556837.84 E 556839.73 E 556840.00 E Dogleg Rate ~OOft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Vertical Section 2515.13 2615.13 2715.12 2815.11 2915.11 3015.10 3115.09 3215.09 3315.08 3415.07 0.000 3429.18 orth Slope, Alaska Kuparuk 1 C Comment ~^, Total Depth: 11914,11ftMD, 3686.80ft TVD 5" Liner Target -1C-104 (B-Toe), Current Target DrillQuest 2.00.09.006 C), '-~ {:t -h,~ -'~-,t Kuparuk River Unit Comments Measured Depth (ft) 0.00 250.00 478.57 1178.57 1628.57 1868.57 5753.57 6046.31 6248.81 6943.11 7080.74 7230.84 7230.85 10801.90 10863.02 29 January, 2002 - 10:08 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 -1C-104 (wp01) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 20 January, 2002 Station Coordinates TVD Northings Eastings Comment (ft) (ft) (ft) 0.00 O.OON 0.00 E 250.00 O.OON 0.00 E 477.83 15.93 N O.OOE 1114.28 210.01 N 179.47 W 1429.06 388.91 N 444.94 W 1556.24 477.47 N 627.37 W 3238.42 1801.07 N 3869.53 W 3369.12 1857.41 N 4124.03 W 3460.84 1865.75 N 4304.38 W 3713.81 1531.35 N 4809.64 W 3733.80 1402.19 N 4851.83 W 3739.80 1253.36 N ~{.§66.91 W 3739.80 1253.35 N 4866.91 W 3681.80 17.O'5t$W' 4831.23 W 3681 .46 8.16 S 4830.60 W 3686.80 3429.18 S 4819.37 W SHL: X=561631.04'E & Y;;ã96!J;.65!fi.41437' FI'lËJ& 625' FWL, SEC. 12-T11 N-R10E) Begin Dir @ 3.5°/100ft (9-7/8" H : 2!"~00ft MD, 250.00ft TVD Increase in Dir Rate @ 5.0"/100ft: 8.57ft MD, 477.83ft TVD Decrease in Dir Rate @ 3.0"/100ft : 1178.57ft MD, 1114.28ft TVD Increase in Dir Rate @ 6.0"/100ft: 1628.57ft MD, 1429.06ft TVD Dir, S8ßail @ 64.34° : 1868.57ft MD, 1556.24ft TVD in Dir ~6.00/100ft: 5753.57ft MD, 3238.42ft TVD (200') PUMP TANGENT @ 63.07°: 6046.31ft MD, 3369.12ft TVD Of PUMP TANGENT; Resume Dir @ 9.5°/100ft: 6248.81ft MD, 3460.84ft TVD op West Sak C Top West Sak B End Dir, Start Sail @ 90.93° : 7230.84ft MD, 3739.80ft TVD 7-5/8" Casing Pt ... Drill out 6-3/4" Hole Begin Dir @ 2.00/100ft: 10801.90ft MD, 3681.80ft TVD End Dir, Start Sail @ 89.71°: 10863.02ft MD, 3681.46ftTVD Total Depth: 11914.11ft MD, 3686.80ft TVD orth Slope, Alaska Kuparuk 1 C ~ Page 8 of 10 DrillQuest 2.00.09.006 0 ::.t:J ----.... ~ ",",",,-<- ~-::: ~ r--- Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 -1C-104 (wp01) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 20 January, 2002 Kuparuk River Unit Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Northings (ft) Profile Penetration Point Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) 1639.00 0.000 0.471 2294.81 1740.80 1639.00 622.6~¡a 2191.00 0.000 0.471 3569.66 2292.80 2191.00 1057.02 N 3033.00 0.000 0.471 5514.27 3134.80 3033.00 1719.54 N 3283.00 0.000 0.471 6080.94 3384.80 3283.00 1858.83 N 3331.00 0.000 0.471 6186.91 3432.80 3331. :20 N 3503.00 0.000 0.471 6581.31 17 .48 N 3588.00 0.000 0.471 6837.87 1621.05 N Casing details From To Measured Vertical Measured Vertical Depth Depth ~ Depth '''''¡mt¥9iDepth Casing Detail (ft) (ft) (ft) (ft) 7230.84 3739.80 7 -5/8" Casing ~~ 11914.11 3686.80 5" Liner 29 January, 2002 -10:08 ase Permafrost Top K-15 Top Ugnu C Top Ugnu B Top Ugnu A 4589.41 W K-13 4760.42 W Top West Sak D orth Slope, Alaska Kuparuk 1 C -. ..-..", Page 9 of 10 DrillQuest 2.00.09.006 C :.:r.:J ~'" --........ ~~ ;;;t~ ~ r--- Kuparuk River Unit Targets associated with this well path Target Name 1C-104 (B-Heel) 1 C-1 04 (B-Mid-pt) 1 C-1 04 (B-Toe) 1C-104 Geo-Poly 29 January, 2002 -10:08 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 -1C-104 (wp01) Your Ref: Parameters (6° DLS, 65° inc, 200' Pump Tangent) Revised: 20 January, 2002 Mean Sea Level/Global Coordinates: ~ Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: ~ Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Boundary Point #1 #2 #3 #4 #5 #6 Mean Sea Level/Global Coordinates #1 #2 #3 #4 #5 #6 Geographical Coordinates #1 #2 #3 #4 #5 #6 Page 10 of 10 orth Slope, Alaska Kuparuk 1 C <¡iF' Eastings Target Target (ft) Shape Type .37N 4866.91 W Point Current Target ,-~ 5970010.00 N 556754.00 E 70° 19' 43.3549" N 1490 32' 22.9548" W 3681.80 2317.05 S 4831.23 W Point Current Target 3580.00 5966440.00 N 556819.00 E 700 19' 08.2370" N 149032' 21.8461" W 3686.80 3429.18 S 4819.37 W Point Current Target 3585.00 5965328.00 N 556840.00 E 700 18' 57.2982" N 1490 32' 21.4789" W 3739.80 1253.37 N 4866.91 W Polygon Current Target 3638.00 5970010.00 N 556754.00 E 700 19' 43.3549" N 1490 32' 22.9548" W 3739.80 1253.16N 4841.91 W 3739.80 2317.25 S 4806.23 W 3739.80 3429.39 S 4794.37 W 3739.80 3428.98 S 4844.37 W 3739.80 2316.84 S 4856.23 W ~~. 3739.80 1253.57 N 4891.91 W 3638.00 5970010.00 N 556779.00 E 3638.00 5966440.00 N 556844.00 E 3638.00 5965328.00 N 556865.00 E 3638.00 5965328.00 N 556815.00 E 3638.00 5966440.00 N 556794.00 E 3638.00 5970010.00 N 556729.00 E 700 19' 43.3530" N 1490 32' 22.2249" W 700 19' 08.2351" N 149032' 21.1165" W 700 18' 57.2964" N 149032' 20.7495" W 700 18' 57.3001" N 1490 32' 22.2084" W 700 19' 08.2388" N 1490 32' 22.5756" W 700 19' 43.3567" N 1490 32' 23.6847" W DrillQuest 2.00.09.006 Sper~y-Sun Drilling Se~ vices Proposal Data - Plan: 1C-104 -1C-104 (wp01) MD Delta Inclin. I Azimuth: lVD I Northings Eastings: Dogleg: TooIface I (ft) MD (ft) ~ (°) (°), (ft). (ft) (ft): (°11 OOft) ~ (°) , 1 ~~ . ~ '~-=~~-~:~~r~'--~ -~~ ~ ~ ~~r~~~~~§~~-~~~§_~.~=~ìr=--~~-~:~:~.-;-~~~-~~~~=..:~~§Qi~..~:~~-:..::.::~._-~j~. ;-'~. . -~--~~:J~-~:- :~:=-j 2 250.00 250.001 0.000 0.000. .2~.00 . 0.00 0.00 O.OOO! O.ooo! 3 478.57 228.571 8.000 0.000: 477.83 ~15.93 N 0.00 3.5001 0.000: 4 1178.57 700.001 39.532: 308.703: 111428 210.01N 179.47W 5.000 300.0001 I 5 1628.57 450.001 51.591 ~' 300.131' 1429.06 388.91 N 444.94 W 3.000 330.000 I 6 ~868.57 240.001. 64.342~~2~.207 ~ 1556.24 ~477.47 N 627.37W 6.000 330.000 ¡ 7 5753.57 3885.001 64.342 292.2071 3238.42 1801.07 N ~ 3869.53 W 0.000, 0.0001 8 6046.31 '292~.74: 63.068 272.648 3369.12 1857.41 N 4124.04 ~ 6.000 261.5161 9 6248.81 202.50 63.068 272;648 3460.84 1865.75 N 4304.38 W 0.000 0.000 10T' 7230.84 ~ 982.03 90.931 179.428 3739.80 1253.37 N 4866.91 W 9.500 269.371 111T 110801.901 3571.061 90.931 179.4281 3681.801 2317.05S 4831.23 Wi 0.0001 0.000 12 10863.02 ~ 61.12 89.709 ~ 179.388 '3681.46 2378.168 4830.60W 2.000 181.871 I 13T11914.11 1051.09 89.709 179~388 3686.80 3429.18 S 4819.37W 0.000 0.000 25 February, 2002 -14:10 - 1 - ORJ /Ì? }."i~l~, t.. sf fl/ ;~~ Sper}y-Sun Drilling Se~ vices Proposal Data - Plan: 1C-104 -1C-104 (wp01) MD ¡ Delta. Inclin. Azimuth ¡ TVD : Northings I Eastings Dogleg ~ Toolface ¡ (ft) ~ MD (ft). (°) (°) I (ft) ¡ (ft) (ft) (o/100ft); (°) i -~ -~ 1-~~~. ~--~~=i9?T~-~-- .._-~.-~t~~~9~~OO~~:~':~:~ ~=~101ß6'-59~~~~~~~~-~~_~-~~i~~~-§_-~: -~ .:~ -- ~~~:[~.=~~:~~] 2 . ~ 250.00 250.00' 0.000 O.OOO.~ : ~14820 5968796.65N. 561631.04 E- 0.0001 0.000; 3 478.57 228.57 8.000 359.529: 376.03 5968812.58 N 561630.91'E 3.5001 359.529: 4 1178.57 700.00~ 39.532' 30823311012.48' 5969005.18 N.' 561449.SS'E 5.000' 300.000: 5 ~ 1628.57 450.0011 5.1.591.' 299.666'~ .132726 5969181.89 N:561182.92'E 3.000 330.0001 6'1868.57 240.00 64.342 291]371454.44' 5969268.95 N 560999:77.E 6.000 330.000 7 ~ 5753.57 3885.001 64.342 291~7373136.62 5970565.88 N557746.85 E; 0.000 0.0001 8 6046,3~ ~ 292.74 ~~ 63.068 272.177 3267.32 5970620.12 N 557491.89E 6.000 ~ 261.5161 9 6248.8f 202.50 63.068 272,177: 3359:04 5970626.98N 557311.48E~ 0.000 ~ ~ ~ 0.000 10T ~ 7230~.84 ~ 982.03 90.931 178.957 3638.00 5970010.00 N 556754.00 E 9.500 ~ 269.371 : 11T 110801~901 3571.061 9O.931 178.9571 3580.001 5966440.00 NI 556819.00 EI 0.0001 : 0.000 ,12 10863.02 ~ ~. ?1.12~ :89.709~ 178.917~3519.66 .5966378.89N 556820.13E 2.000 181.871 ! 13T 11914.11 1051.09' 89.709 178.917 3585.00 5965328.00 N 556840.00 E 0.000 . 0.000 25 February, 2002 - 14:10 - 1 - 0; I h D~iII~uest l"'@ ¿., (pfìfutr;s\ . "'~.;:.IRIA,;;:' ~'''''' i~~r-~,' 'l~,J ~~J1 '¡ .: .~ - _n~~~:::: ;;_._~~ UJ. ~. . .'. 0 -"~ Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 1C Pad 1C-104 (wp01) Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: 5968796.65 N, 561631.04 E Ref. Stucture Referance : 280.27 N, 738.73 W Ref. Geographical Coordinates: 70019' 31.0425" N, 149030' 00.8575" W 1437' FNL & 625' FWL, SEC. 12 - T11N - R10E Plan: 1C-104 SiiPE!r-'r'V-SiiUI1 çtBI~Ç:ç:[~::g,:::'=~~~i3,~[ê'em5 A Halliburton Company RKB Elevation: North Reference: Units: 101.8Oft above Mean Sea Level True North Feet (US) ....::.~:~:..:~.;~;.... ..- 0 .,~~~. .,,,~'- ----- Begin Dir @ 3.5°/100ft (9-7/8" Hole) : 250.00ft MD, 250.0Oft ND SHL: X:=561631 ,04' E & Y=5968796.65' N (1437' FNL & 625' FWL, SEC. 12wT11NwR10E) 700 - :::J' (/') 1400 - ~ «! 0 .... Bd.Y<~ II II) ~ a: ~2100- ã. Q) 0 ëij 0 :e Q) > 2800 - C'" 4= 0 0 ';; 3500 - .s::: 0 .E å) (ij 0 (J) ~-" "'1<.. "'" I -2100 Scale: 1 inch = 700ft It.. DrillQu6st 2.00.09.006 ¡,.ÇJÇJSJ ~ Increase in Dir Rate @ 5.00/10Oft : 478.57ft MD, 477.83ft ND - - 700 Decrease in Dir Rate @ 3.00/lOOft : 1178.57ft MD, 1114.28ft ND Increase in Dir Rate @ 6.00/lOOft : 1628.57ft MD, 1429.06ft ND 5 - 1 400 (/') ~ «! End Dir, Start Sail @ 64.34° : 1868.57ft MD, 1556.24ft ND --. -~--~- ..~ 0 .... -. -~~,- ~ -- .~.__._-_. -- --.---.-" - -.--~.- _.- II II) ~ a: - 2100 ~ ã. Q) 0 ~ :e Q) > r'-'--"'-B;g¡;~"(20Õ;)PÜMP TANGENT l /1 @ 63.07": 6046.31ft MD, 3369. 12ft TVD ~~\fJ /// ~~~'~=~:::~~~;i~~~~::~i~~~~~~;~~i:ii::~=:~~~~~~~~~~~~~'~ / .- Resume Dir @ 9.5c'/100ft : ~'!J\fJSJY/ .--/.-'-- . 6248.8111 MD,~.?~~~..:.~~..~.9..._.. ~.- ~o ~'ò\\ ~O '!J'ò~\' ~\)\\ ~O' '!J'ò~\' \)r¿.~ ~O ~O' \)~'ò'!J' ~~~ ~ 0'\ ~/O \)~\)\~ ~~:\"\' t"'\ '!J'ò/O ' . "\ @ ~'v' \)\)~ . ~i~ \ \ \\ n,°\"\ '().~ o.\~' r¿.~ ~~ \\~ .~ @ ~ ,)\1.., ~'. .~ O~ ~~ ~ ~ortN ~0~" ~ O\'?J: Ë ~ 1C-1~4(""011. -3500~ \ÇJ\fJÇJSJ \<:)ð[:JÇJSJ \ÇJ'lf:JÇJ') \'\'IS>ÇJ.ÇJ \'\ã:>ÇJf:; / ~ 1 ~OO ¡ c. ¡ 041.{~2d-I'( 2~OO ". ¡ ;"~?1'"" ¡¡, )(,8UiIJ TVD. 2317Ji5 S, 4831.'}) W 3ti86.RO lTV, 3~¡29.18 S. ,18f9.37 II' U.524 , PSt & Jfi7f' FWL, SEe. lJ.TlJ:V~Klf}E) (4/2' PSi. &: j(J83' FWL, S'Ee. IJ. TII ,y,.r(f(iEj .~~ - 2800 End Dir, Start Sail @ 90.93° : 7230.84ft MD,f3739.80ft ND ~ Þ-5I." Casing PI ... Onll out 6-314" HOI.! ~11)1) "..~ h 7-5/8' Csg <:) <:) <:) ÇJ' \fJÇJ 7230.811 MD1~<ß~ \1Ó<ß~ 'òo<ß~ 'ò",<ß~! 'ò'iJ' u.~~ ! I I ¡ -1400 J('..]I)4 ([UrN:!) -700 0 3739.8(1 lTD, 12S337 ,'\', 486(',91 W {í85' FNL& 11)38' FWL SEe. ]/-'J11N..RlOEJ Section ß\z¡rnuth: 1 ß(H)o(Y . '!J~<ßSJ . '!Jó\fJSJ I 700 a ~~ ~¡;,:<1 ~~ ~~>: ~çJ.:;:~Â~:';' r-- fto." .,/":.~,.~.~..-"./" «~~~~~~~UPSJ; ~ii;,.r:'~' ,I ~'''i~ ~ ",.4 ~~ r.j , ~. ~'~:~ ;¡::~~" J . 2000 - 1000 - en 0) c :E t 0 Z .1000 - -2000 - ~ 0 0 0 II -3000- ~ 0 .£; åi ãi (.) en DrillQuest 2.00.09.006 Phillips Alaska, Inc. Kuparuk River Unit 1 C Pad 1C-104 (wp01) spel''''''y-sul1 Q', ~~~ (ç: ~~ j' :~~t¡-- -s]?;F{y r~I§)~; A Halliburton Company -1 000 0 1000 I I I I I I I I - 2000 I I I I -5000 -4000 I I r''''---'-i3ëgï;;"' (200') PUMP TANGENT-~-~---l i @ 63.07": 6046.31ft MD, 3369. 12ft TVD . 'I ~ Begin Dir@6.00/100ft: End (200') PUMP TANGENT -.. Resume Dir @ 9.5"/100ft : .-.- ------.., j ------ 5753.57ft MD, 3238.42ft TVD 6248.81ft MD, 3460.84ft TVD / End Dir, Start Sail @ 90.93° : 7230.84ft MD, 3739.80ft TVD ( 7-5/S' Csg ~ . 7230~Sft MD .. ~J.. 3739.8ft TVD 7-5/8" Casing Pt ... Dnll out 6-3/4" Hole ¡ I' ~ 3739.8(j I! U85' FNL& 1038' FWL. ! -7000 f -6000 I -3000 I -2000 I ri ~J " ~. Þ.. 6- ~ y¡ '<}i ~c¡ ~~ I! ~ ¡ i Begin Dir@2.00/10OO:10801.90ftMD,3681.80ftTVD Ii I ~¡ 368IJW End Dir, Start sail@89'710:10863'02ftMD'3681.46ftTV1Dn(1514'PSI-1i ¡ i ...---- 0 ,0. i¿ li~ ~~ 5-1/2'Uner Total Depth: 11914.11ftMD,3686.8OOTV ~~. 11914.1ftMD 36B6.8ft TVD . I I r-'" ....~........................................~.~.........~.~.....,~..~,~¡..~~......""~"'.''''''~'~''''~''~''''''''''''''~~'''''''''~1 I SHL: X;,,£i61631.04'E &. Y;::5968ï9665'N I 1...(~.~:~:!T..~~~~~~..~..?~~~?'~XY.Y..~~..r..§'9.:...1~~~~!..~.~~.~::~~~.1..?.q) I ! i ' I ~~~~ I i~@ A\\i , ! . S\a.(I.\~~õJ; \oçþ'. ! . ..Q\1.:,\\~Q, c.Ool ~1\\) 5' @ U' \lQ \ 'òõ'ò. '1 y\a.\0~ oõ\\ i \ \00\\ . .... ....~~..~~~.~.~... ..~e.\~~, \AZ.~...:...~~~....... ..~. .@~.'3.~Q"""""'''u""()\'(,, ~.........~.~~....~ \1\C10'ò 51\\ Q\1 y\a.,": 'l.'ò\\ i 001\ \:) \õ'l) 0\1\ \\\. @~. . c10a.S \\ ~Q, . y\a.\0 ~"\'IQ " I(\O\0~ . Q01'ò51 '1\ Q\1 ;11 .'ò'?Î .11'õ \ \ a.S0 \ ~ Þt ~ ,~ \1\C<0 ~1\\ \J\ ' ~O\\o~ ~Q A1'ò. Q\< @ ~~~opO ß0~1\ o\\~Q, 'l.~o~ en 0) c :E t 0 Z - 1 000 0 _..~.~~..~~..~ ,- 0 - .1000 N (/*{~'~..'~\., \: .' " "'... ':j '~<.,*".;..,. ~/ Reference is True Nor~h i ,~" - -2000 Current Well Properties Plan: 1C-104 Well: Horizontal Coordinates: Ref. Global Coordinates: 5968796.65 N, 561631.04 E Ref. Stucture Referance: 280.27 N, 738.73 W Ref. Geographical Coordinates: 70.19' 31.0425' N, 149030' 00.8575' W 1437' FNL& 625' FWL, SEC. 12 - T11N - R10E ~ 0 0 0 - .3000 ~ 0 .£; åi ~ (J) RKB Elevation: North Reference: Units: 101.8011 above Mean Sea Level True North Feet (US) I .7000 3686.MJ TFD, W U12' FSL& W83' PhL, SEe 1l.TllN.¡WJEj I I -4000 -3000 Eastings 0 I 1000 I -1000 I -2000 I -6000 I -5000 Scale: 1 inch = 1000ft Phillips Alaska, Inc. 1C-104 (wp01) MD Inc Azim. SSTVD TVD N/S EIW Y X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) (ft) 0.00 0.00 0.00 -101.80 0.00 0.00 N 0.00 E 5968796.65 N 561631.04 E 0.00 0.00 SHL 250.00 0.00 0.00 148.20 250.00 0.00 N 0.00 E 5968796.65 N 561631.04 E 0.00 0.00 Begin Dir @ 3.5°/100ft (9-7/8" Hole) 478.57 8.00 0.00 376.03 477.83 15.93 N 0.00 W 5968812.58 N 561630.91 E 3.50 -15.93 Increase DLS to 5.0°/1 OOft 1178.57 39.53 308.70 1012.48 1114.28 210.02 N 179.47 W 5969005.18 N 561449.85 E 5.00 -210.02 Decrease DLS to 3.0°/1 OOft 1628.57 51.59 300.14 1327.26 1429.06 388.91 N 444.94 W 5969181.89 N 561182.92 E 3.00 -388.91 Increase DLS t06.00/1 OOft 1868.57 64.34 292.21 1454.44 1556.24 477.47 N 627.37 W 5969268.95 N 560999.77 E 6.00 -477.47 End Dir; Start Sail 2294.81 64.34 292.21 1639.00 1740.80 622.69 N 983.08 W 5969411.24 N 560642.88 E 0.00 -622.69 Base Permafrost 3569.66 64.34 292.21 2191.00 2292.80 1057.02 N 2046.98 W 5969836.82 N 559575.45 E 0.00 -1057.02 Top K-15 5514.27 64.34 292.21 3033.00 3134.80 171954 N 3669.82 W 5970485.99 N 557947.22 E 0.00 -171954 Top Ugnu C 5753.57 64.34 292.21 3136.62 3238.42 1801.07 N 3869.53 W 5970565.88 N 557746.85 E 0.00 -1801.07 Begin Dir @ 6.0°/1 OOft 6046.31 63.07 272.65 3267.32 3369.12 1857.41 N 4124.04 W 5970620.12 N 557491.89 E 6.00 -1857.41 End Dir; Begin PUMP TANGENT 6080.94 63.07 272.65 3283.00 3384.80 1858.83 N 4154.87 W 5970621 .29 N 557461.04 E 0.00 -1858.83 Top Ugnu 8 6186.91 63.07 272.65 3331.00 3432.80 1863.20 N 4249.25 W 5970624.88 N 557366.63 E 0.00 -1863.20 Top Ugnu A 6248.81 63.07 272.65 3359.04 3460.84 1865.75 N 4304.38 W 5970626.98 N 557311.48 E 0.00 -1865.75 End PUMP TANGENT; Resume Dir 6581.32 66.99 237.96 3503.00 3604.80 1789.48 N 4589.41 W 5970548.37 N 557027.09 E 9.50 -1789.48 K-13 6837.87 74.83 213.50 3588.00 3689.80 1621.06N 4760.42 W 5970378.55 N 556857.4 7 E 9.50 -162'j .06 Top West Sak 0 6943.11 78.85 204.09 3612.01 3713.81 1531.34 S 4809.64 W 5970288.44 N 556808.98 E 9.50 -1531.84 Top West Sak C 7080.74 85.50 192.17 3632.00 3733.80 1402.19 N 4851.83 W 5970158.95 N 556767.86 E 9.50 -1402.19 Top West Sak B ~ 7230J34 90.93 179.43 3638.00 3739.80 i 253.37 N 4865.91 W 5970010.00 N 556754.00 E 9.50 ~i253.37 (TARGET: B~Hee!) End Dir; Start Sail; 7-5/8" Casing pt ... Drill out 6-3/4" Hole 10801.90 9tL93 119.43 3530.00 3631.80 2317.05 S 4831.23 W 5966440.00 N 556819.00 E 0.00 2311.05 (TARGET: B-Mid-Pt) Begin Dir 10863.02 89.71 179.39 3579.66 3681 .46 2378.16 S 4830.60 W 5966378.89 N 556820.13 E 2.00 2378. 16 End Dir; Start Sail 11914.11 89.1'! 119.39 3585.00 3686.80 3429.18 S 4819.31 W 5965328JJO N 556840.00 E 0.00 3429.18 (TARGET: 8-Toe) Total Depth C :J:J .......... ~ <:: ~ r--- Company: Field: Reference Site: Reference Well: Reference Wellp~th: Phillips Alaska Inc. Kuparuk River Unit Kuparuk 1 C Pad Plan: 1 C-1 04 1 C-1 04 Sperry-SUD Anticollision Report D~te: 2/25/2002 Time: .12:01 :41 1 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan: 1C-104, True North 1C-104 @ 101.8101.8 GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 50.00 ft Depth Range: 41.20 to 11914.11 ft Maximum Radius: 1387.29 ft Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 1/11/2002 Validated: No Planned From To Survey ft ft 41.20 900.00 900.00 11914.11 Casing Points MD TVD ft ft 6740.00 3661.51 11909.82 3686.94 Planned: 1C-104 (wp01) V1 Planned: 1C-104 (wp01) V1 Diameter in 7.625 4.500 Hole Size in Name 9.875 6.750 7-5/8" 4-1/2" Summary <-~-~---~-----;...-~~--- Offset W ellp~th--~~~------~,:~--------> Site Well Wellpath Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 D Pad 1 C-06 1 C-07 1 C-08 1 C-09 1 C-1 0 1 C-1 02 1 C-1 02 1 C-1 09 1 C-1 09 1 C-111 1 C-11 1C-117 1C-119 1C-121 1 C-12 1 C-125 1 C-17 Plan: 1 C-1 04 1 D-112 1 C-06 V1 1 C-07 V1 1 C-08 V2 1 C-09 V2 1C-10 V1 1C-102 V1 1C-102L1 V3 1C-109 V3 1C-109L1 V1 1C-111 V1 1C-11 VO 1C-117V1 1C-119 VO 1C-121 V1 1C-12 VO 1C-125 V3 1C-17VO 1 C-1 04 L 1 VO Plan: 1 C- 1 D-112 V2 Version: Toolcode 6 Tool Name CB-GYRO-SS Camera based gyro single shots MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Reference Offset Ctr-Ctr. . No-Go AlloWable MD MD DiStance. Area Deviation ft ft ft ft ft 545.56 550.00 238.38 10.77 227.61 Pass: Major Risk 653.38 650.00 169.78 11.75 158.06 Pass: Major Risk 868.60 850.00 132.27 15.77 116.61 Pass: Major Risk 813.05 800.00 48.24 15.65 32.62 Pass: Major Risk 298.87 300.00 61.30 6.83 54.47 Pass: Major Risk 400.73 400.00 31.29 7.08 24.37 Pass: Major Risk 400.73 400.00 31.29 6.95 24.50 Pass: Major Risk 395.29 400.00 87.27 7.95 79.34 Pass: Major Risk 395.29 400.00 87.27 7.95 79.34 Pass: Major Risk 3738.14 4000.00 181.28 195.29 27.88 Pass: Major Risk 844.49 800.00 186.30 17.27 170.25 Pass: Major Risk 296.66 300.00 210.02 6.02 204.01 Pass: Major Risk 250.00 250.00 240.07 4.65 235.42 Pass: Major Risk 250.00 250.00 270.79 5.06 265.73 Pass: Major Risk 732.25 700.00 180.28 14.32 166.51 Pass: Major Risk 249.99 250.00 331.76 4.53 327.23 Pass: Major Risk 1468.95 1450.00 77.33 38.92 46.61 Pass: Major Risk 6100.00 6100.00 0.00 0.73 -0.73 FAIL: No Errors Out of range 0 Name Plan: IC-I04 -368 -300 ~"~'-2oo -100 - 0 270 -100 '~-'-200 -300 -368 Q ~4:~.~, WElL DETAILS ANTI-COLLISION SETnNGS +N/-S +FJ-W Northing Easting Latitude Longitude Slot Interpolation MethodMD Interval: 50.00 Depth Range From: 41.20 To: 11914.11 Maximum Range: 1387.29 Reference: Plan: lC-I04 (wpOl) 280.37 -738.78 5%8796~65 561631.04 70"]9'31.042N 149'3O'00.857W N/A SURVEY PROGRAM Depth Pm Depth To SurveylPlan 41.20 900.00 PhMcd: IC-I04 (wpOI) VI 900.00 11914.11 Planned: IC-I04(wpOI) VI Tool CB-GYRO-SS MWD+IFR-AK-CAZ-SC From Colour 0 400 600 800 1000 1500 2000 2500 3000 3500 '¡OIH, '¡~!H) 50lHI (¡IIIHI 701 HI XIIIHI 'JIII"I II fIlH I 'JIHI 0 .11"1 IC-I04 (wpOl) Approved Plan Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [200ft/in] COMPANY DETAILS WElLPATH DETAILS IC-I04 Rig: Nabors 245 Ref. Datum: IC-I04@ 101.8 101.800 V~Section Orig.. Origin ~:'''fvD Angle +NI-S +FJ-W 234.57" 0.00 0.00 0.00 Phn: IC-I04 (wpOI) (phn: IC-I04/IC-I(4) Pbillips Alaska Inc~ Engineering Kuparuk Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North W=:~~~d: ~B~:Ja'ing Creat,," Dy: I,.v" "8OOl\hl Checked: L~lt": 2f25f2('1.Yl Date:- Dute: Reviewed: ---- Appn>vc<I: --- )}lIle: -88 u 00 Fnlt'O Cuiow' Tu MD 0 .~-"--'~ 400 400 - (.00 600 - 800 800 - 1000 1<X>O "'N«^'=~' 1500 1500 - 2<00 2000 2500 2500 - 3000 3000 - 3500 '500 -,"",,- 4000 4000 - 4~OO 4500 - 5000 5000 - WOO (1000 - 7000 7000 - 8000 8000 - 9000 9000 - 10000 I( ( ()()- 11000 000 12000 ~-'75 ~- -50 , f/ . AA~\ ¡: . ""r'. ~~~25 -,~ >.' /..... ;':' . ~~~~U~!--. 'j ~ JC~17(1C.J7). "'~ /~./}\\./ f -0 270)\~~Z\~ \\..,...~ / '. ~~ , \ \-- '\\\\ \\/\ 24~" . -25 ~"'50 -75 -88 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [50ft/in] SECTION DETAILS See MD hIe Azi 1VD +N/-S +E/-W DLcg 1Faw VScc Target 1 41.20 0.00 0.00 11.20 0,00 0.00 0.00 0.00 11.00 2 250.00 0.00 0.00 .'"\11.00 0.00 0.00 0.00 0.00 11.00 3 478.57 8.00 0.00 01.83 15.93 0.00 3.50 0.00 "~24 4 1178.57 39.53 308.70 111~1.29 210.00 -179.47 5.00 300.00 24..49 5 1628.57 51.59 300.14 1-1."1.07 388.89 -444.93 3.00 330.02 1<1.08 6 1868.57 64.34 292.21 1"¡~1..26 477.46 -627.35 6.00 329.99 : 1.'.37 7 5753.57 64.34 292.21 1: 1.<.58 1801.17 -3869.39 0,00 0,00 ~ IIIK.61 8 6046.31 63.07 272.65 'h""J,28 1857.52 -4123.89 6.00 261.53 ~~KI.31 9 6248.81 63.07 272.65 Ur.I,OO 1865.87 -4304.24 O~OO 0.00 :~ ~'.42 10 7230.84 90.93 179.43 17I"~94 1253.51 -4866.8] 9.50 269.37 1,.lx.81 11 10801.90 90.93 179.43 Ir." 1.98 -2316.91 -4831.29 0.00 0.00 '~)".75 12 10863.02 89.71 179.39 't,SI.64 -2378.02 -4830.66 2.00 181.88 '''..67 13 11914.11 89.71 179.39 ~t'S'..96 -3429.04 -4819.47 0.00 0.00 "'114.86 DRAFT GEOLOGIC SUMMARY: Primary Target: West Sak 8 Sand Formation 1 C-1 04 (X7) Heel Mid-point Toe Target Shape: Formation 1 C-1 04L 1 (X7) Heel Mid-point Toe Target Shape: x x 560,644 559,575 557,948 557,460 557,365 557,023 556,856 556,806 556,767 556,754 556,819 556,840 1C-104 Responsible: Mike Werner - 6191 y Z (TVD.SS) Porosity Perm Heservoi r Preferred Temp. Tar. Angle y 5,969,411 5,969,837 5,970,486 5,970,621 5,970,624 5,970,544 5,970,372 5,970,276 5,970,150 5,970,010 5,966,440 5,965,328 3,638' 3,580' 3,585' Approximate Stepout: 4683 horizontal 26 Net Pay: Mike Werner - 6191 Heservoir t'referred Temp. Tar. Angle Z (TVD.SS) Porosity 3,585 3,522 3,529 Approximate Stepout: Perm 4683 horizontal 30 556,754 5,970,010 556,819 5,966,440 556,840 5,965,328 Rectangle +/-25' east/west Remarks: Target depths are 8 feet below the top of the B Secondary Target: West Sak D San' Responsible: 556,754 5,970,010 556,819 5,966,440 556,840 5,965,328 Rectangle +/-25' east/west Remarks: Target depths are 14 feet below the top of the D Geological Prognosis: Responsible: Formation X Y Z {TVD.SS} MD 1C-104 Base Permafrost Top K-15 Top Ugnu C Top Ugnu B Top Ugnu A k13 Top West Sak D C B B Sand Heel Mid-point B Sand Toe 1,639' 2,191' 3,033' 3,283' 3,331' 3,503' 3,588' 3,612' 3,632' 3,638' 3,580' 3,585' Net Pay: Mike Werner - 6191 Pay Frm Press Frac Press 2,295 3,570 5,514 6,081 6,187 6,581 6,838 6,943 7,081 7,231' 10,802' 11,914' 26 26 26 1C-104L1 k13 557,018 5,970,544 3,503' Top West Sak D 556,841 5,970,352 3,574' 6,811' D Sand Heel 556,754 5,970,010 3,585' 7,226' 30 Mid-point 556,819 5,966,440 3,524' 10,797' 31 D Sand Toe 556,840 5,965,328 3,529' 11,909' 29 Remarks: Offset Pressure Data: Responsible: Mavriky Kalugin - 4440 Injector Date of Well Type Fluid PSI MD TVD Meas. Measurement Method 1 C-111 Prod Water 1560 6,340' 3,778' 8/26/2001 SBHP dunk 1C-125 Prod Water 1705 6,900' 3,706' 12/28/2001 SBHP dunk 1 C-121 Prod Water 1777 6,690' 4,056' 11/5/2001 SBHP dunk Estimated: This Well 1639 tbd 3740 1/15/2002 Estimate. Remarks: Pressure estimate at deepest point in geological prognosis plus 102 feet for consistency. 1/17/20021:36 PM 0.1/ I L Tubing Head Assy, (497-0055) Vetco-Gray Gen II for Single Completion, API 13-5/8" 5000 psi Flange up x Vetco 13-5/8" Female Overshot Bottom Casing Head: ~ ~ Vetco-Gray, 16" Weld on Bottom x ~ 13-5/8" Male Overshot Top ;. 16" Conductor ~ @ +1-158' MD Centralization: Weatherford 7-5/8" x 10-1/2" Bowspring (1) on each collar from 4000' to Float Collar (1) on a stop collar in the middle of the joint below the float collar (1) on a stop collar in the middle of the joint above the float shoe (1) on each of the three collars above and below the port collar PHILLIPS PHILLIPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY 11 ~ I~I I I I I I I ~ I I I z I i ~ I I ~ I I I I I I I I I I ~ i I I ~ ~ I I I ~ I I I I I ~ (x) Pup Joints Casing: ~ i 7-5/8",29.7#, L-80, BTCM, as I i ~ required to space out window ~ ~ joint. I i (498-6805) 4 foot pup I ~ (498-6800) 6 foot pup ~ I (498-6795) 10 foot pup I I ~ (477-8475) 20 foot pup I I ~ i (x) Joints Casing: I i (463-4825) 7-5/8",29.7#, L-80, BTCM I i I I I I I ~ I I I I I I I ~ i L- ~ Float Collar: " r ~ ( Weatherford Model 402, 7-5/8", 29.7#,BTCM I I (463-4827) Joint with Float Shoe I ~ (2) Joints Casing: ~ i ( 7-5/8",29.7#, L-80, BTCM I i (463-4828) Joint with Thread Locked I ~ B~ ~ ~ ~FloatShoe: / ~ Weatherford Model 303, 7-5/8",29.7#, BTCM 7 -5/S" Shoe: (463-4826) Joint with Float Shoe 7,231' MD /3,740' TVD +/- 91 degrees TD 9-7/S" Hole: 7,231' MD /3,740' TVD Nabors Rig 245 RKB @ 0' Eastings: 561,631.04 Northings: 5,968,796.65 Elevation: 101.8' AMSL Casing Hanger: (497-0030) Vetco-Gray, with 7-5/8",29.7#, BTC pin down x Acme box up Port Collar: (485-7080) TAM, 7-5/8", 29.7#, L-80, BTC Pin Set @ +1- 1,000' MD I 96S' TVD Planned Top of Whipstock @ 6,740' MD West Sak WeIl1C-104, AFC AK xxxx Planned Completion Schematic Sheet 1 of 4: Suñace Casing Details prepared by Todd Mushovic DRAFT O~ (1/..';' J,fn~.a..,iryfOI2001 !f- r~ if {,'..~ 11"'4 J , '" Ii'! ',Ii ¡jq ~-a §-::J: 5:- ¡¡¡~. -<I !a.- ~-a Fen ~» m- jjD) f2(1) m", ~D) 0" °- Š::J ~ zn -<" :e cn.,,(D ':r_ø (D S» r+ (D::Scn r+::ss» N(D" Oc.:e :;:O(D .. 0 - ....3:: 0"E..0 c:: (D I <r+~ (D -. 0 ..,o~ .... ::s .. -. cn » ::sC')." ~:TO OCD» (D3~ 6tS»~ -. !:to >< -C')>< ø >< >< ~ èi3 ~ Q) èi3 ( ~ " ~ ~ .- ::;:¡ ::-i " 'i:: 0 Q) 8: " ~ ~ ~\:)~ t ~~õ ~~~. Top of Whipstock to be @ +1-6,740' MD See Sheet 1 for Casing Detai Is Liner Top Packer Set @ +1- 7,000' MD Suñace I Production Casing 7-5/8" 29.7# L-80 BTC Mod Set @ 7,231' MD (1) Set Shoe Assembly, Baker, consisting of: (1) Set Shoe, Baker Model 'GPV', 5.560" Max aD, 5", 18# SLHT Box. (1) 18.5 ft Pup Joint, 5", 15#, SLHT, with weephole. (1) Crossover, 4", 11.6#, SLHT Box x 5", 18#, SLHT Pin (2) Joints 4" Blank Pipe, 4",9.5#, L-80, SLHT. (x) joints 4" x 4-1/2" Screen, Baker Excluder 2000,4",9.5#, SLHT (Screen aD = 4.9") alternating every other joint through the production zone with (x) joints 4" Blank Pipe, 4", 9.5#, L-80, SLHT as required from 'GPV' Set Shoe Assembly to 7-518" casing shoe. ,~-~ (x) Joints 4" Blank Pipe, 4",9.5#, L-80, SLHT, as required inside the 7-5/8" Casing to space out the packer +1- 80 feet below the bottom trip anchor of the whipstock assembly (i.e. 103 feet below the top of the whipstock. Top of the whipstock is planned for 5942') (1) Crossover Sub, 4-1/2", 11.6#, SLHT Box x 4",9.5#, SLHT Pin. (1) Joint 4-1/2" Blank Pipe, 4-1/2", 11.6#, L-80, SLHT (1) Sliding Sleeve, Baker Model 4-112" 'CMD', w/3.43" ID, 4-1/2",11.6# SLHT Box x Pin (1) Joint 4-1/2" Blank Pipe, 4-1/2",11.6#, L-80, SLHT. (1) Crossover Sub, Baker, 5",18#, SLHT Box x 4-1/2",11.6#, SLHT Pin (1) KOIV (Knockout Isolation Valve), Baker Model 'C', 5",18#, SLHT Box x Pin (1) Packer Assembly, Baker, consisiting of: (1) Crossover Sub, Baker, 5-1/2",17#, SLHT Box x 5" 18# SLHT Pin (1) Mill Out Extension, Baker, 3' Long, 5-1/2", 17# SLHT pin x pin (1) Packer, Baker Model 'SC1-R' (76B2-40), 7-5/8", 24-29.7#, wI 5-1/2", 17#, SLHT box down. Il~=~=~=~=~=~=~~~=~=~~~= I I~~~~~~~~~~~~~ ~ I~~~~~~~~~~~~~ 3 ) 6-3/4" Open Hole TD: +1- 11,914' MD /3,687' TVD ~'"tJ §-::r:: 6:- ¡¡¡' r- -<r- a.... ~'"tJ r;.cn ~:Þ m- :dO) ~( ) m" ~O) 0'"' 0- ~~ z() -<. :e en.,,(þ ':j'_tn (þS»r+ (þ:::::sen r+:::::ss» w(þ" oQ.:e ~O(þ .. 0 - ï3::: o~O <: (þ- <r+..,)¡, (þ -. 0 ..,o~ ï :::::s .. -. en » :::::s (') ." ~':j'O O(þ» (þ3-r r+S»'" !. ~ >< ëñ(')~ >< a ::ro~< "C -.. ~ Q) (""; Q3 '""'L Q. """"'c... ~ -,Q) ~,~;~ ~ ..~ Q) Q. "J"% ~ ~".~~ I\);;P;:'- c~o ~ :!1 ~. (1) Liner Hanger, Baker Flanged Hook Hanger, Size 7-5/8" x 4-1/2",4-1/2", 11.6#, BTC Pin Down (1) Swivel Sub, Baker, 4-112", 11.6#, BTC Box x Pin (1) Crossover, Baker, 4-1/2", 11.6#, BTC Box x 4-1/2", 12.6#, IBT Pin (x) Joints 4-1/2" Blank Pipe, 4-1/2", 12.6#, L-80, IBTM. (1) ECP I Indicator Sub Assembly, Baker, consisting of: (1) Handling Pup, 8', 4-1/2", 11.6#, L-80, IBTM Box x BTC Pin (1) Indicator Profile Sub, Baker, 10K-15K Snap Force, 4-1/2" ,11.6#, L-80, BTC, Box x Pin (1) Handling Pup, 6' long, 4-1/2", 11.6#, L-80, BTC Box x Pin (1) ECP (External Casing Packer), Baker Model CTC 20' Payzone, 4-1/2", 11.6#, L-80, BTC Box x Box (3.833 Min ID). (1) Bottom Sub, Baker, 3' long, 4-112", 11.6#, L-80 BTC Pin x 4-1/2", IBTM Pin (x) Joints 4-1/2" Blank Pipe, 4-1/2", 12.6#, L-80, IBTM. D Sand Heel at +1-7,226' MD, 3,687' TVD Top of Window at +1- 6,740' MD, 3,661' TVD Liner Top Packer Set@ +1-7,000' MD 13,724' TVD þ (1) ECP I Indicator Sub Assembly, Baker, consisting of: (1) Handling Pup, 8',4-1/2", 11.6#, L-80, IBTM Box x BTC Pin (1) Indicator Profile Sub, Baker, 1 OK-15K Snap Force, 4-1/2",11.6#, L-80, BTC, Box x Pin (1) Handling Pup, 6' long, 4-1/2",11.6#, L-80, BTC Box x Pin (1) ECP (External Casing Packer), Baker Model CTC 20' Payzone, 4-1/2", 11.6#, L-80, BTC Box x Box (3.833 Min ID). (1) Bottom Sub, Baker, 3'long, 4-1/2",11.6#, L-80 BTC Pin x 4-1/2", SLHT Pin (1) Joint 4-1/2" Blank Pipe, Baker, 4-1/2", 11.6#, L-80, SLHT (1) Sliding Sleeve, Baker Model 4-112" 'CMD', wI 3.43" ID, 4-1/2", 11.6# SLHT Box x Pin (1) Joint 4-1/2" Blank Pipe, Baker, 4-1/2", 11.6#, L-80, SLHT (1) Crossover Sub w/4-1/2", 11.6#, SLHT Box x 4",9.5#, SLHT Pin ~, (1) Joint 4" Blank Pipe, 4", 9.5#, L-80, SLHT. (x) joints Screen, 4" x 4-1/2" Baker Excluder 2000,4",9.5#, SLHT alternating every other joint through the production zone with (x) joints 4" Blank Pipe, 4", 9.5#, L-80, SLHT as required from 'GPV' Set Shoe Assembly to Model 'CMD' Sliding Sleeve. (2) Joints 4" Blank Pipe, 4", 9.5#, L-80, SLHT Blank Pipe. (1) Crossover Sub, Baker, 4",9.5#, SLHT Box x 5", 18#, SLHT Pin (1) Joint 5" Blank Pipe, 18.5' long, Baker, 5", 18#, L-80, SLHT, wI Drillable Packoff Bushing (1) Crossover Sub, Baker, 5",18#, SLHT Box x 3-1/2",9.2# SLHT Pin (1) Joint 3-1/2" Bent Pipe, Baker, 3-1/2", 9.2#, L-80, SLHT, Length 18.5'. (1) Set Shoe, 3-1/2", Baker Model'GPV', (4.50" Max OD), 3-1/2", 9.2#, SLHT Box. 1------------- I I------------~ 'r~' =~~~~~~=~=~~=~= ~~~~~~~~~~~~~ r ) Surface I Production Casing 7-5/8" 29.7# L-80 BTC Mod Set@ 7,231' MD 13,740' TVD 6" Open Hole TD: 11,910' MD 13,631' TVD See Sheet 2 for Lower Lateral Liner Details III~=~~=~~=~=~=~=~=~=~*;= 18 - x 4- op, , ! , I ' . . . . ' . ~ ¡ ...- ~ I I .. ... Tree Assembly, Vetco Gray Gen II, API 13-5 5000 psi Flange Down 1/16" 5000 Studded T with Penetrators Tubing Head Assembly Vetco Gray 16" Conductor: +/- 15S' MD Port Collar: +/- 1000' MD / 96S' TVD Top of Window: +/- 6,740' MD /3,661' TVD Top of Lower Lateral Liner: +/- 7,000' MD /3,724' TVD 9-7/S" Hole TD, 7-5/S" Shoe: +/- 7,231' MD / 3,740' TVD l I I ~ ~ ~ ~ I ~ I I ~ ~ ~ I ~ I ~ ~ I I ~ ~ ~ I I ~ I I I I ~ ~ ~ I I I I I I I I I I I I I, I ~ I I I ~ I I I I I I ¡ ti ,~~~~~ .. ?~:+~'«~w~ æ I ! ! 4 ~ I I I I I ~ I I ~ ~ I ~ I I I ~ ~ ~ ~ ~ s I I I ~ ~ I I I ~ ( Nabors Rig 245 RKB @ O' Eastings: 561,631.04 Northings: 5,968,796.65 Elevation: 101.8' AMSL Tubing Hanger, 4-1/2", Vetco Gray wI 4.909" MCA Top Connection, 4-1/2" L-80 NSCT Pup Joint Down ESP Power Cable Penetrator (497-6860) Heat Trace Penetrator (497-9275) (1) Joint Tubing I I I .. (x) Pup Joints Tubing, as required to spaceout heat trace. Connector, Field Attachable, Power Cable (497-6850) Connector, Field Attachable, Heat Trace (497 9270) Power Cable, Centrilift, #4 AWG Double Armor (497-6605) Heat Trace, Raychem, Surface to +1- 3,000' MD. (497-6615) (x) Joints Tubing (1) Gas Lift Mandrel, CAMCO 4-1/2" x 1" Model KBG-2 (481-9620), with dummy valve installed. 4- 1/2" IBT Pin x Pin, with 6 foot 4-1/2" XO Pups, top and bottom. Tubing String: 4-1/2", 12.6#, L-80, NSCT (3) Joints Tubing (1) Sub, Phoenix Discharge Temperature and Pressure (1) Pup JoilïfTubi n9; .1 Oft length (1) Through. :n.lþil1gConvëy~dt::lectric SUbrnersiblePtJrnP (TTCESP) A!;.$ëmbly,Centrilift,consi~ting of: (1 ) Slotted Nipple;Centrilift,4;; 1/2" (1rCröššöv~r,Centrilifti .4-1/2",T'TC (1) Tfihdel11 SêalqeCtior(Çêntrilift ModelGST3 DBHL PFS (497~651 0) (1)ESP Assembly;C$htrilif;tModêI21 FCNPSH /140FC2700 (conveyed thr()ugh. ~ut>ihg) (497'-651~) (1) Mötor; Centfilift,190HP KMH2415/48 (497-6505) (1 )(3aÜg~, Phöehix, Model, MS-1. Gauge (497-6500) (1)C~ntralizer. fv1()tpr,CentrUift,6.25" OD to be spaced out +1- 60' MD âboVè Hook Hanger (497-6550) ==~=~~=~=~~=~~~=~~= I I~~~~~~~~~~~~~ ) D-Sand Lateral 6" Open Hole TD: +/- 11,910' MD / 3,631' TVD ~~."tir~~' '.,~ :'õ' - - - ------ -- -- --- -- ------ -- -=- -=- -=- -=- -=- -=- -=- -=- -=- -=- -=--:. 0>"'. ';"7~'~ \ ) ~,;:,..:~Ifi-_-_-_-------------------- -=--=--=--=--=--=--=--=--=--=--=--:. ~ ) ~~!~; èt.~ ~ II ~ ,,.t..~;~~;;.~'t I=-=~-=-=-=-=-=-=-=-=-=-=- =============~ <'~.~,.7'..~. "~~:~~\ ~~~ B-Sand Lateral 6-3/4" Open Hole TD: .,... 11,914' MD /3,687' TVD PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY I ~ West Sak WeIl1C-104, AFC AK xxxx Planned Completion Schematic Sheet 4 of 4: Tubing String Details prepared by Todd Mushovic J ':)/ j 'r/lT:.. .214:0; " f }~1a; 1 C Pad H2S levels ( Subject: 1 C Pad IDS levels Date: Mon, 11 Mar 2002 11:01 :54 -0900 From: "Todd J Mushovic" <tmushov@ppco.com> To: <bob - crandall@admin.state.ak.us> CC: "Mavriky Kalugin" <mkalugi@ppco.com>, "Sharon Allsup-Drake" <sallsup@ppco.com> Mr. Crandall, My apologies for the wait in getting this information to you. I was unable to find any West Sak H2S levels on 1C. However, offset 1D pad has 22 wells and only 3 have minimum amounts of H2S - 1D-127 @ 2 ppm, 1D-126 @ 1 ppm, and 1D-121 @ 1 ppm. The remaining 19 wells have 0 ppm H28. As we obtain H2S samples on 1C West Sak wells I will pass them along to you. Please let me know if there is anything else that you need. Todd J. Mushovic Drilling Engineer Phillips Alaska Inc. (907) 265-6974 - office (907) 240-5740 - cellular tmushov@ppco.com I~I 3/1112002 11 :22 AM PHILI..IPSAlASKAINC. ALPINE DISBURSEMENT ACCOÚNT P.O. Box 1 03240 A''lchorage,>AK9~510--3240 PAY STATE OF ALASKA TO THE AOGCC ORDER OF: 333W.7TH AVENUE/SUITE 100 ~... ..- SANK=ONE. - BANK ONE, NA - 0710 Chicago, I L Payable <through RèpublîcBank & Tr'ustCömpany TRACE NUMBER: EXACTLY.. **********100 DOLLARSANDOOCENTSi$********100.()() .. Q~..............................................>~............................................~................. :...~..............................................." IX... .... C { ~>-(D4 1112lt11D.5 2.21.111 I:OaaHOI....2b21: ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 STANDARD LETTER DEVELOPMENT v DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL WELL NAME ¡ff4 / L - /6 7' CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) PILOT HOLE (PH) ANNULAR DISPOSAL . L.J NO ANNULAR DISPOSAL c¡6YES ANNULAR DISPOSAL THIS WELL ~ ~ (DISPOSAL INTO OTHE~ ~ ANNULUS - - , ~ - . . L-J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates "CLUE" The permit is for a new wellbore segment of existing weD ----' Permit No, . API No. ~ Production should continue to be reported as a function of the original API number stated above. . In accordance with ~O AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly . differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . Please note that an disposal of fluids generated... . Enclosed is the approved application for permit to drill tbe above referenced well. The permit is approved.sùbject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuan.ce of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY fi 1/05 WELL NAME I(~I''¡ / C. - /0 '-I FIELD&POOL 9?O/$'d INITCLASS /)~ I-ò;/ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . Am ~'Y.TE 12. Permit can be issued without administrative approval.. . . . . ,~ ;W7ð.Z.- 13. Can permit be approved before 15-daywait.. . . . . . . . . . ENGINEERING 14. Conductor string provided . ~. . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USOWs. . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to ~ 000 psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28.~ Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . AWß ...o~!~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . ~~ ~ Y'~~ 34. Contact name/phone for weekly progress reports [exploratory 0 ANNULAR DISPOSAL 35. 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 (0) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: Rr;ð¿: TE~"{\~ COT SFD- WGA ~k DTS D-:\jJq.(O 2- JMH APP~ DATE ""6,,,,,\ "5 ( 12.[ 0 L !Æ~.~/rs.;o< GEOLOGY APPR DATE G:\geology\templates\checklist.doc R"N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ~N .. N )it.'@ilP.{¡TVÞ, N . +- - N Ææ~tuvU eiLøc; So ¥-N- At/A ¥:-N S cy.u-",- S2 N . . fi) N¡J~boy(, 2-45' E '¥::-tt ¡..1IA I, ~ PI S P -= I 30q r; / ~~.. Y(1V Y N Y PROGRAM: Exp - Dev X Redrll - Serv - Wellbore seg - Ann. disposal para req - GEOL AREA &' J' ~ UNIT# / ) / 6 ~ ON/OFF SHORE nA..J þ~ Ct;7 þs t :: 3000 f fA:. N /I./{;4 ~ N 1 Y N Y N 11ì- I I.. . Y N O~ ~u'ktv' dA Sf IOsev( , T\-... \. <=-:. ~ ~ <L\'\ v..~\\ \ "-f'\.\- ~c \..,-\(2- CJ..."- ~"'~ \~~. /' Comments/Instructions: / /, J r ~~ ,v....-c~ ~/J ~c..-~..;I1~ ~~ -t"~ðð~ 0'7 /~ c- 9~A---~~ /e,r~/Y¡¿; fir //4 -#0 0/ ~ ~$/Z7 ~~ Well History File APPENDIX Information of detailed nature that is not particularty germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Sep 12 10:46:49 2002 Reel Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/09/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.......... ... ...UNKNOWN Continuation Number.. ....01 Previous Reel Name.. .... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Tape Header Service name...... ... ... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/09/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........... .... . UNKNOWN Continuation Number. ... ..01 Previous Tape Name. ... ...UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: MWD RUN 5 AK-MW-22102 P. SMITH F. HERBERT MWD RUN 8 AK-MW-22102 J. PITCHER D. WESTER MSL 0) Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services lC-104 500292307600 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services ll-SEP-02 MWD RUN 6 AK-MW-22102 P. SMITH D. WESTER MWD RUN 7 AK-MW-22102 J. PITCHER D. WESTER 12 llN 10E 1437 625 101.85 60.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 161.0 6.750 7.625 7395.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE ~Od.-00J (1035 ( NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-4 WERE DIRECTIONAL ONLY AND ARE NOT PRESENTED. MWD RUN 7 WAS TIME-DRILLED (WITHIN THE 1C-104PB1 WELLBORE) FROM 8830'MD/3713' TVD TO 8864'MD/3711'TVD TO EFFECT THE OPEN-HOLE SIDETRACK. ONLY THE ROP FROM RUN 7 IS PRESENTED - THE OTHER CURVES WERE ACQUIRED WHILST RIH FOR MWD RUN 8. 4. MWD RUNS 5, 6, AND 8 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, INC., DATED 8/21/02. THIS E-MAIL QUOTES AUTHORIZATION OF THE PAl GEOSCIENCE GROUP. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 5, 6, and 8 REPRESENT WELL 1C-104 WITH API#: 50-029-23076-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11561'MD/3688'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 (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name......... ... .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..02/09/12 Maximum Physical Record..65535 File Type............... .LO Previous File Name... ... .STSLIB.OOO Conunent Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE ROP FET RPD RPM RPS RPX GR $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2375.5 2375.5 2375.5 2375.5 2375.5 2375.5 2384.0 STOP DEPTH 11561.0 11513.5 11513.5 11513.5 11513.5 11513.5 11506.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- ( BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 5 6 7 8 MERGE TOP 2375.5 7400.0 8831.5 8864.5 MERGE BASE 7400.0 8831.0 8864.5 11561.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type........ ... ..... ..0 Data Specification Block Type... ..0 Logging Direction.. .............. . Down Optical log depth units... .....,. .Feet Data Reference Point....... ... ... .Undefined Frame Spacing.............. ...... .60 .1IN Max frames per record... ......... .Undefined Absent value........ ....... ..... ..-999 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 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 2375.5 11561 6968.25 18372 2375.5 11561 ROP MWD FT/H 0.16 1548.67 256.202 18372 2375.5 11561 GR MWD API 8.04 127.55 65.3305 18246 2384 11506.5 RPX MWD OHMM 0.51 2000 25.5849 18277 2375.5 11513.5 RPS MWD OHMM 0.61 2000 36.2929 18277 2375.5 11513.5 RPM MWD OHMM 0.06 2000 38.917 18277 2375.5 11513.5 RPD MWD OHMM 0.06 2000 42.5183 18277 2375.5 11513.5 FET MWD HOUR 0.06 104.57 1.19155 18277 2375.5 11513.5 First Reading For Entire File. ..... ....2375.5 Last Reading For Entire File...... .... .11561 File Trailer Service name........ ... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ..... .02/09/12 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. .... ..02/09/12 Maximum Physical Record. .65535 File Type.. .... ... ...... .LO Previous File Name...... .STSLIB.001 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 ROP FET GR $ 2 ( header data for each bit run in separate files. 5 .5000 START DEPTH 2375.5 2375.5 2375.5 2375.5 2375.5 2375.5 2384.0 STOP DEPTH 7356.0 7356.0 7356.0 7356.0 7400.0 7356.0 7363.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....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 30-JUN-02 Insite 66.37 Memory 7400.0 2375.0 7400.0 61.2 84.1 TOOL NUMBER PB00242HGR6 PB00242HGR6 9.875 LSND 9.40 75.0 9.3 100 4.6 4.500 3.070 4.750 4.000 75.0 113.0 75.0 75.0 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 MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2375.5 7400 4887.75 10050 2375.5 7400 ROP MWD050 FT/H 0.47 1432.76 231.2 10050 2375.5 7400 GR MWD050 API 8.04 127.55 68.8574 9959 2384 7363 RPX MWD050 OHMM 1. 82 172.56 16.2985 9962 2375.5 7356 RPS MWD050 OHMM 1. 52 172.74 17 . 0124 9962 2375.5 7356 RPM MWD050 OHMM 1. 34 160.31 17 .222 9962 2375.5 7356 RPD MWD050 OHMM 1. 95 432.24 20.2635 9962 2375.5 7356 FET MWD050 HOUR 0.09 11.8 0.715966 9962 2375.5 7356 First Reading For Entire File.. ..... ...2375.5 Last Reading For Entire File... ..... ...7400 File Trailer Service name........ ... ..STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .02/09/12 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...... .02/09/12 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 FET RPD RPM RPS RPX GR ROP $ 3 header data for each bit run in separate files. 6 .5000 START DEPTH 7356.5 7356.5 7356.5 7356.5 7356.5 7363.5 7400.5 STOP DEPTH 8830.0 8830.0 8830.0 8830.0 8830.0 8830.0 8831.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE 05-JUL-02 VERSION: Insite 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 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. ...... ...........0 Data Specification Block Type... ..0 Logging Direction.. ........ .... ...Down Optical log depth units... ..... ...Feet Data Reference Point. ... ....... ...Undefined Frame Spacing..................... 60 .lIN Max frames per record.. .,.. ..... ..Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O 66.37 Memory 9331.0 7400.0 8830.0 84.4 94.8 TOOL NUMBER PB00237HAGR4 PB00237HAGR4 6.750 BARADRIL-N 9.00 44.0 9.1 21000 4.5 .200 .150 .180 .230 72.0 95.0 72.0 73.0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7356.5 8831 8093.75 2950 7356.5 8831 ROP MWD060 FT/H 0.46 446.77 182.686 2862 7400.5 8831 GR MWD060 API 27.74 83.17 60.264 2934 7363.5 8830 RPX MWD060 OHMM 0.51 1863.06 31. 2043 2948 7356.5 8830 RPS MWD060 OHMM 0.61 2000 52.3324 2948 7356.5 8830 RPM MWD060 OHMM 0.06 2000 77.3829 2948 7356.5 8830 RPD MWD060 OHMM FET MWD060 HOUR 0.06 0.23 2000 104.57 First Reading For Entire File......... .7356.5 Last Reading For Entire File.......... .8831 File Trailer Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation.... ...02/09/12 Maximum Physical Record. .65535 File Type................ LO Next File Name..... ......STSLIB.004 Physical EOF File Header Service name..... ...... ..STSLIB.004 Service Sub Level Name... Version Number. ..... ..., .1.0.0 Date of Generation...... .02/09/12 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 4 77.5261 2948 4.02432 2948 7356.5 7356.5 8830 8830 header data for each bit run in separate files. 7 .5000 START DEPTH 8831.5 STOP DEPTH 8864.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # 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: 05-JUL-02 Insite 66.37 Memory 8864.0 8830.0 8864.0 .0 .0 TOOL NUMBER 6.750 BARADRIL-N 9.00 44.0 9.1 21000 5.0 .200 .150 .180 72 .0 95.0 72.0 MUD CAKE AT MT: .230 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. """" ........0 Data Specification Block Type.....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 MWD070 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD070 FT/H Min 8831.5 0.16 Max 8864.5 79.77 Mean Nsam 8848 67 35.8622 67 First Reading For Entire File..... .... .8831.5 Last Reading For Entire File.......... .8864.5 File Trailer Service name....... .... ..STSLIB.004 Service Sub Level Name... Version Number.... ... ... .1.0.0 Date of Generation...... .02/09/12 Maximum Physical Record..65535 File Type................ LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name..... '" .... .STSLIB.005 Service Sub Level Name... Version Number..... ... ...1.0.0 Date of Generation... ... .02/09/12 Maximum Physical Record. .65535 File Type................ LO Previous File Name.. .....STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL RPD RPM RPS 5 header data for each bit run in separate files. 8 .5000 CODE START DEPTH 8830.5 8830.5 8830.5 STOP DEPTH 11513.5 11513.5 11513.5 ( 73.0 First Reading 8831.5 8831. 5 Last Reading 8864.5 8864.5 RPX GR FET ROP $ 8830.5 8830.5 8830.5 8865.0 11513.5 11506.5 11513.5 11561. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO 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 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ... ........ ....0 Data Specification Block Type.....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. ..0 07-JUL-02 Insite 66.37 Memory 11560.0 8864.0 11560.0 88.0 92.8 TOOL NUMBER PB00237HAGR4 PB00237HAGR4 6.750 BARADRIL-N 9.00 43.0 8.2 21000 4.0 .220 .170 .210 .480 75.0 98.6 72 .0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 ( First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8830.5 11561 10195.8 5462 8830.5 11561 ROP MWD080 FT/H 0.9 1548.67 344.544 5393 8865 11561 GR MWD080 API 36.94 95.76 61.5459 5353 8830.5 11506.5 RPX MWD080 OHMM 8.33 2000 39.7353 5367 8830.5 11513.5 RPS MWDO 8 0 OHMM 20.6 2000 63.2702 5367 8830.5 11513.5 RPM MWD080 OHMM 21. 55 2000 58.0576 5367 8830.5 11513.5 RPD MWDO 8 0 OHMM 15.43 2000 64.5976 5367 8830.5 11513.5 FET MWD080 HOUR 0.06 31.11 0.518308 5367 8830.5 11513.5 First Reading For Entire File. ........ .8830.5 Last Reading For Entire File. ......... .11561 File Trailer Service name....... ..... .STSLIB.005 Service Sub Level Name... Version Number...... ... ..1.0.0 Date of Generation. ..... .02/09/12 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name. ... .... ... ..LISTPE Date.................... .02/09/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name..... .......... . UNKNOWN Continuation Number.... ..01 Next Tape Name. ......... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name....... ..... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/09/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name... ............ . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Sep 12 10:57:03 2002 Reel Header Service name. "'" ... ....LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/09/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.. """'" .... . UNKNOWN Continuation Number.... ..01 Previous Reel Name.. .... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Tape Header Service name. ..., """ ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/09/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name... "'" ""'" . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MW-22102 P. SMITH F. HERBERT # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services 1C-104 PB1 500292307670 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 09-SEP-02 MWD RUN 6 AK-MW-22102 P. SMITH D. WESTER 12 llN 10E 1437 625 101.85 60.60 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 161.0 6.750 7.625 7395.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-4 WERE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 8Dd-Olo) 1/ D3tp 4. MWD RUNS 5 AND 6 WERE DIRECTIONAL WITH DUAL RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). GAMMA 5. THE LOWER PORTION OF THIS WELLBORE WAS ABANDONED AND AN OPEN-HOLE SIDETRACK EFFECTED AT ABOUT 8864'MD/3711'TVD. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, INC., DATED 8/21/02. THIS E-MAIL QUOTES AUTHORIZATION OF THE PAl GEOSCIENCE GROUP. MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 5 & 6 REPRESENT WELL 1C-104 PB1 WITH API#: 50-029-23076-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9330'MD/3706'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 (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name.... ........ .STSLIB.001 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .02/09/12 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.OOO Cormnent Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE ROP FET RPD RPM RPS RPX GR $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2375.5 2375.5 2375.5 2375.5 2375.5 2375.5 2384.0 STOP DEPTH 9330.5 9284.0 9284.0 9284.0 9284.0 9284.0 9277.0 # 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 MERGE TOP 5 2375.5 6 7400.0 MERGE BASE 7400.0 9330.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.. ... ..... ........0 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 2375.5 9330.5 5853 13911 2375.5 9330.5 ROP MWD FT/H 0.46 1432.76 221.041 13911 2375.5 9330.5 GR MWD API 8.04 127.55 68.0516 13787 2384 9277 RPX MWD OHMM 0.51 1863.06 19.7656 13818 2375.5 9284 RPS MWD OHMM 0.61 2000 25.4735 13818 2375.5 9284 RPM MWD OHMM 0.06 2000 31.1973 13818 2375.5 9284 RPD MWD OHMM 0.06 2000 35.0207 13818 2375.5 9284 FET MWD HOUR 0.09 104.57 1.40832 13818 2375.5 9284 First Reading For Entire File....... ...2375.5 Last Reading For Entire File........ ...9330.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..02/09/12 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..... ..02/09/12 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX 2 header data for each bit run in separate files. 5 .5000 START DEPTH 2375.5 STOP DEPTH 7356.0 FET RPD RPS ROP RPM GR $ 2375.5 2375.5 2375.5 2375.5 2375.5 2384.0 7356.0 7356.0 7356.0 7400.0 7356.0 7363.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ..... .... ... ..0 Data Specification Block Type.....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 30-JUN-02 Insite 66.37 Memory 7400.0 2375.0 7400.0 61. 2 84.1 TOOL NUMBER PB00242HGR6 PB00242HGR6 9.870 161.0 LSND 9.40 75.0 9.3 100 4.6 4.500 3.070 4.750 4.000 75.0 113.0 75.0 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 (' FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2375.5 7400 4887.75 10050 2375.5 7400 ROP MWD050 FT/H 0.47 1432.76 231.112 10050 2375.5 7400 GR MWD050 API 8.04 127.55 68.8574 9959 2384 7363 RPX MWD050 OHMM 1. 82 172.56 16.2985 9962 2375.5 7356 RPS MWDO 5 0 OHMM 1. 52 172.74 17 . 0124 9962 2375.5 7356 RPM MWD050 OHMM 1. 34 160.31 17 .222 9962 2375.5 7356 RPD MWD050 OHMM 1. 95 432.24 20.2635 9962 2375.5 7356 FET MWD050 HOUR 0.09 11. 8 0.715966 9962 2375.5 7356 First Reading For Entire File........ ..2375.5 Last Reading For Entire File.......... .7400 File Trailer Service name... ... ...... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .02/09/12 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. ..... .02/09/12 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. 6 .5000 START DEPTH 7356.5 7356.5 7356.5 7356.5 7356.5 7363.5 7400.5 STOP DEPTH 9284.0 9284.0 9284.0 9284.0 9284.0 9277 . 0 9330.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 05-JUL-02 Insite 66.37 Memory 9331.0 7400.0 9331.0 84.4 94.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RES IS. 4 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............ ......0 Data Specification Block Type. ....0 Logging Direction.... """" ... ..Down Optical log depth units..... ..... .Feet Data Reference Point.. .... .... ....Undefined Frame Spacing....... """'" .... .60 .1IN Max frames per record....... .... ..Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O TOOL NUMBER PB00237HAGR4 PB00237HAGR4 6.750 . 7395.0 BARADRIL-N 9.00 44.0 9.1 21000 4.5 .200 .150 .180 .230 72.0 95.0 72.0 73.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7356.5 9330.5 8343.5 3949 7356.5 9330.5 ROP MWD060 FT/H 0.46 498.61 194.828 3861 7400.5 9330.5 GR MWD060 API 27.74 121 65.9554 3828 7363.5 9277 RPX MWD060 OHMM 0.51 1863.06 28.7229 3856 7356.5 9284 RPS MWD060 OHMM 0.61 2000 47.333 3856 7356.5 9284 RPM MWD060 OHMM 0.06 2000 67.3026 3856 7356.5 9284 RPD MWD060 OHMM 0.06 2000 73.146 3856 7356.5 9284 FET MWD060 HOUR 0.23 104.57 3.19702 3856 7356.5 9284 First Reading For Entire File. "'" ....7356.5 Last Reading For Entire File...... .... .9330.5 File Trailer Service name........ "" .STSLIB.003 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation... ....02/09/12 Maximum Physical Record. .65535 File Type................ LO Next File Name.. """" .STSLIB.004 Physical EOF Tape Trailer Service name....... "'" .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/09/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.. """ """ ..UNKNOWN Continuation Number..... .01 Next Tape Name.... ...... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Reel Trailer Service name..... ... "" .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/09/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name... ....... ...., . UNKNOWN Continuation Number......Ol Next Reel Name..... ..... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File Scientific Technical Services Scientific Technical Services
